<PAGE>
AS FILED WITH THE SECURITIES AND EXCHANGE COMMISSION ON OCTOBER 2, 1996
REGISTRATION NO. 333-08913
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
--------------------------
AMENDMENT NO. 3
TO
FORM S-1
REGISTRATION STATEMENT
UNDER
THE SECURITIES ACT OF 1933
------------------------
COSTILLA ENERGY, INC.
(Exact name of Registrant as specified in its charter)
<TABLE>
<S> <C> <C>
DELAWARE 1311 75-2658940
(State or other jurisdiction of (Primary Standard Industrial (I.R.S. Employer
incorporation or organization) Classification Code Number) Identification No.)
</TABLE>
--------------------------
400 WEST ILLINOIS, SUITE 1000
MIDLAND, TEXAS 79701
(915) 683-3092
(Address, including zip code, and telephone number,
including area code, of Registrant's principal executive offices)
MICHAEL J. GRELLA, PRESIDENT
COSTILLA ENERGY, INC.
400 WEST ILLINOIS, SUITE 1000
MIDLAND, TEXAS 79701
(915) 683-3092
(Name, address, including zip code, and telephone number,
including area code, of agent for service)
--------------------------
COPIES TO:
<TABLE>
<S> <C>
Richard T. McMillan R. Joel Swanson
Cotton, Bledsoe, Tighe & Dawson, Baker & Botts, L.L.P.
a Professional Corporation 910 Louisiana
500 West Illinois Houston, Texas 77002
Suite 300
Midland, Texas 79701
</TABLE>
--------------------------
APPROXIMATE DATE OF COMMENCEMENT OF PROPOSED SALE TO THE PUBLIC: As soon as
practicable after this Registration Statement becomes effective.
If any of the securities being registered on this Form are to be offered on
a delayed or continuous basis pursuant to Rule 415 under the Securities Act of
1933, check the following box: / /
If this Form is filed to register additional securities for an offering
pursuant to Rule 462(b) under the Securities Act, please check the following box
and list the Securities Act registration statement number of the earlier
effective registration statement for the same offering. / /
If this Form is a post-effective amendment filed pursuant to Rule 462(c)
under the Securities Act, check the following box and list the Securities Act
registration statement number of the earlier effective registration statement
for the same offering. / /
If delivery of the Prospectus is expected to be made pursuant to Rule 434,
please check the following box. / /
--------------------------
THE REGISTRANT HEREBY AMENDS THIS REGISTRATION STATEMENT ON SUCH DATE OR
DATES AS MAY BE NECESSARY TO DELAY ITS EFFECTIVE DATE UNTIL THE REGISTRANT SHALL
FILE A FURTHER AMENDMENT WHICH SPECIFICALLY STATES THAT THIS REGISTRATION
STATEMENT SHALL THEREAFTER BECOME EFFECTIVE IN ACCORDANCE WITH SECTION 8(A) OF
THE SECURITIES ACT OF 1933 OR UNTIL THE REGISTRATION STATEMENT SHALL BECOME
EFFECTIVE ON SUCH DATE AS THE COMMISSION, ACTING PURSUANT TO SAID SECTION 8(A),
MAY DETERMINE.
- --------------------------------------------------------------------------------
- --------------------------------------------------------------------------------
<PAGE>
INFORMATION CONTAINED HEREIN IS SUBJECT TO COMPLETION OR AMENDMENT. A
REGISTRATION STATEMENT RELATING TO THESE SECURITIES HAS BEEN FILED WITH THE
SECURITIES AND EXCHANGE COMMISSION. THESE SECURITIES MAY NOT BE SOLD NOR ANY
OFFERS TO BUY BE ACCEPTED PRIOR TO THE TIME THE REGISTRATION STATEMENT BECOMES
EFFECTIVE. THIS PROSPECTUS SHALL NOT CONSTITUTE AN OFFER TO SELL OR THE
SOLICITATION OF ANY OFFER TO BUY NOR SHALL THERE BE ANY SALE OF THESE SECURITIES
IN ANY STATE IN WHICH SUCH OFFER, SOLICITATION OR SALE WOULD BE UNLAWFUL PRIOR
TO REGISTRATION OR QUALIFICATION UNDER THE SECURITIES LAWS OF ANY SUCH STATE.
<PAGE>
SUBJECT TO COMPLETION--DATED OCTOBER 2, 1996
PROSPECTUS
- --------------------------------------------------------------------------------
4,000,000 Shares
[LOGO] COSTILLA ENERGY, INC.
Common Stock
- -------------------------------------------------------------------------
All of the shares of the Common Stock, $0.10 par value (the "Common Stock"),
offered hereby (the "Common Stock Offering") are being sold by Costilla Energy,
Inc., a Delaware corporation ("Costilla" or the "Company").
Concurrent with the Common Stock Offering, the Company is offering $100,000,000
of % Senior Notes due 2006 (the "Notes") for sale to the public (the "Notes
Offering," and together with the Common Stock Offering, the "Offerings")
pursuant to an underwritten public offering. The Notes Offering and the Common
Stock Offering are each conditioned on the consummation of the other.
Prior to this Common Stock Offering, there has been no public market for the
Common Stock of the Company. It is currently anticipated that the initial public
offering price will be between $14.00 and $16.00 per share. See "Underwriting"
for a discussion of the factors to be considered in determining the initial
public offering price. The Company has applied for inclusion of the Common Stock
in The Nasdaq Stock Market's National Market (the "Nasdaq National Market")
under the trading symbol "COSE."
SEE "RISK FACTORS" ON PAGES 8 TO 12 FOR A DISCUSSION OF MATERIAL FACTORS THAT
SHOULD BE CONSIDERED IN CONNECTION WITH AN INVESTMENT IN THE COMMON STOCK
OFFERED HEREBY.
- --------------------------------------------------------------------------------
THESE SECURITIES HAVE NOT BEEN APPROVED OR DISAPPROVED BY THE SECURITIES AND
EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION NOR HAS THE
SECURITIES AND EXCHANGE COMMISSION OR ANY STATE SECURITIES COMMISSION
PASSED UPON THE ACCURACY OR ADEQUACY OF THIS PROSPECTUS. ANY
REPRESENTATION TO THE CONTRARY IS A CRIMINAL OFFENSE.
<TABLE>
<CAPTION>
Underwriting
Price to Discounts and Proceeds to
Public Commissions (1) Company (2)
<S> <C> <C> <C>
Per Share..................................... $ $ $
Total (3)..................................... $ $ $
</TABLE>
(1) The Company has agreed to indemnify the several Underwriters against certain
liabilities, including liabilities under the Securities Act of 1933. See
"Underwriting."
(2) Before deducting expenses payable by the Company estimated to be $500,000.
(3) The Company has granted the several Underwriters a 30-day over-allotment
option to purchase up to 600,000 additional shares of Common Stock on the
same terms and conditions as set forth above. If all such additional shares
are purchased by the Underwriters, the total Price to Public will be
$ , the total Underwriting Discounts and Commissions will be $ and
the total Proceeds to Company will be $ . See "Underwriting."
- --------------------------------------------------------------------------------
The shares of Common Stock are offered by the several Underwriters subject to
delivery by the Company and acceptance by the Underwriters, to prior sale and to
withdrawal, cancellation or modification of the offer without notice. Delivery
of the shares to the Underwriters is expected to be made at the office of
Prudential Securities Incorporated, One New York Plaza, New York, New York, on
or about , 1996.
PRUDENTIAL SECURITIES INCORPORATED RAUSCHER PIERCE REFSNES, INC.
October , 1996
<PAGE>
PRIMARY OPERATING AREAS
[A GEOGRAPHIC MAP INDICATING WHERE THE COMPANY HAS
OIL AND GAS PROPERTIES AND OFFICES]
------------------------
IN CONNECTION WITH THIS COMMON STOCK OFFERING, THE UNDERWRITERS MAY
OVER-ALLOT OR EFFECT TRANSACTIONS WHICH STABILIZE OR MAINTAIN THE MARKET PRICE
OF THE COMMON STOCK OFFERED HEREBY AT A LEVEL ABOVE THAT WHICH MIGHT OTHERWISE
PREVAIL IN THE OPEN MARKET. SUCH STABILIZATION, IF COMMENCED, MAY BE
DISCONTINUED AT ANY TIME.
2
<PAGE>
PROSPECTUS SUMMARY
THE FOLLOWING SUMMARY IS QUALIFIED IN ITS ENTIRETY BY THE DETAILED
INFORMATION, FINANCIAL STATEMENTS AND OTHER DATA APPEARING ELSEWHERE IN THIS
PROSPECTUS. THE PRO FORMA INFORMATION GIVES EFFECT TO THE CONVERSION OF COSTILLA
FROM A LIMITED LIABILITY COMPANY TO A CORPORATION, CERTAIN MATERIAL ACQUISITIONS
AND THE OFFERINGS AND THE APPLICATION OF THE ESTIMATED NET PROCEEDS THEREFROM.
SEE "-- SIGNIFICANT ACQUISITIONS," "THE COMPANY -- CORPORATE REORGANIZATION,"
AND "USE OF PROCEEDS." AS USED HEREIN, REFERENCES TO THE COMPANY OR TO COSTILLA
ARE TO COSTILLA ENERGY, INC. AND ITS SUBSIDIARIES. UNLESS OTHERWISE INDICATED,
THE INFORMATION IN THIS PROSPECTUS ASSUMES THE UNDERWRITERS' OVER-ALLOTMENT
OPTION WILL NOT BE EXERCISED. CERTAIN OIL AND GAS TERMS USED IN THIS PROSPECTUS
ARE DEFINED IN THE "GLOSSARY" INCLUDED HEREIN. "ADJUSTED EBITDA," AS USED
HEREIN, MEANS NET INCOME (LOSS), PLUS INTEREST, INCOME TAXES, DEPRECIATION,
DEPLETION AND AMORTIZATION, EXPLORATION AND ABANDONMENT COSTS AND EXTRAORDINARY
LOSS RESULTING FROM EXTINGUISHMENT OF DEBT.
THE COMPANY
Costilla is an independent energy company engaged in the exploration,
acquisition and development of oil and gas properties. The Company's primary
operations are in the Permian Basin area of Texas and New Mexico, the Gulf Coast
and the Rocky Mountain regions. The Company's strategy focuses on increasing
reserves through a targeted exploration program, the exploitation of its
existing properties and selective property acquisitions. In addition, the
Company recently acquired an interest in an entity which has a concession for
the development of mineral interests in the Republic of Moldova, in Eastern
Europe. The Company also has minor interests in the domestic gas gathering and
transmission business.
The Company's predecessor began operating in 1988 with the strategy of
acquiring and exploiting undervalued oil and gas properties, and at December 31,
1992 had net proved reserves of 4.7 MMBOE. Since January 1, 1993, the Company
has successfully closed seven transactions for an aggregate purchase price of
approximately $101 million. As of April 1, 1996, the Company had total estimated
net proved reserves of 16.5 Mmbbls of oil and 112.9 Bcf of gas, aggregating 35.3
MMBOE, with a PV-10 Value of approximately $179.5 million, assuming the 1996
Acquisition (as defined below) had occurred at April 1, 1996. The Company also
has a substantial undeveloped acreage position consisting of 180,704 gross
(165,166 net) acres at June 30, 1996. The Company has identified in excess of
185 drilling locations of which 64 are included in its proved reserves.
Costilla has in-house exploration expertise which uses 3-D seismic
technology as a primary tool to identify drilling opportunities and has
experienced high rates of success in each of its first two major 3-D seismic
drilling programs. Since 1994, the Company has drilled 37 wells based on these
3-D surveys, 31 of which have been productive. The Company has recently
completed two additional 3-D surveys and intends to commence drilling on one of
these acreage blocks in the second half of 1996. The Company currently plans to
drill 63 wells through 1997 based on its 3-D surveys.
Since 1993, Costilla has generated significant growth in reserves,
production and Adjusted EBITDA. The Company increased its estimated proved
reserves from 6.0 MMBOE at December 31, 1993 to 35.3 MMBOE at April 1, 1996 (pro
forma for the 1996 Acquisition), representing a compound annual growth rate of
114%. This reserve growth has been achieved at an average all-in finding cost of
$3.60 per BOE over such period, a level which the Company believes is lower than
industry averages. Concurrently, the Company increased its average net daily
production from 827 BOE for the year ended December 31, 1993 to 10,231 BOE for
the three months ended March 31, 1996 (pro forma for the 1996 Acquisition),
representing a compound annual growth rate of 190%. Adjusted EBITDA increased at
a 234% compound annual growth rate from $1.8 million for 1993 to $20.2 million
for 1995 (pro forma for the 1995 Acquisition and the 1996 Acquisition).
3
<PAGE>
BUSINESS STRATEGY
The Company's strategy is to increase its oil and gas reserves, production
and cash flow from operations through a two-pronged approach which combines an
active exploration program using 3-D seismic and other technological advances
with the acquisition and exploitation of producing properties. The Company seeks
to reduce its operating and commodity risks by holding a geographically diverse
portfolio of properties, the reserves attributable to which are approximately
balanced between oil and gas. The Company also seeks to manage the elements of
its business strategy through the operation of a significant portion of its
properties, the use of a rate of return analysis and the direct marketing and
hedging of its oil and gas production. The elements of the Company's strategy
may be further described as follows:
- EXPLORATION EFFORTS. The Company uses extensive geological and
geophysical analysis to carefully focus its 3-D seismic surveys. This
focus allows the Company to successfully direct the size and scope of its
exploration program in order to improve the likelihood of success while
managing overall exploration costs. The Company's exploration efforts are
concentrated currently on known producing regions. The Company plans to
drill 24 exploratory wells during the last half of 1996 and 36 exploratory
wells in 1997. Capital budgeted for exploration activities is $8.1 million
for the last six months of 1996 and $10.8 million for 1997.
- EXPLOITATION ACTIVITIES. The Company is actively pursuing numerous
exploitation opportunities within its existing properties, including areas
where no proved reserves are currently assigned. Exploitation activities
currently in progress include a carbon dioxide flood, recompletions,
workovers, infill and horizontal drilling and a secondary recovery
project. The Company's capital budget for such activities is $8.4 million
for the last six months of 1996 and $9.2 million for 1997, which includes
the drilling of 12 development wells in 1996 and 13 development wells in
1997.
- PROPERTY ACQUISITIONS. The Company seeks to acquire producing properties
where it has identified opportunities to increase production and reserves
through both exploitation and exploration activities. The Company has
increased the value of its acquisitions by aggressively managing the
operations of existing proved properties and by successfully identifying
and developing previously unproved reserves on acquired acreage. The
Company seeks to acquire reserves which will fit its existing portfolio,
are generally not being actively marketed and where a negotiated sale
would be the method of purchase. The Company does not rely on major oil
company divestitures or property auctions.
- PROPERTY DIVERSIFICATION. The Company holds a portfolio of oil and gas
properties located in the Permian Basin, the Gulf Coast and the Rocky
Mountain regions. The Company believes that by conducting its activities
in distinct regions it is able to reduce commodity price and other
operational risks. The Company's Moldovan interest is an extension of this
strategy and can be characterized by low initial costs, significant
reserve potential and the availability of technical data that may be
further developed by the Company.
- CONTROL OF OPERATIONS. The Company prefers to operate and own the
majority working interest in its properties. This allows the Company
greater control over future development, drilling, completing and lifting
costs and marketing of production. At April 1, 1996, the Company operated
wells constituting approximately 72% of its total PV-10 Value (pro forma
for the 1996 Acquisition).
SIGNIFICANT ACQUISITIONS
1995 ACQUISITION. In a $46.6 million acquisition completed in June 1995,
the Company acquired a group of oil and gas properties located in the Permian
Basin, Gulf Coast and Rocky Mountain regions. At the date of acquisition, the
net proved reserves included 7.1 Mmbbls of oil and 44.1 Bcf of gas, aggregating
14.4 MMBOE. From the date of acquisition until March 31, 1996, the Company
produced 1.5 MMBOE from the acquired properties and sold a portion of the
acquired properties for approximately $3.6 million. At April 1, 1996, the net
proved reserves of the remaining properties were 13.4 MMBOE. The acquired
properties also included 103,010 gross (93,787 net) undeveloped acres.
4
<PAGE>
1996 ACQUISITION. In June 1996, the Company acquired a group of oil and gas
properties located primarily in the Permian Basin and Gulf Coast regions for
approximately $42.5 million. This acquisition included properties with net
proved reserves at April 1, 1996 of 5.0 Mmbbls of oil and 33.5 Bcf of gas,
aggregating 10.6 MMBOE. The acquired properties also included 42,855 gross
(16,646 net) undeveloped acres and a pipeline located in Pennsylvania which had
an allocated purchase price of $3.5 million.
DRILLING ACTIVITIES
Exploration efforts since January 1, 1996 include the drilling of eight
wells located on the Company's Edwards/McElroy Ranch Prospect in the Permian
Basin. While one of such wells is being drilled, the remaining seven wells have
been completed as producers. Three of the productive wells have resulted in
separate field discoveries which have confirmed the Company's seismic
interpretation of a significant trend. Since beginning operations on this
prospect, the Company has drilled 11 producing wells and one dry hole. As a
result, the Company has identified up to 68 additional drilling locations, none
of which are included in the Company's proved reserves.
The Company has also continued drilling in the McGyver-Green Acres 3-D
Prospect. Since commencing activity in this prospect in July 1994, the Company
has drilled 17 wells, of which 14 have been successful. During June 1996, the
average daily capacity from the producing wells in this prospect was
approximately 83 BOE per well. The Company has identified 34 additional drilling
locations in the McGyver-Green Acres Prospect, nine of which are included in the
Company's proved reserves.
The Company has also drilled and completed seven development wells in the
Permian Basin and Gulf Coast regions since the beginning of 1996. Currently, the
Company's principal exploitation activities include a carbon dioxide flood in
the East Goldsmith Unit, infill drilling primarily in the Permian Basin and
horizontal drilling in the Susan Peak Field.
THE COMMON STOCK OFFERING
<TABLE>
<S> <C>
Common Stock Offered by the Company............ 4,000,000 Shares(1)
Common Stock to be Outstanding after the
Offering...................................... 10,000,000 Shares(1)
Concurrent Notes Offering...................... Concurrent with the Common Stock Offering,
the Company is offering $100,000,000 of
% Senior Notes due 2006. See "Notes
Offering." The Notes Offering and the
Common Stock Offering are each conditioned
upon the consummation of the other.
Use of Proceeds................................ To repay existing indebtedness, to pay
certain costs incurred in connection with
the Corporate Reorganization, and for
general corporate purposes. See "Use of
Proceeds."
Nasdaq National Market Symbol.................. COSE
</TABLE>
- ------------------------
(1) Excludes 1,000,000 shares of Common Stock reserved for issuance under the
Company's employee benefit plans. See "Executive Compensation and Other
Information."
RISK FACTORS
Investors should consider the material risk factors involved in connection
with an investment in the Common Stock, including the fact that investors will
experience immediate and substantial dilution in pro forma net tangible book
value per share of $11.86 (assuming an initial public offering price of $15.00
per share, the midpoint of the price range set forth on the cover of this
Prospectus) and the impact to investors from various events which could
adversely affect the Company's business. See "Risk Factors."
5
<PAGE>
SUMMARY FINANCIAL INFORMATION
The following table sets forth certain summary historical and pro forma
financial data of the Company. The historical information should be read in
conjunction with the Consolidated Financial Statements and the notes thereto
included elsewhere in this Prospectus. The Company acquired significant
producing oil and gas properties in certain of the periods presented which
affect the comparability of the historical financial and operating data for the
periods presented. The pro forma information should be read in conjunction with
the Pro Forma Condensed Financial Statements and notes thereto included
elsewhere in this Prospectus. Neither the historical results nor the pro forma
results are necessarily indicative of the Company's future operations or
financial results.
<TABLE>
<CAPTION>
SIX MONTHS ENDED
YEAR ENDED DECEMBER 31, JUNE 30,
-------------------------------------------- -------------------------------
HISTORICAL PRO FORMA HISTORICAL PRO FORMA
------------------------------- ----------- -------------------- ---------
1993 1994 1995 1995(1) 1995 1996 1996(1)
--------- --------- --------- ----------- --------- --------- ---------
(IN THOUSANDS, EXCEPT RATIOS AND PER SHARE DATA)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA:
Revenues................................. $ 4,397 $ 7,836 $ 21,816 $ 52,637 $ 5,573 $ 19,525 $ 28,748
Expenses:
Oil and gas production................. 1,688 2,351 10,355 26,937 2,413 8,278 13,295
General and administrative............. 952 1,184 3,571 4,850 1,008 2,809 3,010
Compensation related to option
settlement............................ -- -- 656 656 656 -- --
Exploration and abandonments........... 218 793 1,650 2,761 1,007 308 555
Depreciation, depletion and
amortization.......................... 884 1,847 5,958 14,176 1,367 4,620 6,981
Interest............................... 605 1,458 4,591 11,635 1,046 4,156 5,817
Other.................................. -- -- 2 2 -- -- --
--------- --------- --------- ----------- --------- --------- ---------
Net income (loss) before income taxes and
extraordinary item...................... 50 203 (4,967) (8,380) (1,924) (646) (910)
Net income (loss)........................ 73 163 (4,970) (8,383) (1,924) (2,286) (910)
Pro forma earnings (loss) per common
share................................... -- -- -- (0.85) -- -- (0.09)
Pro forma weighted average common shares
outstanding............................. -- -- -- 9,861 -- -- 10,000
STATEMENT OF CASH FLOWS DATA:
Net cash provided by (used in):
Operating activities................... $ 322 $ 1,527 $ 6,366 -- $ (3,040) $ (122) --
Investing activities................... (6,731) (12,146) (62,467) -- (57,773) (49,723) --
Financing activities................... 6,315 10,618 58,830 -- 62,094 48,143 --
OTHER FINANCIAL DATA:
Capital expenditures..................... $ 6,862 $ 11,868 $ 62,220 -- $ 57,773 $ 49,723 --
Adjusted EBITDA (2)...................... 1,757 4,301 7,232 $ 20,192 1,496 8,438 $ 12,443
Adjusted EBITDA/interest expense (2)..... 2.9x 2.9x 1.6x 1.7x 1.4x 2.0x 2.1x
Ratio of earnings to fixed charges (3)... 1.0 1.1 -- -- -- -- --
BALANCE SHEET DATA (AS OF PERIOD END):
Working capital.......................... $ 1,612 $ 1,081 $ 2,496 -- -- $ 4,266 $ 13,757
Total assets............................. 13,290 24,904 87,367 -- -- 135,047 146,434
Total debt............................... 12,034 23,613 71,494 -- -- 122,365 100,365
Redeemable members' capital.............. -- -- 11,576 -- -- 13,171 --
Members' capital......................... 51 (747) (7,445) -- -- (11,326) --
Pro forma stockholders' equity........... -- -- -- -- -- -- 35,232
</TABLE>
- ------------------------------
(1) Assumes that the 1995 Acquisition, the 1996 Acquisition, the Corporate
Reorganization (as defined in "The Company-- Corporate Reorganization") and
the Offerings and the application of proceeds therefrom had taken place on
June 30, 1996 for purposes of the Balance Sheet Data (to the extent not
already reflected) and as of January 1, 1995 for purposes of Statement of
Operations Data and Other Financial Data.
(2) Adjusted EBITDA and the ratio of Adjusted EBITDA to interest expense are
presented because of their wide acceptance as financial indicators of a
company's ability to service or incur debt. Adjusted EBITDA (as used
herein) is calculated by adding interest, income taxes, depreciation,
depletion and amortization, exploration and abandonment costs and
extraordinary loss resulting from extinguishment of debt to net income
(loss). The ratio of Adjusted EBITDA to interest expense is calculated by
dividing Adjusted EBITDA by interest. Interest includes interest expense
accrued and amortization of deferred financing costs. Adjusted EBITDA and
the ratio of Adjusted EBITDA to interest expense should not be considered
as alternatives to earnings (loss), or operating earnings (loss), as
defined by generally accepted accounting principles, as indicators of the
Company's financial performance or to cash flow as a measure of liquidity.
(3) For purposes of calculating the ratio of earnings to fixed charges,
"earnings" are net income (loss) before extraordinary loss resulting from
extinguishment of debt, plus income taxes and fixed charges. Fixed charges
are comprised of interest on indebtedness, amortization of deferred
financing costs, and that portion of operating lease expense which is
deemed to be representative of an interest factor. Earnings were
insufficient to cover fixed charges by $4,967,000, $1,924,000 and $646,000
for the historical periods ended December 31, 1995, June 30, 1995 and June
30, 1996, respectively, and $8,380,000 and $910,000 for the pro forma
periods ended December 31, 1995 and June 30, 1996, respectively.
6
<PAGE>
SUMMARY RESERVE DATA
<TABLE>
<CAPTION>
AS OF DECEMBER 31, AS OF APRIL 1, 1996
------------------------------- ------------------------
1993 1994 1995 ACTUAL PRO FORMA(1)
--------- --------- --------- --------- -------------
<S> <C> <C> <C> <C> <C>
ESTIMATED PROVED RESERVES (2):
Oil (MBbls).............................................. 2,365 4,009 10,788 11,479 16,477
Gas (Mmcf)............................................... 21,619 27,512 78,152 79,420 112,921
MBOE (6 Mcf/Bbl)......................................... 5,968 8,594 23,813 24,716 35,297
Percent of proved developed reserves..................... 67.0% 62.3% 76.1% 73.9% 78.2%
Present value of estimated future net cash flow, before
income taxes, discounted at 10% (in thousands).......... $ 26,377 $ 36,779 $ 113,296 $ 129,091 $ 179,527
Reserve life index (in years) (3)........................ 19.8 14.4 13.6 -- --
RESERVE REPLACEMENT DATA:
Production replacement ratio (4)......................... 513% 540% 969% -- --
All-in finding costs per BOE (5)......................... $ 4.31 $ 3.67 $ 3.43 $ 2.84 $ 3.72
</TABLE>
- ------------------------------
(1) Gives effect to the 1996 Acquisition as if such transaction had occurred as
of April 1, 1996.
(2) Estimates of net proved oil and gas reserves at April 1, 1996 are based on
reports prepared by Williamson Petroleum Consultants, Inc. ("Williamson"),
independent petroleum engineers. The 1995 reserve estimates were prepared by
the Company and such estimates of gross reserves with respect to certain of
the Company's producing properties were subject to a limited review by
Williamson. Prior reserve estimates are based on information compiled by the
Company. See "Risk Factors -- Uncertainty of Estimates of Proved Reserves
and Future Net Revenues" and "Business and Properties -- Oil and Gas
Reserves."
(3) Calculated by dividing year-end proved reserves by annual production for the
most recent year.
(4) Calculated by dividing reserve additions through acquisitions of reserves,
extensions and discoveries and revisions during the year by production for
such year.
(5) The average all-in finding costs over the period January 1, 1993 through
March 31, 1996 (pro forma for the 1996 Acquisition) was $3.60 per BOE.
SUMMARY OPERATING DATA
<TABLE>
<CAPTION>
YEAR ENDED DECEMBER 31,
----------------------------------------------
SIX MONTHS ENDED JUNE 30,
HISTORICAL PRO FORMA(1) 1996
------------------------------- ------------- ----------------------------
1993 1994 1995 1995 ACTUAL PRO FORMA(1)
--------- --------- --------- ------------- ----------- ---------------
<S> <C> <C> <C> <C> <C> <C>
PRODUCTION DATA:
Oil (MBbls)..................................... 158 330 950 2,085 709 990
Gas (Mmcf)...................................... 865 1,600 4,806 11,984 3,504 5,345
MBOE............................................ 302 597 1,751 4,083 1,293 1,881
AVERAGE SALES PRICE PER UNIT:
Oil (per Bbl)................................... $ 16.93 $ 15.25 $ 15.53 $ 15.75 $ 18.93 $ 18.26
Gas (per Mcf)................................... 1.82 1.63 1.45 1.59 1.91 1.87
COSTS PER BOE:
Production costs, including severance taxes
(2)............................................ $ 5.59 $ 3.94 $ 5.91 $ 6.60 $ 6.40 $ 7.07
Depreciation, depletion and amortization........ 2.93 3.09 3.40 3.47 3.57 3.71
</TABLE>
- ------------------------------
(1) Gives effect to the 1995 Acquisition and the 1996 Acquisition as if such
transactions had occurred as of January 1, 1995.
(2) Production costs per BOE in 1995 and for the six months ended June 30, 1996
were unusually high as a result of relatively high workover expenses with
respect to properties acquired in the 1995 Acquisition which did not produce
related production improvements until subsequent periods. Additionally, the
Company's 1995 production costs were adversely affected by expenses incurred
in connection with plugging wells to comply with applicable regulatory
requirements.
7
<PAGE>
RISK FACTORS
This Prospectus contains certain forward-looking statements. These
statements include, among others, statements regarding oil and gas reserves,
future drilling and operations, future production of oil and gas and future net
cash flows. Actual results could differ materially from those projected in the
forward-looking statements as a result of various factors, including, without
limitation, those set forth below and elsewhere in this Prospectus. Investors
should carefully consider the following factors, in addition to other
information contained in this Prospectus, in connection with an investment in
the shares of Common Stock offered hereby.
SIGNIFICANT LEVERAGE AND DEBT SERVICE. As of June 30, 1996, as adjusted for
the Corporate Reorganization, the Offerings and the application of the net
proceeds therefrom, the Company's total debt and stockholders' equity would have
been $100.4 million and $35.2 million, respectively. See "Capitalization." In
addition, the Company may currently incur additional indebtedness under its
Credit Facility (as defined under "Description of Certain Indebtedness").
Immediately following the consummation of the Offerings, the Credit Facility
will afford the Company $50.0 million of available borrowing capacity, none of
which is expected to be necessary to finance the Company's existing business
plan. See "Management's Discussion and Analysis of Financial Condition and
Results of Operations -- Liquidity and Capital Resources" and "Description of
Certain Indebtedness."
The Company's level of indebtedness will have several important effects on
its future operations, including (i) a substantial portion of the Company's cash
flow from operations must be dedicated to the payment of interest on its
indebtedness and will not be available for other purposes, (ii) covenants
contained in the Credit Facility and the Indenture governing the Notes (the
"Indenture") will require the Company to meet certain financial tests, and other
restrictions may limit its ability to borrow additional funds or to dispose of
assets and may affect the Company's flexibility in planning for, and reacting
to, changes in its business, including possible acquisition activities and (iii)
the Company's ability to obtain additional financing in the future for working
capital, capital expenditures, acquisitions, general corporate purposes or other
purposes may be impaired. See "Management's Discussion and Analysis of Financial
Condition and Results of Operations -- Liquidity and Capital Resources."
The Company's ability to meet its debt service obligations and to reduce its
total indebtedness will be dependent upon the Company's future performance,
which will be subject to general economic conditions and to financial, business
and other factors affecting the operations of the Company, many of which are
beyond its control. Earnings were insufficient to cover fixed charges by $5.0
million and $0.6 million for the year ended December 31, 1995 and six months
ended June 30, 1996, respectively, and $8.4 million and $0.9 million for the pro
forma year ended December 31, 1995 and six months ended June 30, 1996,
respectively. Based upon the current and anticipated level of operations, the
Company believes, however, that its cash flow from operations, together with
amounts available under its Credit Facility and its other sources of liquidity,
will be adequate to meet its anticipated requirements in the foreseeable future
for working capital, capital expenditures, interest payments and scheduled
principal payments. There can be no assurance, however, that the Company's
business will continue to generate cash flow at or above current levels. If the
Company is unable to generate sufficient cash flow from operations in the future
to service its debt, it may be required to refinance all or a portion of its
existing debt including the Notes, or to obtain additional financing. There can
be no assurance that any such refinancing would be possible or that any
additional financing could be obtained. The inability to obtain additional
financing could have a material adverse effect on the Company. For example, a
default by the Company under the terms of the Indenture could result in a
default under the terms of the Credit Facility.
RESTRICTIONS IMPOSED BY LENDERS. The instruments governing the indebtedness
of the Company and its subsidiaries impose significant operating and financial
restrictions on the Company. The terms of the Indenture and the Credit Facility
affect, and in many respects significantly limit or prohibit, among other
things, the ability of the Company to incur additional indebtedness, pay
dividends, repay indebtedness prior to its stated maturity, sell assets or
engage in mergers or acquisitions. These restrictions could also limit the
ability of the Company to effect future financing, make needed capital
expenditures, withstand a future downturn in the Company's business or the
economy in general, or otherwise conduct necessary corporate activities. A
failure by the Company to comply with these restrictions could lead to a default
under the terms
8
<PAGE>
of such indebtedness. In the event of default, the holders of such indebtedness
could elect to declare all of the funds borrowed pursuant thereto to be due and
payable together with accrued and unpaid interest. In such event, there can be
no assurance that the Company would be able to make such payments or borrow
sufficient funds from alternative sources to make any such payment. Even if
additional financing could be obtained, there can be no assurance that it would
be on terms that are favorable or acceptable to the Company. In addition, the
Company's indebtedness under its Credit Facility is expected to be secured by
substantially all of the assets of the Company and its subsidiaries. The pledge
of such collateral to existing lenders could impair the Company's ability to
obtain additional financing. See "Description of Certain Indebtedness."
POTENTIAL INABILITY TO FUND A CHANGE OF CONTROL OFFER. The Indenture
provides that upon the occurrence of a Change of Control, the Company is
required to offer to repurchase any or all of the outstanding Notes at a price
equal to 101% of the aggregate principal amount thereof, together with accrued
and unpaid interest, if any, to the date of purchase. Generally, a "Change of
Control" includes any person or group other than Cadell S. Liedtke, Michael J.
Grella and Henry G. Musselman, the Chairman of the Board, President and
Executive Vice President of the Company, respectively, acquiring 50% or more of
the voting securities of the Company, and certain other events. If a Change of
Control occurs, there is no assurance that the Company will have available funds
sufficient to pay for the Notes tendered for repurchase. If an offer to
repurchase is required to be made and the Company does not have available funds
sufficient to pay for Notes tendered for repurchase, an event of default would
occur under the Indenture. The occurrence of an event of default could result in
the acceleration of maturity of the Notes and of all amounts due under the
Credit Facility. In addition, the Change of Control covenant in the Indenture
could have the effect of discouraging a takeover of the Company by making any
such attempt potentially more expensive.
UNCERTAINTY OF ESTIMATES OF PROVED RESERVES AND FUTURE NET CASH
FLOWS. There are numerous uncertainties in estimating quantities of proved
reserves and in projecting future rates of production and the timing of
development expenditures, including many factors beyond the control of the
Company. The reserve data set forth in this Prospectus are estimates only.
Although the Company believes such estimates to be reasonable, reserve estimates
are imprecise and should be expected to change as additional information becomes
available. Furthermore, estimates of oil and gas reserves, of necessity, are
projections based on engineering data, and there are uncertainties inherent in
the interpretation of such data as well as the projection of future rates of
production and the timing of development expenditures. Reserve engineering is a
subjective process of estimating underground accumulations of oil and gas that
cannot be exactly measured, and the accuracy of any reserve estimate is a
function of the quality of available data and of engineering and geological
interpretation and judgment. Accordingly, estimates of the economically
recoverable quantities of oil and gas attributable to any particular group of
properties, classifications of such reserves based on risk of recovery, and
estimates of the future net cash flows expected therefrom prepared by different
engineers or by the same engineers at different times may vary substantially.
Moreover, there can be no assurance that the reserves set forth herein will
ultimately be produced or that the proved undeveloped reserves will be developed
within the periods anticipated. Variances from the estimates contained herein
could be material. In addition, the estimates of future net revenues from proved
reserves of the Company and the present value thereof are based upon certain
assumptions about production levels, prices and costs, which may not be correct.
The Company emphasizes with respect to such estimates that the discounted future
net cash flows should not be construed as representative of the fair market
value of the proved oil and gas properties belonging to the Company, because
discounted future net cash flows are based upon projected cash flows that do not
provide for changes in oil and gas prices or for escalation of expenses and
capital costs. The meaningfulness of such estimates is highly dependent upon the
accuracy of the assumptions upon which they were based. Actual results may
differ materially from the results estimated. Prospective purchasers of shares
of Common Stock offered hereby are cautioned not to place undue reliance on the
reserve data included in this Prospectus.
ACQUISITION RISKS. The Company's rapid growth in recent years has been
largely the result of acquisitions of producing properties. The Company expects
to continue to evaluate and pursue acquisition opportunities available on terms
management considers favorable to the Company. The successful acquisition of
producing properties requires an assessment of recoverable reserves, future oil
and gas prices, operating costs, potential environmental and other liabilities
and other factors beyond the Company's control. Such an
9
<PAGE>
assessment is necessarily inexact and its accuracy is inherently uncertain. In
connection with such an assessment, the Company performs a review of the subject
properties it believes to be generally consistent with industry practices. Such
a review, however, will not reveal all existing or potential problems, nor will
it permit a buyer to become sufficiently familiar with the properties fully to
assess their deficiencies and capabilities. Inspections may not be performed on
every well, and structural and environmental problems are not necessarily
observable even when an inspection is undertaken. The Company is generally not
entitled to contractual indemnification for preclosing liabilities, including
environmental liabilities, and generally acquires interests in the properties on
an "as is" basis.
DRILLING RISKS. Drilling involves numerous risks, including the risk that
no commercially productive oil or gas will be encountered. The cost of drilling,
completing and operating wells is often uncertain, and drilling operations may
be curtailed, delayed or cancelled as a result of a variety of factors,
including unexpected drilling conditions, pressure or irregularities in
formations, equipment failures or accidents, adverse weather conditions and
shortages or delays in the delivery of equipment. The Company's future drilling
activities may not be successful and, if unsuccessful, such failure may have a
material adverse effect on the Company's future results of operations and
financial condition.
OPERATING HAZARD AND UNINSURED RISKS. The Company's operations are subject
to hazards and risks inherent in the drilling for and production and
transportation of oil and gas, including fires, natural disasters, explosions,
encountering formations with abnormal pressures, blowouts, cratering, pipeline
ruptures, and spills, any of which can result in loss of hydrocarbons,
environmental pollution, personal injury or loss of life, severe damage to and
destruction of properties of the Company and others, and suspension of
operations. Although the Company maintains insurance coverage that it considers
to be adequate and customary in the industry, it is not fully insured against
certain of these risks, either because such insurance is not available or
because of high premium costs. The occurrence of a significant event not fully
covered by insurance could have a material adverse effect on the Company's
financial condition and results of operations.
COMPETITION. The Company encounters substantial competition in acquiring
properties, marketing oil and gas and securing trained personnel. Many
competitors have substantially larger financial resources, staffs and
facilities. See "Business and Properties -- Competition and Markets."
VOLATILITY OF OIL AND GAS PRICES. The Company's financial results and,
therefore, its ability to service its debt, including the Notes, are
significantly affected by the price received for the Company's oil and gas
production. Historically, the markets for oil and gas have been volatile and may
continue to be volatile in the future. Prices of oil and gas are subject to wide
fluctuations in response to market uncertainty, changes in supply and demand and
a variety of additional factors, all of which are beyond the control of the
Company. These factors include domestic and foreign political conditions, the
overall level of supply of and demand for oil and gas, the price of imported oil
and gas, weather conditions, the price and availability of alternative fuels and
overall economic conditions. The Company's future financial condition and
results of operations will be dependent, in part, upon the prices received for
the Company's oil and gas production, as well as the costs of acquiring,
finding, developing and producing reserves. To reduce its exposure to price
risks in the sale of its oil and gas, the Company enters into hedging
arrangements from time to time. Although the Company hedges a significant
portion of its production, any substantial or extended decline in the price of
oil and gas would have a material adverse effect on the Company's financial
condition and results of operations, as well as reduce the amount of the
Company's oil and gas that could be produced economically. Moreover, if oil and
gas prices fall materially below their current levels, the availability of funds
and the Company's ability to repay outstanding amounts under its Credit Facility
and the Notes could be materially adversely affected. See "Management's
Discussion and Analysis of Financial Condition and Results of Operations."
DEPENDENCE ON KEY PERSONNEL. The Company depends to a large extent on the
services of Messrs. Liedtke, Grella and Musselman. The loss of the services of
any of Messrs. Liedtke, Grella or Musselman could have a material adverse effect
on the Company's operations. Pursuant to employment agreements which are to be
effective upon the consummation of the Offerings, Messrs. Liedtke, Grella and
Musselman have agreed not to compete with the Company for a one year period
should they voluntarily leave the Company's employment or should their
employment be terminated for cause within the initial three-year term of each
employment agreement. The Company believes that its success is also dependent
upon its ability to continue to employ and retain skilled technical personnel.
See "Management."
10
<PAGE>
CONTROL OF THE COMPANY. If the Offerings are completed, Messrs. Liedtke,
Grella and Musselman will own directly and indirectly, in the aggregate, 49.2%
of the outstanding Common Stock (or 46.4% if the Underwriters' over-allotment
option in the Common Stock Offering is exercised in full). Accordingly, Messrs.
Liedtke, Grella and Musselman will be able to exercise significant influence
over the election of the directors of the Company and the control of the
Company's management, operations and affairs. The voting power held by such
principal stockholders and their ability to exercise significant influence over
the election of directors may have the effect of discouraging certain types of
transactions involving an actual or potential change of control of the Company,
including transactions in which the holders of Common Stock might otherwise
receive a premium for their shares over then current market prices. See
"Security Ownership of Certain Beneficial Owners and Management" and
"Description of Capital Stock."
FOREIGN INVESTMENT. The Company's investment in Moldova involves risks
typically associated with investments in emerging markets such as foreign
exchange restrictions and currency fluctuations, foreign taxation, changing
political conditions, foreign and domestic monetary and tax policies,
expropriation, nationalization, nullification, modification or renegotiation of
contracts, war and civil disturbances and other risks that may limit or disrupt
markets. In addition, if a dispute arises in its Moldovan operations, the
Company may be subject to the exclusive jurisdiction of foreign courts or may
not be successful in subjecting foreign persons to the jurisdiction of the
United States. The Company attempts to conduct its business and financial
affairs so as to protect against political and economic risks applicable to
operations in Moldova, but there can be no assurance the Company will be
successful in so protecting itself.
GOVERNMENT LAWS AND REGULATIONS. The Company's operations are affected from
time to time in varying degrees by political developments and federal, state and
local laws and regulations. In particular, oil and gas production, operations
and economics are or have been significantly affected by price controls, taxes
and other laws relating to the oil and gas industry, by changes in such laws and
by changes in administrative regulations. The Company cannot predict how
existing laws and regulations may be interpreted by enforcement agencies or
court rulings, whether additional laws and regulations will be adopted, or the
effect such changes may have on its business, financial condition or results of
operations. See "Business and Properties -- Regulation."
ENVIRONMENTAL REGULATIONS. The Company's operations are subject to complex
and constantly changing environmental laws and regulations adopted by federal,
state and local governmental authorities. The Company believes that compliance
with such laws has had no material adverse effect upon the Company's operations
to date and that the cost of such compliance has not been material.
Nevertheless, the discharge of oil, gas or other pollutants into the air, soil
or water may give rise to significant liabilities on the part of the Company to
the government and third parties and may require the Company to incur
substantial costs of remediation. Moreover, the Company has agreed to indemnify
sellers of producing properties from whom the Company has acquired reserves
against certain liabilities for environmental claims associated with the
properties being purchased by the Company, including, without limitation, in
connection with both the 1995 Acquisition and the 1996 Acquisition. No assurance
can be given that existing environmental laws or regulations, as currently
interpreted or reinterpreted in the future, or future laws or regulations, will
not materially adversely affect the Company's results of operations and
financial condition or that material indemnity claims will not arise against the
Company with respect to properties acquired by the Company. See "Business and
Properties -- Environmental Matters."
ABSENCE OF PUBLIC MARKET FOR THE COMMON STOCK AND POSSIBLE VOLATILITY OF
STOCK PRICE. Prior to the Common Stock Offering, there has been no public
market for the Common Stock of the Company and there can be no assurance that an
active trading market will develop or be sustained after the Common Stock
Offering, or that the market price of the Common Stock will not decline below
the initial public offering price. The initial public offering price of the
Common Stock will be determined through negotiations between the Company and the
Underwriters, and may bear no relationship to the market price of the Common
Stock after the Common Stock Offering. Factors such as quarterly or cyclical
variations in the Company's financial condition and results of operations,
variations in interest rates, future announcements concerning the Company or its
competitors, government regulation, general economic and other conditions and
developments affecting the oil and gas industry could cause the market price of
the Common Stock to fluctuate substantially. See "Underwriting."
11
<PAGE>
DILUTION. Purchasers of the Common Stock offered hereby will experience
immediate and substantial dilution in the pro forma net tangible book value per
share of Common Stock from the initial public offering price set forth on the
cover of this Prospectus. Such dilution to new investors will be $11.86 per
share (assuming an initial public offering price of $15.00 per share), while the
pro forma net tangible book value of the shares of Common Stock owned by the
existing stockholders will increase by $5.77 per share. See "Dilution."
NO INTENTION TO PAY DIVIDENDS. The Company intends to retain future
earnings for use in its business and does not anticipate paying any cash
dividends in the foreseeable future. In addition, the payment of dividends by
the Company is limited and restricted by the Credit Facility and under the terms
of the Indenture. See "-- Restrictions Imposed by Lenders," "Dividend Policy"
and "Description of Certain Indebtedness."
ANTI-TAKEOVER EFFECT OF CERTAIN PROVISIONS OF THE COMPANY'S CERTIFICATE OF
INCORPORATION AND BYLAWS. The Company's Certificate of Incorporation and bylaws
provide that (i) the Company's Board of Directors will be divided into classes,
with the directors of each class serving staggered terms of three years each or
until their respective successors are elected and qualified, and (ii) the Board
of Directors may issue serial preferred stock with such rights and preferences
as the Board may determine, without stockholder approval. These provisions may
have the effect, either alone or in combination, of making more difficult or
discouraging an acquisition or potential acquisition of the Company which is
deemed undesirable by the Board of Directors. See "Description of Capital Stock
- -- Anti-Takeover Provisions."
SHARES ELIGIBLE FOR FUTURE SALE. Sales of substantial amounts of Common
Stock on the public market after the Common Stock Offering could adversely
affect the market price of the Common Stock. Upon completion of the Common Stock
Offering, the Company will have a total of 10,000,000 shares of Common Stock
outstanding. Of these shares, the 4,000,000 shares of Common Stock offered
hereby (4,600,000 shares if the Underwriters' over-allotment option is exercised
in full) will be freely tradeable without restriction or registration under the
Securities Act of 1933 (the "Securities Act") by persons other than "affiliates"
of the Company, as defined under the Securities Act. The remaining 6,000,000
shares of Common Stock outstanding will be "restricted securities" as that term
is defined by Rule 144 as promulgated under the Securities Act. The Company
currently has eight options outstanding for 550,000 shares. See "Executive
Compensation and Other Information."
Under Rule 144 (and subject to the conditions thereof, including volume
limitations), approximately 4,919,992 of the 6,000,000 restricted shares will
become eligible for sale 90 days after the Common Stock Offering. All 6,000,000
of the restricted shares are subject to lockup restrictions as described below.
The holders of these shares, which include certain of the Company's executive
officers and directors and NationsBanc Capital Corp. ("NBCC"), have agreed that
they will not, directly or indirectly, offer, sell, offer to sell, contract to
sell, pledge, grant any option to purchase or otherwise sell or dispose (or
announce any offer, sale, offer of sale, contract to sell, pledge, grant of any
options to purchase or sale or disposition) of any shares of Common Stock or
other capital stock of the Company, or any securities convertible into, or
exercisable or exchangeable for, any shares of Common Stock or other capital
stock of the Company without the prior written consent of Prudential Securities
Incorporated, on behalf of the Underwriters, for a period of 180 days from the
date of this Prospectus. After such 180-day period, this restriction will expire
and shares permitted to be sold under Rule 144 would be eligible for sale. In
addition, NBCC has demand registration rights to require the Company to file up
to two registration statements to effect the registration under the Securities
Act of the shares of Common Stock held by such holder, and the other majority
stockholders have "piggyback" registration rights, which would permit such
holders to resell such shares without complying with Rule 144. Registration and
sale of such shares could have an adverse effect on the trading price of the
Common Stock. See "Description of Capital Stock -- Registration Rights" and
"Shares Eligible for Future Sale."
Prior to the Common Stock Offering, there has been no public market for the
Common Stock and no predictions can be made of the effect, if any, that the sale
or availability for sale of additional shares of Common Stock will have on the
market price of the Common Stock. Nevertheless, sales of substantial amounts of
such shares in the public market, or the perception that such sales could occur,
could materially and adversely affect the market price of the Common Stock and
could impair the Company's future ability to raise capital through an offering
of its equity securities.
12
<PAGE>
THE COMPANY
GENERAL
The Company is an independent energy company that is engaged in the
acquisition, exploration, exploitation and development of oil and gas
properties. The Company's primary operations are in the Permian Basin, the Gulf
Coast and the Rocky Mountain regions. The Company recently acquired an interest
in an entity which has a concession for the development of mineral interests in
the Republic of Moldova, in Eastern Europe. The Company also has minor interests
in the domestic gas gathering and transmission business.
CORPORATE REORGANIZATION
Costilla was incorporated in Delaware in June 1996 to consolidate and
continue the activities previously conducted by Costilla Energy, L.L.C., a Texas
limited liability company (the "LLC"), and its wholly owned subsidiaries, to
acquire the assets of CSL Management Corporation ("CSL") (which owns certain
office equipment used by the Company), and to acquire the stock of Valley
Gathering Company ("Valley"). Costilla has been formed solely for the purpose of
conducting the Offerings, and has not commenced operations. Both CSL and Valley
are owned by Messrs. Liedtke, Grella and Musselman. See "Certain Transactions."
Contemporaneously with the closings of the Offerings: (1) the redeemable
membership interests of NBCC in the LLC will be redeemed for $15.5 million; (2)
the LLC will be merged into Costilla (the "Merger") and an aggregate of
6,000,000 shares of Common Stock will be issued to the four members of the LLC;
(3) Costilla will acquire all of the issued and outstanding stock of Valley and
the assets of CSL for $0.7 million; and (4) $4.3 million in distributions will
be made to the members of the LLC, $3.5 million of which, in the case of Messrs.
Liedtke, Grella and Musselman, will be provided to such persons for certain
estimated income tax effects of the Merger. These transactions are referred to
throughout this Prospectus as the "Corporate Reorganization." As a result of the
Corporate Reorganization, Costilla will have four wholly owned subsidiaries: (i)
Costilla Petroleum Corporation, a Texas corporation ("CPC"), which operates
properties owned by Costilla and owns minor interests in the same properties;
(ii) Statewide Minerals, Inc., a Texas corporation ("Statewide"), which is
engaged in the purchase of small royalty and mineral interests; (iii) Valley,
which owns several small gas gathering systems, a small gas processing plant,
certain salt water disposal systems and gas compressors; and (iv) Costilla
Pipeline Corporation, a Texas corporation ("Pipeline"), which owns a gas
pipeline in Pennsylvania held for resale. CSL will be dissolved. Costilla and
CPC are the sole members of two Texas limited liability companies through which
the Company's Moldovan operations are conducted. Costilla also owns a 40.5%
interest in a Delaware limited liability company which owns and operates a gas
pipeline and associated facilities in Louisiana.
The Company's executive offices are located at 400 West Illinois, Suite
1000, Midland, Texas, 79701 and its telephone number is (915) 683-3092.
NOTES OFFERING
Concurrent with the Common Stock Offering, the Company is offering
$100,000,000 of % Senior Notes due 2006. The Notes Offering and the Common
Stock Offering are each conditioned upon the consummation of the other.
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<PAGE>
USE OF PROCEEDS
The net proceeds to the Company from the Common Stock Offering are expected
to be $55.3 million, based upon an initial public offering price of $15.00 per
share after deducting underwriting discounts and commissions and estimated
offering expenses to the Company ($63.7 million if the Underwriters' over-
allotment option is exercised). The net proceeds to the Company from the Notes
Offering are estimated to be $96.2 million. Approximately $125.8 million of such
proceeds, including all the net proceeds of the Notes Offering, will be used to
repay all of the existing senior indebtedness of the Company (the "Existing
Debt") incurred in connection with the 1996 Acquisition, and to refinance its
previous credit facility. The Existing Debt matures in June 1999. Approximately
$30.0 million of the Existing Debt currently bears interest at 14.0% per annum
(increasing to 14.5% on September 13, 1996) and the balance currently bears
interest at a rate selected by the Company equal to a base rate (generally the
prime rate established by NationsBank, N.A.) plus 0.75% or LIBOR plus 3.0%. See
"Description of Certain Indebtedness." In addition, $20.5 million of the net
proceeds will be used to pay certain amounts incurred in connection with the
Corporate Reorganization, including $15.5 million to redeem certain membership
interests of NBCC in the LLC prior to the Merger, $0.7 million to acquire the
stock of Valley and the assets of CSL and $4.3 million in distributions to the
members of the LLC, $3.5 million of which, in the case of Messrs. Liedtke,
Grella and Musselman, will be provided to such persons for certain estimated
federal income tax effects of the Merger. See "Certain Transactions." The
remaining estimated net proceeds of $5.1 million will be used by the Company for
general corporate purposes. Pending such uses, the remaining net proceeds will
be invested in short-term, investment grade, interest-bearing securities.
The following is a description of sources and uses of proceeds from the
Offerings, assuming the Underwriters' over-allotment option in connection with
the Common Stock Offering is not exercised (in millions):
<TABLE>
<S> <C>
Sources:
Notes Offering............................................................ $ 100.0
Common Stock Offering..................................................... 60.0
---------
$ 160.0
---------
---------
Uses:
Refinance Existing Debt................................................... $ 125.8
Redeem membership interests............................................... 15.5
Distributions to individual members to pay estimated income tax liability
of such members.......................................................... 3.5
Pro rata distribution to remaining member................................. 0.8
Purchase of stock of Valley and assets of CSL............................. 0.7
Working capital........................................................... 5.1
Estimated fees, commissions, underwriting discounts and expenses related
to the Offerings......................................................... 8.6
---------
$ 160.0
---------
---------
</TABLE>
DIVIDEND POLICY
The Company intends to retain future earnings for use in its business and
does not anticipate declaring or paying any cash dividends in the foreseeable
future. The terms of the Credit Facility are expected to prohibit the payment of
dividends by the Company. In addition, the Indenture also contains provisions
restricting the payment of dividends (or other restricted payments) generally to
(i) 50% of consolidated net income of the Company (less 100% of losses) for the
period commencing the first day of the month during which the closing of the
Offerings occurs to the most recently ended fiscal quarter, plus (ii) 100% of
certain equity sales after the date of the Indenture. Subject to the
restrictions imposed by the Company's lenders, future dividend policy will
depend on a number of factors, including future earnings, capital requirements,
the financial condition and future prospects of the Company and such other
factors as the Board of Directors may deem relevant.
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<PAGE>
DILUTION
Purchasers of Common Stock offered hereby will experience an immediate and
substantial dilution in the net tangible book value of the Common Stock from the
initial public offering price. At June 30, 1996, the net tangible book value per
share of Common Stock of the Company, on a pro forma basis after giving effect
to the issuance of 6,000,000 shares in the Merger and the redemption of certain
membership interests in the LLC was ($2.64). Such amount does not give effect to
the Offerings or to the distributions to members of the LLC in the Corporate
Reorganization. Net tangible book value per share represents the amount of the
Company's tangible book value (total book value of tangible assets less total
liabilities) divided by the total number of shares of Common Stock outstanding.
After giving effect to the receipt of $55.3 million of estimated proceeds from
the Common Stock Offering, the issuance of the Notes in the Notes Offering and
the completion of the Corporate Reorganization, the net tangible book value of
the Common Stock outstanding at June 30, 1996 would have been $31.4 million or
$3.14 per share, representing an immediate increase in net tangible book value
of approximately $5.78 per share to current stockholders and an immediate
dilution of $11.86 per share (the difference between the assumed initial public
offering price and the net tangible book value per share after the Offerings) to
persons purchasing Common Stock at the assumed initial public offering price.
The following table illustrates such per share dilution:
<TABLE>
<S> <C> <C>
Assumed initial public offering price....................... $ 15.00
Net tangible book value before Offerings.................. $ (2.64)
Increase in net tangible book value attributable to sale
of Common Stock in the Common Stock Offering............. 5.78
---------
Net tangible book value after giving effect to the
Offerings.................................................. $ 3.14
---------
Dilution in net tangible book value to new investors........ $ 11.86
---------
---------
</TABLE>
Messrs. Liedtke, Grella and Musselman will receive 4,919,992 shares of
Common Stock in the Corporate Reorganization. These shares of Common Stock will
be issued to such persons in exchange for their membership interests in the LLC.
The effective cash cost of these shares to Messrs. Liedtke, Grella and
Musselman, on a per share basis, is not significant. In February 1995, upon
formation of the LLC, NBCC contributed $10,000,000 in cash in exchange for a 30%
membership interest in the LLC, forty percent of which was redeemable and sixty
percent was non-redeemable. In the Corporate Reorganization, such redeemable
interest will be redeemed and such non-redeemable interest will be exchanged for
1,080,008 shares of Common Stock issued to NBCC. As discussed in Note 10 of the
Notes to the Consolidated Financial Statements, the value of such non-redeemable
interest, and thus the effective cash cost of the shares of Common Stock to be
issued to NBCC in the Corporate Reorganization, is deemed to be $1,266,000.
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<PAGE>
CAPITALIZATION
The following table sets forth the unaudited capitalization of the Company
as of June 30, 1996, on an historical basis and on a pro forma basis giving
effect to the Corporate Reorganization and the Offerings and the application of
the net proceeds therefrom, as if such transactions had been consummated as of
June 30, 1996, assuming an initial public offering price for the Common Stock in
the Common Stock Offering of $15.00 per share. The following table should be
read in conjunction with the Consolidated Financial Statements of the LLC, the
unaudited Pro Forma Condensed Financial Statements, the related notes, and the
other information contained elsewhere in this Prospectus, including the
information set forth in "Management's Discussion and Analysis of Financial
Condition and Results of Operations." For further information regarding the
terms of the long-term debt reflected in the following table, see "Description
of Certain Indebtedness" and Note 7 and Note 12 of the Notes to Consolidated
Financial Statements.
<TABLE>
<CAPTION>
JUNE 30, 1996
-----------------------
HISTORICAL PRO FORMA
---------- -----------
(IN THOUSANDS)
<S> <C> <C>
Long-term debt:
Existing debt........................................................................... $ 122,365 $ 365
Credit Facility......................................................................... -- --
% Senior Notes due 2006.............................................................. -- 100,000
---------- -----------
Total long-term debt...................................................................... 122,365 100,365
---------- -----------
Redeemable members' capital............................................................... 13,171 --
---------- -----------
Members' capital and stockholders' equity:
Members' capital........................................................................ (11,326) --
Preferred stock, $.10 par value (3,000,000 shares authorized; no shares issued or
outstanding)........................................................................... -- --
Common Stock, $.10 par value (20,000,000 shares authorized; no shares outstanding
actual, 10,000,000 shares outstanding pro forma)....................................... -- 1,000
Paid-in capital......................................................................... -- 34,232
---------- -----------
Total members' capital and stockholders' equity........................................... (11,326) 35,232
---------- -----------
Total capitalization...................................................................... $ 124,210 $ 135,597
---------- -----------
---------- -----------
</TABLE>
16
<PAGE>
PRO FORMA CONDENSED FINANCIAL STATEMENTS
The unaudited Pro Forma Condensed Financial Statements of the Company have
been prepared to give effect to the 1995 Acquisition and the 1996 Acquisition,
the Corporate Reorganization, and the Offerings and the application of the
estimated net proceeds therefrom as if such transactions (to the extent not
already reflected) had taken place on June 30, 1996 for purposes of the Pro
Forma Condensed Balance Sheet and as if the transactions had taken place on
January 1, 1995 for purposes of the Pro Forma Condensed Statements of
Operations. The Pro Forma Condensed Financial Statements of the Company are not
necessarily indicative of the results for the periods presented had the 1995
Acquisition and the 1996 Acquisition, the Corporate Reorganization, and the
Offerings and the application of the estimated net proceeds therefrom taken
place on January 1, 1995. In addition, future results may vary significantly
from the results reflected in the accompanying Pro Forma Condensed Financial
Statements because of normal production declines, changes in product prices, and
the success of future exploration and development activities, among other
factors. This information should be read in conjunction with the Consolidated
Financial Statements of Costilla Energy, L.L.C. and subsidiaries, and the
Statements of Revenues and Direct Operating Expenses with respect to the
properties acquired in the 1995 Acquisition and the 1996 Acquisition, all
included elsewhere herein.
17
<PAGE>
COSTILLA ENERGY, INC.
PRO FORMA CONDENSED BALANCE SHEET -- UNAUDITED
JUNE 30, 1996
(IN THOUSANDS)
<TABLE>
<CAPTION>
PRO FORMA
PRO FORMA COSTILLA
COSTILLA OFFERING ENERGY,
ASSETS L.L.C. ADJUSTMENTS INC.
- ----------------------------------------------------------------------- ------------- ------------ -----------
<S> <C> <C> <C>
Current assets:
Cash and cash equivalents............................................ $ 1,164 $ (700)(1) $ 10,655
151,450(3)
(141,259)(4)
Accounts receivable.................................................. 8,785 8,785
Prepaid and other current assets..................................... 2,629 2,629
------------- -----------
Total current assets............................................. 12,578 22,069
Oil and gas properties, using the successful efforts method of
accounting:
Proved properties.................................................... 126,809 126,809
Unproved properties.................................................. 4,615 4,615
Accumulated depreciation, depletion and amortization................. (13,933) (13,933)
------------- -----------
117,491 117,491
Other property and equipment, net...................................... 1,640 700(1) 2,340
Deferred charges (Note 2).............................................. 2,654 3,850(3) 3,850
(2,654)(4)
Note receivable -- affiliate........................................... 684 684
------------- -----------
$ 135,047 $ 146,434
------------- -----------
------------- -----------
<CAPTION>
LIABILITIES, REDEEMABLE MEMBERS' CAPITAL AND EQUITY
- -----------------------------------------------------------------------
<S> <C> <C> <C>
Current liabilities:
Current maturities of long-term debt................................. $ 98 $ 98
Trade accounts payable............................................... 4,587 4,587
Undistributed revenue................................................ 1,524 1,524
Other current liabilities............................................ 2,103 2,103
------------- -----------
Total current liabilities........................................ 8,312 8,312
Long-term debt, less current maturities................................ 122,267 100,000(3) 100,267
(122,000)(4)
Deferred income........................................................ 2,623 2,623
------------- -----------
Total liabilities................................................ 133,202 111,202
Redeemable members' capital............................................ 13,171 (13,171)(4) --
Members' capital and stockholders' equity:
Members' capital..................................................... (11,326) 11,326(2) --
Preferred stock, $.10 par value (3,000,000 shares authorized; no
shares outstanding)................................................. -- --
Common Stock, $.10 par value (20,000,000 shares authorized; no shares
outstanding historical, 10,000,000 shares outstanding pro forma).... -- 1,000(3) 1,000
Paid-in capital...................................................... -- (2,654)(4) 34,232
(1,829)(4)
(4,259)(4)
54,300(3)
(11,326)(2)
------------- -----------
Total members' capital and stockholders' equity...................... (11,326) 35,232
------------- -----------
$ 135,047 $ 146,434
------------- -----------
------------- -----------
</TABLE>
See accompanying notes to unaudited pro forma condensed financial statements.
18
<PAGE>
COSTILLA ENERGY, INC.
PRO FORMA CONDENSED STATEMENT OF OPERATIONS -- UNAUDITED
YEAR ENDED DECEMBER 31, 1995
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<TABLE>
<CAPTION>
PRE OFFERING PRO FORMA
1995 1996 PRO FORMA COSTILLA OFFERING
COSTILLA L.L.C. ACQUISITION ACQUISITION ADJUSTMENTS L.L.C. ADJUSTMENTS
--------------- ----------- ----------- ------------- ------------- -------------
<S> <C> <C> <C> <C> <C> <C>
Revenues................................ $ 21,816 $ 10,930 $ 19,891 $ 52,637
------- ----------- ----------- -------------
Expenses:
Oil and gas production................ 10,355 5,473 11,409 $ (300)(1) 26,937
General and administrative............ 3,571 -- -- (172)(1) 4,850
1,451(5)
Compensation related to option
settlement........................... 656 656
Exploration and abandonments.......... 1,650 109 1,002 2,761
Depreciation, depletion and
amortization......................... 5,958 -- -- 100(1) 14,176
8,118(6)
Interest.............................. 4,591 -- -- 10,046(7) 14,637 $ (14,637)(8)
11,635(8)
Other................................. 2 -- -- 2
------- ----------- ----------- -------------
26,783 5,582 12,411 64,019
------- ----------- ----------- -------------
Net income (loss) before federal income
taxes.................................. (4,967) 5,348 7,480 (11,382)
Provision for federal income taxes...... 3 -- -- 3
------- ----------- ----------- -------------
Net income (loss)....................... $ (4,970) $ 5,348 $ 7,480 $ (11,385)
------- ----------- ----------- -------------
------- ----------- ----------- -------------
Net loss per share......................
<CAPTION>
PRO FORMA
COSTILLA
ENERGY,
INC.
-----------
<S> <C>
Revenues................................ $ 52,637
-----------
Expenses:
Oil and gas production................ 26,937
General and administrative............ 4,850
Compensation related to option
settlement........................... 656
Exploration and abandonments.......... 2,761
Depreciation, depletion and
amortization......................... 14,176
Interest.............................. 11,635
Other................................. 2
-----------
61,017
-----------
Net income (loss) before federal income
taxes.................................. (8,380)
Provision for federal income taxes...... 3
-----------
Net income (loss)....................... $ (8,383)
-----------
-----------
Net loss per share...................... $ (.85)
-----------
-----------
</TABLE>
See accompanying notes to unaudited pro forma condensed financial statements.
19
<PAGE>
COSTILLA ENERGY, INC.
PRO FORMA CONDENSED STATEMENT OF OPERATIONS -- UNAUDITED
SIX MONTHS ENDED JUNE 30, 1996
(IN THOUSANDS, EXCEPT PER SHARE DATA)
<TABLE>
<CAPTION>
PRO FORMA
1996 PRO FORMA PRE OFFERING OFFERING
COSTILLA L.L.C. ACQUISITION ADJUSTMENTS COSTILLA L.L.C. ADJUSTMENTS
--------------- ------------- -------------- --------------- -------------
<S> <C> <C> <C> <C> <C>
Revenues................................. $ 19,525 $ 9,223 $ 28,748
Expenses:
Oil and gas production................. 8,278 5,167 $ (150)(1) 13,295
General and administrative............. 2,809 (86)(1) 3,010
287(5)
Exploration and abandonments........... 308 247 555
Depreciation, depletion and
amortization.......................... 4,620 50(1) 6,981
2,311(6)
Interest............................... 4,156 2,832(7) 6,988 $ (6,988)(8)
5,817(8)
------- ------ -------
20,171 5,414 30,829
------- ------ -------
Net income (loss) before federal income
taxes................................... (646) 3,809 (2,081)
------- ------ -------
Net income (loss)........................ $ (646) $ 3,809 $ (2,081)
------- ------ -------
------- ------ -------
Net income (loss) per share..............
<CAPTION>
PRO FORMA
COSTILLA
ENERGY,
INC.
-----------
<S> <C>
Revenues................................. $ 28,748
Expenses:
Oil and gas production................. 13,295
General and administrative............. 3,010
Exploration and abandonments........... 555
Depreciation, depletion and
amortization.......................... 6,981
Interest............................... 5,817
-----------
29,658
-----------
Net income (loss) before federal income
taxes................................... (910)
-----------
Net income (loss)........................ $ (910)
-----------
-----------
Net income (loss) per share.............. $ (0.09)
-----------
-----------
</TABLE>
See accompanying notes to unaudited pro forma condensed financial statements.
20
<PAGE>
COSTILLA ENERGY, INC.
NOTES TO UNAUDITED PRO FORMA CONDENSED FINANCIAL STATEMENTS
NOTE 1. -- BASIS OF PRESENTATION
The Pro Forma Condensed Financial Statements of the Company have been
prepared to give effect to the 1995 Acquisition and the 1996 Acquisition, the
Corporate Reorganization and the Offerings and the application of estimated net
proceeds therefrom, as if such transactions had taken place on June 30, 1996 for
purposes of the Pro Forma Condensed Balance Sheet (with the exception of the
1995 Acquisition which was previously reflected in the balance sheet of Costilla
Energy, L.L.C.), and as if each of the transactions had taken place on January
1, 1995 for purposes of the Pro Forma Condensed Statements of Operations. The
1995 Acquisition and 1996 Acquisition are accounted for by the purchase method.
Costilla L.L.C. -- Represents the consolidated balance sheet of
Costilla Energy, L.L.C. and subsidiaries as of June 30, 1996 and the
related consolidated statements of operations for the year ended
December 31, 1995 and the six months ended June 30, 1996.
1995 Acquisition -- Represents the revenues and direct operating
expenses of the properties acquired in the 1995 Acquisition for the
period from January 1, 1995 to June 12, 1995 (date of the 1995
Acquisition).
1996 Acquisition -- Represents the revenues and direct operating
expenses of the properties acquired in the 1996 Acquisition for the
period from January 1, 1995 to June 14, 1996 (date of the 1996
Acquisition).
NOTE 2. -- PRO FORMA ENTRIES
(1) To record the acquisition of Valley Gathering Company and CSL Management
Corporation from certain members of Costilla Energy, L.L.C. and to record the
related additional depreciation and amortization, and reduction in oil and gas
production and general and administrative expenses.
(2) To reflect the Corporate Reorganization including the transfer of
members' capital to stockholders' equity.
(3) To reflect the issuance of 4,000,000 shares of Common Stock at an
estimated price of $15.00 per share for estimated proceeds of $55,300,000, net
of estimated expenses of the Common Stock Offering, and issuance of the Notes at
$100,000,000; and to reflect payment of related debt issuance expenses of
$3,850,000.
(4) To record the repayment of the Existing Debt and the write-off of
related debt issuance costs, the distribution of cash to certain members, and
the repurchase of redeemable members capital for approximately $15,000,000 from
proceeds of the Offerings.
The redemption amount is composed of the following:
<TABLE>
<S> <C>
Redeemable members' interest subject to preferred return....... $11,000,000
Redeemable members' interest not subject to preferred return... 1,500,000
Accrued 15% preferred return including associated 10%
redemption premium............................................ 2,500,000
----------
$15,000,000
----------
----------
</TABLE>
(5) Estimated incremental general and administrative expenses necessary to
administer the properties acquired in the 1995 and 1996 acquisitions and
increased public reporting and administration costs include salary and benefits
for one executive level employee and revised compensation arrangements for the
remaining executives, approximately 29 additional administrative personnel (the
majority of which were added prior to December 31, 1995), directors' fees,
insurance coverage and estimated costs to administer shareholder communications.
21
<PAGE>
COSTILLA ENERGY, INC.
NOTES TO UNAUDITED PRO FORMA CONDENSED FINANCIAL STATEMENTS (CONTINUED)
NOTE 2. -- PRO FORMA ENTRIES (CONTINUED)
(6) To record estimated incremental depletion expense for the properties
acquired in the 1995 Acquisition from January 1, 1995 through June 12, 1995
(date of the 1995 Acquisition) and for the properties acquired in the 1996
Acquisition from January 1, 1995 through June 14, 1996 (date of the 1996
Acquisition).
(7) To adjust interest expense to reflect additional borrowings for the
properties acquired in the 1995 Acquisition from January 1, 1995 to June 12,
1995 (date of the 1995 Acquisition) and for the properties acquired in the 1996
Acquisition from January 1, 1995 to June 14, 1996 (date of the 1996
Acquisition). The adjustment also reflects adjusted interest expense due to the
Existing Debt. Also included is the amortization of estimated debt issuance
costs of $2,728,000 over a three-year period. A 1/8% change in interest rate on
the variable portion of such borrowings would result in a $115,000 change in
annual interest expense.
Incremental interest expense includes the following components:
<TABLE>
<CAPTION>
YEAR ENDED SIX MONTHS ENDED
DECEMBER 31, 1995 JUNE 30, 1996
----------------- -----------------
<S> <C> <C>
Additional interest on borrowings associated with the
1995 Acquisition for the period of January 1 to June
12, 1995 (Average rate 10.0%).......................... $ 2,350 $ --
Additional interest on borrowings for the 1996
Acquisition through June 14, 1996 (including Tranche B
interest ranging from 14% to 16.5%).................... 6,750 2,300
Adjustment of average interest rate on previously
existing debt and amortization of loan fees............ 946 532
------- ------
$ 10,046 $ 2,832
------- ------
------- ------
</TABLE>
(8) To reverse interest on the Existing Debt and to adjust interest expense
to reflect issuance of the Notes at 11.25% plus the amortization of estimated
debt issuance costs over 10 years ($385,000 annually).
NOTE 3. -- INCOME TAXES
Upon consummation of the Corporate Reorganization, the Company intends to
account for income taxes pursuant to the provisions of SFAS 109. At June 30,
1996, the pro forma tax basis of the Company's assets and liabilities exceeded
the pro forma book basis by approximately $5,000,000. The pro forma temporary
differences are primarily related to the differences in book and tax basis of
oil and gas properties due to the expensing of intangible development costs for
tax purposes and other income tax differences arising from the tax treatment of
oil and gas producing activities.
NOTE 4. -- NET LOSS PER SHARE
Net loss per share is calculated based on the pro forma weighted average
shares outstanding during the respective periods. Weighted average shares
reflect the pro forma issuance of 1,080,008 shares of Common Stock to NBCC on
February 17, 1995 and the pro forma issuance of 4,919,992 shares of Common Stock
to the remaining holders prior to January 1, 1995. In addition, the issuance of
4,000,000 shares in the Common Stock Offering is assumed to have taken place on
January 1, 1995 and assumes that the Underwriters' over-allotment option is not
exercised.
NOTE 5. -- SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION
The estimates of proved oil and gas reserves, which are located in the
United States, were prepared by the Company as of December 31, 1993, 1994 and
1995, and Williamson as of April 1, 1996. Reserves were estimated in accordance
with guidelines established by the Securities and Exchange Commission and FASB
which require that reserve estimates be prepared under existing economic and
operating conditions with no provision for price and cost escalations, except by
contractual arrangements. The Company has presented the pro forma reserve
estimates utilizing an oil price of $17.79 per Bbl and a gas price of $2.03 per
Mcf as of
22
<PAGE>
COSTILLA ENERGY, INC.
NOTES TO UNAUDITED PRO FORMA CONDENSED FINANCIAL STATEMENTS (CONTINUED)
NOTE 5. -- SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION (CONTINUED)
December 31, 1995, and an oil price of $20.91 per Bbl and a gas price of $2.02
per Mcf as of April 1, 1996. The pro forma information assumes that both the
1995 Acquisition and the 1996 Acquisition took place on January 1, 1995.
OIL AND GAS PRODUCING ACTIVITIES
Oil and gas reserve quantity estimates are subject to numerous uncertainties
inherent in the estimation of quantities of proved reserves and in the
projection of future rates of production and the timing of development
expenditures. The accuracy of such estimates is a function of the quality of
available data and of engineering and geological interpretation and judgment.
Results of subsequent drilling, testing and production may cause either upward
or downward revision of previous estimates. Further, the volumes considered to
be commercially recoverable fluctuate with changes in prices and operating
costs. The Company emphasizes that reserve estimates are inherently imprecise
and that estimates of new discoveries are more imprecise that those of currently
producing oil and gas properties. Accordingly, these estimates are expected to
change as additional information becomes available in the future.
<TABLE>
<CAPTION>
OIL AND GAS
CONDENSATE (MBBLS) (MMCF)
------------------- -----------
<S> <C> <C>
Balance, January 1, 1995.............................................. 17,990 115,281
Revisions of previous estimates..................................... (570) 425
Extensions and discoveries.......................................... 605 8,922
Production.......................................................... (2,085) (11,984)
------- -----------
Balance, December 31, 1995............................................ 15,940 112,644
Revisions of previous estimates..................................... 437 2,615
Extensions and discoveries.......................................... 592 296
Production.......................................................... (492) (2,634)
------- -----------
Balance, April 1, 1996................................................ 16,477 112,921
------- -----------
------- -----------
Proved Developed Reserves:
December 31, 1995................................................... 13,235 87,345
April 1, 1996....................................................... 13,552 84,369
</TABLE>
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS RELATING TO PROVED OIL
AND GAS RESERVES
The standardized measure of discounted future net cash flows is computed by
applying period-end prices of oil and gas (with consideration of price changes
only to the extent provided by contractual arrangements) to the estimated future
production of proved oil and gas reserves less estimated future production of
proved oil and gas reserves less estimated future expenditures (based on
period-end costs) to be incurred in developing and producing the proved
reserves, less estimated future income tax expenses (based on period-end
statutory tax rates, with consideration of future tax rates already legislated)
to be incurred on pretax net cash flows less tax basis of properties and
available credits, and assuming continuation of existing economic conditions.
The estimated future net cash flows are then discounted using a rate of 10% per
year to reflect the estimated timing of the future cash flows.
Discounted future cash flow estimates like those shown below are not
intended to represent estimates of the fair value of oil and gas properties.
Estimates of fair value should also consider probable reserves,
23
<PAGE>
COSTILLA ENERGY, INC.
NOTES TO UNAUDITED PRO FORMA CONDENSED FINANCIAL STATEMENTS (CONTINUED)
NOTE 5. -- SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION (CONTINUED)
anticipated future oil and gas prices, interest rates, changes in development
and production costs and risks associated with future production. Because of
these and other considerations, any estimate of fair value is necessarily
subjective and imprecise.
<TABLE>
<CAPTION>
DECEMBER 31, MARCH 31,
1995 1996
------------ --------------
(IN THOUSANDS)
<S> <C> <C>
Future cash flows........................................................ $ 516,515 $ 572,426
Future costs:
Production............................................................. (239,388) (253,348)
Development............................................................ (20,907) (22,076)
------------ --------------
Future net cash flows before income taxes (a)............................ 256,220 297,002
Future income taxes...................................................... (48,735) (63,418)
------------ --------------
Future net cash flows.................................................... 207,485 233,584
10% annual discount for estimated timing of cash flows................... (66,851) (76,359)
------------ --------------
Standardized measure of discounted net cash flows........................ $ 140,634 $ 157,225
------------ --------------
------------ --------------
</TABLE>
- ------------------------
(a) Present value of estimated future net cash flows, before income taxes would
be $155,984 and $179,527 as of December 31, 1995 and March 31, 1996,
respectively.
Changes in Standardized Measure of Discounted Future Net Cash Flows From Proved
Reserves:
<TABLE>
<CAPTION>
YEAR ENDED THREE MONTHS
DECEMBER 31, ENDED MARCH 31,
1995 1996
------------ ---------------
(IN THOUSANDS)
<S> <C> <C>
Increase (decrease):
Extensions and discoveries and improved recovery, net of future
production and development costs..................................... $ 9,598 $ 6,002
Accretion of discount................................................. 14,147 3,516
Net change in sales prices, net of production costs................... 2,992 20,807
Changes in estimated future development costs......................... (1,651) (238)
Revisions of quantity estimates....................................... (2,392) 4,694
Net change in income taxes............................................ 1,633 (9,563)
Sales, net of production costs........................................ (27,055) (7,264)
Changes of production rates (timing) and other........................ 1,893 (1,363)
------------ ---------------
Net increase (decrease)............................................. (835) 16,591
Standardized measure of discounted future net cash flows:
Beginning of period................................................... 141,469 140,634
------------ ---------------
End of period......................................................... $ 140,634 $ 157,225
------------ ---------------
------------ ---------------
</TABLE>
24
<PAGE>
SELECTED FINANCIAL INFORMATION
The following table sets forth selected financial data of Costilla Energy,
L.L.C. See "Management's Discussion and Analysis of Financial Condition and
Results of Operations." The historical information should be read in conjunction
with the Consolidated Financial Statements and the notes thereto included
elsewhere in this Prospectus. Costilla Energy, L.L.C. acquired significant
producing oil and gas properties in certain of the periods presented which
affect the comparability of the historical financial and operating information.
The historical results are not necessarily indicative of the Company's future
operations or financial results.
<TABLE>
<CAPTION>
SIX MONTHS ENDED
YEAR ENDED DECEMBER 31, JUNE 30,
----------------------------------------------------- --------------------
1991 1992 1993 1994 1995 1995 1996
--------- --------- --------- --------- --------- --------- ---------
(IN THOUSANDS, EXCEPT RATIOS)
<S> <C> <C> <C> <C> <C> <C> <C>
STATEMENT OF OPERATIONS DATA:
Operating revenues.......................... $ 1,623 $ 2,362 $ 4,231 $ 7,637 $ 21,693 $ 5,568 $ 19,445
Total revenues.............................. 2,134 2,887 4,397 7,836 21,816 5,573 19,525
Expenses:
Oil and gas production.................... 769 1,340 1,688 2,351 10,355 2,413 8,278
General and administrative................ 354 388 952 1,184 3,571 1,008 2,809
Compensation related to option
settlement............................... -- -- -- -- 656 656 --
Exploration and abandonments.............. 106 4 218 793 1,650 1,007 308
Depreciation, depletion and
amortization............................. 494 404 884 1,847 5,958 1,367 4,620
Interest.................................. 179 365 605 1,458 4,591 1,046 4,156
Other..................................... -- -- -- -- 2 -- --
--------- --------- --------- --------- --------- --------- ---------
Income (loss) before income taxes and
extraordinary item......................... 232 386 50 203 (4,967) (1,924) (646)
Net income (loss)........................... 234 368 73 163 (4,970) (1,924) (2,286)
STATEMENT OF CASH FLOWS DATA:
Net cash provided by (used in):
Operating activities...................... $ 276 $ 140 $ 322 $ 1,527 $ 6,366 $ (3,040) $ (122)
Investing activities...................... (2,659) (1,432) (6,731) (12,146) (62,467) (57,773) (49,723)
Financing activities...................... 2,440 1,450 6,315 10,618 58,830 62,094 48,143
OTHER FINANCIAL DATA:
Capital expenditures........................ $ 3,092 $ 3,720 $ 6,862 $ 11,868 $ 62,220 $ 57,773 $ 49,723
Distributions to members.................... -- -- 456 961 55 55 --
Adjusted EBITDA (1)......................... 1,011 1,159 1,757 4,301 7,232 1,496 8,438
Adjusted EBITDA/interest expense (1)........ 5.6x 3.2x 2.9x 2.9x 1.6x 1.4x 2.0x
Ratio of earnings to fixed charges (2)...... 1.3 1.5 1.0 1.1 -- -- --
BALANCE SHEET DATA (AS OF PERIOD END):
Working capital............................. $ (580) $ 185 $ 1,612 $ 1,081 $ 2,496 -- $ 4,266
Total assets................................ 4,602 6,675 13,290 24,904 87,367 -- 135,047
Total debt.................................. 3,610 5,352 12,034 23,613 71,494 -- 122,365
Redeemable members' capital................. -- -- -- -- 11,576 -- 13,171
Members' capital............................ 504 434 51 (747) (7,445) -- (11,326)
</TABLE>
- ------------------------------
(1) Adjusted EBITDA and the ratio of Adjusted EBITDA to interest expense are
presented because of their wide acceptance as financial indicators of a
company's ability to service or incur debt. Adjusted EBITDA (as used herein)
is calculated by adding interest, income taxes, depreciation, depletion and
amortization, exploration and abandonment costs and extraordinary loss
resulting from extinguishment of debt to net income (loss). The ratio of
Adjusted EBITDA to interest expense is calculated by dividing Adjusted
EBITDA by interest. Interest includes interest expense accrual and
amortization of deferred financing costs. Adjusted EBITDA and the ratio of
Adjusted EBITDA to interest expense should not be considered as alternatives
to earnings (loss), or operating earnings (loss), as defined by generally
accepted accounting principles, as indicators of the Company's financial
performance or to cash flow as a measure of liquidity.
(2) For purposes of calculating the ratio of earnings to fixed charges,
"earnings" are net income (loss) before extraordinary loss resulting from
extinguishment of debt, plus income taxes and fixed charges. Fixed charges
are comprised of interest on indebtedness, amortization of deferred
financing costs, and that portion of operating lease expense which is deemed
to be representative of an interest factor. Earnings were insufficient to
cover fixed charges by $4,967,000, $1,924,000 and $646,000 for the
historical periods ended December 31, 1995, June 30, 1995 and June 30, 1996,
respectively.
25
<PAGE>
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS
GENERAL
Costilla is an independent energy company engaged in the exploration,
acquisition and development of oil and gas properties. The Company's predecessor
began operating in 1988 and through mid-1995 had grown primarily through a
series of small acquisitions of oil and gas properties and the exploitation of
those properties. In June 1995, Costilla consummated the 1995 Acquisition for a
purchase price of approximately $46.6 million, and in June 1996, the 1996
Acquisition was consummated for a purchase price of approximately $42.5 million.
To date, the Company has achieved its high rate of growth primarily through
acquisitions. This has impacted its reported financial results in a number of
ways. Properties sold by others frequently have not received focused attention
prior to sale. After acquisition, certain of these properties are in need of
maintenance, workovers, recompletions and other remedial activity not
constituting capital expenditures, which substantially increase lease operating
expenses. The increased production and revenue resulting from these expenditures
is predominately realized in periods subsequent to the period of expense. In
addition, the rapid growth of the Company has required it to develop operating,
accounting and administrative personnel compatible with its increased size. The
Company believes it has now achieved a sufficient size to expand its reserve
base without a corresponding increase in its general and administrative expense.
The Company also believes it now has a sufficient inventory of prospects and the
professional staff necessary to follow a more balanced program of exploration
and exploitation activities to complement its acquisition efforts.
Costilla's strategy is to increase its oil and gas reserves, production and
cash flow from operations through a two-pronged approach which combines an
active exploration program with the acquisition and exploitation of proved
reserves. In addition, Costilla continues to evaluate the acquisition of
undeveloped acreage for its exploration efforts. Costilla has in-house
exploration expertise using 3-D seismic technology to identify new drilling
opportunities as well as for the exploitation of acquired properties.
Costilla has shown a significant increase in its oil and gas reserves,
production and Adjusted EBITDA, especially due to the 1995 Acquisition and the
1996 Acquisition. The following table sets forth certain operating data of
Costilla for the periods presented:
<TABLE>
<CAPTION>
SIX MONTHS ENDED
YEAR ENDED DECEMBER 31, JUNE 30,
------------------------------- --------------------
1993 1994 1995 1995 1996
--------- --------- --------- --------- ---------
<S> <C> <C> <C> <C> <C>
OIL AND GAS PRODUCTION:
Oil (MBbls).......................................... 158 330 950 233 709
Gas (Mmcf)........................................... 865 1,600 4,806 1,233 3,504
MBOE................................................. 302 597 1,751 438 1,293
AVERAGE SALES PRICES (1):
Oil (per Bbl)........................................ $ 16.93 $ 15.25 $ 15.53 $ 16.12 $ 18.93
Gas (per Mcf)........................................ 1.82 1.63 1.45 1.46 1.91
PRODUCTION COST (2):
Per BOE (3).......................................... $ 5.59 $ 3.94 $ 5.91 $ 5.51 $ 6.40
Per dollar of sales.................................. 0.40 0.31 0.48 0.43 0.43
DEPRECIATION, DEPLETION AND AMORTIZATION:
Per BOE.............................................. $ 2.93 $ 3.09 $ 3.40 $ 3.12 $ 3.57
Per dollar of sales.................................. 0.21 0.24 0.27 0.25 0.24
</TABLE>
- ------------------------------
(1) Before deduction of production taxes and net of hedging results.
(2) Excludes depreciation, depletion and amortization. Production cost includes
lease operating expenses and production and ad valorem taxes, if
applicable.
(3) Production costs per BOE in 1995 and for the six months ended June 30, 1996
were unusually high as a result of relatively high workover expenses with
respect to properties acquired in the 1995 Acquisition which did not
produce related production improvement until subsequent periods.
Additionally, the Company's 1995 production costs were adversely affected
by expenses incurred in connection with plugging wells to comply with
applicable regulatory requirements.
26
<PAGE>
Costilla uses the successful efforts method of accounting for its oil and
gas activities. Costs to acquire mineral interests in oil and gas properties, to
drill and equip exploratory wells that result in proved reserves, and to drill
and equip development wells are capitalized. Costs to drill exploratory wells
that do not result in proved reserves, geological, geophysical and seismic
costs, and costs of carrying and retaining unproved properties are expensed.
Capitalized costs of producing oil and gas properties, after considering
estimated dismantlement and abandonment costs and estimated salvage values, are
depreciated and depleted using the unit-of-production method. Unproved oil and
gas properties that are individually significant are periodically reviewed for
impairment of value, and a loss is recognized at the time of impairment by
providing an impairment allowance. Other unproved properties are amortized based
on the Company's experience of successful drilling and average holding period.
The Company utilizes option contracts to hedge the effect of price changes
on a portion of its future oil and gas production. Premiums paid and amounts
receivable under the option contracts are amortized and accrued to oil and gas
sales, respectively. If market prices of oil and gas exceed the strike price of
put options, the options will expire unexercised, therefore, reducing the
effective price received for oil and gas sales by the cost of the related
option. Conversely, if market prices of oil and gas decline below the strike
price of put options, the options will be exercised, therefore, increasing the
effective price received for oil and gas sales by the proceeds received from the
related option. The net effect of the Company's commodity hedging activities
reduced oil and gas revenues by $9,000, $80,000, $80,000 and $854,000 for the
years ended December 31, 1994 and 1995, and the six months ended June 30, 1995
and 1996, respectively, and increased oil and gas revenues by $71,000 for the
year ended December 31, 1993. See "Business and Properties -- Risk Management."
The Company utilizes interest rate swap agreements to reduce the potential
impact of increases in interest rates on floating-rate, long term debt. If
market rates of interest experienced during the applicable swap term are below
the rate of interest effectively fixed by the swap agreement, the rate of
interest incurred by the Company will exceed the rate that would have been
experienced under the Credit Agreement. The net effect of the Company's interest
rate hedging activities increased interest expense by $8,000 for the year ended
December 31, 1995 and $359,000 for the six months ended June 30, 1996.
The Company's predecessors were classified as partnerships for federal
income tax purposes. Therefore, no income taxes were paid or provided for by the
Company prior to the Offerings. Future tax amounts, if any, will be dependent
upon several factors, including but not limited to the Company's results of
operations.
RESULTS OF OPERATIONS
SIX MONTHS ENDED JUNE 30, 1996 COMPARED TO SIX MONTHS ENDED JUNE 30, 1995
The Company's total oil and gas revenues for the six months ended June 30,
1996 were $19,445,000, representing an increase of $13,877,000 (249%) over
revenues of $5,568,000 for the comparable period in 1995. This increase was
primarily due to the 1995 Acquisition which accounted for approximately
$12,300,000 of the revenue increase. Prior to accounting for the impact of the
1995 Acquisition and the 1996 Acquisition, the Company's total oil and gas
revenues for the six months ended June 30, 1996 increased by $658,000 (12%) over
the same period in 1995.
Oil and gas production was 1,293 MBOE in the 1996 period compared to 438
MBOE in the 1995 period. Of the 855 MBOE increase, approximately 800 MBOE was
due to the properties acquired in the 1995 Acquisition. The remainder of the
increase was due to a combination of successful drilling activities and the
enhancement of existing production.
Interest and other revenues were $40,000 for the six months ended June 30,
1996 compared to $5,000 for the comparable period in 1995, representing an
increase of $35,000, which was primarily comprised of an increase in interest
income of $33,000 in 1996 due to increased funds earning interest. Also in the
1996 period, the Company realized gains of $40,000 on various transactions for
which there were no comparable transactions for the six months ended June 30,
1995.
27
<PAGE>
Oil and gas production costs in the 1996 period were $8,278,000 ($6.40 per
BOE), compared to $2,413,000 in 1995 ($5.51 per BOE), representing an increase
of $5,865,000 (243%), due principally to the 1995 Acquisition. On a per BOE
basis, production costs increased $0.89 due primarily to costs incurred to
exploit the properties acquired in the 1995 Acquisition which did not produce
related production improvement for the full period.
General and administrative expense for the six months ended June 30, 1996
was $2,809,000, representing an increase of $1,801,000 (179%) from the
comparable period in 1995 of $1,008,000. The increase is primarily due to an
increase in personnel and related costs necessary to accommodate the increased
activities of the Company due to the 1995 Acquisition and in anticipation of the
1996 Acquisition.
Results of operations for the six months ended June 30, 1995 include
non-cash compensation expense of $656,000 deemed to have been accrued to a
minority owner of the Company in connection with the cancellation of an option
to purchase an additional interest in the Company held by the other minority
owner.
Exploration and abandonment expense decreased to $308,000 in the 1996 period
compared to $1,007,000 in 1995. The Company incurred $4,000 of seismic costs for
the six months ended June 30, 1996, compared to $514,000 which were incurred for
the comparable period in 1995. Dry hole costs decreased from $493,000 to
$304,000 for the comparable periods in 1995 and 1996, respectively.
Depreciation, depletion and amortization expense for the 1996 period was
$4,620,000 compared to $1,367,000 for the 1995 period, representing an increase
of $3,253,000 (238%). During 1996, depreciation, depletion and amortization on
oil and gas production was provided at an average rate of $3.57 per BOE compared
to $3.12 per BOE for 1995. The increase was due primarily to the 1995
Acquisition.
Interest expense was $4,156,000 in the 1996 period, compared to $1,046,000
for the comparable period in 1995. The $3,110,000 (297%) increase was
attributable primarily to increased levels of debt which the Company used to
finance the 1995 Acquisition. The average amounts of applicable interest-bearing
debt for the comparable periods in 1996 and 1995 were $77,646,000 and
$25,145,000, respectively.
Results of operations for the six months ended June 30, 1996 include an
extraordinary charge of $1,640,000 related to the early extinguishment of the
Company's previous credit agreement. The charge consisted of previously
capitalized debt issuance costs. The previous credit agreement was replaced by
the Existing Debt.
YEAR ENDED DECEMBER 31, 1995 COMPARED TO YEAR ENDED DECEMBER 31, 1994
The Company's total oil and gas revenues for 1995 were $21,693,000,
representing an increase of $14,056,000 (184%) over revenues of $7,637,000 in
1994. This increase was primarily due to the 1995 Acquisition which accounted
for approximately $13,373,000 of the revenue increase.
Oil and gas production was 1,751 MBOE in 1995 and 597 MBOE in 1994. Of the
1,154 MBOE increase, 1,099 MBOE was due to the properties acquired in the 1995
Acquisition.
Interest and other revenues were $123,000 in 1995 compared to $87,000 in
1994, representing an increase of $36,000 (41%), which was comprised of an
increase in interest income of $59,000 in 1995 due to an increased amount of
funds earning interest, partially offset by a decrease of other income of
$23,000. In 1994, the Company realized a gain of $112,000 on the sale of various
properties for which there were no comparable gains in 1995.
Oil and gas production costs in 1995 were $10,355,000 ($5.91 per BOE),
compared to $2,351,000 in 1994 ($3.94 per BOE), representing an increase of
$8,004,000 (340%). The major portion of the increase was due to increased
production associated with the 1995 Acquisition. In addition, certain acquired
properties required remedial workovers and other activity immediately following
acquisition resulting in unusual operating costs of approximately $600,000
during 1995. In addition, $1,605,000 of operating costs were incurred in
connection with properties acquired in late 1994.
28
<PAGE>
General and administrative expense for 1995 was $3,571,000, representing an
increase of $2,387,000 (202%) from 1994 expense of $1,184,000. The increase is
primarily due to an increase in personnel and related costs necessary to
accommodate the increased activities of the Company due to the 1995 Acquisition.
Results of operations for the year ended December 31, 1995 include non-cash
compensation expense of $656,000 deemed to have been accrued to a minority owner
of the Company in connection with the cancellation of an option to purchase an
additional interest in the Company held by the other minority owner.
Exploration and abandonment expense increased to $1,650,000 in 1995 compared
to $793,000 in 1994. The increase of $857,000 (108%) was comprised principally
of $790,000 of seismic costs.
Depreciation, depletion and amortization expense for 1995 was $5,958,000
compared to $1,847,000 for 1994, representing an increase of $4,111,000 (223%).
During 1995, depreciation, depletion and amortization on oil and gas production
was provided at an average rate of $3.40 per BOE compared to $3.09 per BOE for
1994. The increase was due primarily to the 1995 Acquisition.
Interest expense was $4,591,000 in 1995 compared to $1,458,000 in 1994. The
$3,133,000 (215%) increase was attributable to increased levels of debt which
the Company used to finance the 1995 Acquisition. The average amounts of
applicable interest-bearing debt in 1995 and 1994 were $49,972,000 and
$17,632,000, respectively.
YEAR ENDED DECEMBER 31, 1994 COMPARED TO YEAR ENDED DECEMBER 31, 1993
The Company's total oil and gas revenues for 1994 were $7,637,000,
representing an increase of $3,406,000 (81%) over revenues of $4,231,000 in
1993. The primary reason for the increase in revenues was due to two
acquisitions of properties in 1994, one of which occurred in January 1994 and
the other in October 1994.
Oil and gas production was 597 MBOE in 1994 and 302 MBOE in 1993. The
increase in production of 295 MBOE was principally due to the properties
acquired during 1994.
Interest and other revenues were $87,000 in 1994 compared to $56,000 in
1993. The increase of $31,000 was comprised of an increase in interest income of
$26,000 in 1994, due to increased funds earning interest, and an additional
$5,000 in other income.
Oil and gas production costs in 1994 were $2,351,000 ($3.94 per BOE),
compared to $1,688,000 in 1993 ($5.59 per BOE), representing an increase of
$663,000. The increase in production costs is primarily attributable to two
acquisitions in 1994.
In 1994, general and administrative expense was $1,184,000, representing an
increase of $232,000 (24%) from 1993 expense of $952,000. The increase is due to
an increase in personnel and costs related primarily to acquisitions made in
1994.
Exploration and abandonment expense increased to $793,000 in 1994 compared
to $218,000 in 1993. The increase of $575,000 (264%) was due to an increase in
non-productive wells drilled in 1994 compared to 1993.
Depreciation, depletion and amortization expense for 1994 was $1,847,000
compared to $884,000 for 1993, representing an increase of $963,000 (109%),
primarily due to increased production. During 1994, depreciation, depletion and
amortization expense on oil and gas production was provided at an average rate
of $3.09 per BOE compared to $2.93 per BOE for 1993. The increase was due to
increased drilling and development, and the acquisition of additional
properties.
Interest expense was $1,458,000 in 1994 compared to $605,000 in 1993. The
$853,000 increase was attributable to increased debt levels related primarily to
the Company's acquisition of additional oil and gas properties in 1994. The
average amount of applicable interest-bearing debt in 1994 and 1993 was
$17,632,000 and $8,258,000, respectively.
29
<PAGE>
LIQUIDITY AND CAPITAL RESOURCES
NET CASH USED IN OPERATING ACTIVITIES
For the six months ended June 30, 1996, net cash used in operating
activities decreased to $0.1 million from $3.0 million for the comparable period
in 1995. Cash provided by operations, before changes in operating assets and
liabilities, increased to $4.2 million from $0.1 million for the comparable
period in 1995 due primarily to the 1995 Acquisition and the increase in results
of operations therefrom.
NET CASH USED IN INVESTING ACTIVITIES
Net cash used in investing activities for the six months ended June 30, 1996
was $49.7 million. Approximately $42.5 million was used for the 1996
Acquisition, $5.2 million was used for other oil and gas expenditures and $2.0
million was used for other property and equipment. For the year ended December
31, 1995, net cash used in investing activities was $62.5 million. Approximately
$46.6 million was used for the 1995 Acquisition, $14.9 million for additional
acquisition of producing oil and gas properties and exploration and development
activities and $1.0 million primarily for other property and equipment.
NET CASH PROVIDED BY FINANCING ACTIVITIES
The Company entered into a $125.0 million senior credit agreement in June
1996, against which $122.0 million was initially funded. Approximately $74.5
million was for the extension and refinancing of prior debt, $42.5 million was
used for the 1996 Acquisition and approximately $5.0 million was used for
general corporate purposes.
CAPITAL SOURCES
Funding for the Company's business activities has historically been provided
by bank financings, cash flow from operations, private equity sales, property
divestitures and joint ventures with industry participants. The Company
completed a $10 million private equity placement in February 1995. Subsequently,
the 1995 Acquisition and the 1996 Acquisition were substantially funded by bank
financings. The Company plans to finance its continuing operations and execute
its business strategy with cash flow from operations, net proceeds from the
Offerings and borrowings under the Credit Facility.
While the Company regularly engages in discussions relating to potential
acquisitions, the Company has no present agreement, commitment or understanding
with respect to any such acquisition, other than the acquisition of undeveloped
acreage and royalty and overriding royalty interests in its normal course of
business. Any future acquisition may require additional financing and will be
dependent upon financing arrangements available at the time.
The Company believes that cash flow from operations will be sufficient for
anticipated operating and capital expenditure requirements. However, because
future cash flows and the availability of financing are subject to a number of
variables beyond the Company's control, there can be no assurance that the
Company's capital resources will be sufficient to maintain currently planned
levels of capital expenditures. The Company's historical and pro forma earnings
for the year ended December 31, 1995 and the six months ended June 30, 1996 were
insufficient to cover fixed charges. Although the Company's earnings were
insufficient to cover fixed charges for these periods, the Company does not have
covenants in the Indenture or the Credit Facility requiring it to maintain a
specific ratio of earnings to fixed charges. However, if the Company is unable
to generate sufficient cash flow from operations to service its debt, it may be
required to refinance all or a portion of its debt, including the Notes, or to
obtain additional financing. There can be no assurance that any such refinancing
would be possible or that any additional financing could be obtained. See "Risk
Factors -- Significant Leverage and Debt Service."
The Company has received a commitment from NationsBank of Texas, N.A. (the
"Bank") to provide the Credit Facility to the Company following the Offerings.
The Credit Facility will provide for a revolving line of credit with the
availability of funds and letters of credit being subject to a borrowing base
determination at least semi-annually. The borrowing base will provide for a
maximum availability of $50.0 million (which amount is also expected to be the
initial borrowing base), none of which is expected to be outstanding immediately
following the Offerings. Availability under the borrowing base is initially
limited to $20.0 million for working capital and $30.0 million for acquisitions
of oil and gas properties meeting certain criteria
30
<PAGE>
established by the Bank. Borrowings under the Credit Facility will bear interest
at the Company's option at a floating rate which is at or above the NationsBank,
N.A. prime rate or the LIBOR rate, depending on the percentage of committed
funds which have been borrowed. Interest will be payable quarterly and principal
will be amortized in twelve equal installments commencing two years following
the execution of definitive loan documents. Under the Credit Facility, the
Company will be obligated to pay certain fees to the Bank, including a
commitment fee based on the unused portion of the commitment. The Credit
Facility will contain customary restrictive covenants (including restrictions on
the payment of dividends and the incurrence of additional indebtedness) and will
require the Company to maintain a current ratio of not less than 1.0 to 1.0, a
ratio of Adjusted EBITDA to interest expense of not less than 2.0 to 1 and a
minimum tangible net worth. At June 30, 1996, on a pro forma basis, the
Company's current ratio would have been 2.7 to 1.0, the ratio of Adjusted EBITDA
to interest expense would have been 2.1 to 1 and the Company would have exceeded
the tangible net worth test by $1.4 million. The Company believes it will be in
compliance with such covenants on the date of closing of the Offerings.
Borrowings under the Credit Facility will be secured by substantially all of the
assets of the Company and any subsidiary of the Company that guarantees the
obligations of the Company under the Credit Facility. Initially, none of the
Company's subsidiaries will guarantee the obligations of the Company under the
Credit Facility. The Bank's commitment is subject to certain conditions,
including completion of the Offerings and the Corporate Reorganization and
application of the net proceeds therefrom to repay the Company's prior secured
indebtedness. See "Use of Proceeds."
Although certain of the Company's costs and expenses may be affected by
inflation, inflationary costs have not had a significant effect on the Company's
results of operations.
CAPITAL EXPENDITURES
The Company requires capital primarily for the exploration, development and
acquisition of oil and gas properties, the repayment of indebtedness and general
working capital needs.
The following table sets forth costs incurred by the Company in its
development, exploration and acquisition activities during the periods
indicated.
<TABLE>
<CAPTION>
SIX MONTHS
YEAR ENDED DECEMBER 31, ENDED
------------------------------- JUNE 30,
1993 1994 1995 1996
--------- --------- --------- -----------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Development costs.......................................... $ -- $ -- $ 158 $ 607
Exploration costs.......................................... 2,017 2,167 5,627 3,881
Acquisition costs:
Unproved properties...................................... 829 1,232 1,742 1,712
Proved properties........................................ 4,665 9,649 52,470 41,791
--------- --------- --------- -----------
Total.................................................. $ 7,511 $ 13,048 $ 59,997 $ 47,991
--------- --------- --------- -----------
--------- --------- --------- -----------
</TABLE>
The Company anticipates that costs incurred for 1996 will be approximately
$64.8 million, of which approximately $42.5 million was expended for the 1996
Acquisition, and approximately $5.2 million was expended for acquisition,
exploration and development activities during the six months ended June 30,
1996.
DELIVERY COMMITMENT
In November 1995, the Company entered into gas sales agreements whereby it
committed to delivery of a total of 2,379,000 Mmbtu, from December 1, 1995
through December 1, 1996, for a total fixed price of $3,429,610. Income from the
agreements is recognized in the period of delivery.
31
<PAGE>
BUSINESS AND PROPERTIES
GENERAL
Costilla is an independent energy company engaged in the exploration,
acquisition and development of oil and gas properties. The Company's primary
operations are in the Permian Basin area of Texas and New Mexico, the Gulf Coast
and the Rocky Mountain regions. The Company's strategy focuses on increasing
reserves through targeted exploration programs, the exploitation of its existing
properties and selective property acquisitions. In addition, the Company
recently acquired an interest in an entity which has a concession for the
development of mineral interests in the Republic of Moldova, in Eastern Europe.
The Company also has minor interests in the domestic gas gathering and
transmission business.
The Company's predecessor began operating in 1988 with the strategy of
acquiring and exploiting undervalued oil and gas properties, and at December 31,
1992 had net proved reserves of 4.7 MMBOE. Since January 1, 1993, the Company
has successfully closed seven transactions for an aggregate purchase price of
approximately $101 million. As of April 1, 1996, the Company had total estimated
net proved reserves of 16.5 Mmbbls of oil and 112.9 Bcf of gas, aggregating 35.3
MMBOE, with a PV-10 Value of approximately $179.5 million, assuming the 1996
Acquisition had occurred at April 1, 1996. The Company also has a substantial
undeveloped acreage position consisting of 180,704 gross (165,166 net) acres at
June 30, 1996. The Company has identified in excess of 185 drilling locations of
which 64 are included in its proved reserves.
Costilla has in-house exploration expertise which uses 3-D seismic
technology as a primary tool to identify drilling opportunities and has
experienced high rates of success in each of its first two major 3-D seismic
drilling programs. Since 1994, the Company has drilled 37 wells based on these
3-D surveys, 31 of which have been productive. The Company has recently
completed two additional 3-D surveys and intends to commence drilling on one of
these acreage blocks in the second half of 1996. The Company currently plans to
drill 63 wells through 1997 based on its 3-D surveys.
Since 1993, Costilla has generated significant growth in reserves,
production and Adjusted EBITDA. The Company increased its estimated proved
reserves from 6.0 MMBOE at December 31, 1993 to 35.3 MMBOE at April 1, 1996 (pro
forma for the 1996 Acquisition), representing a compound annual growth rate of
114%. This reserve growth has been achieved at an average all-in finding cost of
$3.60 per BOE over such period, a level which the Company believes is lower than
industry averages. Concurrently, the Company increased its average net daily
production from 827 BOE for the year ended December 31, 1993 to 10,231 BOE for
the three months ended March 31, 1996 (pro forma for the 1996 Acquisition),
representing a compound annual growth rate of 190%. Adjusted EBITDA increased at
a 234% compound annual growth rate from $1.8 million for 1993 to $20.2 million
for 1995 (pro forma for the 1995 Acquisition and the 1996 Acquisition).
BUSINESS STRATEGY
The Company's strategy is to increase its oil and gas reserves, production
and cash flow from operations through a two-pronged approach which combines an
active exploration program using 3-D seismic and other technological advances
with the acquisition and exploitation of producing properties. The Company seeks
to reduce its operating and commodity risks by holding a geographically diverse
portfolio of properties, the reserves attributable to which are approximately
balanced between oil and gas. The Company also seeks to manage the elements of
its business strategy through the operation of a significant portion of its
properties, the use of a rate of return analysis and the direct marketing and
hedging of its oil and gas production. The elements of the Company's strategy
may be further described as follows:
- EXPLORATION EFFORTS. The Company uses extensive geological and
geophysical analysis to carefully focus its 3-D seismic surveys. This
focus allows the Company to successfully direct the size and scope of its
exploration program in order to improve the likelihood of success while
managing overall exploration costs. The Company's exploration efforts are
concentrated currently on known producing
32
<PAGE>
regions. The Company plans to drill 24 exploratory wells during the last
half of 1996 and 36 exploratory wells in 1997. Capital budgeted for
exploration activities is $8.1 million for the last six months of 1996 and
$10.8 million for 1997.
- EXPLOITATION ACTIVITIES. The Company is actively pursuing numerous
exploitation opportunities within its existing properties, including areas
where no proved reserves are currently assigned. Exploitation activities
currently in progress include a carbon dioxide flood, recompletions,
workovers, infill and horizontal drilling and a secondary recovery
project. The Company's capital budget for such activities is $8.4 million
for the last six months of 1996 and $9.2 million for 1997, which includes
the drilling of 12 development wells in 1996 and 13 development wells in
1997.
- PROPERTY ACQUISITIONS. The Company seeks to acquire producing properties
where it has identified opportunities to increase production and reserves
through both exploitation and exploration activities. The Company has
increased the value of its acquisitions by aggressively managing the
operations of existing proved properties and by successfully identifying
and developing previously unproved reserves on acquired acreage. The
Company seeks to acquire reserves which will fit its existing portfolio,
are generally not being actively marketed and where a negotiated sale
would be the method of purchase. The Company does not rely on major oil
company divestitures or property auctions.
- PROPERTY DIVERSIFICATION. The Company holds a portfolio of oil and gas
properties located in the Permian Basin, the Gulf Coast and the Rocky
Mountain regions. The Company believes that by conducting its activities
in distinct regions it is able to reduce commodity price and other
operational risks. The Company's Moldovan interest is an extension of this
strategy and can be characterized by low initial costs, significant
reserve potential and the availability of technical data that may be
further developed by the Company.
- CONTROL OF OPERATIONS. The Company prefers to operate and own the
majority working interest in its properties. This allows the Company
greater control over future development, drilling, completing and lifting
costs and marketing of production. At April 1, 1996, the Company operated
wells constituting approximately 72% of its total PV-10 Value (pro forma
for the 1996 Acquisition).
SIGNIFICANT ACQUISITIONS
1995 ACQUISITION. In a $46.6 million acquisition completed in June 1995,
the Company acquired a group of oil and gas properties located in the Permian
Basin, Gulf Coast and Rocky Mountain regions. At the date of acquisition, the
net proved reserves included 7.1 Mmbbls of oil and 44.1 Bcf of gas, aggregating
14.4 MMBOE. From the date of acquisition until March 31, 1996, the Company
produced 1.5 MMBOE from the acquired properties and sold a portion of the
acquired properties for approximately $3.6 million. At April 1, 1996, the net
proved reserves of the remaining properties were 13.4 MMBOE. The acquired
properties also included 103,010 gross (93,787 net) undeveloped acres.
1996 ACQUISITION. In June 1996, the Company acquired a group of oil and gas
properties located primarily in the Permian Basin and Gulf Coast regions for
approximately $42.5 million. This acquisition included properties with net
proved reserves at April 1, 1996 of 5.0 Mmbbls of oil and 33.5 Bcf of gas,
aggregating 10.6 MMBOE. The acquired properties also included 42,855 gross
(16,646 net) undeveloped acres and a pipeline located in Pennsylvania which had
an allocated purchase price of $3.5 million.
33
<PAGE>
PRINCIPAL PROPERTIES
The following table sets forth certain information, as of April 1, 1996 (pro
forma for the 1996 Acquisition), which relates to the principal oil and gas
properties owned by the Company.
<TABLE>
<CAPTION>
PROVED RESERVES
-------------------------------------------------------------
TOTAL OIL PERCENT OF
GROSS OIL GAS EQUIVALENT TOTAL OIL
REGION WELLS (MBBLS) (MMCF) (MBOE) EQUIVALENT
- ------------------------------------------------------------ --------- ----------- --------- ----------- -------------
<S> <C> <C> <C> <C> <C>
Permian Basin............................................... 1,890 9,200 55,200 18,400 52.1%
Gulf Coast.................................................. 968 2,054 38,440 8,461 24.0
Rocky Mountain.............................................. 236 4,526 12,886 6,674 18.9
Other....................................................... 428 697 6,395 1,762 5.0
--------- ----------- --------- ----------- -----
Total....................................................... 3,522 16,477 112,921 35,297 100.0%
--------- ----------- --------- ----------- -----
--------- ----------- --------- ----------- -----
</TABLE>
PERMIAN BASIN. At April 1, 1996, 52.1% of the Company's proved reserves
were concentrated in the Permian Basin, an approximately 70-county region in
West Texas and Southeast New Mexico. The Company's production comes from well
known fields such as the Spraberry Trend, Sawyer Canyon, Goldsmith Unit and
Susan Peak. The majority of the Company's producing intervals in the Permian
Basin range from 4,500 feet to 9,500 feet in depth.
The Company has several exploratory projects in the Permian Basin based
primarily on 3-D seismic surveys. The most significant include:
EDWARDS/MCELROY RANCH PROSPECT, ECTOR AND CRANE COUNTIES, TEXAS. Costilla
has identified 68 drilling locations on the Company's 11,513 gross (5,066 net)
acres in this prospect based on 3-D seismic data. Since January 1, 1996, the
Company has drilled seven successful wells on this prospect, three of which have
resulted in three separate field discoveries. In addition, these wells have
confirmed the Strawn and Wolfcamp trends defined by the Company's extensive
approximate 50-square mile 3-D seismic project undertaken jointly with Texaco
Exploration and Production Inc. ("Texaco"). One additional well is being drilled
on seismic delineated features. The Company plans to drill 21 wells in this
trend through 1997. The Company's working interest in this prospect is
approximately 44%.
Costilla and Texaco are also developing a Queen Sand field identified from
the Edwards/McElroy Ranch seismic program. The four producing wells drilled
through June 30, 1996 are producing an aggregate of approximately 80 Bbls of oil
per day and the Company has participated in the drilling of two additional
productive wells subsequent to June 30, 1996. Drilling of six additional Queen
Sand wells is anticipated through 1997, with the field ultimately being
developed on a planned waterflood pattern in order to maximize recovery of the
oil in place.
MCGYVER-GREEN ACRES PROSPECT, HOWARD COUNTY, TEXAS. The Company has
identified 34 drilling locations in this prospect based on information derived
from approximately 30 square miles of 3-D seismic data that the Company acquired
on the area in 1994. The Talbot Fuller well was the first well drilled by the
Company on this prospect and was completed in the Canyon Lime formation at 8,200
feet in August 1994. From completion to June 30, 1996, the well produced 61
MBbls of oil and 238 Mmcf of gas, and had average capacity of 71 Bbls of oil per
day and 278 Mcf of gas per day during June 1996. Subsequent to the first well,
16 additional wells have been drilled on this prospect of which 13 are
productive. The Company is drilling or intends to drill five additional wells
during the balance of 1996 on its 9,801 gross (7,057 net) acres. The Company's
working interest in this prospect averages approximately 72%.
The following two 3-D programs currently being undertaken by the Company in
the Permian Basin are expected to provide additional drilling locations:
WILSON RANCH 3-D PROJECT, PECOS COUNTY, TEXAS. The Wilson Ranch is located
in northeastern Pecos County, approximately 10 miles west of the Yates field.
The Company recently completed an approximate 17-square mile seismic survey on
the project. A second phase will be initiated in the first quarter of 1997. The
34
<PAGE>
project presents several potential exploration targets, including the Queen, San
Andres, Wolfcamp, Devonian and Ellenberger formations, found at depths ranging
from 1,600 to 8,000 feet. The Company has agreed to lease 3,750 gross acres on
this 50,000 acre ranch. Upon acquiring the lease, the Company intends to sell up
to one-half of its approximate 75% working interest to a major oil company. The
Company believes that there is significant additional potential in this area.
DAVAN UNIT 3-D PROJECT, STONEWALL COUNTY, TEXAS. The Company has completed
another 3-D seismic project with Texaco to further develop the Company-operated
Davan Unit. The project involves a 3-D seismic evaluation of approximately 3,200
gross acres adjacent to a Company-operated waterflood which has produced in
excess of three Mmbbls of oil. An exploratory well is scheduled on this prospect
for the first quarter of 1997.
Two examples of the Company's current exploitation efforts in the Permian
Basin include:
EAST GOLDSMITH FIELD C02 PROJECT, ECTOR COUNTY, TEXAS. The Company owns
3,053 gross (2,656 net) acres in this field located 20 miles northwest of
Midland, Texas. Since its discovery, the field has produced in excess of 20
Mmbbls of oil from seven formations. The most productive zones in the East
Goldsmith Field have been the San Andres and Holt formations, both of which have
been subject to secondary recovery by waterflooding. The Company has been
analyzing a tertiary recovery project in those formations using CO2, and intends
to initiate the project in the fourth quarter of 1996. The Company's working
interest in this project averages approximately 87%.
SUSAN PEAK FIELD WORKOVER AND HORIZONTAL DRILLING PROGRAM, TOM GREEN COUNTY,
TEXAS. The Company recently completed the first horizontal well in this field
located south of San Angelo, Texas, in which it owns a 100% working interest
until payout. Production from this well drilled in the Strawn formation was
approximately 68 Bbls of oil per day and 225 Mcf of gas per day in July 1996.
With only two workovers and the new horizontal well, the Company has increased
Susan Peak production from approximately 31 Bbls of oil per day and 760 Mcf of
gas per day in the last half of 1995 to an average rate of approximately 126
Bbls of oil per day and 1,330 Mcf of gas per day in July 1996. Two possible
horizontal drilling locations and additional workover candidates remain on this
7,461 gross (3,730 net) acre lease. The Company's working interest in this
project is 50%.
GULF COAST. At April 1, 1996, 24.0% of the Company's proved reserves were
concentrated in the Gulf Coast region. The Company's production in this region
primarily comes from known formations such as Frio, Yegua, Austin Chalk and
Wilcox.
The Company plans to use its expertise in aggressively developing 3-D
opportunities on the extensive acreage position it holds in the region. Examples
of such exploration projects in progress include:
SEALY PROSPECT, AUSTIN COUNTY, TEXAS. The Sealy Field, consisting of 3,534
gross and net acres, was acquired in the 1995 Acquisition. The Wilcox formation
in this field has produced over 66 Bcf of gas and there are subsurface
indications of the presence of several fault blocks that lie untested. The
Company's working interest in this prospect is 100%. The Company is currently
attempting to acquire additional acreage in this prospect prior to initiating a
3-D survey in late 1996 or 1997.
SOUTHWEST SPEAKS, LAVACA COUNTY, TEXAS. This project, consisting of 5,078
gross (2,539 net) acres, was also acquired in the 1995 Acquisition and is held
by several shallow Company-operated wells. Multiple producing horizons from
shallow depths to below 14,000 feet have produced over 122 Bcf of gas from this
highly faulted field. A recent well was completed in the Rainbow Wilcox sand on
acreage adjoining Costilla's lease. A well, in which Costilla holds a 5%
interest as a result of a farmout, has also been completed on Costilla's lease.
The Company's plans are to conduct a 3-D survey in the Speaks area in late 1996
or 1997. The Company's working interest in this prospect is approximately 50%.
BORCHERS FIELD, LAVACA COUNTY, TEXAS. This field was acquired by the
Company in the 1996 Acquisition. The property is on trend with the Speaks
project and is also a highly faulted field providing opportunity for
35
<PAGE>
further development. The Company's lease in the Borchers field area has produced
a total of 21.2 Bcf of gas from two Wilcox sands. Costilla has a 100% working
interest in this field consisting of 1,322 gross and net acres. The Company
plans to conduct a 3-D survey in the Borchers field in 1997.
Examples of exploitation activities in this region include:
JOSEY RANCH LEASE, HARRIS COUNTY, TEXAS. Two examples of the Company's
production enhancement of Gulf Coast properties were undertaken on this
prospect. When the lease was acquired in the 1995 Acquisition, production had
nearly ceased. Through a series of workovers, the Company has improved daily
capacity, as of June 30, 1996, to 63 Bbls of oil per day and 73 Mcf of gas per
day. In addition, Costilla has participated in a 10,900 foot test well on the
Josey Ranch lease to test the Wilcox formation. The well was completed in April
1996 and has consistently produced approximately 1,000 Mcf of gas per day. The
Josey Ranch lease covers 1,661 gross (650 net) acres, and the Company's working
interest in this prospect is approximately 39%.
PERSONVILLE, LIMESTONE COUNTY, TEXAS. The Company has recently completed an
11,000 foot Cotton Valley well, which is producing 2.8 Mmcf of gas per day. The
Company is currently drilling an additional well on this prospect. Costilla
leases 411 gross (119 net) acres in this prospect, and has identified one
additional drilling location. The Company is the operator of this prospect and
its working interest is approximately 29%.
AUSTIN CHALK, BRAZOS, BURLESON, FAYETTE AND LEE COUNTIES, TEXAS. Costilla
acquired the majority of the working interest in nine gross Austin Chalk wells
in the 1995 Acquisition and an additional 80 gross Austin Chalk wells were
included in the 1996 Acquisition. The Company intends to enhance production on
certain of these wells through stimulation and workover activities, and analyze
further development potential. Costilla has 30,414 gross (20,985 net) acres in
the Austin Chalk area, and its working interest in this area averages
approximately 69%.
ROCKY MOUNTAIN. At April 1, 1996, 18.9% of the Company's proved reserves
were concentrated in the Rocky Mountain region, which includes Montana, North
Dakota, Wyoming, Colorado and Utah.
The Company has a number of opportunities in the Rocky Mountain region
involving 3-D seismic surveys, exploratory drilling and exploitation activities.
Examples of each of these opportunities are:
RAYMOND FIELD, SHERIDAN COUNTY, MONTANA. Since its discovery in 1972, the
Raymond Field has produced over five Mmbbls of oil from five different
formations. Daily production from the field has increased from 179 Bbls of oil
per day since its acquisition in June 1995 to 368 Bbls of oil per day in June
1996 primarily as a result of the Company's improved operations. The Company
plans a 3-D program on its 960 gross and net acres in this field. The Company
owns a 100% working interest in this prospect.
OUTLOOK FIELD, SHERIDAN COUNTY, MONTANA. The Company undertook its first
Rocky Mountain 3-D seismic survey in the Outlook area to further develop the
field. Three drilling locations were identified from the data. The Company
anticipates commencing an Outlook test well in October 1996 that will be drilled
to 10,500 feet, a depth sufficient to test several different formations.
Costilla leases 5,169 gross (1,292 net) acres in the Outlook prospect, and owns
an approximate 25% working interest in this prospect.
NATURAL BUTTES FIELD, UINTAH COUNTY, UTAH. The Company owns a 100% working
interest in 4,640 gross and net acres in this prospect. Development by prior
owners was on 640-acre spacing while offset acreage has been developed on
80-acre spacing. Low gas prices in the area have precluded the assignment of
proved reserves to any undeveloped acres. As gas prices improve, the Company
plans to drill additional wells on the prospect.
The Company owns an interest in significant acreage positions in the Rocky
Mountain region which are operated by third parties and are the subject of
active exploitation efforts. The most significant property is:
CIRCLE RIDGE FIELD, FREMONT COUNTY, WYOMING. The Circle Ridge Field, in
which the Company has an approximate 18% working interest, is operated by
Marathon Oil Company. This field is an approximate 1,100 acre waterflood located
in the Wind River Basin of Wyoming, approximately 30 miles north of
36
<PAGE>
Riverton, Wyoming. There are 97 active producing wells and 10 active injection
wells in the field. Production originates from the Phosphoria, Tensleep and
Amsden formations that are present at depths ranging from 500 to 2,000 feet.
Since January 1995, 45 projects have been completed in the field. These projects
include recompletions, stimulation treatments and reactivations, which have
increased production from 1,469 Bbls of oil per day in January 1995 to a rate of
1,778 Bbls of oil per day for June 1996. The operator has several other projects
scheduled for the remainder of 1996 and is evaluating various different methods
of enhanced oil recovery for the field.
MARKETING ARRANGEMENTS
The Company utilizes an active marketing program for a portion of its crude
oil production in order to enhance the net price it receives. The Company sells
its crude oil production from operated properties in North Dakota, Montana and
Wyoming, at the lease level to an oil transportation company for the posted
price, plus an agreed upon bonus, with a corresponding agreement to repurchase
this production at its delivery point (typically, Cushing, Oklahoma) for a price
equal to the then posted price for West Texas Intermediate crude oil less an
agreed upon deduction for transportation and quality differentials, if any,
between the repurchased crude oil and West Texas Intermediate crude oil. The
Company then employs a broker to resell its crude oil to end users (such as
refineries) on a month-to-month basis. The lease level sales and repurchase
contracts are typically of six months duration. With respect to its other
operated oil production (primarily located in Texas), the Company employs a
similar price enhancement strategy, although the repurchase feature is absent.
Instead, the lease level purchaser resells the crude oil to end users at the
delivery point for the account of the Company. While these arrangements have the
effect of increasing the net price the Company receives for its crude oil, such
arrangements do not have the effect of limiting the Company's exposure to
movements in crude oil prices. The Company markets its gas production at the
lease level pursuant to month-to-month contracts. Phibro Energy USA, Inc.'s
purchases of the Company's oil production for the year ended December 31, 1995
accounted for 17.7% of the Company's 1995 consolidated revenue. Because of the
number of crude oil purchasers, the Company does not anticipate any difficulty
in replacing Phibro Energy USA, Inc.
RISK MANAGEMENT
The Company typically employs a strategy of purchasing put options on a
portion of its anticipated oil and gas production. This strategy is designed to
protect the Company from significant downward movements in commodity prices
while preserving the benefit of rising prices. The Company does not establish
hedges in excess of its anticipated production. Upon consummation of the
Offerings, substantially all of the Company's debt will be fixed rate. The
Company's current position with regard to its 1996 commodity hedges is as
follows:
OIL SALES. The Company has purchased put options to provide a floor price
for 3,000 Bbls of oil per day of its oil production for August 1996 through
December 1996. These put options currently in place represent approximately 52%
of the Company's estimated oil production for August 1996 through December 1996.
The floor price the Company has an agreement to receive is $18.00 per Bbl,
irrespective of the prices actually paid by purchasers of the oil at the lease
level.
GAS SALES. The Company has purchased put options which provide a floor
price for 900,000 Mmbtu's per month of its gas production through October 1996.
The put options currently in place represent approximately 84% of the Company's
estimated gas production for July 1996 through October 1996. The floor prices
with respect to such put options varies from $1.65 to $1.75 per Mmbtu depending
on the area in which the gas is produced.
37
<PAGE>
OIL AND GAS RESERVES
The Company's estimated total proved and proved developed reserves of oil
and gas as of December 31, 1993, 1994 and 1995, and as of April 1, 1996 were as
follows:
<TABLE>
<CAPTION>
AS OF DECEMBER 31,
---------------------------------------------------------------------- PRO FORMA
APRIL 1,
1993 1994 1995 1996 (1)
---------------------- ---------------------- ---------------------- ----------------------
OIL GAS OIL GAS OIL GAS OIL GAS
(MBBLS) (MMCF) (MBBLS) (MMCF) (MBBLS) (MMCF) (MBBLS) (MMCF)
----------- --------- ----------- --------- ----------- --------- ----------- ---------
<S> <C> <C> <C> <C> <C> <C> <C> <C>
Proved developed producing....... 1,785 13,268 2,632 15,757 8,338 50,542 13,122 76,439
Proved developed non-producing... 0 0 0 583 228 6,851 430 7,930
Proved undeveloped............... 580 8,351 1,377 11,172 2,222 20,759 2,925 28,552
----- --------- ----------- --------- ----------- --------- ----------- ---------
Total proved................... 2,365 21,619 4,009 27,512 10,788 78,152 16,477 112,921
----- --------- ----------- --------- ----------- --------- ----------- ---------
----- --------- ----------- --------- ----------- --------- ----------- ---------
</TABLE>
- ------------------------
(1) Assumes that the 1996 Acquisition had been consummated at April 1, 1996.
The following table sets forth the future net cash flows from the Company's
estimated proved reserves:
<TABLE>
<CAPTION>
DECEMBER 31, PRO FORMA
-------------------------------- APRIL 1,
1993 1994 1995 1996 (1)
--------- --------- ---------- -----------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Future net cash flows before income taxes.......................... $ 47,213 $ 68,596 $ 188,337 $ 297,002
Future net cash flows before income taxes, discounted at 10%....... $ 26,377 $ 36,779 $ 113,296 $ 179,527
</TABLE>
- ------------------------
(1) Assumes that the 1996 Acquisition had been consummated at April 1, 1996.
The reserve estimates reflected above for 1993, 1994 and 1995 were prepared
by the Company. The Company's 1995 estimates of gross reserves with respect to
certain of the Company's producing properties were subject to a limited review
by Williamson of the Company's engineering analysis covering approximately 54.0%
of the Company's proved reserves at such date. The pro forma estimates for April
1, 1996, including the properties acquired in the 1996 Acquisition, were
prepared by Williamson and are part of reports on the Company's oil and gas
properties prepared by Williamson, a summary of which is set forth herein as
Appendix A.
The reserve data set forth herein present estimates only. In general,
estimates of economically recoverable oil and gas reserves and of the future net
revenues therefrom are based upon an number of variable factors and assumptions,
such as historical production from the subject properties, the assumed effects
of regulation by governmental agencies and assumptions concerning future oil and
gas prices and future operating costs, all of which may vary considerably from
actual results. All such estimates are to some degree speculative, and
classifications of reserves are only attempts to define the degree of
speculation involved. For these reasons, estimates of the economically
recoverable oil and gas reserves attributable to any particular group of
properties, classifications of such reserves based on risk of recovery and
estimates of the future net revenues expected therefrom, prepared by different
engineers or by the same engineers at different times, may vary substantially.
The Company therefore emphasizes that the actual production, revenues, severance
and excise taxes, development and operating expenditures with respect to its
reserves will likely vary from such estimates, and such variances could be
material.
Estimates with respect to proved reserves that may be developed and produced
in the future are often based upon volumetric calculations and upon analogy to
similar types of reserves rather than actual production history. Estimates based
on these methods are generally less reliable than those based on actual
production history. Subsequent evaluation of the same reserves based upon
production history will result in variations, which may be substantial, in the
estimated reserves.
38
<PAGE>
In accordance with applicable requirements of the Securities and Exchange
Commission (the "Commission"), the estimated discounted future net revenues from
estimated proved reserves are based on prices and costs as of the date of the
estimate unless such prices or costs are contractually determined at such date.
Actual future prices and costs may be materially higher or lower. Actual future
net revenues also will be affected by factors such as actual production, supply
and demand for oil and natural gas, curtailments or increases in consumption by
natural gas purchasers, changes in governmental regulations or taxation and the
impact of inflation on costs.
EXPLORATION AND DEVELOPMENT ACTIVITIES
The Company drilled, or participated in the drilling of, the following
number of wells during the periods indicated. At June 30, 1996, the Company was
in the process of drilling two gross (0.49 net) wells and was in the process of
completing three gross (1.22 net) wells as producers which are not reflected in
the following table.
<TABLE>
<CAPTION>
1993 1994 1995
---------------------- ---------------------- ----------------------
GROSS NET GROSS NET GROSS NET
----------- --------- ----------- --------- ----------- ---------
<S> <C> <C> <C> <C> <C> <C>
Exploratory:
Productive......................................... 3 0.83 9 2.27 10 4.58
Dry................................................ 2 1.06 10 3.73 6 2.57
--- --- --- --- --- ---
Total............................................ 5 1.89 19 6.00 16 7.15
--- --- --- --- --- ---
--- --- --- --- --- ---
Development:
Productive......................................... -- -- -- -- 1 0.44
Dry................................................ -- -- -- -- -- --
--- --- --- --- --- ---
Total............................................ -- -- -- -- 1 0.44
--- --- --- --- --- ---
--- --- --- --- --- ---
Total:
Productive......................................... 3 0.83 9 2.27 11 5.02
Dry................................................ 2 1.06 10 3.73 6 2.57
--- --- --- --- --- ---
Total............................................ 5 1.89 19 6.00 17 7.59
--- --- --- --- --- ---
--- --- --- --- --- ---
<CAPTION>
SIX MONTHS
ENDED
JUNE 30,
1996
----------------------
GROSS NET
----------- ---------
<S> <C> <C>
Exploratory:
Productive......................................... 3 1.74
Dry................................................ 1 0.72
--- ---
Total............................................ 4 2.46
--- ---
--- ---
Development:
Productive......................................... 4 1.98
Dry................................................ -- --
--- ---
Total............................................ 4 1.98
--- ---
--- ---
Total:
Productive......................................... 7 3.72
Dry................................................ 1 0.72
--- ---
Total............................................ 8 4.44
--- ---
--- ---
</TABLE>
The Company does not own any drilling rigs and all of its drilling
activities are conducted by independent contractors under standard drilling
contracts.
PRODUCTIVE WELL SUMMARY
The following table sets forth the Company's gross and net interests in
productive oil and gas wells as of June 30, 1996. Productive wells are producing
wells and wells capable of production.
<TABLE>
<CAPTION>
ACTUAL (1)
--------------------
GROSS NET
--------- ---------
<S> <C> <C>
Oil wells....................................................................................... 2,248 678.54
Gas wells....................................................................................... 1,278 231.11
--------- ---------
Total....................................................................................... 3,526 909.65
--------- ---------
--------- ---------
</TABLE>
- ------------------------
(1) Does not include royalty and overriding royalty interests owned by Statewide
or the Company. See "-- Other Activities -- Minerals Acquisition Program."
In addition, one well with multiple completions is counted as a single well.
39
<PAGE>
ACREAGE
The following table sets forth certain information regarding the Company's
developed and undeveloped leasehold acreage as of June 30, 1996. Acreage in
which the Company's interest is limited to royalty, overriding royalty, mineral
and similar interests (such as all acreage owned by Statewide) is excluded.
<TABLE>
<CAPTION>
DEVELOPED UNDEVELOPED TOTAL
-------------------- -------------------- --------------------
REGION GROSS NET GROSS NET GROSS NET
- ------------------------------------------------ --------- --------- --------- --------- --------- ---------
<S> <C> <C> <C> <C> <C> <C>
Permian Basin................................... 126,091 50,151 65,741 59,669 191,832 109,820
Gulf Coast...................................... 197,650 65,547 46,040 39,713 243,690 105,260
Rocky Mountain.................................. 8,534 6,126 24,757 24,650 33,291 30,776
Other........................................... 43,651 26,108 44,166 41,134 87,817 67,242
--------- --------- --------- --------- --------- ---------
375,926 147,932 180,704 165,166 556,630 313,098
</TABLE>
OTHER ACTIVITIES
MOLDOVA CONCESSION AGREEMENT. In July 1995, the Republic of Moldova
(located in Eastern Europe between Romania and the Ukraine) granted a Concession
Agreement to Resource Development Company Limited, L.L.C. ("Redeco"), an entity
not affiliated with the Company. The Company has paid Redeco $90,000 and agreed
to bear the first $2.0 million of Concession expenses ($1.2 million of which had
been expended through June 30, 1996) in return for a 50.0% interest in Redeco.
After the initial $2.0 million expenditure, the Company and the other members of
Redeco are responsible for bearing 50.0% each of future expenses. The Concession
Agreement covers the entire country with respect to oil and gas and other
minerals and continues for various time periods depending on the nature of the
activity conducted. In connection with two previously producing but now
abandoned fields, Redeco's exclusive rights continue for 20 years. Redeco's
exclusive period to explore throughout the remainder of Moldova expires in 2005,
but Redeco will maintain exclusive development rights with respect to fields
discovered for a period of 20 years from the date of first production from such
field. The Company has no material fixed financial commitments with respect to
the Concession.
MINERALS ACQUISITION PROGRAM. Statewide, a Company subsidiary, was
organized for the purpose of acquiring overriding royalty interests and other
types of non cost-bearing mineral interests underlying producing oil and gas
fields primarily in Texas. The strategy of such acquisitions is to make blanket
offers to holders of small interests. From inception through June 30, 1996,
Statewide expended approximately $3.3 million in acquiring interests in
approximately 1,400 properties. Through June 30, 1996, Statewide had received
revenues from such interests aggregating approximately $1.4 million, as well as
proceeds from sales of such interests of approximately $102,000.
GAS GATHERING AND TRANSMISSION. In 1996, the Company purchased a 40.5%
membership interest (which reduces to 32.4% when the Company and certain other
members recoup their original investment) in Republic Gas Partners, L.L.C., a
Delaware limited liability company ("Republic"), for approximately $941,000.
Republic owns all of the stock of Mid Louisiana Gas Company, Mid Louisiana
Marketing Company and Mid Louisiana Gas Transmission Company (collectively, the
"Midla Companies"). The assets of the Midla Companies include 409 miles of
mainly 22 inch pipeline extending from the Monroe field area south of the city
of Baton Rouge serving various Louisiana and Mississippi municipal and
industrial customers along its route. Mid Louisiana Gas Company's pipeline is
subject to the jurisdiction of the Federal Energy Regulatory Commission
("FERC").
Valley, a Company subsidiary, owns a small gas gathering system, several
small gas plants, 11 salt water disposal wells located in each of its three
principal regions and compressors used in the compression of gas located in the
Gulf Coast region. For the year ended December 31, 1995, Valley had revenues of
$553,000 and net income of $264,000, substantially all of which were related to
transactions with Costilla.
In the 1996 Acquisition, Pipeline, a Company subsidiary, acquired a 120 mile
gas transportation pipeline in southwestern Pennsylvania for an allocated value
of $3.5 million. The Company regards this asset as non-strategic to its business
activities and is presently marketing the pipeline for sale.
40
<PAGE>
COMPETITION AND MARKETS
Competition in all areas of the Company's operations is intense. Major and
independent oil and gas companies and oil and gas syndicates actively bid for
desirable oil and gas properties, as well as for the equipment and labor
required to operate and develop such properties. A number of the Company's
competitors have financial resources and acquisition, exploration and
development budgets that are substantially greater than those of the Company,
which may adversely affect the Company's ability to compete with these
companies. Many of the Company's competitors have been engaged in the energy
business for a much longer time than the Company. Such companies may be able to
pay more for productive oil and gas properties and exploratory prospects and to
define, evaluate, bid for and purchase a greater number of properties and
prospects than the Company's financial or human resources permit. The Company's
ability to acquire additional properties and to discover reserves in the future
will be dependent on its ability to evaluate and select suitable properties and
to consummate transactions in a highly competitive environment.
The market for oil, gas and natural gas liquids produced by the Company
depends on factors beyond its control, including domestic and foreign political
conditions, the overall level of supply of and demand for oil, gas and natural
gas liquids, the price of imports of oil and gas, weather conditions, the price
and availability of alternative fuels, the proximity and capacity of gas
pipelines and other transportation facilities and overall economic conditions.
The oil and gas industry as a whole also competes with other industries in
supplying the energy and fuel requirements of industrial, commercial and
individual consumers.
REGULATION
The Company's oil and gas exploration, production and related operations are
subject to extensive rules and regulations promulgated by federal, state and
local agencies. Failure to comply with such rules and regulations can result in
substantial penalties. The regulatory burden on the oil and gas industry
increases the Company's cost of doing business and affects its profitability.
Because such rules and regulations are frequently amended or reinterpreted, the
Company is unable to predict the future cost or impact of complying with such
laws.
The State of Texas and many other states require permits for drilling
operations, drilling bonds and reports concerning operations and impose other
requirements relating to the exploration and production of oil and gas. Such
states also have statutes or regulations addressing conservation matters,
including provisions for the unitization or pooling of oil and gas properties,
the establishment of maximum rates of production from oil and gas wells and the
regulation of spacing, plugging and abandonment of such wells. The statutes and
regulations of certain states limit the rate at which oil and gas can be
produced from the Company's properties.
The FERC regulates interstate natural gas transportation rates and service
conditions, which affect the marketing of gas produced by the Company, as well
as the revenues received by the Company for sales of such production. Since the
mid-1980s, the FERC has issued a series of orders, culminating in Order Nos.
636, 636-A and 636-B ("Order 636"), that have significantly altered the
marketing and transportation of gas. Order 636 mandates a fundamental
restructuring of interstate pipeline sales and transportation service, including
the unbundling by interstate pipelines of the sales, transportation, storage and
other components of the city-gate sales services such pipelines previously
performed. One of the FERC's purposes in issuing the orders is to increase
competition within all phases of the gas industry. Order 636 and subsequent FERC
orders on rehearing have been appealed and are pending judicial review. Because
these orders may be modified as a result of the appeals, it is difficult to
predict the ultimate impact of the orders on the Company and its gas marketing
efforts. Generally, Order 636 has eliminated or substantially reduced the
interstate pipelines' traditional role as wholesalers of natural gas, and has
substantially increased competition and volatility in natural gas markets. While
significant regulatory uncertainty remains, Order 636 may ultimately enhance the
Company's ability to market and transport its gas, although it may also subject
the Company to greater competition and the more restrictive pipeline imbalance
tolerances and greater associated penalties for violation of such tolerances.
Sales of oil and natural gas liquids by the Company are not regulated and
are made at market prices. The price the Company receives from the sale of these
products is affected by the cost of transporting the
41
<PAGE>
products to market. Effective as of January 1, 1995, the FERC implemented
regulations establishing an indexing system for transportation rates for oil
pipelines, which, generally, would index such rates to inflation, subject to
certain conditions and limitations. These regulations could increase the cost of
transporting oil and natural gas liquids by pipeline, although the most recent
adjustment generally decreased rates. These regulations are subject to pending
petitions for judicial review. The Company is not able to predict with certainty
what effect, if any, these regulations will have on it, but, other factors being
equal, the regulations may, over time, tend to increase transportation costs or
reduce wellhead prices for oil and natural gas liquids.
ENVIRONMENTAL MATTERS
Operations of the Company are subject to numerous and constantly changing
federal, state and local laws and regulations governing the discharge of
materials into the environment or otherwise relating to environmental
protection. These laws and regulations may require the acquisition of certain
permits, restrict or prohibit the types, quantities and concentration of
substances that can be released into the environment in connection with drilling
and production, restrict or prohibit drilling activities that could impact
wetlands, endangered or threatened species or other protected natural resources
and impose substantial liabilities for pollution resulting from the Company's
operations. Such laws and regulations may substantially increase the cost of
exploring for, developing or producing oil and gas and may prevent or delay the
commencement or continuation of a given project. In the opinion of the Company's
management, the Company is in substantial compliance with current applicable
environmental laws and regulations, and the cost of compliance with such laws
and regulations has not been material and is not expected to be material during
the next fiscal year. Nevertheless, changes in existing environmental laws and
regulations or in interpretations thereof could have a significant impact on the
operating costs of the Company, as well as the oil and gas industry in general.
For instance, legislation has been proposed in Congress from time to time that
would reclassify certain oil and gas production wastes as "hazardous wastes,"
which reclassification would make exploration and production wastes subject to
much more stringent handling, disposal and clean-up requirements. State
initiatives to further regulate the disposal of oil and gas wastes and naturally
occurring radioactive materials are also pending in certain states, including
Texas, and these various initiatives could have a similar impact on the Company.
The Comprehensive Environmental Response, Compensation, and Liability Act
("CERCLA"), also known as the "Superfund" law, imposes liability, without regard
to fault or the legality of the original conduct, on certain classes of persons
that are considered to have contributed to the release of a "hazardous
substance" into the environment. These persons include the owner or operator of
the disposal site or the site where the release occurred and companies that
disposed or arranged for the disposal of the hazardous substances found at the
site. Persons who are or were responsible for releases of hazardous substances
found at the site and persons who are or were responsible for releases of
hazardous substances under CERCLA may be subject to joint and several liability
for the costs of cleaning up the hazardous substances that have been released
into the environment and for damages to natural resources, and it is not
uncommon for neighboring landowners and other third parties to file claims for
personal injury and property damage allegedly caused by the hazardous substances
released into the environment. The Company is able to control directly the
operation of only those wells with respect to which its acts as operator.
Notwithstanding the Company's lack of control over wells operated by others, the
failure of the operator to comply with applicable environmental regulations may,
in certain circumstances, be attributed to the Company. The Company has no
material commitments for capital expenditures to comply with existing
environmental requirements.
EMPLOYEES
At June 30, 1996, the Company had 109 full-time employees. None of the
Company's employees is subject to a collective bargaining agreement. The Company
considers its relations with its employees to be good.
42
<PAGE>
LEGAL PROCEEDINGS
The Company is a defendant or codefendant in minor lawsuits that have arisen
in the ordinary course of business. While the outcome of the these lawsuits
cannot be predicted with certainty, management does not expect any of these to
have a material adverse effect on the Company's consolidated financial condition
or results of operations.
TITLE TO PROPERTIES
The Company has obtained title opinions on substantially all of its
producing properties and believes that it has satisfactory title to such
properties in accordance with standards generally accepted in the oil and gas
industry. As is customary in the oil and gas industry, the Company performs a
minimal title investigation before acquiring undeveloped properties. A title
opinion is obtained prior to the commencement of drilling operations on such
properties. The Company's properties are subject to customary royalty interests,
liens incident to operating agreements, liens for current taxes and other
burdens which the Company believes do not materially interfere with the use of
or affect the value of such properties. Substantially all of the Company's oil
and gas properties are mortgaged to secure borrowings under the Company's
Existing Debt Facility and will continue to be mortgaged to secure borrowings
under the Credit Facility. See "Management's Discussion and Analysis of
Financial Conditions and Results of Operations -- Liquidity and Capital
Resources," and "Description of Certain Indebtedness."
OPERATIONAL HAZARDS AND INSURANCE
The Company's operations are subject to the hazards and risks inherent in
drilling and production and transportation of oil and gas, including fires,
natural disasters, explosions, encountering formations with abnormal pressures,
blowouts, cratering, pipeline ruptures, and spills, any of which can result in
loss of hydrocarbons, environmental pollution, personal injury or loss of life,
severe damage to and destruction of properties of the Company and others, and
suspension of operations. See "Risk Factors -- Drilling Risks" and "Risk Factors
- -- Operating Hazards and Uninsured Risks."
The Company maintains insurance of various types to cover its operations.
The limits provided under its liability policies total $21 million. In addition,
the Company maintains operator's extra expense coverage which provides for care,
custody and control of all material wells drilled by the Company as operator.
The Company believes that its insurance is adequate and customary for companies
of a similar size engaged in operations similar to those of the Company, but
losses could occur for uninsurable or uninsured risks or in amounts in excess of
existing insurance coverage. The Company's general policy is to only engage
drilling contractors who provide substantial insurance coverage and name the
Company as an additional named insured. The occurrence of a significant adverse
event, the risks of which are not fully covered by insurance, could have a
material adverse effect on the Company's financial condition and results of
operations. Moreover, no assurances can be given that the Company will be able
to maintain adequate insurance in the future at rates it considers reasonable.
43
<PAGE>
MANAGEMENT
The executive officers and directors of the Company following completion of
the Corporate Reorganization are listed below, together with a description of
their experience and certain other information (ages provided are as of June 30,
1996). Executive officers are appointed by the Board of Directors.
<TABLE>
<CAPTION>
NAME AGE EMPLOYED SINCE POSITION WITH COMPANY
- -------------------------- --- ----------------- ---------------------------------------------------------------
<S> <C> <C> <C>
Cadell S. Liedtke 41 1988 Chairman of the Board, Chief Executive Officer and Director
Michael J. Grella 47 1988 President, Chief Operating Officer and Director
Henry G. Musselman 42 1992 Executive Vice President and Director
Jerry J. Langdon 43 n/a Director
W.D. Kennedy 76 n/a Director
Bobby W. Page 53 1996 Senior Vice President, Treasurer and Chief Financial Officer
Clifford N. Hair, Jr. 49 1992 Vice President -- Land and Secretary
Roger J. Wetz 47 1992 Vice President -- Exploration (Geology)
Roger A. Freidline 46 1993 Vice President -- Exploration (Geophysics)
Brian K. Miller 36 1992 Vice President -- Reservoir Engineering
Sal J. Pagano 45 1995 Vice President -- Engineering and Operations
Keith Atwood 42 1992 Vice President -- Field Operations
Celia A. Zinn 48 1996 Controller
</TABLE>
Cadell S. Liedtke entered the oil and gas business in Midland, Texas in 1977
as an independent landman generating oil and gas prospects in the Permian Basin.
He founded the Company's predecessor with Michael J. Grella in 1988 and has
served as managing partner and/or chief executive officer since that time. Mr.
Liedtke has served on the Board of Directors of Texas Commerce Bank-Permian
Basin and has been appointed by Texas Governor George W. Bush to the Oil and Gas
Compact Commission. Mr. Liedtke is a member of the All-American Wildcatters
Association, the Permian Basin Petroleum Association, the Permian Basin
Landman's Association and the Independent Producer's Association of America. Mr.
Liedtke graduated from the University of Texas at Austin in 1977 with a B.A.
degree in economics.
Michael J. Grella has served as Chief Operating Officer of the Company and
its predecessor entities since their formation in 1988. He owned and operated an
independent oil and gas company and has invested in the oil and gas business
since 1982. Mr. Grella is a member of the Permian Basin Petroleum Association,
the Independent Producer's Association of America, the Texas Independent
Producers and Royalty Owners Association and the Permian Basin Landman's
Association. Mr. Grella has a B.S. degree in computer science from the
University of California.
Henry G. Musselman began his oil and gas career in 1975 with Musselman
Petroleum and Land Company where he served as Vice President and a Director
until forming Musselman, Owen & King in 1982. For the 10 years until merging his
company into Costilla's predecessor in 1992, Mr. Musselman developed and
acquired oil and gas properties throughout the Permian Basin. Mr. Musselman is a
member and former director of the Independent Producer's Association of America.
Mr. Musselman graduated from the University of Texas at Austin in 1975 with a
B.B.A. degree.
Jerry J. Langdon has previously held positions with WP Corporation, Houston
Pipeline Company, Texas Oil & Gas Corporation and W. Wilson Corporation. In
1980, Mr. Langdon formed Texas IntraMark Gas Company, Inc., an intrastate gas
gathering company engaging in the business of constructing and operating natural
gas gathering, treating and processing facilities. In 1984, Mr. Langdon formed
Langdon & Associates, a natural gas consulting group advising petroleum
resource-oriented companies, financial institutions and law firms on a variety
of technical, commercial and regulatory issues. Mr. Langdon served as a member
of the FERC from 1988 to June 1993. Since leaving the FERC, Mr. Langdon formed
Republic Gas Corp. to
44
<PAGE>
acquire, construct and operate intrastate natural gas pipeline, gathering,
processing, treating and marketing facilities. Mr. Langdon is the President of
both Republic and the Midla Companies. Mr. Langdon is a 1975 graduate of the
University of Texas at Austin with a B.S. degree.
W. D. Kennedy has been continually involved in the oil and gas business
since 1948. From 1953 until 1980, Mr. Kennedy was an executive officer and
director of C&K Petroleum, Inc., and its predecessor. C&K Petroleum, Inc. was a
publicly held corporation from 1971 until 1980, when the company was sold for in
excess of $200 million. Mr. Kennedy remains an active investor in the oil and
gas business. Mr. Kennedy is a graduate of the University of Texas, and a member
of the All-American Wildcatters Association, a past president of the Permian
Basin Petroleum Association, a former director of the Texas Mid-Continent Oil
and Gas Association, and an advisory director of Norwest Bank Texas, Midland.
Bobby W. Page began his oil and gas career with MGF Oil Corporation in 1967,
where he remained until 1988, ultimately serving as Executive Vice President,
Chief Financial Officer and a member of the Board of Directors. Following two
years as a self-employed financial consultant, Mr. Page joined Alta Energy
Corporation in 1990 as Executive Vice President, Treasurer and Chief Financial
Officer. From July 1993 until joining the Company, Mr. Page served as Vice
President, Chief Financial Officer and Secretary of Marcum Natural Gas Services,
Inc. Mr. Page graduated from the University of Oklahoma with a B.B.A. degree in
accounting in 1965.
Clifford N. Hair, Jr. has served in district and division landman roles, as
well as a corporate officer with Texas Gas Exploration Corporation, Samedan Oil
Corporation, Henry Petroleum Corporation and Donald C. Slawson Oil Producer. For
the two year period prior to joining the Company in 1992, Mr. Hair was an
independent landman involved in drilling projects in Texas and Oklahoma. Mr.
Hair is a Certified Petroleum Landman and a member of the American Association
of Petroleum Landmen and the Petroleum Basin Landman's Association. Mr. Hair
graduated with honors from the University of Houston in 1971 with a B.B.A.
degree in accounting.
Roger J. Wetz began his oil and gas career with IMCO Services, a division of
Halliburton, Inc. in 1974. He held a variety of geological positions with Gulf
Energy & Minerals Company, TXO Production Corporation and Terra Resources, Inc.
from 1976 to 1989. From 1989 until joining the Company in 1992, Mr. Wetz was an
independent geologist generating prospects in the Permian Basin. Mr. Wetz
graduated from St. Mary's University in 1973 with a B.S. degree in geology.
Roger A. Freidline began his industry career with Union Oil Company of
California. From 1976 until 1985, Mr. Freidline served in various geophysical
capacities with Forest Oil Corporation, Gifford, Mitchell and Wisenbaker and
Heritage Resources, Inc. Mr. Freidline was an independent geophysicist from 1985
until joining the Company, except for a period of employment as district
geologist for Hondo Oil & Gas Company prior to its sale. Mr. Freidline is a
Certified Petroleum Geologist, and a member of the Society of Exploration
Geophysicists, the Permian Basin Geophysical Society and the West Texas
Geological Society. He has co-authored papers which have appeared in Geology and
The Bulletin of the Seismological Society of America. Mr. Freidline received a
B.S. degree with highest honors from the New Mexico Institute of Mining and
Technology in 1972 and a Masters of Science degree in geophysics from the
University of Utah in 1974.
Brian K. Miller entered the oil and gas business as an operations engineer
for ARCO Oil and Gas Company. From 1984 to 1987, he was a reservoir engineer
with First City National Bank of Midland, Texas, and from 1987 to 1989, Mr.
Miller was an independent consulting engineer. Prior to joining the Company in
1992, Mr. Miller served as an oil and gas analyst under appointment to the
Federal Deposit Insurance Corporation. Mr. Miller is a member of the Society of
Petroleum Engineers. Mr. Miller received a B.S. degree with highest honors in
petroleum engineering from the University of Texas at Austin in 1982 and a
Master of Business Administration degree with honors in finance in 1984.
Sal J. Pagano began his oil and gas career with Amoco Production Company
where he was employed until 1978. From 1978 through 1989, Mr. Pagano was
employed by several independent oil and gas companies in Midland, Texas in a
variety of petroleum engineering capacities. Prior to joining the Company in
1995,
45
<PAGE>
Mr. Pagano was employed by Midland Resources Company from 1989 as a vice
president. Mr. Pagano is a registered petroleum engineer and a member of the
Society of Petroleum Engineers. Mr. Pagano graduated in 1973 from the University
of Missouri at Rolla with a B.S. degree in petroleum engineering.
Keith Atwood began his oil and gas career with Otis Engineering Corp. in
1974. Mr. Atwood worked as an independent consultant from 1979 to 1983 when he
joined Musselman, Owen & King Operating Co. to manage field operations. He
served in that capacity until joining the Company in 1992. Mr. Atwood attended
Southwest Texas State University and the University of Texas.
Celia A. Zinn joined the Company in 1996. From 1992 to 1996, she practiced
public accounting in Midland. Ms. Zinn has 18 years experience in the oil and
gas industry, including 12 years as Controller for Clayton W. Williams, Jr.,
Inc. from 1981 to 1992. Ms. Zinn is a certified public accountant. Ms. Zinn
graduated from the University of Texas-Arlington in 1978 with a B.A. in
mathematics.
46
<PAGE>
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL
OWNERS AND MANAGEMENT
The following table sets forth the names and addresses of each of the
Company's stockholders who beneficially own more than five percent of the
Company's Common Stock, the number of shares beneficially owned by such
shareholders and the percentage of the Common Stock so owned at June 30, 1996,
assuming in each case the Corporate Reorganization had been consummated at June
30, 1996 and that the Common Stock Offering is consummated without the
Underwriters' over-allotment option being exercised.
<TABLE>
<CAPTION>
AMOUNT AND NATURE OF
BENEFICIAL OWNERSHIP PERCENT OF
NAME AND ADDRESS OF BENEFICIAL OWNER (1) CLASS
- ------------------------------------ ---------------------- -------------
<S> <C> <C>
Cadell S. Liedtke .................. 2,656,796 26.6%
400 W. Illinois
Midland, Texas 79701
Michael J. Grella .................. 1,558,161 15.6%
400 W. Illinois
Midland, Texas 79705
NationsBanc Capital Corp. .......... 1,080,008 10.8%
100 North Tryon Street
Charlotte, North Carolina 28255
Henry G. Musselman ................. 705,035 7.0%
400 W. Illinois
Midland, Texas 79701
</TABLE>
- ------------------------
(1) All persons own the listed shares of record.
The table appearing below sets forth information as of June 30, 1996
(assuming the Corporate Reorganization had been consummated on such date) with
respect to the shares of Common Stock beneficially owned by each of the
Company's Directors, the Chief Executive Officer and the three other most highly
compensated executive officers for 1996 (whose annualized compensation for such
year based on compensation levels following the Offering is expected to exceed
$100,000) and all Directors and executive officers as a group, and the percent
of the outstanding Common Stock owned by each, assuming that the Common Stock
Offering is consummated without the Underwriters' over-allotment option being
exercised.
<TABLE>
<CAPTION>
DIRECTORS AND NAMED AMOUNT AND NATURE OF PERCENT OF
EXECUTIVE OFFICER BENEFICIAL OWNERSHIP CLASS (1)
- ------------------------------------ ---------------------- -------------
<S> <C> <C>
Cadell S. Liedtke................... 2,656,796 26.6%
Michael J. Grella................... 1,558,161 15.6%
Henry G. Musselman.................. 705,035 7.0%
Bobby W. Page....................... 75,000(2) 0.7%
All Officers and Directors as a
group (13 persons).................. 5,469,992(3) 51.8%
</TABLE>
- ------------------------
(1) For the sole purpose of calculating these percentages, the shares, which the
named person has the right to acquire within 60 days, by exercise of the
options described in these footnotes, are deemed outstanding shares with
respect to that person's percentage ownership and with respect to the
percentage ownership of all Officers and Directors as a group.
(2) Includes 75,000 shares issuable pursuant to an option granted under the
Company's 1996 Stock Option Plan which option will be immediately
exercisable upon closing of the Offerings at a price equal to the initial
public offering price of the Common Stock.
(3) Includes 550,000 shares issuable pursuant to options granted under the
Company's 1996 Stock Option Plan which options will be immediately
exercisable upon closing of the Offerings at a price equal to the initial
public offering price of the Common Stock.
47
<PAGE>
EXECUTIVE COMPENSATION AND OTHER INFORMATION
SUMMARY COMPENSATION TABLE
The following table sets forth information for the Company's Chief Executive
Officer and the three other most highly compensated executive officers whose
annual compensation for the fiscal year ending December 31, 1996 is expected to
exceed $100,000. Information is presented for 1995, and for 1996 on an
annualized basis based on salaries to be effective following consummation of the
Offerings. Information for 1994 and prior years is not comparable since the
Company's predecessor was a general partnership in which the partners received
periodic partnership distributions in lieu of salary.
<TABLE>
<CAPTION>
LONG-TERM
COMPENSATION
AWARDS
-------------
ANNUAL COMPENSATION SECURITIES
------------------------------------------------- UNDERLYING
OTHER ANNUAL OPTIONS/ ALL OTHER
NAME AND PRINCIPAL POSITION YEAR SALARY($) BONUS($) COMPENSATION($) SARS(#)(2) COMPENSATION($)
- --------------------------------- --------- --------- --------- ---------------- ------------- ----------------
<S> <C> <C> <C> <C> <C> <C>
Cadell S. Liedtke
Chairman of the Board and Chief 1995 185,700 -- -- -- --
Executive Officer 1996 300,000 -- -- -- --
Michael J. Grella
President and Chief Operating 1995 261,750 -- -- -- 656,000(3)
Officer 1996 300,000 -- -- -- --
Henry G. Musselman 1995 139,800 -- -- -- --
Executive Vice President 1996 215,000 -- -- -- --
Bobby W. Page
Senior Vice President,
Treasurer and Chief Financial 1995(1) -- -- -- -- --
Officer 1996 150,000 -- -- 75,000 --
</TABLE>
- ------------------------
(1) Mr. Page joined the Company in June 1996.
(2) The amount shown represents the number of shares subject to a stock option
to be granted upon the closing of the Offerings pursuant to the Company's
1996 Stock Option Plan described under "-- Benefit Plans -- 1996 Stock
Option Plan." The option will be granted with an exercise price per share
equal to the initial public offering price of the Common Stock will be
granted for a 10-year term.
(3) The amount shown represents non-cash compensation deemed to have been
accrued to Mr. Grella in connection with the cancellation of an option held
by a minority owner to purchase an additional interest in the Company. See
Note 11 of the Notes to the Consolidated Financial Statements.
DIRECTORS' COMPENSATION
Compensation for non-employee directors (Messrs. Langdon and Kennedy) will
consist of an annual retainer fee of $10,000, plus a $1,000 fee for each Board
meeting attended and a $1,000 fee for attending a committee meeting held on a
day other than the same day of a Board meeting. In addition, outside Directors
are participants in the Company's Outside Directors Stock Option Plan described
under "-- Benefit Plans -- Outside Directors Stock Option Plan." Employee
Directors do not receive compensation for serving on the Board or the Board's
committees.
EMPLOYMENT AGREEMENTS
Messrs. Liedtke, Grella and Musselman have entered into employment
agreements (the "Founders Employment Agreements") with the Company which will
become effective upon the closing of the Offerings and replace certain existing
agreements. The Founders Employment Agreements are each for three years,
commencing on the closing of the Offerings and each will automatically renew for
successive one-year periods thereafter unless the employee is notified to the
contrary. The Founders Employment Agreements provide for salary levels for
Messrs. Liedtke, Grella and Musselman of $300,000, $300,000 and $215,000,
respectively.
Each of Messrs. Liedtke, Grella and Musselman would receive his salary for
the remaining term of the applicable Founders Employment Agreement if the
Company were to terminate such person's employment
48
<PAGE>
other than for cause. However, if such person were to voluntarily leave his
employment with the Company prior to the second anniversary of the Agreement, no
further payments would be required. If a voluntary termination were to occur
subsequent to the second anniversary of the Agreement, such person would be
entitled to one year's salary from the date of termination. Each Founders
Employment Agreement provides that the covered employee will not compete with
the Company for a one year period following his voluntary cessation of
employment or termination of employment for cause, in either case if such event
occurs within the initial three-year term of the Agreement. Competitive
activities are defined as engaging in the oil and gas business in any area in
which the Company is then active.
Bobby W. Page has entered into an employment agreement (the "Page Employment
Agreement") with the Company effective June 30, 1996. The Page Employment
Agreement is for a period of three years from June 30, 1996 and will
automatically renew for successive one-year periods thereafter unless Mr. Page
is notified to the contrary by the Company. The Page Employment Agreement
provides a $25,000 bonus (which includes Mr. Page's cost of relocation), plus a
base salary of $150,000 until January 1, 1997; $175,000 until January 1, 1998;
and $185,000 thereafter. In addition, Mr. Page will receive options to purchase
75,000 shares of Common Stock, certain insurance benefits and other benefits
generally available to the Company's employees. Mr. Page would receive his
salary for the remaining term of the Page Employment Agreement if the Company
were to terminate the Page Employment Agreement other than for cause. However,
if Mr. Page were to voluntarily leave his employment with the Company, no
further payments would be required.
BENEFIT PLANS
OUTSIDE DIRECTORS STOCK OPTION PLAN. The Outside Directors Stock Option
Plan provides for the issuance of stock options to the outside directors of the
Company. A total of 50,000 shares of Common Stock has been authorized and
reserved for issuance under the plan, subject to adjustments to reflect changes
in the Company's capitalization resulting from stock splits, stock dividends and
similar events. Only outside directors are eligible to participate in the plan.
Outside directors are those directors of the Company who are not executive
officers or regular salaried employees of the Company as of the date an option
is granted. Under the plan, an option for 1,000 shares of Common Stock will be
granted to each person who qualifies as an outside director each year that such
person is elected as a director of the Company. The exercise price of each
option granted under the plan will be the fair market value (as reported on the
Nasdaq National Market) of the Common Stock at the time the option is granted,
and may be paid either in cash, shares of Common Stock or a broker-assisted
cashless transaction. Each option will be exercisable immediately, and will
expire ten years from the date of grant. An option granted under the plan is not
transferrable other than by will or the laws of descent and distribution. In the
event a participant in the plan ceases to be an outside director, other than by
reason of death, such participant may exercise an outstanding option under the
plan within six months after such termination, to the extent the participant was
entitled to exercise the option on the date of termination. In the event of the
death of a participant under the plan, such participant's option(s) may be
exercised by the executors or administrators of the optionee's estate or by the
legatees of such participant within one year after his death, so long as the
term of the option has not expired. The Company does not receive any
consideration upon the grant of options under the plan. The options granted
under the plan are intended to be non-qualifying options for federal income tax
purposes. Because options under the plan are not generally transferrable, do not
appear to be subject to a substantial risk of forfeiture and the exercise price
will be the fair market value of the common stock on the date of grant, the
options should not be taxable to an optionee until the optionee exercises the
option, at which time the optionee would recognize income on the difference
between the exercise price and the fair market value of the shares on the date
of exercise. The grant of options under the plan should be treated as
compensation paid by the Company for purposes of the Company's federal income
tax considerations. The Board of Directors may amend the plan without the
approval of the stockholders of the Company in any respect other than any
amendment which requires stockholder approval by law and may only modify an
outstanding option, including the repricing of such options, with the consent of
the option holder. The Company currently has five directors, two of whom are
eligible to participate in the plan.
49
<PAGE>
1996 STOCK OPTION PLAN. The 1996 Employee Stock Option Plan provides for
the grant of both incentive stock options and non-qualifying stock options, as
well as limited stock appreciation rights and supplemental bonuses, to the
employees of the Company and its subsidiaries, including officers and directors
who are salaried employees. A total of 850,000 shares of Common Stock has been
authorized and reserved for issuance under the plan, subject to adjustment to
reflect changes in the Company's capitalization resulting from stock splits,
stock dividends and similar events. The plan is administered by the Board of
Directors. The Board of Directors has the sole authority to interpret the plan,
to determine the persons to whom options will be granted, to determine the basis
upon which the options will be granted, and to determine the exercise price,
duration and other terms of the options to be granted under the plan; provided
that (a) the exercise price of each option granted under the plan may not be
less than the fair market value of the Common Stock on the date the option is
granted (and for incentive stock options, 110% of fair market value if the
employee is the beneficial owner of 10% or more of the Company's voting
securities), (b) the exercise price must be paid in cash, by surrendering
previously owned shares of Common Stock upon the exercise of the option or by a
promissory note or broker-assisted cashless exercise approved by the Board of
Directors, (c) the term of the option may not exceed ten years, and (d) no
option is transferrable other than by will, the laws of descent and distribution
or pursuant to a qualified domestic relations order. Upon termination of an
optionee's employment (other than by death or disability), an incentive stock
option may be exercised prior to the expiration date of the option or within
three months after the date of such termination, whichever is earlier, but only
to the extent the optionee had the right to exercise the option upon the date of
such termination, while the rights of the holder of a non-qualifying stock
option will be set forth in each option agreement. In the event of the
disability of an optionee, the option may be exercised by such person or his
personal representative at any time within one year of the termination of such
person's employment, but only to the extent the optionee had the right to
exercise the option as of the date of his disability. In the event of death of
the optionee, the option may be exercised by his personal representative or
successor in interest at any time until the later of the expiration of the
option or one year after the optionee's death, to the extent the option was
exercisable at the time of the optionee's death. Incentive stock options may not
be granted under the plan to any individual if the effect of such grant would
permit that person to have the first opportunity to exercise such options, in
any calendar year, for the purchase of shares having a fair market value (at the
time of grant of the option) in excess of $100,000. Neither the Company nor any
of its subsidiaries will receive any consideration for the granting of options
under the plan. Limited stock appreciation rights may be granted under the plan
with respect to specified options, allowing the option holder to receive, in
cash, the difference between the exercise price and the market value in the
event of a change of control of the Company. The Board of Directors may also
grant supplemental bonuses under the plan which are cash bonuses not to exceed
the amount of income tax liability incurred by a plan participant upon the
exercise of a non-qualifying stock option or a limited stock appreciation right
with respect to which the bonus was granted. Incentive stock options granted
under the plan are intended to have the federal income tax consequences of a
qualified stock option. As a result, the exercise of an incentive stock option
will not be a taxable event; the taxable event occurs at the time the shares of
Common Stock acquired upon exercise of the option are sold. If the optionee
holds such shares for the later of two years from the date the option was
granted or one year from the date of exercise of the option, the difference
between the price paid for the shares at exercise and the price for which those
shares are sold will be treated as capital gains income. If the optionee does
not hold the shares for the required holding period, the income would be treated
as ordinary income rather than capital gains income. The non-qualifying stock
options granted under the plan should be taxable when the option is exercised,
at which time the optionee would recognize ordinary income on the difference
between the exercise price and the fair market value of the shares on the date
of exercise. The grant of options under the plan will be treated as compensation
by the Company for federal income tax purposes. The Board of Directors may amend
the plan, without stockholder approval, in any respect other than any amendment
that requires stockholder approval by law, and may modify an outstanding option,
including the repricing of non-qualifying options, with the consent of the
option holder. There are currently approximately 100 persons who are eligible to
participate under the plan.
BONUS INCENTIVE PLAN. The Company has adopted the Bonus Incentive Plan to
become effective upon the completion of the Offerings. The plan provides that
the Board of Directors each year may award bonuses
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in cash, Common Stock, or some combination thereof, to those officers,
directors, employees and advisors of the Company or a subsidiary of the Company,
who the Board of Directors determines have contributed to the success of the
Company. A total of 100,000 shares of Common Stock has been authorized and
reserved for issuance under the plan, subject to adjustments to reflect changes
in the Company's capitalization resulting from stock splits, stock dividends and
similar events. All officers, directors and advisors of the Company or a
subsidiary of the Company and all employees of the Company or a subsidiary of
the Company who have completed a minimum of 180 days of service and are employed
by the Company or such subsidiary on the last day of the plan year, other than
such persons who own ten percent or more of the outstanding shares of Common
Stock during that year, are eligible to participate in the plan. Bonus awards
will be determined based on a number of factors, including performance and
salary level of the participant and the financial performance of the Company and
its subsidiaries. Bonuses will be awarded after review and upon approval of the
Board of Directors, subject to the terms and conditions of the plan.
CERTAIN TRANSACTIONS
A&P Meter Sales and Services, Inc. ("A&P"), a corporation in which Messrs.
Liedtke, Grella and Musselman own 60.0% of the outstanding common stock,
supplies meter reading services which measure gas production to the Company, as
well as to unaffiliated oil and gas companies. A&P is also engaged in the sale
of gas meter and regulating equipment, and in certain other oil field related
businesses. For the fiscal year ended December 31, 1995, the Company accounted
for approximately 27% of A&P's gross revenues. From time to time, the Company
has advanced funds to A&P for working capital needs. These advances have been
consolidated into two promissory notes. One note was executed December 31, 1994
in the original principal amount of $370,000. The note bears interest at a
floating rate equal to the "prime rate" plus 1.0%. No principal or interest
payments are due until the maturity of the note at December 31, 2004. The note
is secured by a second lien on A&P's accounts receivable, inventory and
equipment. The second note is in the original principal amount of $247,000 and
is dated May 22, 1996. The note bears interest at 6.0% per annum, is unsecured
and is payable upon demand. During the fiscal year ended December 31, 1995, A&P
received $612,139 from the Company for meter reading, meter repair, calibration,
flow line installation and other related services provided to the Company. The
Company believes that the services and charges therefor are comparable to those
the Company could have obtained from unaffiliated third parties.
During 1995 the Company paid $440,884 to Valley for gas compression and salt
water disposal charges. During 1995, Valley paid the Company $109,399 for
operating costs of its salt water disposal wells and gas compressors. Also
during 1995, the Company paid CSL $592,920 for management fees and lease
payments on equipment.
During a portion of 1995, the Company leased office space from 511 Tex L.C.,
in which Messrs. Liedtke, Grella and Musselman are the sole members. The amount
of rental payments to 511 Tex L.C. during 1995 was $67,896. The Company no
longer leases office space from any affiliated party.
The Company has agreed that, upon the request of NBCC, on up to two
occasions, the Company will register under the Securities Act of 1933, as
amended (the "Securities Act"), and applicable state securities laws the sale of
the Common Stock owned by NBCC. The Company's obligation is subject to certain
limitations regarding the timing of registrations and certain other matters. The
Company is also obligated to offer to NBCC and Messrs. Liedtke, Grella and
Musselman (collectively, the "Affiliated Holders") the opportunity to include
shares of the Common Stock owned by them in certain registration statements
filed by the Company. In addition, the Company has agreed to indemnify the
Affiliated Holders and their respective officers and directors against
securities law liabilities arising in connection with such offerings, other than
liabilities arising as a result of information furnished to the Company by the
Affiliated Holders participating in the registration. The Company is obligated
to pay all expenses incident to such registration, except underwriters'
discounts and commissions allocable to the sale of shares by Affiliated Holders
and any professional fees and expenses incurred by the Affiliated Holders
incident to such registration. The Affiliated Holders have agreed that they will
not sell any shares of Common Stock for a period of 180 days after the Offerings
without the consent of Prudential Securities Incorporated.
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In 1995, non-cash compensation of $656,000 was deemed to have accrued to Mr.
Grella in connection with the cancellation of an option held by Mr. Musselman to
acquire an interest in the Company's predecessors. To effect such cancellation,
Mr. Liedtke agreed to transfer a portion of his ownership interest in the
Company's predecessors directly to Mr. Musselman. See Note 11 of the Notes to
the Consolidated Financial Statements.
Certain of the transactions comprising the Corporate Reorganization
represent transactions between the Company, or its predecessors, and its
affiliates. Messrs. Liedtke, Grella and Musselman, the shareholders of Valley
and CSL will sell the stock of Valley and the assets of CSL to the Company for
$0.7 million. The purchase price is based on negotiations between Messrs.
Liedtke, Grella and Musselman, on the one hand, and NBCC, considering the value
to the Company of the stock and assets being acquired. No third party conducted
an appraisal of either Valley or CSL.
Messrs. Liedtke, Grella and Musselman will receive an aggregate distribution
from the LLC of approximately $3.5 million which is estimated to be the federal
income tax liability (as well as the federal income tax liability on such
distribution) which will be owed by Messrs. Liedtke, Grella and Musselman as a
result of the Corporate Reorganization. However, the precise amount of such
liability will be dependent upon a number of factors which cannot be determined
with certainty until subsequent to December 31, 1996. While the amount to be
distributed has been determined in good faith by the Company's tax advisors,
there can be no assurance that the actual tax liability of any of Messrs.
Liedtke, Grella or Musselman will not be less or greater than the distributed
amounts. If the distributed amounts exceed the ultimate tax liabilities, none of
such persons will reimburse the Company. Correspondingly, if the tax liability
exceeds the amount of such distributions, the Company will not make any further
distributions to cover such short-fall. NBCC is also receiving a distribution of
$0.8 million, which represents its post-redemption ownership percentage of the
distribution made to Messrs. Liedtke, Grella and Musselman. However, NBCC has no
tax or other liability with respect to such distribution. In addition, Messrs.
Liedtke, Grella and Musselman and NBCC will receive an aggregate of 6,000,000
shares of Common Stock in the Merger in exchange for their interests in the LLC.
DESCRIPTION OF CERTAIN INDEBTEDNESS
EXISTING DEBT FACILITY
In June 1996, the Company entered into a credit agreement (the "Existing
Debt Facility") provided by NationsBridge, L.L.C. and NationsBank, N.A. and
consisting of a $95.0 million revolving credit loan (the "Existing Revolver")
and a $30.0 million term loan (the "Existing Term Loan"). The Existing Debt
Facility provided funds to consummate the 1996 Acquisition and to refinance the
Company's prior senior bank facility. Prudential Securities Group Inc. ("PGI")
has purchased an interest in the Existing Debt Facility.
The Existing Revolver and the Existing Term Loan each matures June 10, 1999.
No periodic principal reductions are required with respect to the Existing Term
Loan; however, quarterly principal reductions in the amount of $3.0 million are
required with respect to the Existing Revolver, commencing January 1, 1997. In
addition, the Existing Debt Facility requires that the net proceeds from the
Notes Offering be applied to reduce the amounts outstanding under the Existing
Revolver and the Existing Term Loan, and 100% of the net proceeds from the
Common Stock Offering are required to be utilized to reduce the amounts
outstanding under the Existing Term Loan and Existing Revolver.
Interest accrues on the Existing Term Loan initially at 14.0% per annum,
increasing by 0.5% at per annum the end of each successive three month period
(commencing September 13, 1996) up to a maximum of 16.5% per annum. Interest may
be paid in cash or "in kind" by delivery of additional notes having the same
terms as the notes issued pursuant to the Existing Term Loan. Interest under the
Existing Revolver accrues, at the option of the Company, at a margin in excess
of either NationsBank, N.A. "LIBOR" rate, up to a maximum of 5.0% per annum, or
NationsBank, N.A. fluctuating "prime rate" up to a maximum of 2.75% per annum.
The Existing Debt Facility is secured by a pledge of substantially all of
the Company's assets, a guaranty by the Company's subsidiaries and limited
guaranties by Messrs. Liedtke, Grella and Musselman proportionate to their
membership interests in the LLC.
CREDIT FACILITY
The Credit Facility will provide the Company with a revolving facility based
on the borrowing base of its oil and gas assets which will initially be set at
$50.0 million, none of which is expected to be outstanding at its inception. The
Credit Facility is expected to be secured by a pledge of substantially all of
the assets of the
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Company and any subsidiary of the Company that guarantees the Company's
obligations under the Credit Facility. Initially, none of the Company's
subsidiaries will guarantee such obligations. Messrs. Liedtke, Grella and
Musselman will not guarantee indebtedness due under the Credit Facility. See
"Management's Discussion and Analysis of Financial Condition and Results of
Operations -- Liquidity and Capital Resources" for a further description of the
Credit Facility.
THE NOTES
The Company is concurrently offering $100 million in aggregate principal
amount of the Notes by means of a separate prospectus. The closing of the Common
Stock Offering and the Notes Offering are conditioned upon each other.
The Notes will be general unsecured obligations of the Company, will be pari
passu in right of payment to all existing and future senior indebtedness of the
Company and will be senior in right of payment to all other subordinated
indebtedness of the Company. The Notes will bear interest payable semiannually
at a rate to be determined at the pricing of the Notes Offering and will mature
in 2006.
The Notes will not be redeemable until 2001. Thereafter, the
Notes will be redeemable at any time at the option of the Company in whole or in
part at the redemption prices set forth in the Indenture. There will be no
mandatory sinking fund for the Notes. Upon the occurrence of a change of
control, the Company will be required to make an offer to purchase all the Notes
at 101% of the principal amount thereof, plus accrued and unpaid interest to the
date of purchase.
The Indenture will contain certain covenants that, among other things, limit
the ability of the Company and certain of its subsidiaries to pay dividends or
make certain other restricted payments, issue preferred stock, incur additional
indebtedness, enter into transactions with affiliates, incur liens, engage in
certain sale and leaseback arrangements, make certain asset dispositions and
merge or consolidate with, or transfer substantially all of its assets to, any
other person. The Indenture will also contain certain covenants that limit the
ability of certain of the Company's subsidiaries to restrict their ability to
make payments to the Company. The Indenture will contain customary events of
default.
DESCRIPTION OF CAPITAL STOCK
The authorized capital stock of the Company consists of 20,000,000 shares of
Common Stock, par value $0.10 per share ("Common Stock") and 3,000,000 shares of
Preferred Stock, par value $0.10 per share ("Preferred Stock"). Upon the
completion of the Offerings and the Corporate Reorganization, the issued and
outstanding capital stock of the Company will consist of 10,000,000 shares of
Common Stock (or 10,600,000 shares if the Underwriters' over-allotment option is
exercised in full).
The following description of certain matters relating to the capital stock
of the Company is summary in nature and is qualified in its entirety by the
provisions of the Company's Certificate of Incorporation and Bylaws, copies of
which have been filed as exhibits to the Registration Statement of which this
Prospectus is a part.
COMMON STOCK
Except as otherwise required by law, the holders of Common Stock are
entitled to one vote per share on all matters submitted to a vote of
stockholders of the Company. In addition, such holders are entitled to receive
ratably such dividends, if any, as may be declared from time to time by the
Board of Directors out of funds legally available therefor, subject to the
payment of preferential dividends with respect to any Preferred Stock that from
time to time may be outstanding. In the event of the dissolution, liquidation or
winding-up of the Company, the holders of Common Stock are entitled to share
ratably in all assets remaining after payment of all liabilities of the Company
and subject to the prior distribution rights of the holders of any Preferred
Stock that may be outstanding at that time. The holders of Common Stock do not
have cumulative voting rights or preemptive rights. All shares of Common Stock
outstanding and to be outstanding after the Common Stock Offering will be fully
paid and nonassessable.
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PREFERRED STOCK
The Board of Directors has the authority to issue 3,000,000 shares of
Preferred Stock, in one or more series, and to fix the rights, preferences,
qualifications, privileges, limitations or restrictions of each such series
without any further vote or action by the stockholders, including the dividend
rights, dividend rate, conversion rights, voting rights, terms of redemption
(including sinking fund provisions), redemption price or prices, liquidation
preferences and the number of shares constituting any series or the designations
of such series. No shares of Preferred Stock have ever been issued, and the
Company has no present plans to issue any Preferred Stock. The Indenture
governing the Notes limits the issuance of Preferred Stock in some instances.
While providing desirable flexibility in connection with possible
acquisitions and other corporate purposes, and eliminating delays associated
with a stockholder vote on specific issuances, the issuance of Preferred Stock
could adversely affect the voting power of holders of Common Stock and the
likelihood that such holders will receive dividend payments and payments upon
liquidation and could have the effect of delaying, deferring or preventing a
change in control of the Company.
REGISTRATION RIGHTS
The Company has agreed that, upon the request of NBCC, on up to two
occasions, the Company will register under the Securities Act and applicable
state securities laws the sale of the Common Stock owned by NBCC. The Company's
obligation is subject to certain limitations regarding the timing of
registrations and certain other matters. The Company is also obligated to offer
to the Affiliated Holders the opportunity to include shares of the Common Stock
owned by them in certain registration statements filed by the Company. In
addition, the Company has agreed to indemnify the Affiliated Holders and their
respective officers and directors against securities law liabilities arising in
connection with such offerings, other than liabilities arising as a result of
information furnished by the Company by the Affiliated Holders participating in
the registration. The Company is obligated to pay all expenses incident to such
registration, except underwriting discounts and commissions allocable to the
sale of shares by Affiliated Holders and any professional fees and expenses
incurred by the Affiliated Holders incident to such registration.
ANTI-TAKEOVER PROVISIONS
The Certificate of Incorporation and Bylaws of the Company and the Delaware
General Corporation Law (the "DGCL") include a number of provisions which may
have the effect of encouraging persons considering unsolicited tender offers or
other unilateral takeover proposals to negotiate with the Board of Directors
rather than pursue non-negotiated takeover attempts. These provisions include a
classified board of directors, authorized blank check preferred stock,
restrictions on business combinations and the availability of authorized but
unissued Common Stock.
CLASSIFIED BOARD OF DIRECTORS. The Company's Certificate of Incorporation
and Bylaws contain provisions for a board of directors divided into classes with
only one class standing for election each year. Directors can only be removed
for cause. A staggered board makes it more difficult for stockholders to change
the majority of the directors and instead promotes a continuity of existing
management.
BLANK CHECK PREFERRED STOCK. The Certificate of Incorporation authorizes
blank check Preferred Stock. See "-- Preferred Stock." The Board of Directors
can set the voting rights, redemption rights, conversion rights and other rights
relating to such Preferred Stock and could issue such stock in either a private
or public transaction. In some circumstances, the blank check Preferred Stock
could be issued and have the effect of preventing a merger, tender offer or
other takeover attempt which the Board of Directors opposes.
DELAWARE TAKEOVER STATUTE
The Company is subject to Section 203 of the DGCL. In general, Section 203
prevents an "interested stockholder" from engaging in a "business combination"
with a Delaware corporation for three years following the date such person
became an interested stockholder, unless (i) prior to the date such person
became an interested stockholder, the board of directors of the corporation
approved the transaction in which the interested stockholder became an
interested stockholder or approved the business combination; (ii) upon
consummation of the transaction that resulted in the interested stockholder's
becoming an
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interested stockholder, the interested stockholder owns at least 85% of the
voting stock of the corporation outstanding at the time the transaction
commenced, excluding stock held by directors who are also officers of the
corporation and stock held by certain employee stock plans; or (iii) on or
subsequent to the date of the transaction in which such person became an
interested stockholder, the business combination is approved by the board of
directors of the corporation and authorized at a meeting of the stockholders by
the affirmative vote of the holders of two-thirds of the outstanding voting
stock of the corporation not owned by the interested stockholder.
Section 203 defines a "business combination" to include (i) any merger or
consolidation involving the corporation and an interested stockholder; (ii) any
sale, transfer, pledge or other disposition involving an interested stockholder
of 10% or more of the assets of the corporation; (iii) subject to certain
exceptions, any transaction which results in the issuance or transfer by the
corporation of any stock of the corporation to an interested stockholder; (iv)
any transaction involving the corporation which has the effect of increasing the
proportionate share of the stock of any class or series of the corporation
beneficially owned by the interested stockholder or (v) the receipt by an
interested stockholder of any loans, guarantees, pledges or other financial
benefits provided by or through the corporation. For purposes of Section 203,
the term "corporation" also includes the Company's majority-owned subsidiaries.
In addition, Section 203 defines an "interested stockholder" as an entity or
person beneficially owning 15% or more of the outstanding voting stock of the
corporation and any entity or person affiliated with or controlling or
controlled by such entity or person.
STOCKHOLDER ACTION
With respect to any act or action required of or by the holders of the
Common Stock, the affirmative vote of a majority of the shares of Common Stock
present in person or represented by proxy at a meeting and entitled to vote
thereon is sufficient to authorize, affirm, ratify or consent to such act or
actions, except as otherwise provided by law or in the Certificate of
Incorporation. The DGCL requires the approval of the holders of a majority of
the outstanding stock entitled to vote for certain extraordinary corporate
transactions, such as a merger, sale of substantially all assets, dissolution or
amendment of the Certificate of Incorporation.
Pursuant to Delaware law, stockholders may take actions without the holding
of a meeting by written consent or consents signed by the holders of a
sufficient number of shares to approve the transaction had all of the
outstanding shares of the capital stock of the Company entitled to vote thereon
been present at a meeting. The Affiliated Holders will own 49.2% of the
outstanding Common Stock after the Offering. See "Security Ownership of Certain
Beneficial Owners and Management." Pursuant to the rules and regulations of the
Commission, if stockholder action is taken by written consent, the Company will
be required to send each stockholder entitled to vote on the matter acted on,
but whose consent was not received, an information statement containing
information substantially similar to that which would have been contained in a
proxy statement.
TRANSFER AGENT AND REGISTRAR
The transfer agent and registrar for the Common Stock will be The First
National Bank of Boston, 100 Federal Street, Boston, Massachusetts 02110.
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SHARES ELIGIBLE FOR FUTURE SALE
Upon completion of the Common Stock Offering, the Company will have a total
of 10,000,000 shares of Common Stock outstanding. Of these shares, the 4,000,000
shares of Common Stock offered hereby (4,600,000 shares if the Underwriters'
over-allotment option is exercised in full) will be freely tradable without
restriction or registration under the Securities Act by persons other than
"affiliates" of the Company, as defined under the Securities Act. The remaining
6,000,000 shares of Common Stock outstanding will be "restricted securities" as
that term is defined by Rule 144 as promulgated under the Securities Act.
In general, under Rule 144 as currently in effect, a person (or persons
whose shares are aggregated) who has beneficially owned restricted securities
for at least two years, including persons who may be deemed "affiliates" of the
Company, would be entitled to sell within any three-month period a number of
shares that does not exceed the greater of one percent of the number of shares
of Common Stock then outstanding (approximately 100,000 shares upon completion
of the Common Stock Offering) or the average weekly trading volume of the Common
Stock during the four calendar weeks preceding the filing of a Form 144 with
respect to such sale. Sales under Rule 144 are also subject to certain manner of
sale provisions and notice requirements, and to the availability of current
public information about the Company. In addition, a person who is not deemed to
have been an affiliate of the Company at any time during the 90 days preceding a
sale, and who has beneficially owned the shares proposed to be sold for at least
three years, would be entitled to sell such shares under Rule 144(k) without
regard to the requirements described above.
Under Rule 144 (and subject to the conditions thereof, including the volume
limitations described above), approximately 4,919,992 of the 6,000,000
restricted shares will become eligible for sale 90 days after the Common Stock
Offering. All 6,000,000 of the restricted shares are subject to lockup
restrictions. Pursuant to these restrictions the holders of these restricted
shares, including certain of its executive officers and directors and NBCC, have
agreed that they will not, subject to certain exceptions, directly or
indirectly, offer, sell, offer to sell, contract to sell, pledge, grant any
option to purchase or otherwise sell or dispose (or announce any offer, sale,
offer of sale, contract to sell, pledge, grant of any options to purchase or
sale or disposition) of any shares of Common Stock or other capital stock of the
Company, or any securities convertible into, or exercisable or exchangeable for,
any shares of Common Stock or other capital stock of the Company without the
prior written consent of Prudential Securities Incorporated, on behalf of the
Underwriters, for a period of 180 days from the date of this Prospectus. After
such 180-day period, this restriction will expire and shares permitted to be
sold under Rule 144 would be eligible for sale. In addition, NBCC has demand
registration rights to require the Company to file up to two registration
statements under the Securities Act of the shares of Common Stock held by such
holder and NBCC and the other major stockholders have "piggyback" registration
rights, which would permit such holders to resell such shares without complying
with Rule 144. Registration and sale of such shares could have an adverse effect
on the trading price of the Common Stock. The Company currently has eight stock
options outstanding for 550,000 shares. See "Executive Compensation and Other
Information."
Prior to the Common Stock Offering, there has been no public market for the
Common Stock and no predictions can be made of the effect, if any, that the sale
or availability for sale of shares of additional Common Stock will have on the
market price of the Common Stock. Nevertheless, sales of substantial amounts of
such shares in the public market, or the perception that such sales could occur,
could materially and adversely affect the market price of the Common Stock and
could impair the Company's future ability to raise capital through an offering
of its equity securities.
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UNDERWRITING
The Underwriters named below (the "Underwriters"), for whom Prudential
Securities Incorporated and Rauscher Pierce Refsnes, Inc. are acting as
Representatives, have severally agreed, subject to the terms and conditions
contained in the Underwriting Agreement, to purchase from the Company the number
of shares of Common Stock set forth below opposite their respective names:
<TABLE>
<CAPTION>
NUMBER
UNDERWRITER OF SHARES
- --------------------------------------------------------------------------------------- ----------
<S> <C>
Prudential Securities Incorporated.....................................................
Rauscher Pierce Refsnes, Inc...........................................................
----------
Total................................................................................ 4,000,000
----------
----------
</TABLE>
The Company is obligated to sell, and the Underwriters are obligated to
purchase, all of the shares of Common Stock offered hereby if any are purchased.
The Underwriters, through the Representatives, have advised the Company that
they propose to offer the shares of Common Stock initially at the public
offering price set forth on the cover page of this Prospectus; that the
Underwriters may allow to selected dealers a concession of $ per share; and
that such dealers may reallow a concession of $ per share to certain other
dealers. After the initial public offering, the offering price and the
concessions may be changed by the Representatives.
The Company has granted to the Underwriters an option, exercisable for 30
days from the date of this Prospectus, to purchase up to 600,000 additional
shares of Common Stock at the initial public offering price less underwriting
discounts and commissions, as set forth on the cover page of this Prospectus.
The Underwriters may exercise such option solely for the purpose of covering
over-allotments incurred in the sale of the shares of Common Stock offered
hereby. To the extent such option to purchase is exercised, each Underwriter
will become obligated, subject to certain conditions, to purchase approximately
the same percentage of such additional shares as the number of shares set forth
opposite each Underwriters' name in the preceding table bears to 4,000,000.
The Company, its executive officers and directors, and all of the Company's
stockholders have agreed that they will not, directly or indirectly, offer,
sell, offer to sell, contract to sell, pledge, grant any option to purchase, or
otherwise sell or dispose of (or announce any offer, sale, offer of sale,
contract of sale, pledge, grant of any option to purchase or other sale or
disposition) of any shares of Common Stock of the Company or any securities
convertible into, or exercisable or exchangeable for, any shares of Common Stock
or other capital stock of the Company without the prior written consent of
Prudential Securities Incorporated, on behalf of the Underwriters, for a period
of 180 days after the date of this Prospectus.
The Company has agreed to indemnify the several Underwriters or to
contribute to losses arising out of certain liabilities, including liabilities
under the Securities Act.
The Representatives have informed the Company that the Underwriters do not
intend to confirm sales to any accounts over which they exercise discretionary
authority.
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Prior to the Common Stock Offering, there has been no public market for the
Common Stock of the Company. Consequently, the initial public offering price for
the Common Stock will be determined through negotiation between the Company and
the Representatives of the Underwriters. Among the factors to be considered in
making such determination will be the prevailing market conditions, the results
of operations of the Company in recent periods relevant to its prospects and the
prospects for its industry in general, the management of the Company and the
market prices of securities for companies in businesses similar to that of the
Company.
PGI, an affiliate of Prudential Securities Incorporated, is a lender under
the Existing Debt Facility. See "Description of Certain Indebtedness." The
lenders under the Existing Debt Facility will receive customary fees and other
compensation. PGI will receive its proportionate share of the repayment by the
Company of borrowings under the Existing Debt Facility from the net proceeds of
the Notes Offering. Prudential Securities Incorporated is also acting as an
underwriter in the Company's concurrent Notes Offering for which it will receive
customary underwriting discounts and commissions.
LEGAL MATTERS
Certain legal matters related to the Common Stock offered hereby are being
passed upon for the Company by Cotton, Bledsoe, Tighe & Dawson, a Professional
Corporation, Midland, Texas. Certain matters will be passed upon for the
Underwriters by Baker & Botts, L.L.P., Houston, Texas.
EXPERTS
The consolidated financial statements of Costilla Energy, L.L.C. and
subsidiaries as of December 31, 1995 and for the year then ended, the statements
of revenues and direct operating expenses of the 1996 Acquisition for the years
ended December 31, 1993, 1994 and 1995, and the statements of revenues and
direct operating expenses of the 1995 Acquisition for the years ended December
31, 1993 and 1994, and the period ended June 12, 1995, have been included herein
and in the registration statement in reliance upon the report of KPMG Peat
Marwick LLP, independent certified public accountants, appearing elsewhere
herein, and upon the authority of said firm as experts in accounting and
auditing.
The consolidated financial statements of Costilla Energy, L.L.C. and
subsidiaries as of December 31, 1994, and for the years ended December 31, 1993
and 1994, have been included herein and in the registration statement in
reliance upon the report of Elms, Faris & Co., P.C., independent certified
public accountants, appearing elsewhere herein, and upon the authority of said
firm as experts in accounting and auditing.
In September 1995, the Company changed its principal accountants from Elms,
Faris & Co., P.C. to KPMG Peat Marwick LLP. The reports of Elms, Faris & Co.,
P.C. on the Company's financial statements for the year ended December 31, 1994
did not contain an adverse opinion or a disclaimer of opinion, nor was it
qualified or modified in any way as to uncertainty, audit scope or accounting
principles. Moreover, there were no disagreements with Elms, Faris & Co., P.C.
on any matter of accounting principles or practices,
financial statement disclosure, or auditing scope or procedure. The members of
the LLC made the decision to change the LLC's principal accountants.
Certain information appearing in this Prospectus regarding estimated
quantities of oil and gas reserves and the discounted present value of future
pre-tax cash flows therefrom attributable to the Company's properties and to the
properties included in the 1996 Acquisition is based upon estimates of such
reserves and present values prepared by Williamson Petroleum Consultants, Inc.
All of such information has been so included herein in reliance upon the
authority of such firm as experts in such matters. Set forth as Appendix A is
Williamson's Summary Reserve Report dated July 23, 1996 with respect to the oil
and gas interests of the Company and with respect to properties acquired in the
1996 Acquisition.
AVAILABLE INFORMATION
Upon completion of the Offerings, the Company will be subject to the
informational requirements of the Securities Exchange Act of 1934, as amended
(the "Exchange Act"), and, in accordance therewith, will
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<PAGE>
file reports, proxy statements and other information with the Commission. Such
reports, proxy statements and other information filed by the Company with the
Commission can be inspected at the Public Reference Section of the Commission at
Room 1024, Judiciary Plaza, 450 Fifth Street, N.W., Washington, D.C. 20549, and
the Regional Offices of the Commission at Citicorp Center, 500 West Madison
Street, Suite 1400, Chicago, Illinois 60661-2511, and 7 World Trade Center, New
York, New York 10048. Copies of such material can also be obtained from the
Public Reference Section of the Commission at Room 1024, Judiciary Plaza, 450
Fifth Street, N.W., Washington, D.C. 20549, at prescribed rates. The Commission
maintains a World Wide Web site on the Internet at HTTP:\\WWW.SEC.GOV that
contains reports, proxy and information statements and other information
regarding registrants that file electronically with the Commission.
The Company has filed with the Commission a Registration Statement on Form
S-1 under the Securities Act with respect to the Common Stock offered hereby.
This Prospectus, which constitutes a part of the Registration Statement, does
not contain all of the information set forth in the Registration Statement,
certain items of which are contained in exhibits to the Registration Statement
as permitted by the rules and regulations of the Commission. For further
information with respect to the Company and the Common Stock offered hereby,
reference is made to the Registration Statement, including the exhibits thereto,
which may be inspected without charge at the public reference facilities
maintained by the Commission at 450 Fifth Street, N.W., Washington, D.C. 20549
and at the Regional Offices of the Commission, and copies of which may be
obtained from the Commission at prescribed rates. Statements made in this
Prospectus concerning the contents of any document referred to herein are not
necessarily complete. With respect to each such document filed with the
Commission as an exhibit to the Registration Statement, reference is made to the
exhibit for a more complete description of the matter involved, and each such
statement made herein shall be deemed qualified by such reference.
59
<PAGE>
GLOSSARY
The terms defined in this section are used throughout this Prospectus.
ADJUSTED EBITDA. Calculated by adding interest, income taxes, depreciation,
depletion and amortization, exploration and abandonment costs and extraordinary
loss resulting from extinguishment of debt to net income (loss).
ALL-IN FINDING COSTS. The amount of total capital expenditures, including
acquisition costs, and exploration and abandonment costs for oil and gas
activities divided by the amount of proved reserves (expressed in BOE) added
during the specified period (including the effect on proved reserves of reserve
revisions).
BBL. One stock tank barrel, or 42 U.S. gallons liquid volume, used herein
in reference to crude oil or other liquid hydrocarbons.
BCF. One billion cubic feet.
BOE. Equivalent barrels of oil. In reference to natural gas, natural gas
equivalents are determined using the ratio of six Mcf of natural gas to one Bbl
of crude oil, condensate or natural gas liquids.
BTU. One British thermal unit. The quantity of heat required to raise the
temperature of one pound of water one degree Fahrenheit.
DEVELOPED ACREAGE. The number of acres which are allocated or assignable to
producing wells or wells capable of production.
DEVELOPMENT WELL. A well drilled within the proved area of an oil or gas
reservoir to the depth of a stratigraphic horizon known to be productive.
DRY WELL. A well found to be incapable of producing either oil or gas in
sufficient quantifies to justify completion of an oil or gas well.
EXPLORATORY WELL. A well drilled to find and produce oil or gas in an
unproved area, to find a new reservoir in a field previously found to be
productive of oil or gas in another reservoir, or to extend a known reservoir.
GROSS ACRES OR GROSS WELLS. The total acres or wells, as the case may be,
in which a working interest is owned.
MBBL. One thousand barrels of crude oil or other liquid hydrocarbons.
MBOE. One thousand barrels of oil equivalent.
MMBOE. One million barrels of oil equivalent.
MMBBLS. One million barrels of crude oil or other liquid hydrocarbons.
MMBTU. One million Btu's.
MCF. One thousand cubic feet.
MMCF. One million cubic feet.
NET ACRES OR NET WELLS. The sum of the fractional working interests owned
in gross acres or gross wells.
PRESENT VALUE OF ESTIMATED FUTURE NET REVENUES OR PV-10 VALUE. The present
value of estimated future net revenues is an estimate of future net revenues
from a property at its acquisition date, at a specified date, after deducting
production and ad valorem taxes, future capital costs and operating expenses,
but before deducting federal income taxes. The future net revenues have been
discounted at an annual rate of 10% to determine their "present value." The
present value is shown to indicate the effect of time on the value of the
revenue stream and should not construed as being the fair market value of the
properties. Estimates have been made using constant oil and natural gas prices
and operating costs at the specified date.
PRODUCTIVE WELL. A well that is producing oil or gas that is capable of
production.
60
<PAGE>
PROVED DEVELOPED RESERVES. Reserves that can be expected to be recovered
through existing wells with existing equipment and operating methods.
PROVED RESERVES. The estimated quantities of crude oil, natural gas and
natural gas liquids which geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from known reservoirs
under existing economic and operating conditions.
PROVED UNDEVELOPED RESERVES. Reserves that are expected to be recovered
from new wells on undrilled acreage, or from existing wells where a relatively
major expenditure is required for recompletion.
ROYALTY INTEREST. An interest in an oil and gas property entitling the
owner to a share of oil and gas production free of costs of production.
3-D SEISMIC. Advanced technology method of detecting accumulations of
hydrocarbons identified by the collection and measurement of the intensity and
timing of sound waves transmitted into the earth as they reflect back to the
surface.
UNDEVELOPED ACREAGE. Lease acreage 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 such acreage contains proved reserves.
WORKING INTEREST. The operating interest which gives the owner the right to
drill, produce and conduct operating activities on the property and a share of
production.
61
<PAGE>
INDEX TO FINANCIAL STATEMENTS
<TABLE>
<S> <C>
Financial Statements of Costilla Energy, L.L.C.:
Independent Auditors' Reports...................................................... F-2
Consolidated Balance Sheets as of December 31, 1994 and 1995, and June 30, 1996
(unaudited)....................................................................... F-4
Consolidated Statements of Operations for the years ended December 31, 1993, 1994,
and 1995, and the six months ended June 30, 1995 and 1996 (unaudited)............. F-5
Consolidated Statements of Members' Capital for the years ended December 31, 1993,
1994, and 1995, and the six months ended June 30, 1995 (unaudited)................ F-6
Consolidated Statements of Cash Flows for the years ended December 31, 1993, 1994,
and 1995, and the six months ended June 30, 1995 and 1996 (unaudited)............. F-7
Notes to Consolidated Financial Statements......................................... F-8
Financial Statements of the 1995 Acquisition:
Independent Auditors' Report....................................................... F-22
Statements of Revenues and Direct Operating Expenses for the years ended December
31, 1993 and 1994 and the period ended June 12, 1995.............................. F-23
Notes to the Statements of Revenues and Direct Operating Expenses.................. F-24
Financial Statements of the 1996 Acquisition:
Independent Auditors' Report....................................................... F-27
Statements of Revenues and Direct Operating Expenses for the years ended December
31, 1993, 1994 and 1995, and the periods ended June 14, 1995 and 1996
(unaudited)....................................................................... F-28
Notes to the Statements of Revenues and Direct Operating Expenses.................. F-29
</TABLE>
Note: The financial statements of Costilla Energy, Inc. (incorporated in June
1996) are not presented, as Costilla Energy, Inc. has no material assets,
liabilities or equity, and has not generated any material revenues or
incurred any material expenses.
F-1
<PAGE>
INDEPENDENT AUDITORS' REPORT
The Members
Costilla Energy, L.L.C. (a Texas limited liability company):
We have audited the accompanying consolidated balance sheet of Costilla
Energy, L.L.C. (a Texas limited liability company) and subsidiaries as of
December 31, 1995, and the related consolidated statement of operations,
members' capital, and cash flows for the year then ended. These consolidated
financial statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audit.
We conducted our audit 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 audit provides a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above
present fairly, in all material respects, the financial position of Costilla
Energy, L.L.C. and subsidiaries as of December 31, 1995, and the results of
their operations and their cash flows for the year then ended, in conformity
with generally accepted accounting principles.
KPMG PEAT MARWICK LLP
Midland, Texas
April 16, 1996 (except with respect to matters discussed in the last paragraph
of Note 7 and Note 12, as to which the date is June 14, 1996.)
F-2
<PAGE>
INDEPENDENT AUDITORS' REPORT
The Members
Costilla Energy, L.L.C.:
We have audited the accompanying consolidated balance sheet of Costilla
Energy, L.L.C. (a Texas limited liability company) and subsidiaries (the
combination of CSL Partners, Costilla Petroleum Corporation and Statewide
Minerals, L.C.) as of December 31, 1994, and the related consolidated statements
of operations, members' capital, and cash flows for the years ended December 31,
1993 and 1994. These consolidated 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 audits 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 provides a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above
present fairly, in all material respects, the consolidated financial position of
Costilla Energy, L.L.C. and subsidiaries as of December 31, 1994, and the
results of their operations and their cash flows for the years ended December
31, 1993 and 1994, in conformity with generally accepted accounting principles.
ELMS, FARIS & CO., P.C.
Midland, Texas
March 31, 1995
F-3
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS)
ASSETS
<TABLE>
<CAPTION>
DECEMBER 31,
---------------- JUNE 30,
1994 1995 1996
------- ------- -----------
(UNAUDITED)
<S> <C> <C> <C>
Current assets:
Cash and cash equivalents............................................................... $ 137 $ 2,866 $ 1,164
Accounts receivable:
Trade, net............................................................................ 1,042 3,154 2,521
Affiliates............................................................................ -- 507 927
Oil and gas sales..................................................................... 1,715 3,915 5,337
Prepaid and other current assets........................................................ 223 439 2,629
------- ------- -----------
Total current assets.............................................................. 3,117 10,881 12,578
------- ------- -----------
Property, plant and equipment, at cost:
Oil and gas properties, using the successful efforts method of accounting:
Proved properties..................................................................... 22,794 79,897 126,809
Unproved properties................................................................... 2,060 2,903 4,615
Accumulated depletion, depreciation and amortization.................................... (3,562) (9,413) (13,933)
------- ------- -----------
21,292 73,387 117,491
------- ------- -----------
Other property and equipment, net......................................................... 76 679 1,640
Deferred charges (Note 2)................................................................. 29 1,736 2,654
Note receivable -- affiliate.............................................................. 390 684 684
------- ------- -----------
$24,904 $87,367 $135,047
------- ------- -----------
------- ------- -----------
<CAPTION>
LIABILITIES, REDEEMABLE MEMBERS' CAPITAL AND MEMBERS' CAPITAL
<S> <C> <C> <C>
Current liabilities:
Current maturities of long-term debt.................................................... $ 22 $ -- $ 98
Trade accounts payable.................................................................. 1,712 5,467 4,587
Undistributed revenue................................................................... 110 1,227 1,524
Other current liabilities............................................................... 192 1,691 2,103
------- ------- -----------
Total current liabilities......................................................... 2,036 8,385 8,312
------- ------- -----------
Long-term debt, less current maturities (Note 7).......................................... 23,591 71,494 122,267
Deferred income (Note 2).................................................................. 24 3,319 2,623
Other noncurrent liabilities.............................................................. -- 38 --
------- ------- -----------
Total liabilities................................................................. 25,651 83,236 133,202
------- ------- -----------
Redeemable members' capital (Note 10)..................................................... -- 11,576 13,171
------- ------- -----------
Members' capital (Note 10)................................................................ (747) (7,445) (11,326)
Commitments and contingencies (Note 8).................................................... -- -- --
------- ------- -----------
$24,904 $87,367 $135,047
------- ------- -----------
------- ------- -----------
</TABLE>
See accompanying notes to consolidated financial statements.
F-4
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
CONSOLIDATED STATEMENTS OF OPERATIONS
(IN THOUSANDS)
<TABLE>
<CAPTION>
SIX MONTHS ENDED
YEARS ENDED DECEMBER 31, JUNE 30,
------------------------------- --------------------
1993 1994 1995 1995 1996
--------- --------- --------- --------- ---------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
Revenues:
Oil and gas sales........................................... $ 4,231 $ 7,637 $ 21,693 $ 5,568 $ 19,445
Interest and other.......................................... 56 87 123 5 40
Gain on sale of assets...................................... 110 112 -- -- 40
--------- --------- --------- --------- ---------
4,397 7,836 21,816 5,573 19,525
--------- --------- --------- --------- ---------
Expenses:
Oil and gas production...................................... 1,688 2,349 10,024 2,268 8,093
Oil and gas production -- affiliates........................ -- 2 331 145 185
General and administrative.................................. 639 634 2,910 678 2,439
General and administrative -- affiliates.................... 313 550 661 330 370
Compensation related to option settlement
(Note 11).................................................. -- -- 656 656 --
Exploration and abandonments................................ 218 793 1,650 1,007 308
Depreciation, depletion and amortization.................... 884 1,847 5,958 1,367 4,620
Interest.................................................... 605 1,458 4,591 1,046 4,156
Other....................................................... -- -- 2 -- --
--------- --------- --------- --------- ---------
4,347 7,633 26,783 7,497 20,171
--------- --------- --------- --------- ---------
Income (loss) before federal income taxes and
extraordinary item....................................... 50 203 (4,967) (1,924) (646)
Provision for federal income taxes
Current..................................................... (25) 8 3 -- --
Deferred.................................................... 2 32 -- -- --
--------- --------- --------- --------- ---------
Income (loss) before extraordinary item................... 73 163 (4,970) (1,924) (646)
Extraordinary loss resulting from extinguishment of debt
(Note 7)................................................. -- -- -- -- (1,640)
--------- --------- --------- --------- ---------
Net income (loss)............................................. 73 163 (4,970) (1,924) (2,286)
Preferred return and accretion of redeemable members'
capital...................................................... -- -- (2,842) (975) (1,595)
--------- --------- --------- --------- ---------
Net income (loss) applicable to members' capital.............. $ 73 $ 163 $ (7,812) $ (2,899) $ (3,881)
--------- --------- --------- --------- ---------
--------- --------- --------- --------- ---------
</TABLE>
See accompanying notes to consolidated financial statements.
F-5
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
CONSOLIDATED STATEMENTS OF MEMBERS' CAPITAL
(IN THOUSANDS)
<TABLE>
<CAPTION>
MEMBERS'
CAPITAL
----------
<S> <C>
Balance at January 1, 1993............................................................................ $ 433
Net income.......................................................................................... 73
Contributions....................................................................................... 1
Withdrawals......................................................................................... (456)
----------
Balance at December 31, 1993.......................................................................... 51
Net income.......................................................................................... 163
Withdrawals......................................................................................... (961)
----------
Balance at December 31, 1994.......................................................................... (747)
Issuance of members' interest (Note 10)............................................................. 1,266
Issuance costs (Note 10)............................................................................ (753)
Net loss............................................................................................ (4,970)
Withdrawals......................................................................................... (55)
Imputed capital contribution on settlement of option (Note 11)...................................... 656
Preferred return and accretion of redeemable members' capital....................................... (2,842)
----------
Balance at December 31, 1995.......................................................................... (7,445)
Net loss (unaudited)................................................................................ (2,286)
Preferred return and accretion of redeemable members' capital (unaudited)........................... (1,595)
----------
Balance at June 30, 1996 (unaudited).................................................................. $ (11,326)
----------
----------
</TABLE>
See accompanying notes to consolidated financial statements.
F-6
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
<TABLE>
<CAPTION>
SIX MONTHS ENDED
YEARS ENDED DECEMBER 31, JUNE 30,
--------------------------- ------------------
1993 1994 1995 1995 1996
------- -------- -------- -------- --------
(UNAUDITED)
<S> <C> <C> <C> <C> <C>
Cash flows from operating activities:
Net income (loss)............................................................. $ 73 $ 163 $ (4,970) $ (1,924) $ (2,286)
Adjustments to reconcile net income (loss) to net cash provided by operating
activities:
Depreciation, depletion and amortization.................................... 884 1,847 5,958 1,367 4,620
Amortization of deferred charges............................................ -- -- 137 -- 169
Other noncash............................................................... (21) 35 (75) (28) 79
Compensation related to option settlement................................... -- -- 656 656 --
Gain on sale of oil and gas properties...................................... (110) (112) -- -- (40)
Extraordinary loss resulting from extinguishment of debt.................... -- -- -- -- 1,640
Change in operating assets and liabilities:
Increase in accounts receivable........................................... (837) (1,535) (4,818) (3,568) (1,209)
Decrease (increase) in other assets....................................... 20 301 (216) (107) (2,190)
Increase (decrease) in accounts payable................................... 262 723 4,863 2,188 (880)
Increase (decrease) in other liabilities.................................. 59 102 1,537 (1,624) 671
Increase (decrease) in deferred income.................................... (8) 3 3,294 -- (696)
------- -------- -------- -------- --------
Total adjustments....................................................... 249 1,364 11,336 (1,116) 2,164
------- -------- -------- -------- --------
Net cash provided by (used in) operating activities..................... 322 1,527 6,366 (3,040) (122)
------- -------- -------- -------- --------
Cash flows from investing activities:
Capital expenditures for oil and gas properties............................... (6,634) (11,819) (61,500) (57,261) (47,727)
Proceeds from sale of oil and gas properties.................................. 131 112 -- -- --
Additions to other property and equipment..................................... (228) (49) (720) (512) (1,996)
Advances on affiliate notes receivable........................................ -- (390) (247) -- --
------- -------- -------- -------- --------
Net cash used in investing activities................................... (6,731) (12,146) (62,467) (57,773) (49,723)
------- -------- -------- -------- --------
Cash flows from financing activities:
Borrowings under long-term debt............................................... 6,770 11,579 62,704 62,680 125,390
Payments of long-term debt.................................................... -- -- (11,232) (7,902) (74,519)
Deferred loan and financing costs............................................. -- -- (2,587) (2,587) (2,728)
Proceeds from redeemable members' capital..................................... -- -- 10,000 10,000 --
Contributions................................................................. 1 -- -- -- --
Withdrawals................................................................... (456) (961) (55) (97) --
------- -------- -------- -------- --------
Net cash provided by financing activities............................... 6,315 10,618 58,830 62,094 48,143
------- -------- -------- -------- --------
Net increase (decrease) in cash and cash equivalents............................ (94) (1) 2,729 1,281 (1,702)
Cash and cash equivalents, beginning of period.................................. 232 138 137 137 2,866
------- -------- -------- -------- --------
Cash and cash equivalents, end of period........................................ $ 138 $ 137 $ 2,866 $ 1,418 $ 1,164
------- -------- -------- -------- --------
------- -------- -------- -------- --------
</TABLE>
See accompanying notes to consolidated financial statements.
F-7
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(1) ORGANIZATION AND NATURE OF OPERATIONS
Costilla Energy, L.L.C. (the "Company"), a Texas limited liability company,
was formed on February 14, 1995, as the successor to CSL Partners, a Texas
general partnership, which was organized on January 11, 1989. The Company is an
unincorporated association of several individuals and a corporation and will
cease to exist thirty (30) years from the date of formation. Its members have
limited personal liability for the Company's obligations and debts. The Company
is classified as a partnership for federal income tax purposes.
The Company is an oil and gas exploration and production concern with
properties located principally in West Texas, South Texas, and the Rocky
Mountain regions of the United States.
(2) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
PRINCIPLES OF CONSOLIDATION
As of December 31, 1995, the consolidated financial statements include the
accounts of the Company and its wholly-owned subsidiaries. The Company
proportionately consolidates less-than-100%-owned oil and gas partnerships and
joint ventures in accordance with industry practice. All significant accounts
and transactions between the Company and its subsidiaries have been eliminated.
At December 31, 1993 and 1994, the financial statements of the Company and its
affiliates were combined. The combining companies were owned by three
individuals prior to the formation of the Company. Such individuals owned
exactly the same proportionate interest in each of the combining companies prior
to their combination into the Company on February 14, 1995. Each individual held
exactly the same proportionate interest in the combining companies as was their
proportionate interest in the Company after its formation. Management believes,
based on the exact same proportionate interests being held in the combining
companies and the Company before and after the date of its formation, that the
combination lacks substance and is not the purchase of a minority interest.
Subsequent to the formation of the Company, NBCC acquired a 30% interest in
the Company as described in Note 10.
Significant intercompany transactions were eliminated.
USE OF ESTIMATES
Preparation of the accompanying consolidated financial statements in
conformity with generally accepted accounting principles requires management to
make estimates and assumptions that affect the reported amounts of assets and
liabilities and disclosure of contingent assets and liabilities at the date of
the financial statements and the reported amounts of revenues and expenses
during the reporting period. Actual results could differ from those estimates.
CASH AND CASH EQUIVALENTS
For purposes of the statements of cash flows, cash and cash equivalents
include cash on hand and depository accounts held by banks.
CONCENTRATIONS OF CREDIT RISK
Financial instruments that potentially expose the Company to concentrations
of credit risk consist primarily of unsecured accounts receivable from
unaffiliated working interest owners and crude oil and natural gas purchasers.
During the year ended December 31, 1995, the Company had sales to one customer
which accounted for 17.7% of total revenues.
F-8
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(2) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
TRADE RECEIVABLES
Trade receivables generally consist of amounts due from outside working
interest owners for their proportionate share of drilling and operating costs
incurred by the Company, as operator of the related properties.
HEDGING
Premiums paid for commodity option contracts and interest rate swap
agreements are amortized to oil and gas sales and interest expense,
respectively, over the terms of the agreements. Unamortized premiums are
included in other assets in the consolidated balance sheet. Amounts receivable
under the commodity option contracts and interest rate swap agreements are
accrued as an increase in oil and gas sales and a reduction of interest expense,
respectively, for the applicable periods.
OIL AND GAS PROPERTIES
The Company uses the successful efforts method of accounting for oil and gas
producing activities. Costs to acquire mineral interests in oil and gas
properties, to drill and equip exploratory wells that find proved reserves, and
to drill and equip development wells are capitalized. Costs to drill exploratory
wells that do not find proved reserves, geological and geophysical costs, and
costs of carrying and retaining unproved properties are expensed.
Unproved oil and gas properties that are individually significant are
periodically assessed for impairment of value, and a loss is recognized at the
time of impairment by providing an impairment allowance. Other unproved
properties are amortized based on the Company's experience of successful
drilling and average holding period. Capitalized costs of producing oil and gas
properties, after considering estimated dismantlement and abandonment costs and
estimated salvage values, are depreciated and depleted by the unit-of-production
method. Support equipment and other property and equipment are depreciated on a
straight-line basis over the estimated useful lives of the assets, which range
from 5 to 7 years.
Prior to the adoption of FAS 121 on January 1, 1995, the Company's aggregate
oil and gas properties were carried at cost, not in excess of total estimated
undiscounted future net revenues, on a worldwide basis.
On sale or retirement of a complete unit of a proved property, the cost and
related accumulated depreciation, depletion, and amortization are eliminated
from the property accounts, and the resultant gain or loss is recognized. On
retirement or sale of a partial unit of proved property, the cost is charged to
accumulated depreciation, depletion, and amortization with a resulting gain or
loss recognized in income.
On sale of an entire interest in an unproved property for cash or cash
equivalent, gain or loss on the sale is recognized, taking into consideration
the amount of any recorded impairment if the property had been assessed
individually. If a partial interest in an unproved property is sold, the amount
received is treated as a reduction of the cost of the interest retained.
IMPAIRMENT OF LONG-LIVED ASSETS
As of January 1, 1995, the Company adopted the provisions of Statement of
Financial Accounting Standards No. 121 -- ACCOUNTING FOR THE IMPAIRMENT OF
LONG-LIVED ASSETS AND FOR LONG-LIVED ASSETS TO BE DISPOSED OF ("FAS 121").
Consequently, the Company reviews its long-lived assets to be held and used,
including oil and gas properties accounted for under the successful efforts
method of accounting, whenever events or circumstances indicate that the
carrying value of those assets may not be recoverable. An impairment loss is
indicated if the sum of the expected future cash flows is less than the carrying
amount of the assets. In this circumstance, the Company recognizes an impairment
loss for the amount by which the carrying amount of the asset exceeds the fair
value of the asset.
F-9
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(2) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (CONTINUED)
DEFERRED CHARGES
The Company capitalized certain costs incurred in connection with obtaining
the Credit Agreement and the related revolver and term notes (see Note 7 for
definitions and descriptions of each). These costs are being amortized over the
lives of the notes.
DEFERRED INCOME
In November 1995, the Company entered into gas sales agreements whereby it
committed to delivery of a total of 2,379,000 Mmbtu, from December 1, 1995
through December 1, 1996, for a total fixed price of $3,429,610. Income from the
agreements is recognized in the period of delivery.
REVENUE RECOGNITION
The Company uses the sales method of accounting for crude oil revenues.
Under this method, revenues are recognized based on actual volumes of oil sold
to purchasers.
The Company uses the entitlements method of accounting for natural gas
revenues. Under this method, revenues are recognized based on actual production
of natural gas. Natural gas revenues would not have been significantly altered
in any period had the sales method of recognizing natural gas revenues been
utilized.
ENVIRONMENTAL
The Company is subject to extensive Federal, state and local environmental
laws and regulations. These laws, which are constantly changing, regulate the
discharge of materials into the environment and may require the Company to
remove or mitigate the environmental effects of the disposal or release of
petroleum or chemical substances at various sites. Environmental expenditures
are expensed or capitalized depending on their future economic benefit.
Expenditures that relate to an existing condition caused by past operations and
that have no future economic benefits are expensed. Liabilities for expenditures
of a noncapital nature are recorded when environmental assessment and/or
remediation is probable, and the costs can be reasonably estimated.
RECLASSIFICATIONS
Certain reclassifications have been made to the 1993 and 1994 financial
statements to conform to the 1995 presentation.
INTERIM FINANCIAL STATEMENTS
The interim financial information as of June 30, 1996, and for the six
months ended June 30, 1995 and 1996, is unaudited. However, in the opinion of
management, these interim financial statements include all the necessary
adjustments to fairly present the results of the interim periods, and all such
adjustments are of a normal recurring nature. The interim financial statements
should be read in conjunction with the audited financial statements for the
years ended December 31, 1993, 1994 and 1995.
(3) ACQUISITION OF OIL AND GAS PROPERTIES
On June 12, 1995, the Company completed the acquisition of certain oil and
gas properties and related assets from Parker & Parsley Development L.P. and
Parker & Parsley Producing L.P. for $46,621,371. The transaction was accounted
for using the purchase method. The results of operations of the acquired
properties are included in the Consolidated Statements of Operations beginning
June 12, 1995. The Company funded the acquisition under the Credit Agreement
described in Note 7. Certain of the acquired properties, which were located
outside of the Company's areas of strategic focus, were sold in 1995. No gain or
loss was recorded on these sales.
F-10
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(3) ACQUISITION OF OIL AND GAS PROPERTIES (CONTINUED)
PRO FORMA RESULTS OF OPERATIONS (UNAUDITED)
The following table reflects the pro forma results of operations as though
the acquisition, net of the related properties sold, had occurred on January 1,
1994. The pro forma amounts are not necessarily indicative of the results that
may be reported in the future.
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER
31,
1994 1995
--------- ---------
(IN THOUSANDS)
<S> <C> <C>
Revenues................................................................... 35,460 32,746
Net income (loss).......................................................... 1,563 (4,655)
</TABLE>
(4) IMPAIRMENT OF LONG-LIVED ASSETS
The Company adopted FAS 121 effective as of January 1, 1995. FAS 121
requires that long-lived assets held and used by an entity, including oil and
gas properties accounted for under the successful efforts method of accounting,
be reviewed for impairment whenever events or changes in circumstances indicate
that the carrying amount of an asset may not be recoverable. Long-lived assets
to be disposed of are to be accounted for at the lower of carrying amount or
fair value less cost to sell when management has committed to a plan to dispose
of the assets. All companies, including successful efforts oil and gas
companies, are required to adopt FAS 121 for fiscal years beginning after
December 15, 1995.
In order to determine whether an impairment had occurred, the Company
estimated the expected future cash flows of its oil and gas properties and
compared such future cash flows to the carrying amount of the oil and gas
properties to determine if the carrying amount was recoverable. Based on this
process, no writedown in the carrying amount of the Company's proved properties
was necessary at December 31, 1995.
(5) DERIVATIVE FINANCIAL INSTRUMENTS
The Company utilizes derivative financial instruments to manage well-defined
interest rate and commodity price risks. The Company is exposed to credit losses
in the event of nonperformance by the counterparties to its interest rate swap
agreements and its commodity hedges. The Company anticipates, however, that such
counterparties will be able to fully satisfy their obligations under the
contracts. The Company does not obtain collateral or other security to support
financial instruments subject to credit risk but monitors the credit standing of
the counterparties.
COMMODITY HEDGES. The Company utilizes option contracts to hedge the effect
of price changes on future oil and gas production. If market prices of oil and
gas exceed the strike price of put options, the options will expire unexercised,
therefore reducing the effective price received for oil and gas sales by the
cost of the related option. The following table sets forth the future volumes
hedged by year and the weighted-average strike price of the option contracts at
December 31, 1995:
<TABLE>
<CAPTION>
OIL GAS
VOLUME VOLUME STRIKE PRICE
(BBLS) (MMBTU) PER BBL/MMBTU
---------- ---------- --------------------
<S> <C> <C> <C>
Oil:
1996.................................................. 1,830,000 -- $16.00 - $20.38(a)
1997.................................................. 912,500 -- $16.00 - $20.65(a)
Gas:
1996.................................................. -- 1,500,000 $1.65(b)
1997.................................................. -- 1,350,000 $1.65(b)
</TABLE>
F-11
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(5) DERIVATIVE FINANCIAL INSTRUMENTS (CONTINUED)
- ------------------------
(a) Represents the weighted-average price of collars established with the
purchase of put option contracts and the sale of call option contracts.
(b) Represents the strike price on purchased put option contracts.
INTEREST RATE SWAP AGREEMENTS. The Company utilizes interest rate swap
agreements to reduce the potential impact of increases in interest rates on
floating-rate, long-term debt. If market rates of interest experienced during
the applicable swap term are below the rates of interest effectively fixed by
the swap agreement, the rate of interest experienced by the Company will exceed
the rate that would have been experienced under the Credit Agreement. At
December 31, 1995, the Company was a party to two interest rate swap agreements,
providing the Company with a fixed interest rate for the terms of the
agreements. The following table sets forth the terms, fixed rates, and notional
amounts of the agreements in place as of December 31, 1995:
<TABLE>
<CAPTION>
NOTIONAL
PRINCIPAL FIXED
TERM AMOUNT INTEREST RATE
- ---------------------------------- ------------- ------------------------------
<S> <C> <C>
Jan. 25, 1996 to Jan. 25, 1999 $24 million ranging from 7.5% to 8.5%
May 24, 1995 to May 27, 1997 $60 million 5.99%
</TABLE>
(6) FAIR VALUE OF FINANCIAL INSTRUMENTS
The following table presents the carrying amounts and estimated fair values
of the Company's financial instruments at December 31, 1994 and 1995. FASB
Statement No. 107, DISCLOSURES ABOUT FAIR VALUE OF FINANCIAL INSTRUMENTS,
defines the fair value of a financial instrument as the amount at which the
instrument could be exchanged in a current transaction between willing parties.
<TABLE>
<CAPTION>
1994 1995
-------------------- --------------------
CARRYING FAIR CARRYING FAIR
AMOUNT VALUE AMOUNT VALUE
--------- --------- --------- ---------
<S> <C> <C> <C> <C>
(IN THOUSANDS)
Financial assets:
Cash, cash equivalents and restricted cash.......................... $ 137 $ 137 $ 2,866 $ 2,866
Receivables (trade)................................................. 1,042 1,042 3,154 3,154
Receivables (oil and gas sales)..................................... 1,715 1,715 3,915 3,915
Commodity option contracts.......................................... -- -- 165 555
Interest rate swap and option agreements............................ 203 -- 146 (2,970)
Notes receivable -- affiliate....................................... 390 390 684 684
Financial liabilities:
Payables (trade).................................................... 1,712 1,712 5,467 5,467
Deferred income..................................................... -- -- 3,319 2,950
Long-term debt...................................................... 23,613 23,613 71,494 71,494
</TABLE>
The carrying amounts shown in the table are included in the statement of
financial position under the indicated captions.
The following methods and assumptions were used to estimate the fair value
of each class of financial instruments:
CASH, TRADE RECEIVABLES, AND TRADE PAYABLES: The carrying amounts
approximate fair value because of the short maturity of those instruments.
F-12
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(6) FAIR VALUE OF FINANCIAL INSTRUMENTS (CONTINUED)
OTHER CURRENT ASSETS: The amounts reported relate to the commodity option
contracts and interest rate swap agreements described in Note 5. The carrying
amount comprises the unamortized premiums paid for the contracts. The fair value
is estimated using option pricing models and essentially values the potential
for the contracts and agreements to become in-the-money through changes in
commodity prices and interest rates during the remaining terms.
NOTES RECEIVABLE-AFFILIATE: The amounts reported relate to notes receivable
from an affiliated company. The carrying amount approximates fair value because
the rate given to the affiliate company is not materially different from the
affiliate company's bank debt.
DEFERRED INCOME: The amounts reported relate to the gas purchase agreements
described in Note 2. The carrying amount represents the payments received under
the agreements for which subsequent delivery is required. The fair value is
estimated based upon the commodity price at December 31, 1995, for a similar
agreement.
LONG-TERM DEBT: The fair value of the Company's long-term debt is estimated
by discounting expected cash flows at the rates currently offered to the Company
for debt of the same remaining maturities, as advised by the Company's bankers.
(7) LONG-TERM DEBT
Long-term debt consists of the following:
<TABLE>
<CAPTION>
DECEMBER 31,
--------------------
1994 1995
--------- ---------
(IN THOUSANDS)
<S> <C> <C>
Revolver note........................................................... $ -- $ 59,824
Term notes.............................................................. -- 11,670
Note payable to bank.................................................... 23,591 --
Note payable to member.................................................. 22 --
--------- ---------
23,613 71,494
Less current maturities............................................. 22 --
--------- ---------
$ 23,591 $ 71,494
--------- ---------
--------- ---------
</TABLE>
At December 31, 1995, the Company and certain of its subsidiaries are
parties to a Credit Agreement with a syndicate of banks (the "Banks"). The
Credit Agreement provides for an aggregate $185 million senior secured revolving
line of credit ("Revolver Notes") and an aggregate of $15 million in senior
secured term notes ("Term Notes"). All notes are secured with the assets of the
Company and are guaranteed by the Company's subsidiaries and, to a limited
extent, its individual members.
The Revolver Notes and Term Notes are subject to an aggregate borrowing
base, as determined by the Banks or their agents in their sole discretion and is
redetermined at least bi-annually as of January 15 and July 15, utilizing oil
and gas reserve information as of the immediately preceding period end. As of
January 15, 1996, the borrowing base was $71,670,000.
All outstanding balances under the Credit Agreement may be designated, at
the Company's option, as either "Base Rate Portions" or "Fixed Rate Portions"
(both as defined in the Credit Agreement), provided that no more than five
Eurodollar Tranches may be outstanding at any time. The Base Rate Portions of
the Revolver Notes bear interest at the fluctuating Base Rate, plus a Revolver
Base Rate Spread ranging from 0.25% to 0.75%, depending upon the outstanding
principal balances of the Term Notes. The Base Rate
F-13
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(7) LONG-TERM DEBT (CONTINUED)
Portions of the Term Notes bear interest at the fluctuating Base Rate plus
0.75%. The Fixed Rate Portions of the Revolver Notes bear interest at the
Eurodollar Rate for a fixed period of time elected by the Company, plus a
Revolver Fixed Rate Spread ranging from 2.25% to 3.00%, depending on the
outstanding principal balances of the Term Notes. The Fixed Rate Portions of the
Term Notes bear interest at the Eurodollar Rate for a fixed period of time
elected by the Company, plus a Fixed Rate Spread of 3.00%. As of December 31,
1995, the Company had elected a fixed rate of 8.82% for the Revolver Notes and
had elected fixed rates ranging from 8.82% to 8.94% for $14,000,000 of the
outstanding Term Notes at December 31, 1995. The remaining balances of the Term
Notes bear interest at the Base Rate of NationsBank Prime plus 1.50% at December
31, 1995.
The outstanding principal balance of the Revolver Notes is due and payable
in sixty (60) monthly installments beginning August 1, 1996, and continuing
regularly thereafter until July 1, 2001. The outstanding principal balance of
the Term Notes is due and payable in two (2) installments, each of which shall
be equal to one-half of the unpaid principal balance of each note, on July 1,
1996, and January 1, 1997.
The Credit Agreement requires the Company to hedge not less than 60% of the
Company's total sales volume, through December 31, 1997, from its proved
developed producing oil and gas reserves, with a floor price of not less than
$16 per Bbl of oil or $1.50 per Mcf of gas.
Additionally, the Credit Agreement contains various restrictive covenants
and compliance requirements, which include: (a) restrictions on dividends and
the incurrence of additional indebtedness; (b) restrictions as to merger, sale
or transfer of assets; (c) limiting total lease payments and total aggregate
executive compensation to $750,000 and $500,000, respectively, in any fiscal
year; and (d) compliance with certain financial ratios.
The Company was in violation of certain covenants and compliance
requirements as of December 31, 1995. Subsequent to December 31, 1995, such
violations were waived by the Banks.
Maturities of long-term debt at December 31, 1995, are as follows (in
thousands):
<TABLE>
<S> <C>
1996....................................................... $ 10,820
1997....................................................... 17,800
1998....................................................... 11,965
1999....................................................... 11,965
2000....................................................... 11,965
Thereafter................................................. 6,979
</TABLE>
The Company paid interest on long-term debt of $546,147, $1,356,604 and
$4,453,684 in 1993, 1994 and 1995, respectively.
As described in Note 12, on June 10, 1996, the Company demonstrated its
intent and ability to refinance the current maturities under the Credit
Agreement by entering into a new loan agreement, proceeds of which were used to
repay the existing notes. Concurrently, the deferred charges associated with the
Credit Agreement were expensed as an extraordinary loss.
F-14
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(8) COMMITMENTS AND CONTINGENCIES
LEASES
The Company leases equipment and office facilities under operating leases on
which rental expense for the years ended December 31, 1993, 1994 and 1995, was
$110,023, $197,533 and $311,221, respectively. Future minimum lease commitments
under noncancellable operating leases at December 31, 1995, are as follows (in
thousands):
<TABLE>
<S> <C>
1996........................................................ $ 257
1997........................................................ 272
1998........................................................ 268
1999........................................................ 195
2000........................................................ 188
Thereafter.................................................. 1,190
</TABLE>
SEVERANCE AGREEMENTS
On February 17, 1995, the Company entered into employment agreements with
each of the officers which are effective from the above date through February
17, 2000, or until terminated by the officer or the Company. In addition to
providing a base salary and nominal yearly increases for each officer, the
employment agreements provide for severance payments upon termination of any
such officer's employment or a significant reduction in that officer's duties or
responsibilities.
In the event of such a termination, the Company is obligated to pay the
officer an amount equal to the present value (discounted at 10%) of the
officer's salary which would have been paid through February 17, 2000. The
current annual base salaries for the officers covered under such employment
agreements total approximately $500,000.
EXPLORATION AND DEVELOPMENT
In July 1995, the Republic of Moldova (located in Eastern Europe between
Romania and the Ukraine) granted a Concession Agreement to Resource Development
Company Limited, L.L.C. ("Redeco"), an entity not affiliated with the Company.
The Company has paid Redeco $90,000 and agreed to bear the first $2.0 million of
Concession expenses ($214,178 of which had been expended through December 31,
1995) in return for a 50.0% interest in Redeco. After the initial $2.0 million
expenditure, Redeco and the Company are responsible for bearing 50.0% each of
future expenses. The Concession Agreement covers the entire country with respect
to oil and gas and other minerals and continues for various time periods
depending on the nature of the activity conducted. In connection with two
previously producing but now abandoned fields, Redeco's exclusive rights
continue for 20 years. Redeco's exclusive period to explore throughout the
remainder of Moldova expires in 2005, but Redeco will maintain exclusive
development rights with respect to fields discovered for a period of 20 years
from the date of first production from such field. The Company has no material
fixed financial commitments with respect to the Concession.
LETTERS OF CREDIT
As a result of certain bonding and trade creditor requirements, the Company
has caused irrevocable letters of credit to be issued by a bank totaling
$106,000. As of December 31, 1995, no amounts had been drawn on these letters of
credit.
(9) 401(K) PLAN
The Company has established a qualified cash or deferred arrangement under
IRS code section 401(k) covering substantially all employees. Under the plan,
the employees have an option to make elective contributions of a portion of
their eligible compensation, not to exceed specified annual limitations, to the
F-15
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(9) 401(K) PLAN (CONTINUED)
plan and the Company has an option to match a percentage of the employee's
contribution. The Company has made matching contributions to the plan totaling
$16,950, $8,921 and $22,531 in 1993, 1994 and 1995, respectively.
(10) REDEEMABLE MEMBERS' CAPITAL AND MEMBERS' CAPITAL
During 1995, NationsBanc Capital Corporation ("NBCC") contributed $10
million in exchange for a 30% ownership interest in the Company including the
preferential return described below. Of this amount, $1,266,000 was attributed
to the non-redeemable portion of members' capital and $8,734,000 was attributed
to redeemable members' capital. Preferred return and accretion of members'
capital included in the consolidated statements of operations and the
consolidated statements of members' capital includes accretion of the amount
attributable to redeemable members' capital to $10,000,000 over a two year
period beginning February 17, 1995. As described below, the redemption amount
will ultimately be equal to $10,000,000 plus a preferred return and an
additional redemption amount related to NBCC's redeemable interest not subject
to preferential return. The Company incurred $751,737 in legal fees and broker's
commissions in connection with this transaction and recorded these costs as
direct charges to members' capital in 1995.
Redeemable members' capital is subject to a preferential return of 15% per
annum on $10,000,000 and is redeemable at any time at the Company's option,
subject to a redemption premium as described below, or at NBCC's option on
February 17, 2003 or at an earlier date upon occurrence of certain events
including a change in control, certain changes in management, a change in the
Company's status as a limited liability company for tax purposes, or violation
of any of various other restrictive provisions contained in the Regulations of
Costilla Energy, L.L.C. (the "Regulations"). The 15% preferred return is treated
as a reduction of members' capital. The redemption price to be paid by the
Company shall be equal to $10,000,000 plus a premium, determined in the year the
units are purchased, as follows:
<TABLE>
<CAPTION>
YEAR AFTER PREMIUM
FEBRUARY 17, 1995 PERCENTAGE
- ----------------------- -------------
<S> <C>
1 10%
2 10%
3 8%
4 6%
5 4%
6 2%
7 0%
8 0%
</TABLE>
In addition, a portion of NBCC's interest not subject to preferential return
is classified as redeemable members' capital as the Company may be required to
repurchase such interest upon the occurrence of certain events similar to those
events requiring redemption of the redeemable members' capital described above
and, in any event, on or after February 17, 2000. Such interest may, at the
Company's option, be repurchased to the extent the Company has exercised its
right to redeem all or a portion of the redeemable members' interest subject to
the preferential return. The redemption price the Company would pay in either
instance is determined by the year in which the members' capital is repurchased,
as follows:
<TABLE>
<CAPTION>
AGGREGATE
BEFORE FEBRUARY 17 REDEMPTION PRICE
- ------------------------------------------------------------------ ----------------
<S> <C>
1996.............................................................. $ 1
1997.............................................................. 1,500,000
1998.............................................................. 3,000,000
</TABLE>
F-16
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(10) REDEEMABLE MEMBERS' CAPITAL AND MEMBERS' CAPITAL (CONTINUED)
<TABLE>
<S> <C>
1999.............................................................. 4,500,000
2000.............................................................. 5,500,000
</TABLE>
The ultimate redemption price of $5,500,000 is being accrued ratably over
the period from February 17, 1995 through February 17, 2000 and is treated as a
reduction of members' capital.
NBCC would retain an 18% interest in the Company after the redemptions
described above occur. Such interest is not subject to redemption.
At December 31, 1995, the Company was in violation of various restrictive
provisions of the Regulations. Subsequent to December 31, 1995, NBCC waived such
violations.
(11) RELATED PARTY TRANSACTIONS
Certain members and officers of the Company own interests in and hold
positions with A&P Meter Service and Supply, Inc. ("A&P"), CSL Management
Corporation ("CSL"), 511 Tex L.C. ("511 Tex") and Valley Gathering Company
("Valley").
Advances from the Company to A&P have been consolidated into two promissory
notes. The first note, which was originally executed December 31, 1994, totals
$390,000, including accrued interest of $20,000 at December 31, 1995. The note
bears interest at a floating rate equal to the "prime rate" plus 1.0%. No
principal or interest payments are due until the maturity of the note at
December 31, 2004. The note is secured by a second lien on A&P's accounts
receivable, inventory and equipment. The second note is in the amount of
$294,000, including accrued interest of $47,000, and is dated May 22, 1996. The
note bears interest at 6.0% per annum, is unsecured and is payable upon demand.
During 1995, the Company paid $612,139 to A&P for goods and services provided.
During 1993, 1994 and 1995, the Company paid $312,623, $549,620 and
$592,920, respectively, to CSL for management fees and lease payments on
equipment.
During 1995, the Company paid $67,896 to 511 Tex for office rent.
During 1994 and 1995, the Company paid $2,458 and $440,884, respectively, to
Valley for gas compression and salt water disposal charges. During 1995, Valley
paid the Company $109,399 for operating costs of its salt water disposal wells
and gas compressors.
In connection with the acquisition of a 5% interest in the Company in 1992,
a minority owner also acquired an option to purchase an additional 20% interest
in the Company for $750,000. In 1995, the majority owner of the Company agreed
to settle this option on behalf of the Company by transferring a portion of his
ownership directly to such minority owner. The option was cancelled. This
transaction was deemed to be compensation to the remaining minority owner in the
amount of $656,000.
(12) SUBSEQUENT EVENTS
On March 8, 1996, the Company executed a Purchase and Sale Agreement with
Parker and Parsley Petroleum Company to acquire certain oil and gas properties
for an estimated adjusted purchase price of approximately $42.5 million. The
properties are located primarily in south and west Texas. The transaction was
accounted for using the purchase method. The results of operations of the
acquired properties are included in the Consolidated Statements of Operations as
of the closing date, June 14, 1996.
F-17
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(12) SUBSEQUENT EVENTS (CONTINUED)
PRO FORMA RESULTS OF OPERATIONS (UNAUDITED)
The following table reflects the pro forma results of operations for the
six-months ended June 30, 1995 and 1996, as though both acquisitions, which
closed on June 12, 1995 and June 14, 1996, had occurred as of January 1, 1995.
The pro forma amounts are not necessarily indicative of the results that may be
reported in the future.
<TABLE>
<CAPTION>
SIX MONTHS ENDED
JUNE 30,
--------------------
1995 1996
--------- ---------
(IN THOUSANDS)
<S> <C> <C>
Revenues................................................................ $ 25,706 $ 28,748
Net loss................................................................ (4,435) (2,081)
</TABLE>
In connection with the foregoing, the Company entered into a new loan
agreement with NationsBridge L.L.C., an affiliate of the Company's current
lender, to provide financing of up to $125 million in advances (the "Loans"),
subject to certain terms and conditions. Proceeds of the Loans were used to fund
the Acquisition, to refinance substantially all of the Company's outstanding
indebtedness, and for other general corporate purposes.
Advances under the Loans were to be made in two portions, Tranche A was up
to $95,000,000 and Tranche B was $30,000,000. Tranche A initially bears
interest, at the Company's option, at the applicable prime rate ("Prime") plus
0.75% or LIBOR plus 3.0%. Each margin above Prime and LIBOR increases by 0.50%
at the end of each successive three-month period, up to a maximum of 2.75% and
5.0% for Prime and LIBOR, respectively. Tranche B initially bears interest at
14.00% per annum, increasing 0.50% at the end of each successive three-month
period, up to a maximum of 16.5%.
Tranche A loans are subject to a borrowing base determination. The initial
borrowing base is $95,000,000 which is automatically reduced by $3,000,000 per
quarter beginning January 1, 1997. The borrowing base is also subject to
periodic redetermination by NationsBridge L.L.C. based on its determination of
the collateral value of the Company's oil and gas properties. Final maturity of
loans made under Tranches A and B is June 10, 1999.
The Loans are secured by first priority liens, assignments and security
interests in all oil and gas properties, pipelines and gathering systems of the
Company and stock of the Company's subsidiaries. Additionally, the Loans are
subject to various restrictive covenants and compliance requirements, including
but not limited to (a) restrictions on dividends and the incurrence of
additional indebtedness, (b) minimum limitations on the Company's current ratio
and tangible net worth, (c) limitations on payments for leases and executive
compensation, (d) maximum limitations on general and administrative expenses,
capital expenditures and the Company's ratio of debt to adjusted cash flow, and
(e) a requirement to pay to the lender all net oil and gas revenues (as defined
and as adjusted for capital expenditures) on a quarterly basis.
The Company paid the lender's fees and expenses in connection with obtaining
the Loans. The fees were approximately $2,625,000 and will increase by an
additional $625,000 if the Tranche B Loans remain outstanding for more than 90
days. As the Company believes that it is probable that the additional $625,000
in fees will be paid, the total fees of $3,250,000 are being amortized as
additional interest expense over a period of one year from the date of the
Loans. In addition, if the Tranche B amounts are not repaid within one year, an
additional amount of $4,800,000 will accrue. If such additional fee is incurred,
it will be amortized over the remaining period that the Loans are expected to be
outstanding.
F-18
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(13) OIL AND GAS EXPENDITURES
The following table reflects costs incurred in oil and gas property
acquisition, exploration and development activities:
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER 31, THREE MONTHS
------------------------------- ENDED MARCH 31,
1993 1994 1995 1996
--------- --------- --------- ---------------
(IN THOUSANDS) (UNAUDITED)
<S> <C> <C> <C> <C>
Property acquisition costs:
Proved.......................................................... $ 4,665 $ 9,649 $ 52,470 $ 2,246
Unproved........................................................ 829 1,232 1,742 677
Exploration....................................................... 2,017 2,167 5,627 1,822
Development....................................................... -- -- 158 232
--------- --------- --------- ------
$ 7,511 $ 13,048 $ 59,997 $ 4,977
--------- --------- --------- ------
--------- --------- --------- ------
</TABLE>
(14) SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION (UNAUDITED)
The estimates of proved oil and gas reserves, which are located principally
in the United States, were prepared by the Company as of December 31, 1993, 1994
and 1995, and Williamson Petroleum Consultants as of March 31, 1996. Reserves
were estimated in accordance with guidelines established by the SEC and FASB
which require that reserve estimates be prepared under existing economic and
operating conditions with no provision for price and cost escalations, except by
contractual arrangements. The Company has presented the reserve estimates
utilizing an oil price of $17.79 per Bbl and a gas price of $2.03 per Mcf as of
December 31, 1995, and an oil price of $20.71 per Bbl and a gas price of $2.00
per Mcf as of March 31, 1996.
OIL AND GAS PRODUCING ACTIVITIES
Oil and gas reserve quantity estimates are subject to numerous uncertainties
inherent in the estimation of quantities of proved reserves and in the
projection of future rates of production and the timing of development
expenditures. The accuracy of such estimates is a function of the quality of
available data and of engineering and geological interpretation and judgment.
Results of subsequent drilling, testing and production may cause either upward
or downward revision of previous estimates. Further, the volumes considered to
be commercially recoverable fluctuate with changes in prices and operating
costs. The
F-19
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(14) SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION (UNAUDITED) (CONTINUED)
Company emphasizes that reserve estimates are inherently imprecise and that
estimates of new discoveries are more imprecise than those of currently
producing oil and gas properties. Accordingly, these estimates are expected to
change as additional information becomes available in the future.
<TABLE>
<CAPTION>
OIL AND CONDENSATE GAS
(MBBLS) (MMCF)
------------------- -------------
<S> <C> <C>
Total Proved Reserves:
Balance, January 1, 1993....................................................... 1,985 16,418
Revisions of previous estimates.............................................. 57 1,160
Extensions and discoveries................................................... 380 591
Production................................................................... (158) (865)
Purchases of minerals-in-place............................................... 101 4,315
------ ------
Balance, December 31, 1993..................................................... 2,365 21,619
Revisions of previous estimates.............................................. (460) (5,424)
Extensions and discoveries................................................... 761 1,520
Production................................................................... (330) (1,600)
Purchases of minerals-in-place............................................... 1,673 11,397
------ ------
Balance, December 31, 1994..................................................... 4,009 27,512
Revisions of previous estimates.............................................. (570) 425
Extensions and discoveries................................................... 605 8,922
Production................................................................... (950) (4,806)
Purchases of minerals-in-place............................................... 7,694 46,099
------ ------
Balance, December 31, 1995..................................................... 10,788 78,152
Revisions of previous estimates.............................................. 437 2,615
Extensions and discoveries................................................... 592 296
Production................................................................... (338) (1,643)
Purchases of minerals-in-place............................................... -- --
------ ------
Balance, March 31, 1996........................................................ 11,479 79,420
------ ------
------ ------
Proved Developed Reserves:
January 1, 1993.............................................................. 1,488 10,055
December 31, 1993............................................................ 1,785 13,268
December 31, 1994............................................................ 2,632 16,340
December 31, 1995............................................................ 8,566 57,393
March 31, 1996............................................................... 9,037 55,408
</TABLE>
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS RELATING TO PROVED
OIL AND GAS RESERVES
The standardized measure of discounted future net cash flows is computed by
applying year-end prices of oil and gas (with consideration of price changes
only to the extent provided by contractual arrangements) to the estimated future
production of proved oil and gas reserves, less estimated future expenditures
(based on year-end costs) to be incurred in developing and producing the proved
reserves, less estimated future income tax expenses (based on year-end statutory
tax rates, with consideration of future tax rates already legislated) to be
incurred on pretax net cash flows, less tax basis of the properties and
available credits, and assuming continuation of existing economic conditions.
The estimated future net cash flows are then discounted using a rate of 10% per
year to reflect the estimated timing of the future cash flows.
F-20
<PAGE>
COSTILLA ENERGY, L.L.C.
(A TEXAS LIMITED LIABILITY COMPANY)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
(THE INFORMATION AND AMOUNTS FOR INTERIM PERIODS ARE UNAUDITED.)
(14) SUPPLEMENTAL OIL AND GAS RESERVE INFORMATION (UNAUDITED) (CONTINUED)
Discounted future cash flow estimates like those shown below are not
intended to represent estimates of the fair value of oil and gas properties.
Estimates of fair value should also consider probable reserves, anticipated
future oil and gas prices, interest rates, changes in development and production
costs and risks associated with future production. Because of these and other
considerations, any estimate of fair value is necessarily subjective and
imprecise.
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
----------------------------------- ---------------
1993 1994 1995 1996
---------- ---------- ----------- ---------------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Future cash flows.......................................... $ 83,510 $ 122,098 $ 350,653 $ 396,919
Future costs:
Production............................................... (31,811) (46,345) (145,510) (162,146)
Development.............................................. (4,486) (7,157) (16,806) (17,975)
---------- ---------- ----------- ---------------
Future net cash flows...................................... 47,213 68,596 188,337 216,798
10% annual discount for estimated timing of cash flows..... (20,836) (31,817) (75,041) (87,707)
---------- ---------- ----------- ---------------
Standardized measure of discounted net cash flows.......... $ 26,377 $ 36,779 $ 113,296 $ 129,091
---------- ---------- ----------- ---------------
---------- ---------- ----------- ---------------
</TABLE>
CHANGES IN STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS FROM
PROVED RESERVES
<TABLE>
<CAPTION>
THREE MONTHS
YEARS ENDED DECEMBER 31, ENDED MARCH 31,
-------------------------------- ---------------
1993 1994 1995 1996
--------- --------- ---------- ---------------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Increase (decrease):
Purchase of minerals-in-place............................... $ 3,732 $ 15,231 $ 77,343 $ --
Extensions and discoveries and improved recovery, net of
future production and development costs.................... 2,707 4,072 9,799 6,002
Accretion of discount....................................... 2,056 2,638 3,678 2,832
Net change in sales prices, net of production costs......... (209) 503 (3,422) 9,229
Changes in estimated future development costs............... (16) 940 (2,419) (235)
Revisions of quantity estimates............................. 1,203 (7,248) (2,855) 4,839
Sales, net of production costs.............................. (2,543) (5,286) (11,338) (5,174)
Changes of production rates (timing) and other.............. (1,114) (448) 5,731 (1,698)
--------- --------- ---------- ---------------
Net increase.............................................. 5,816 10,402 76,517 15,795
Standardized measure of discounted future net cash flows:
Beginning of period....................................... 20,561 26,377 36,779 113,296
--------- --------- ---------- ---------------
End of period............................................. $ 26,377 $ 36,779 $ 113,296 $ 129,091
--------- --------- ---------- ---------------
--------- --------- ---------- ---------------
</TABLE>
The 1995 future cash flows shown above include amounts attributable to
proved undeveloped reserves requiring approximately $15.0 million of future
development costs. If these reserves are not developed, the standardized measure
of discounted future net cash flows for 1995 shown above would be reduced by
approximately $22.4 million.
F-21
<PAGE>
INDEPENDENT AUDITORS' REPORT
The Members
Costilla Energy, L.L.C.:
We have audited the accompanying statements of revenues and direct operating
expenses of the 1995 Acquisition (see Note 1) for the years ended December 31,
1993 and 1994, and the period ended June 12, 1995. These statements are the
responsibility of the Company's management. Our responsibility is to express an
opinion on these 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 statements of revenues and direct
operating expenses 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 statement presentation. We believe that our audits
provide a reasonable basis for our opinion.
The accompanying statements of revenues and direct operating expenses were
prepared for the purpose of complying with the rules and regulations of the
Securities and Exchange Commission (for inclusion in Forms S-1 of Costilla
Energy, Inc. as described in Note 1) and are not intended to be a complete
presentation of the 1995 Acquisition interests' revenue and expenses.
In our opinion, the statements of revenues and direct operating expenses
referred to above present fairly, in all material respects, the revenues and
direct operating expenses of the 1995 Acquisition for the years ended December
31, 1993 and 1994, and the period ended June 12, 1995, in conformity with
generally accepted accounting principles.
KPMG PEAT MARWICK LLP
Midland, Texas
July 4, 1996
F-22
<PAGE>
COSTILLA ENERGY, L.L.C.
1995 ACQUISITION
STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
(IN THOUSANDS)
<TABLE>
<CAPTION>
YEARS ENDED
DECEMBER 31,
-------------------- PERIOD ENDED
1993 1994 JUNE 12, 1995
--------- --------- --------------
<S> <C> <C> <C>
Revenues:
Oil and condensate........................................................ $ 18,542 $ 16,217 $ 7,572
Natural gas............................................................... 13,780 11,407 3,358
--------- --------- -------
32,322 27,624 10,930
Direct operating expenses:
Lease operating........................................................... 13,376 11,220 4,550
Workovers and dry hole costs.............................................. 462 470 109
Production taxes.......................................................... 2,070 2,023 923
--------- --------- -------
15,908 13,713 5,582
--------- --------- -------
Revenues in excess of direct operating expenses............................. $ 16,414 $ 13,911 $ 5,348
--------- --------- -------
--------- --------- -------
</TABLE>
See the accompanying notes to these statements.
F-23
<PAGE>
COSTILLA ENERGY, L.L.C.
1995 ACQUISITION
NOTES TO THE STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
(1) BASIS OF PRESENTATION
On June 12, 1995, Costilla Energy, L.L.C. and Costilla Petroleum Corporation
(collectively, the "Company") acquired from Parker & Parsley Development L.P.
and Parker & Parsley Producing L.P. (collectively, "Parker & Parsley") certain
oil and gas properties (the "1995 Acquisition") for $46,621,371. The
accompanying statements of revenues and direct operating expenses for the 1995
Acquisition do not include general and administrative expenses, interest income
or expense, a provision for depreciation, depletion and amortization, or any
provision for income taxes since historical expenses of this nature incurred by
Parker & Parsley are not necessarily indicative of the costs to be incurred by
the Company.
Historical financial information reflecting financial position, results of
operations, and cash flows of the 1995 Acquisition, are not presented because
the purchase price was assigned to the oil and gas property interests acquired.
Other assets acquired and liabilities assumed were not material. Accordingly,
the historical statements of revenues and direct operating expenses of the 1995
Acquisition are presented in lieu of the financial statements required under
Rule 3-05 of Securities and Exchange Commission Regulation S-X.
Revenues in the accompanying statements of revenues and direct operating
expenses are recognized on the sales method. Under this method, revenues are
recognized based on actual volumes of oil and gas sold to purchasers. Direct
operating expenses are recognized on the accrual method.
(2) SUPPLEMENTARY FINANCIAL INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES
(UNAUDITED)
ESTIMATED QUANTITIES OF PROVED OIL AND GAS RESERVES
Reserve information presented below for the 1995 Acquisition is based on
Company prepared reserve estimates, using prices and costs in effect at December
31, 1993 and 1994, and the period ended June 12, 1995. Changes in reserve
estimates were derived by adjusting the period-end quantities and values for
actual production using historical prices and costs.
Proved reserves are estimated quantities of crude oil and natural gas which
geological and engineering data demonstrate with reasonable certainty to be
recoverable in future years from known reservoirs under existing economic and
operating conditions. Proved developed reserves are those which are expected to
be recovered through existing wells with existing equipment and operating
methods. Oil and gas reserve quantity estimates are subject to numerous
uncertainties inherent in the estimation of quantities of proved reserves and in
the projection of future rates of production and the timing of development
expenditures. The accuracy of such estimates is a function of the quality of
available data and of engineering and geological interpretation and judgment.
Results of subsequent drilling, testing and production may cause either upward
or downward revision of previous estimates. Further, the volumes considered to
be commercially recoverable fluctuate with changes in prices and operating
costs. The Company emphasizes that reserve estimates are inherently imprecise
and that estimates of new discoveries are more imprecise than those of currently
producing oil and gas properties. Accordingly, these reserve estimates are
expected to change as additional information becomes available in the future.
F-24
<PAGE>
COSTILLA ENERGY, L.L.C.
1995 ACQUISITION
NOTES TO THE STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES (CONTINUED)
(2) SUPPLEMENTARY FINANCIAL INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES
(UNAUDITED)
(CONTINUED)
Below are the net estimated quantities of proved reserves and proved
developed reserves for the 1995 Acquisition.
<TABLE>
<CAPTION>
OIL (MBBLS) GAS (MMCF)
------------- -------------
<S> <C> <C>
Proved reserves at December 31, 1992............................... 9,880 60,199
Production......................................................... (1,204) (6,914)
------ ------
Proved reserves at December 31, 1993............................... 8,676 53,285
Production......................................................... (1,142) (6,778)
------ ------
Proved reserves at December 31, 1994............................... 7,534 46,507
Production......................................................... (479) (2,405)
------ ------
Proved reserves at June 12, 1995................................... 7,055 44,102
------ ------
------ ------
Proved developed reserves at June 12, 1995......................... 6,707 38,151
------ ------
------ ------
</TABLE>
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS OF PROVED OIL AND
GAS RESERVES
The Company has estimated the standardized measure of discounted future net
cash flows and changes therein relating to proved oil and gas reserves in
accordance with the standards established by the Financial Accounting Standards
Board through its Statement No. 69. The estimates of future cash flows and
future production and development costs are based on period-end sales prices for
oil and gas, estimated future production of proved reserves, and estimated
future production and development costs of proved reserves, based on current
costs and economic conditions. The estimated future net cash flows are then
discounted at a rate of 10%.
Discounted future net cash flow estimates like those shown below are not
intended to represent estimates of the fair market value of oil and gas
properties. Estimates of fair market value should also consider probable
reserves, anticipated future oil and gas prices, interest rates, changes in
development and production costs and risks associated with future production.
Because of these and other considerations, any estimate of fair market value is
necessarily subjective and imprecise.
The following are the Company's estimated standardized measure of discounted
future net cash flows from proved reserves attributable to the 1995 Acquisition:
<TABLE>
<CAPTION>
DECEMBER 31,
----------------------
1993 1994 JUNE 12, 1995
---------- ---------- -------------
(IN THOUSANDS)
<S> <C> <C> <C>
Future:
Cash inflows................................................... $ 222,698 $ 188,828 $ 191,758
Production costs............................................... (111,619) (97,988) (93,268)
Development costs.............................................. (4,797) (4,797) (4,797)
---------- ---------- -------------
Net cash flows before income taxes........................... 106,282 86,043 93,693
10% annual discount for estimated timing of cash flows........... (37,518) (30,373) (33,074)
---------- ---------- -------------
Standardized measure of discounted future net cash flows before
income taxes.................................................... $ 68,764 $ 55,670 $ 60,619
---------- ---------- -------------
---------- ---------- -------------
</TABLE>
F-25
<PAGE>
COSTILLA ENERGY, L.L.C.
1995 ACQUISITION
NOTES TO THE STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES (CONTINUED)
(2) SUPPLEMENTARY FINANCIAL INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES
(UNAUDITED)
(CONTINUED)
The following are the sources of changes in the standardized measure of
discounted net cash flows:
<TABLE>
<CAPTION>
YEARS ENDED DECEMBER
31,
---------------------- PERIOD ENDED
1993 1994 JUNE 12, 1995
---------- ---------- -------------
(IN THOUSANDS)
<S> <C> <C> <C>
Standardized measure, beginning of period..................... $ 96,022 $ 68,764 $ 55,670
Sales, net of production costs................................ (16,414) (13,911) (5,348)
Net change in prices.......................................... (15,892) (3,910) 8,032
Accretion of discount......................................... 9,602 6,876 2,517
Other......................................................... (4,554) (2,149) (252)
---------- ---------- -------------
Standardized measure, end of period........................... $ 68,764 $ 55,670 $ 60,619
---------- ---------- -------------
---------- ---------- -------------
</TABLE>
F-26
<PAGE>
INDEPENDENT AUDITORS' REPORT
The Members
Costilla Energy, L.L.C.:
We have audited the accompanying statements of revenues and direct operating
expenses of the 1996 Acquisition (see Note 1) for the years ended December 31,
1993, 1994 and 1995. These statements are the responsibility of the Company's
management. Our responsibility is to express an opinion on these 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 statements of revenues and direct
operating expenses 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 statement presentation. We believe that our audits
provide a reasonable basis for our opinion.
The accompanying statements of revenues and direct operating expenses were
prepared for the purpose of complying with the rules and regulations of the
Securities and Exchange Commission (for inclusion in Forms S-1 of Costilla
Energy, Inc. as described in Note 1) and are not intended to be a complete
presentation of the 1996 Acquisition interests' revenues and expenses.
In our opinion, the statements of revenues and direct operating expenses
referred to above present fairly, in all material respects, the revenues and
direct operating expenses of the 1996 Acquisition for the years ended December
31, 1993, 1994 and 1995, in conformity with generally accepted accounting
principles.
KPMG PEAT MARWICK LLP
Midland, Texas
July 4, 1996
F-27
<PAGE>
COSTILLA ENERGY, L.L.C.
1996 ACQUISITION
STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
(IN THOUSANDS)
<TABLE>
<CAPTION>
YEARS ENDED PERIODS
DECEMBER 31, ENDED JUNE 14,
------------------------------- --------------------
1993 1994 1995 1995 1996
--------- --------- --------- --------- ---------
<S> <C> <C> <C> <C> <C>
(UNAUDITED)
Revenues:
Oil and condensate......................................... $ 11,467 $ 10,170 $ 10,564 $ 5,140 $ 5,205
Natural gas................................................ 11,294 10,105 8,645 3,763 3,434
Gas plant.................................................. 57 57 126 47 42
Transportation............................................. 39 379 556 253 542
--------- --------- --------- --------- ---------
22,857 20,711 19,891 9,203 9,223
Direct operating expenses:
Lease operating............................................ 10,977 9,053 9,232 3,965 4,020
Workovers and dry hole costs............................... 675 869 1,002 256 450
Production taxes........................................... 1,166 1,089 992 458 453
Gas plant.................................................. 131 350 598 393 269
Transportation............................................. 10 394 587 268 222
--------- --------- --------- --------- ---------
12,959 11,755 12,411 5,340 5,414
--------- --------- --------- --------- ---------
Revenues in excess of direct operating expenses.............. $ 9,898 $ 8,956 $ 7,480 $ 3,863 $ 3,809
--------- --------- --------- --------- ---------
--------- --------- --------- --------- ---------
</TABLE>
See the accompanying notes to these statements.
F-28
<PAGE>
COSTILLA ENERGY, L.L.C.
1996 ACQUISITION
NOTES TO THE STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
(1) BASIS OF PRESENTATION
On June 14, 1996, Costilla Energy, L.L.C. and Costilla Petroleum Corporation
(collectively, the "Company") acquired from Parker & Parsley Development L.P.,
Parker & Parsley Producing L.P. and Parker & Parsley Gas Processing Co.
(collectively, "Parker & Parsley") certain oil and gas properties (the "1996
Acquisition") for approximately $42.5 million. The accompanying statements of
revenues and direct operating expenses for the 1996 Acquisition do not include
general and administrative expenses, interest income or expense, a provision for
depreciation, depletion and amortization, or any provision for income taxes
since historical expenses of this nature incurred by Parker & Parsley are not
necessarily indicative of the costs to be incurred by the Company.
Historical financial information reflecting financial position, results of
operations, and cash flows of the 1996 Acquisition, are not presented because
the purchase price was assigned to the oil and gas property interests acquired.
Other assets acquired and liabilities assumed were not material. Accordingly,
the historical statements of revenues and direct operating expenses of the 1996
Acquisition are presented in lieu of the financial statements required under
Rule 3-05 of Securities and Exchange Commission Regulation S-X.
Revenues in the accompanying statements of revenues and direct operating
expenses are recognized on the sales method. Under this method, revenues are
recognized based on actual volumes of oil and gas sold to purchasers. Direct
operating expenses are recognized on the accrual method.
INTERIM STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES
The interim financial information for the periods ended June 14, 1995 and
1996, is unaudited. However, in the opinion of management, the interim
statements of revenues and direct operating expenses include all the necessary
adjustments to fairly present the results of the interim periods and all such
adjustments are of a normal recurring nature. The interim statements of revenues
and direct operating expenses should be read in conjunction with the audited
statements of revenues and direct operating expenses for the years ended
December 31, 1993, 1994 and 1995.
(2) SUPPLEMENTARY FINANCIAL INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES
(UNAUDITED)
ESTIMATED QUANTITIES OF PROVED OIL AND GAS RESERVES
Reserve information presented below for the 1996 Acquisition, as of March
31, 1996, is based on reserve estimates prepared by Williamson Petroleum
Consultants, using prices and costs in effect at that date. Changes in reserve
estimates were derived by adjusting such quantities and values for actual
production using historical prices and costs.
Proved reserves are estimated quantities of crude oil and natural gas which
geological and engineering data demonstrate with reasonable certainty to be
recoverable in future years from known reservoirs under existing economic and
operating conditions. Proved developed reserves are those which are expected to
be recovered through existing wells with existing equipment and operating
methods. Oil and gas reserve quantity estimates are subject to numerous
uncertainties inherent in the estimation of quantities of proved reserves and in
the projection of future rates of production and the timing of development
expenditures. The accuracy of such estimates is a function of the quality of
available data and of engineering and geological interpretation and judgment.
Results of subsequent drilling, testing and production may cause either upward
or downward revision of previous estimates. Further, the volumes considered to
be commercially recoverable fluctuate with changes in prices and operating
costs. The Company emphasizes that reserve estimates are inherently imprecise
and that estimates of new discoveries are more imprecise than those of currently
producing oil and gas properties. Accordingly, these reserve estimates are
expected to change as additional information becomes available in the future.
F-29
<PAGE>
COSTILLA ENERGY, L.L.C.
1996 ACQUISITION
NOTES TO THE STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES (CONTINUED)
(2) SUPPLEMENTARY FINANCIAL INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES
(UNAUDITED) (CONTINUED)
Below are the net estimated quantities of proved reserves and proved
developed reserves for the 1996 Acquisition.
<TABLE>
<CAPTION>
OIL (MBBLS) GAS (MMCF)
------------- -----------
<S> <C> <C>
Proved reserves at December 31, 1992.................................................... 7,211 49,963
Production.............................................................................. (718) (5,481)
----- -----------
Proved reserves at December 31, 1993.................................................... 6,493 44,482
Production.............................................................................. (685) (5,217)
----- -----------
Proved reserves at December 31, 1994.................................................... 5,808 39,265
Production.............................................................................. (656) (4,773)
----- -----------
Proved reserves at December 31, 1995.................................................... 5,152 34,492
Production.............................................................................. (154) (991)
----- -----------
Proved reserves at March 31, 1996....................................................... 4,998 33,501
----- -----------
----- -----------
Proved developed reserves at March 31, 1996............................................. 4,515 28,961
----- -----------
----- -----------
</TABLE>
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS OF PROVED OIL AND GAS
RESERVES
The Company has estimated the standardized measure of discounted future net
cash flows and changes therein relating to proved oil and gas reserves in
accordance with the standards established by the Financial Accounting Standards
Board through its Statement No. 69. The estimates of future cash flows and
future production and development costs are based on year-end sales prices for
oil and gas, estimated future production of proved reserves, and estimated
future production and development costs of proved reserves, based on current
costs and economic conditions. The estimated future net cash flows are then
discounted at a rate of 10%.
Discounted future net cash flow estimates like those shown below are not
intended to represent estimates of the fair market value of oil and gas
properties. Estimates of fair market value should also consider probable
reserves, anticipated future oil and gas prices, interest rates, changes in
development and production costs and risks associated with future production.
Because of these and other considerations, any estimate of fair market value is
necessarily subjective and imprecise.
The following are the Company's estimated standardized measure of discounted
future net cash flows from proved reserves attributable to the 1996 Acquisition:
<TABLE>
<CAPTION>
DECEMBER 31,
------------------------------------ MARCH 31,
1993 1994 1995 1996
----------- ----------- ---------- ----------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Future:
Cash inflows................................................. $ 181,010 $ 156,222 $ 165,862 $ 175,507
Production costs............................................. (116,115) (105,104) (93,878) (91,202)
Development costs............................................ (4,101) (4,101) (4,101) (4,101)
----------- ----------- ---------- ----------
Net cash flows before income taxes......................... 60,794 47,017 67,883 80,204
10% annual discount for estimated timing of cash flows......... (22,564) (17,451) (25,195) (29,768)
----------- ----------- ---------- ----------
Standardized measure of discounted future net cash flows before
income taxes.................................................. $ 38,230 $ 29,566 $ 42,688 $ 50,436
----------- ----------- ---------- ----------
----------- ----------- ---------- ----------
</TABLE>
F-30
<PAGE>
COSTILLA ENERGY, L.L.C.
1996 ACQUISITION
NOTES TO THE STATEMENTS OF REVENUES AND DIRECT OPERATING EXPENSES (CONTINUED)
(2) SUPPLEMENTARY FINANCIAL INFORMATION FOR OIL AND GAS PRODUCING ACTIVITIES
(UNAUDITED) (CONTINUED)
The following are the sources of changes in the standardized measure of
discounted net cash flows:
<TABLE>
<CAPTION>
THREE MONTH
YEARS ENDED DECEMBER 31, PERIOD ENDED
------------------------------- MARCH 31,
1993 1994 1995 1996
--------- --------- --------- ------------
(IN THOUSANDS)
<S> <C> <C> <C> <C>
Standardized measure, beginning of period......................... $ 56,372 $ 38,230 $ 29,566 $ 42,688
Sales, net of production costs.................................... (9,943) (9,264) (7,983) (2,090)
Net change in prices.............................................. (11,890) (2,838) 18,141 9,277
Accretion of discount............................................. 5,637 3,823 2,957 1,067
Other............................................................. (1,946) (385) 7 (506)
--------- --------- --------- ------------
Standardized measure, end of period............................... $ 38,230 $ 29,566 $ 42,688 $ 50,436
--------- --------- --------- ------------
--------- --------- --------- ------------
</TABLE>
F-31
<PAGE>
APPENDIX A
July 23, 1996
Costilla Energy, Inc.
400 West Illinois, Suite 1000
Midland, Texas 79701
Attention Mr. Michael J. Grella
Gentlemen:
Subject: Summary Letter (for Inclusion in a Prospectus Included in a
Registration Statement for Costilla Energy, Inc. on Form S-1)
Combining Specific Data from Two Williamson Petroleum
Consultants, Inc. Evaluations (1) to the Interests of Costilla
Petroleum Corporation in Various Properties and (2) to the
Interests of Parker & Parsley Petroleum USA, Inc. in Various
Properties Included in Their First Quarter 1996 Sales Package
Effective April 1, 1996
Williamson Project 6.8393
In accordance with your request, Williamson Petroleum Consultants, Inc.
(Williamson) has prepared a summary letter for inclusion in a prospectus for
Costilla Energy, Inc. (Costilla). The filing of this Prospectus gives effect to
the conversion of Costilla Energy, L.L.C. to Costilla Energy, Inc. This summary
letter includes specific data from two evaluations the subjects of which are
described in Item I. All values and discussion of proved reserves and net
revenues, data utilized, assumptions, and qualifications are taken from and
include by reference data from these two evaluations.
Interests in this summary letter represent the April 1, 1996 effective date
consolidation of the ownership interests of Costilla and the ownership interests
of Parker & Parsley in various properties included in their first quarter 1996
sales package which Costilla acquired on June 14, 1996 but which was made
effective as of January 1, 1996. The Costilla interests include all the
interests of Costilla Energy, L.L.C. and all its wholly-owned subsidiaries
including Costilla Petroleum Corporation.
I. THE TWO SUBJECT EVALUATIONS
This summary letter combines certain proved oil and gas reserves and
revenues from the following two Williamson evaluations:
(1) Evaluation of Oil and Gas Reserves to the Interests of Costilla
Petroleum Corporation in Various Properties, Effective April 1, 1996,
Utilizing Nonescalated Economics, for Disclosure to the Securities and
Exchange Commission, Williamson Project 6.8393, transmitted July 18, 1996
(the Costilla report)
(2) Evaluation of Oil and Gas Reserves to the Interests of Parker & Parsley
Petroleum USA, Inc. in Various Properties Included in Their First Quarter
1996 Sales Package, Effective April 1, 1996, Utilizing Nonescalated
Economics, for Disclosure to the Securities and Exchange Commission,
Williamson Project 6.8393, transmitted July 18, 1996 (the Acquisition
report)
II. ESTIMATED SEC RESERVES AND FUTURE NET REVENUES
Projections of the reserves that are attributable to the consolidated
interests in this summary letter were based on economic parameters and operating
conditions considered applicable as of April 1, 1996 and are pursuant to the
requirements of the Securities and Exchange Commission (SEC).
In accordance with instructions from Costilla, Williamson utilized lease
operating expenses for the Costilla-operated properties in the Costilla report
that excluded COPAS overhead and internal indirect overhead which are billed to
outside working interest owners. The exclusion of these costs for the operated
properties results in the calculation of a lower economic limit and causes the
economic lifetime to be
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Costilla Energy, Inc.
Mr. Michael J. Grella
July 23, 1996
Page 2
extended. Williamson has not quantified the incremental reserves resulting from
this procedure. COPAS overhead was excluded from the lease operating expenses
for the Parker & Parsley-operated properties in the Acquisition report.
The present values of the estimated future net revenues from proved reserves
were calculated using a discount rate of 10.00 percent per year and were
computed in accordance with the financial reporting requirements of the SEC.
Following is a summary of the results of the two evaluations effective April 1,
1996:
<TABLE>
<CAPTION>
PROVED PROVED
DEVELOPED DEVELOPED PROVED TOTAL
PRODUCING NONPRODUCING UNDEVELOPED PROVED
------------- ----------------- ---------------- -------------
<S> <C> <C> <C> <C>
Net Reserves to the Evaluated Interests:
Oil/Condensate, BBL......................... 13,122,088 429,450 2,924,589 16,476,127
Gas, MCF.................................... 76,439,217 7,929,591 28,551,497 112,920,305
Future Net Revenue, $:
Undiscounted................................ 212,071,507 18,097,949 66,832,632 297,002,088
Discounted Per Annum at 10.00 Percent....... 135,185,097 9,530,285 34,811,523 179,526,905
</TABLE>
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Note: The values presented in this table are taken from evaluations described in
Item I and include by reference all data, qualifications, and assumptions
from these evaluations. Realization of these values is contingent on
achieving successful results from the various schedules and assumptions in
these evaluations. The available engineering data and the completeness
and/or quality of data utilized in evaluating the properties are detailed
in the specific evaluation. Review of any additionally available data may
necessitate revision to these interpretations and assumptions and impact
these values.
III. DEFINITIONS OF SEC RESERVES (1)
The estimated reserves presented in this summary letter are net proved
reserves, including proved developed producing, proved developed nonproducing,
and proved undeveloped reserves, and were computed in accordance with the
financial reporting requirements of the SEC. In preparing these evaluations, no
attempt has been made to quantify the element of uncertainty associated with any
category. Reserves were assigned to each category as warranted. The definitions
of oil and gas reserves pursuant to the requirements of the Securities Exchange
Act are:
PROVED RESERVES (2)
Proved reserves are the estimated quantities of crude oil, natural gas, and
natural gas liquids which geological and engineering data demonstrate with
reasonable certainty to be recoverable in future years from known reservoirs
under the economic criteria employed and existing operating conditions, i.e.,
prices and costs as of the date the estimate is made. Prices and costs include
consideration of changes provided only by contractual arrangements but not on
escalations based upon an estimate of future conditions.
A. Reservoirs are considered proved if economic producibility is supported by
either actual production or conclusive formation test. The area of a
reservoir considered proved includes:
1. that portion delineated by drilling and defined by gas-oil and/or
oil-water contacts, if any; and
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(1) For evaluations prepared for disclosure to the Securities and Exchange
Commission, see SEC ACCOUNTING RULES. Commerce Clearing House, Inc. October
1981, Paragraph 290, Regulation 210.4-10, p. 329.
(2) Any variations to these definitions will be clearly stated in the report.
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Costilla Energy, Inc.
Mr. Michael J. Grella
July 23, 1996
Page 3
2. the immediately adjoining portions not yet drilled, but which can be
reasonably judged as economically productive on the basis of available
geological and engineering data. In the absence of information on fluid
contacts, the lowest known structural occurrence of hydrocarbons controls
the lower proved limit of the reservoir.
B. Reserves which can be produced economically through application of improved
recovery techniques (such as fluid injection) are included in the "proved"
classification when successful testing by a pilot project, or the operation
of an installed program in the reservoir, provides support for the
engineering analysis on which the project or program was based.
C. Estimates of proved reserves do not include the following:
1. oil that may become available from known reservoirs but is classified
separately as "indicated additional reserves;"
2. crude oil, natural gas, and natural gas liquids, the recovery of which
is subject to reasonable doubt because of uncertainty as to geology,
reservoir characteristics, or economic factors;
3. crude oil, natural gas, and natural gas liquids, that may occur in
undrilled prospects; and
4. crude oil, natural gas, and natural gas liquids, that may be recovered
from oil shales, coal (3), gilsonite and other such sources.
PROVED DEVELOPED RESERVES (4)
Proved developed reserves are reserves that can be expected to be recovered
through existing wells with existing equipment and operating methods. Additional
oil and gas expected to be obtained through the application of fluid injection
or other improved recovery techniques for supplementing the natural forces and
mechanisms of primary recovery should be included as "proved developed reserves"
only after testing by a pilot project or after the operation of an installed
program has confirmed through production response that increased recovery will
be achieved.
PROVED UNDEVELOPED RESERVES
Proved undeveloped reserves are reserves that are expected to be recovered
from new wells on undrilled acreage, or from existing wells where a relatively
major expenditure is required for recompletion. Reserves on undrilled acreage
shall be limited to those drilling units offsetting productive units that are
reasonably certain of production when drilled. Proved reserves for other
undrilled units can be claimed only where it can be demonstrated with certainty
that there is continuity of production from the existing productive formation.
Under no circumstances should estimates for proved undeveloped reserves be
attributable to any acreage for which an application of fluid injection or other
improved recovery technique is contemplated, unless such techniques have been
proved effective by actual tests in the area and in the same reservoir.
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(3) According to Staff Accounting Bulletin 85, excluding certain coalbed methane
gas.
(4) Williamson Petroleum Consultants, Inc. separates proved developed reserves
into proved developed producing and proved developed nonproducing reserves.
This is to identify proved developed producing reserves as those to be
recovered from actively producing wells; proved developed nonproducing
reserves as those to be recovered from wells or intervals within wells,
which are completed but shut in waiting on equipment or pipeline
connections, or wells where a relatively minor expenditure is required for
recompletion to another zone.
A-3
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Costilla Energy, Inc.
Mr. Michael J. Grella
July 23, 1996
Page 4
IV. DISCUSSION OF SEC RESERVES
A. THE COSTILLA REPORT
A total of 1,014 properties in 294 fields were evaluated in the Costilla
report. Nineteen individual properties had values greater than 1.0 percent
of the total future net revenue discounted at 10.00 percent per annum (DFNR)
and in aggregate represent 34.5 percent of the DFNR in the Costilla report.
The most valued property, the T.B. Pruett Gas Unit No. 3, Soda Lake field,
Ward County, Texas, had a value equal to 4.5 percent of the total DFNR in
the Costilla report. The top eight major-value fields are Talbot (Canyon),
Howard County, Texas; Spraberry (Trend Area), Various Counties, Texas; Soda
Lake (Fusselman), Ward County, Texas; South Buffalo Ridge, Crane County,
Texas; Wattenberg, Weld County, Colorado; East Goldsmith, Ector County,
Texas; Raymond, Sheridan County, Montana; and South West Speaks, Lavaca
County, Texas. These fields contain ten of the 19 top value properties and
represent, in aggregate, 41.0 percent of the total DFNR in the Costilla
report. The remaining 286 fields represent 59.0 percent with no field having
more than 2.9 percent of the DFNR in the Costilla report. A more detailed
property review is included in the Costilla report.
Area oil prices were provided by Costilla to be used at the effective date
with the written assurance that the use of these area prices is reasonable
on an aggregate basis and would not materially affect the income from any
major-value property. These area prices were calculated by adjusting the
West Texas Intermediate oil April 1, 1996 posted price of $20.75 per barrel.
The oil price adjustments for each area are the calculated differences
between the actual price received during 1995 and the posted price for West
Texas Intermediate oil during that same period. After the effective date,
prices were held constant for the life of the properties. No attempt has
been made to account for oil price fluctuations which have occurred in the
market subsequent to the effective date of this report.
Gas prices were provided by Costilla to be used at the effective date. These
prices were based on the April 1996 spot price of $1.75 per million British
thermal units (MMBTU) at the Waha, Texas receipt point. This price was
adjusted with an area price adjustment which was calculated as the
difference between the actual price received during 1995 and the stop price.
The resultant price was further adjusted for the BTU content of the gas for
each well. If the BTU content was unknown, it was assumed to be one MMBTU
per MCF of gas. After the effective date, prices were held constant for the
life of the properties unless Costilla indicated that changes were provided
for by contract. All gas prices were applied to projected wellhead volumes.
It should be emphasized that with the current economic uncertainties,
fluctuation in market conditions could significantly change the economics of
the properties included in this report.
Operating expenses were provided by Costilla and represented, when possible,
the latest available 12-month average of all recurring expenses excluding
COPAS and internal indirect overhead costs which are billable to the working
interest owners. These expenses included, but were not limited to, all
direct operating expenses, field overhead costs, and any ad valorem taxes
not deducted separately. Expenses for workovers, well stimulations, and
other maintenance were not included in the operating expenses unless such
work was expected on a recurring basis. Judgments for the exclusion of the
nonrecurring expenses were made by Costilla. In accordance with instructions
from Costilla, Williamson has excluded COPAS overhead and internal indirect
overhead which are billed to the outside working interest owners from the
operating expenses for Costilla-operated properties. The exclusion of these
costs for operated properties results in the calculation of a lower economic
limit and causes the economic lifetime to be extended. Williamson has not
calculated the reserves that have been added as a result of this procedure.
For new and developing properties where data were unavailable, operating
expenses were estimated by Costilla. Operating costs were held constant for
the life of the properties.
A-4
<PAGE>
Costilla Energy, Inc.
Mr. Michael J. Grella
July 23, 1996
Page 5
State production taxes have been deducted at the published rates as
appropriate. For operated properties, average county ad valorem taxes
provided by Costilla were deducted for those properties located in states
for which the data were available. Any ad valorem taxes for nonoperated
properties or for properties in other states were assumed to be included in
the operating expenses.
All capital costs for drilling and completion of wells and nonrecurring
workover or operating costs have been deducted as applicable. These costs
were provided by Costilla. No adjustments were made to account for the
potential effect of inflation on these costs.
Neither salvage values nor abandonment costs were provided by Costilla to be
included in this evaluation.
B. THE ACQUISITION REPORT
A total of 1,091 properties in 135 fields were evaluated in the Acquisition
report. Eighteen individual properties had values greater than 1.0 percent
of the total DFNR and in aggregate represent 35.5 percent of the DFNR in the
Acquisition report. The most valued property, the H.W. Glasscock Unit,
Howard-Glasscock field, Glasscock County, Texas, has a projected value of
5.7 percent of the total DFNR in the Acquisition report. The top eight
major-value fields are World, Crockett County, Texas; Dimmitt, Loving
County, Texas; Panna Maria, Karnes County, Texas; Giddings, Various
Counties, Texas; Caldwell, Burleson County, Texas; Coletto Creek, Victoria
County, Texas; Sawyer, Sutton County, Texas; and Jameson, Coke County,
Texas. These fields contain 11 of the 18 top value properties and represent,
in aggregate, 51.9 percent of the total DFNR in the Acquisition report. The
remaining fields represent 48.1 percent with no field having more than 2.9
percent of the DFNR in the Acquisition report. A more detailed property
review is included in the Acquisition report.
Area oil prices were provided by Costilla and Parker & Parsley to be used at
the effective date with the written assurance that the use of these area
prices is reasonable on an aggregate basis and would not materially affect
the income from any major-value property. These area prices were calculated
by adjusting the West Texas Intermediate oil April 1, 1996 posted price of
$20.75 per barrel. The oil price adjustments as calculated by Parker &
Parsley for each area are the calculated differences between the actual
price received during 1995 and the posted price for West Texas Intermediate
oil during that same period. After the effective date, prices were held
constant for the life of the properties. No attempt has been made to account
for oil price fluctuations which have occurred in the market subsequent to
the effective date of this report.
Gas prices were provided by Costilla and Parker & Parsley to be used at the
effective date. These prices were based on the April 1996 spot price of
$1.75 per million British thermal units (MMBTU) at the Waha, Texas receipt
point. This price was adjusted with an area price adjustment which was
calculated as the difference between the actual price received during 1995
and the stop price. The resultant price was further adjusted for the BTU
content of the gas for each well. If the BTU content was unknown, it was
assumed to be one MMBTU per MCF of gas. After the effective date, prices
were held constant for the life of the properties unless Costilla indicated
that changes were provided for by contract. All gas prices were applied to
projected wellhead volumes.
It should be emphasized that with the current economic uncertainties,
fluctuation in market conditions could significantly change the economics of
the properties included in this report.
Operating expenses were provided by Costilla and Parker & Parsley and
represented, when possible, the latest available 12-month average of all
recurring expenses excluding COPAS and internal indirect overhead costs
which are billable to the working interest owners. These expenses included,
but were not limited to, all direct operating expenses, field overhead
costs, and any ad valorem taxes not deducted
A-5
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Costilla Energy, Inc.
Mr. Michael J. Grella
July 23, 1996
Page 6
separately. Expenses for workovers, well stimulations, and other maintenance
were not included in the operating expenses unless such work was expected on
a recurring basis. Judgments for the exclusion of the nonrecurring expenses
were made by Costilla or Parker & Parsley. In accordance with instructions
from Costilla, Williamson has excluded COPAS overhead which is billed to the
outside working interest owners from the operating expenses for Parker &
Parsley-operated properties. The exclusion of these costs for operated
properties results in the calculation of a lower economic limit and causes
the economic lifetime to be extended. Williamson has not calculated the
reserves that have been added as a result of this procedure. For new and
developing properties where data were unavailable, operating expenses were
estimated by Costilla or Parker & Parsley. Operating costs were held
constant for the life of the properties.
State production taxes have been deducted at the published rates as
appropriate. For operated properties, average county ad valorem taxes
provided by Costilla were deducted for those properties located in states
for which the data were available. Any ad valorem taxes for nonoperated
properties or for properties in other states were assumed to be included in
the operating expenses.
All capital costs for drilling and completion of wells and nonrecurring
workover or operating costs have been deducted as applicable. These costs
were provided by Costilla or Parker & Parsley. No adjustments were made to
account for the potential effect of inflation on these costs.
Neither salvage values nor abandonment costs were provided by Costilla to be
included in this evaluation.
V. GENERAL EVALUATION CONSIDERATIONS PERTAINING TO THE COSTILLA AND ACQUISITION
REPORTS
The individual projections prepared to produce this summary letter include
data that describe the production forecasts and associated evaluation parameters
such as interests, taxes, product prices, operating costs, investments, salvage
values, abandonment costs, and net profit interests, as applicable.
Net income to the evaluated interests is the future net revenue payable to
others, taxes, operating expenses, investments, salvage values, abandonment
costs, and net profit interests, as applicable. The future net revenue is before
federal income tax and excludes consideration of any encumbrances against the
properties if such exist.
No opinion is expressed by Williamson as to the fair market value of the
evaluated properties.
The future net revenues presented in this summary letter were based on
projections of oil and gas production. It was assumed there would be no
significant delay between the date of oil and gas production and the receipt of
the associated revenue for this production.
This summary letter includes only those costs and revenues which are
considered by Costilla to be directly attributable to individual leases and
areas. There could exist other revenues, overhead costs, or other costs
associated with Costilla which are not included in this summary letter. Such
additional costs and revenues are outside the scope of this summary letter. This
summary letter is not a financial statement for Costilla and should not be used
as the sole basis for any transaction concerning Costilla, Parker & Parsley, or
the evaluated properties.
The reserves projections in this summary letter are based on the use of the
available data and accepted industry engineering methods. Future changes in any
operational or economic parameters or production characteristics of the
evaluated properties could increase or decrease their reserves. Unforeseen
changes in market demand or allowables set by various regulatory agencies could
also cause actual production rates to vary from those projected. The dates of
first production for nonproducing properties were based on
A-6
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Costilla Energy, Inc.
Mr. Michael J. Grella
July 23, 1996
Page 7
estimates by Costilla or Williamson and the actual dates may vary from those
estimated. Williamson reserves the right to alter any of the reserves
projections and the associated economics included in this summary letter in any
future evaluation based on additional data that may be acquired.
All data utilized in the preparation of this summary letter with respect to
interests, reversionary status, oil and gas prices, gas categories, gas contract
terms, operating expenses, investments, salvage values, abandonment costs, net
profit interests, well information and current operating conditions, as
applicable, were provided by Costilla, Parker & Parsley, and the operators. Data
obtained after the effective date of the report but prior to the completion of
the report were used only if such data were applied consistently. If such data
were used, the reserves category assignments reflect the status of the wells as
of the effective date. In the Costilla report, daily production data after April
1, 1996 were utilized for new wells in the South Buffalo Ridge, Concho Bluff
(Queen), East Goldsmith (Queen), King Mountain (Penn), and Talbot (Canyon)
fields to assist in determining initial producing and decline rates. Daily
production since the effective date was also used for the Pyote Gas Unit 5 No.
1A, Block 16 (Devonian) field, Ward County, Texas to establish the producing
rate after the well was affected by gas plant problems and for the State 16-05
well in the Raymond field, Sheridan County, Montana to establish the initial
rate of production subsequent to the installation of a downhole pump. Production
data generally through December 1995 or January 1996 provided by Costilla for
the properties in the Costilla report and through November or December 1995
provided by Parker & Parsley for the properties in the Acquisition report were
utilized. All data have been reviewed for reasonableness and, unless obvious
errors were detected, have been accepted as correct. It should be emphasized
that revisions to the projections of reserves and economics included in this
summary letter may be required if the provided data are revised for any reason.
No inspection of the properties was made as this was not considered within the
scope of these projects. No investigation was made of any environmental
liabilities that might apply to the evaluated properties, and no costs are
included for any possible related expenses.
Unless specifically identified and documented by Costilla or Parker &
Parsley as having curtailment problems, gas production trends have been assumed
to be a function of well productivity and not of market conditions. The effect
of "take or pay" clauses in gas contracts was not considered.
Oil reserves are expressed in United States (U.S.) barrels of 42 U.S.
gallons. Gas volumes are expressed in thousands of cubic feet (MCF) at 60
degrees Fahrenheit and at the legal pressure base that prevails in the state in
which the reserves are located. No adjustment of the individual gas volumes to a
common pressure base has been made.
Costilla represented to Williamson that it has, or can generate, the
financial and operational capabilities to accomplish those projects evaluated by
Williamson which require capital expenditures.
The estimates of reserves contained in this summary letter were determined
by accepted industry methods and in accordance with the definitions of oil and
gas reserves set forth above. Methods utilized in this summary letter include
extrapolation of historical production trends, material balance determinations,
analogy to similar properties, and volumetric calculations.
Where sufficient production history and other data were available, reserves
for producing properties were determined by extrapolation of historical
production trends or through the use of material balance determinations. Analogy
to similar properties or volumetric calculations were used for nonproducing
properties and those producing properties which lacked sufficient production
history and other data to yield a definitive estimate of reserves. Reserves
projections based on analogy are subject to change due to subsequent changes in
the analogous properties or subsequent production from the evaluated properties.
Volumetric calculations are often based upon limited log and/or core analysis
data and incomplete reservoir
A-7
<PAGE>
Costilla Energy, Inc.
Mr. Michael J. Grella
July 23, 1996
Page 8
fluid and formation rock data. Since these limited data must frequently be
extrapolated over an assumed drainage area, subsequent production performance
trends or material balance calculations may cause the need for significant
revisions to the estimates of reserves.
It should be emphasized that with the current economic uncertainties,
fluctuation in market conditions could significantly change the economics in
this summary letter.
VII. DECLARATION OF INDEPENDENT STATUS AND CONSENT
We understand that our estimates are to be included in a Registration
Statement on Form S-1 (the Registration Statement) to be filed with the SEC and
in the Prospectus as included in such Registration Statement which will be
registered under the Securities Act of 1933, as amended.
Williamson is an independent consulting firm and does not own any interests
in the oil and gas properties covered by this summary letter. Roy C. Williamson,
Jr., Chief Executive Officer, owns a 2.5 percent working interest in six wells
in the Outlook field, Sheridan County, Montana, which have a total value of
$138,912 to the interests of Costilla. No employee, officer or director of
Williamson is an employee, officer or director of Costilla or Parker & Parsley.
Neither the employment of nor the compensation received by Williamson is
contingent upon the values assigned to the oil and gas properties covered by
this summary letter.
We consent to the inclusion of this summary letter in the Registration
Statement, the inclusion in the Registration Statement of data extracted from
this summary letter and to all references to our firm in the Prospectus,
including any references to our firm as Experts.
Yours very truly,
WILLIAMSON PETROLEUM CONSULTANTS, INC.
A-8
<PAGE>
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NO DEALER, SALESMAN OR ANY OTHER PERSON HAS BEEN AUTHORIZED TO GIVE ANY
INFORMATION OR TO MAKE ANY REPRESENTATIONS OTHER THAN THOSE CONTAINED IN THIS
PROSPECTUS IN CONNECTION WITH THE OFFER MADE BY THIS PROSPECTUS AND, IF GIVEN OR
MADE, SUCH INFORMATION OR REPRESENTATIONS MUST NOT BE RELIED UPON AS HAVING BEEN
AUTHORIZED BY THE COMPANY OR ANY OF THE UNDERWRITERS. THIS PROSPECTUS DOES NOT
CONSTITUTE AN OFFER TO SELL OR THE SOLICITATION OF ANY OFFER TO BUY ANY SECURITY
OTHER THAN THE SHARES OF COMMON STOCK OFFERED BY THIS PROSPECTUS, NOR DOES IT
CONSTITUTE AN OFFER TO SELL OR A SOLICITATION OF ANY OFFER TO BUY THE SHARES OF
COMMON STOCK BY ANYONE IN ANY JURISDICTION IN WHICH SUCH OFFER OR SOLICITATION
IS NOT AUTHORIZED, OR IN WHICH THE PERSON MAKING SUCH OFFER OR SOLICITATION IS
NOT QUALIFIED TO DO SO, OR TO ANY PERSON TO WHOM IT IS UNLAWFUL TO MAKE SUCH
OFFER OR SOLICITATION. NEITHER THE DELIVERY OF THIS PROSPECTUS NOR ANY SALE MADE
HEREUNDER SHALL, UNDER ANY CIRCUMSTANCES, CREATE ANY IMPLICATION THAT THE
INFORMATION CONTAINED HEREIN IS CORRECT AS OF ANY TIME SUBSEQUENT TO THE DATE
HEREOF.
UNTIL , 1996, ALL DEALERS EFFECTING TRANSACTIONS IN THE REGISTERED
SECURITIES, WHETHER OR NOT PARTICIPATING IN THIS DISTRIBUTION, MAY BE REQUIRED
TO DELIVER A PROSPECTUS. THIS IS IN ADDITION TO THE OBLIGATION OF DEALERS TO
DELIVER A PROSPECTUS WHEN ACTING AS UNDERWRITERS AND WITH RESPECT TO THEIR
UNSOLD ALLOTMENTS OR SUBSCRIPTIONS.
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P R O S P E C T U S
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TABLE OF CONTENTS
<TABLE>
<CAPTION>
PAGE
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<S> <C>
Prospectus Summary.................................... 3
Risk Factors.......................................... 8
The Company........................................... 13
Notes Offering........................................ 13
Use of Proceeds....................................... 14
Dividend Policy....................................... 14
Dilution.............................................. 15
Capitalization........................................ 16
Pro Forma Condensed Financial Statements.............. 17
Selected Financial Information........................ 25
Management's Discussion and Analysis of Financial
Condition and Results of Operations.................. 26
Business and Properties............................... 32
Management............................................ 44
Security Ownership of Certain Beneficial Owners and
Management........................................... 47
Executive Compensation and Other Information.......... 48
Certain Transactions.................................. 51
Description of Certain Indebtedness................... 52
Description of Capital Stock.......................... 53
Shares Eligible for Future Sale....................... 56
Underwriting.......................................... 57
Legal Matters......................................... 58
Experts............................................... 58
Available Information................................. 58
Glossary.............................................. 60
Index to Financial Statements......................... F-1
Summary Reserve Report................................ A-1
</TABLE>
4,000,000 Shares
[logo]
COSTILLA ENERGY, INC.
Common Stock
PRUDENTIAL SECURITIES INCORPORATED
RAUSCHER PIERCE REFSNES, INC.
September , 1996
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<PAGE>
PART II
INFORMATION NOT REQUIRED IN PROSPECTUS
ITEM 13. OTHER EXPENSES OF ISSUANCE AND DISTRIBUTION.
<TABLE>
<S> <C>
SEC registration fee.............................................. $ 20,690
NASD filing fee................................................... 7,860
Nasdaq listing fee................................................ 42,500
Blue Sky fees and expenses........................................ 15,000
Accounting fees and expenses...................................... 65,625
Engineering fees and expenses..................................... 68,250
Transfer Agent fees and expenses.................................. 5,000
Legal fees and expenses........................................... 93,750
Printing and mailing expenses..................................... 175,000
Miscellaneous..................................................... 6,325
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TOTAL....................................................... 500,000
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</TABLE>
ITEM 14. INDEMNIFICATION OF DIRECTORS AND OFFICERS.
Section 145 of the General Corporation Law of the State of Delaware permits
a corporation to indemnify certain persons, including officers and directors and
former officers and directors, and to purchase insurance with respect to
liability arising out of their capacity or status as officers and directors.
Such law provides further that the indemnification permitted thereunder shall
not be deemed exclusive of any other rights to which officers and directors may
be entitled under the corporation's bylaws, any agreement or otherwise. Article
IX of the Company's Certificate of Incorporation, included in Exhibit 3.1
hereto, and Article VI of the Company's Bylaws, included in Exhibit 3.2 hereto,
provide, in general, that the Company shall indemnify its directors and officers
under the circumstances defined in Section 145 of the General Corporation Law of
the State of Delaware and gives authority to the Company to purchase insurance
with respect to such indemnification. The Company may in the future seek to
obtain insurance providing for indemnification of officers and directors of the
Company and certain other persons against liabilities and expenses incurred by
any of them in certain stated proceedings and under certain stated conditions.
In addition, Section 102(b)(7) of the General Corporation Law of the State
of Delaware permits a corporation to limit the liability of its directors
subject to certain exceptions. In accordance with Section 102(b)(7), Article VI
of the Company's Certificate of Incorporation, included in Exhibit 3.1 hereto,
provides, in general, that no director of the Company shall be personally liable
for (i) any breach of the director's duty of loyalty to the Company or its
stockholders, (ii) acts or omissions not in good faith or which involve
intentional misconduct or a knowing violation of law, (iii) unlawful payments of
dividends or unlawful stock repurchases or redemptions as provided in Section
174 of the General Corporation Law of the State of Delaware or (iv) any
transaction from which the director derived an improper personal benefit.
The Underwriting Agreement provides for indemnification by the Underwriters
of the Registrant, its directors and officers, and by the Registrant of the
Underwriters, for certain liabilities, including liabilities arising under the
Securities Act of 1933 (the "Securities Act").
ITEM 15. RECENT SALES OF UNREGISTERED SECURITIES.
Prior to the consummation of the Offerings, the Company issued an aggregate
of 3 shares of Common Stock to Messrs. Liedtke, Grella and Musselman in its
initial capitalization, which shares were cancelled in connection with the
Corporate Reorganization, and an aggregate of 6,000,000 shares of Common Stock
to the four members of the LLC in the merger of the LLC with and into the
Company. Such shares were not registered under the Securities Act in reliance
upon the exemption from registration provided by Section 4(2) thereof.
II-1
<PAGE>
ITEM 16. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES.
(a) Exhibits
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION OF EXHIBIT
- ---------- --------------------------------------------------------------------------------------
<C> <S>
*1.1 Form of Underwriting Agreement
***3.1 Certificate of Incorporation of the Company
***3.2 Bylaws of the Company
***4.1 Form of Notes or Global Certificate (included as Exhibit A to the form of Indenture
filed as Exhibit Number 4.2 to the Registration Statement on Form S-1, File No.
333-08909, filed with respect to the Notes)
***4.2 Form of Indenture
*4.3 Form of Stock Certificate
*5.1 Opinion of Cotton, Bledsoe, Tighe & Dawson, a Professional Corporation
***10.1 Commitment Letter dated September 20, 1996 between NationsBank of Texas, N.A. and the
Company
***10.2 Lease Agreement dated January 12, 1996 between Independence Plaza, Ltd. and Costilla
Energy, L.L.C.
***10.3 Concession Agreement dated July 6, 1995 between the Government of the Republic of
Moldova and the Resource Development Company, Limited
***10.4 Purchase and Joint Exploration Agreement dated February 21, 1996 between the Company
and Resources Development Limited, L.L.C. (DE)
***10.5 Form of Consolidation Agreement to be effective contemporaneously with closing of the
Offerings to consummate the Corporate Reorganization
***10.6 Form of 1996 Stock Option Plan
***10.7 Form of Outside Directors Stock Option Plan
***10.8 Employment Agreement between the Company and Bobby W. Page effective June 30, 1996
***10.9 Employment Agreement between the Company and Cadell S. Liedtke to be effective
contemporaneously with the closing of the Offerings
***10.10 Employment Agreement between the Company and Michael J. Grella to be effective
contemporaneously with the closing of the Offerings
***10.11 Employment Agreement between the Company and Henry G. Musselman to be effective
contemporaneously with the closing of the Offerings
***10.12 Exchange Agreement dated January 5, 1995 between Costilla Petroleum Corporation and
Koch Oil Company
***10.13 Agreement dated January 2, 1996 between Costilla Petroleum Corporation and Frontier
Oil and Refining Company
***10.14 Purchase and Sale Agreement dated April 3, 1995 by and between Parker & Parsley
Development L.P. and Parker & Parsley Producing L.P. and Parker & Parsley Gas
Processing Co. as Seller and Costilla Petroleum Corporation and Costilla Energy,
L.L.C. as Purchaser
***10.15 Purchase and Sale Agreement dated March 8, 1996 by and between Parker & Parsley
Development L.P. and Parker & Parsley Producing L.P. and Parker & Parsley Gas
Processing Co. as Seller and Costilla Petroleum Corporation and Costilla Energy,
L.L.C. as Purchaser
***10.16 Supplemental Agreement to Purchase and Joint Exploration Agreement dated August 7,
1996 among the Company, Costilla Redeco Energy, L.L.C. and Resource Development
Company Limited, L.L.C. (DE)
</TABLE>
II-2
<PAGE>
<TABLE>
<CAPTION>
EXHIBIT
NUMBER DESCRIPTION OF EXHIBIT
- ---------- --------------------------------------------------------------------------------------
<C> <S>
***10.17 Form of Bonus Incentive Plan
***12.1 Computation of Ratio of Adjusted EBITDA to Interest Expense
***12.2 Computation of Ratio of Earnings to Fixed Charges
*16.1 Letter Regarding Change of Accountants
***21.1 Subsidiaries of the Registrant
**23.1 Consent of KPMG Peat Marwick LLP
*23.2 Consent of Williamson Petroleum Consultants, Inc.
**23.3 Consent of Elms, Faris & Co., P.C.
*23.4 Consent of Cotton, Bledsoe, Tighe & Dawson, a Professional Corporation (such consent
is included in the opinion filed as Exhibit 5.1 to this Registration Statement)
*24.1 Power of Attorney
*24.2 Certified copy of resolution of Board of Directors of Costilla Energy, Inc.
authorizing signature pursuant to Power of Attorney
*27.1 Financial Data Schedule
</TABLE>
- ------------------------
* Previously filed
** Filed herewith
*** Incorporated by reference to Registration Statement on Form S-1, File No.
333-08909, filed with respect to the Notes
(b) Financial Statement Schedules.
ITEM 17. UNDERTAKINGS
Insofar as indemnification for liabilities arising under the Securities Act
may be permitted to directors, officers and controlling persons of the
Registrant pursuant to the provisions described under Item 14 above, or
otherwise, the Registrant has been advised that in the opinion of the Securities
and Exchange Commission, such indemnification is against public policy as
expressed in the Securities Act and is, therefore, unenforceable. In the event
that a claim for indemnification against such liabilities (other than the
payment by the Registrant of expenses incurred or paid by a director, officer of
controlling person of the Registrant in the successful defense of any action,
suit or proceeding) is asserted by such directors, officer or controlling person
in connection with the securities being registered, the Registrant will, unless
in the opinion of its counsel the matter has been settled by controlling
precedent, submit to a court of appropriate jurisdiction the question whether
such indemnification by it is against public policy as expressed in the
Securities Act and will be governed by the final adjudication of such issue.
The undersigned Registrant hereby undertakes that, for purposes of
determining any liability under the Securities Act, (i) the information omitted
from the Prospectus filed as part of this Registration Statement in reliance
upon Rule 430A under the Securities Act and contained in a form of Prospectus
filed by the Registrant pursuant to Rule 424(b)(1) or (4) or 497(h) under the
Securities Act shall be deemed to be part of this Registrant Statement as of the
time it was declared effective and (ii) each post-effective amendment that
contains a form of prospectus shall be deemed to be a new Registration Statement
relating to the securities offered therein, and the offering of such securities
at that time shall be deemed to be the initial bona fide offering thereof.
The undersigned registrant hereby undertakes to provide to the Underwriters,
at the closing specified in the Underwriting Agreement, certificates in such
denominations and registered in such names as required by the Underwriters to
permit prompt delivery to each purchaser.
II-3
<PAGE>
SIGNATURES
Pursuant to the requirements of the Securities Act of 1933, the Registrant
has duly caused this Registration Statement to be signed on its behalf by the
undersigned, thereunto duly authorized in the City of Midland, State of Texas,
on October 2, 1996.
COSTILLA ENERGY, INC.
(Registrant)
By: *
-----------------------------------
Michael J. Grella
PRESIDENT AND CHIEF OPERATING
OFFICER
Pursuant to the requirements of the Securities Act of 1933, this
Registration Statement has been signed by the following persons on behalf of the
Registrant and in the capacities and on the dates indicated.
SIGNATURE TITLE DATE
- ----------------------------------- ------------------------- ----------------
* Chairman of the Board,
- ----------------------------------- Chief Executive Officer October 2, 1996
Cadell S. Liedtke and Director
* President, Chief
- ----------------------------------- Operating Officer and October 2, 1996
Michael J. Grella Director
*
- ----------------------------------- Executive Vice President October 2, 1996
Henry G. Musselman and Director
/s/ BOBBY W. PAGE Senior Vice Present,
- ----------------------------------- Treasurer and Chief October 2, 1996
Bobby W. Page Financial Officer
*
- ----------------------------------- Director October 2, 1996
Jerry J. Langdon
*
- ----------------------------------- Director October 2, 1996
W.D. Kennedy
*By: /s/ BOBBY W. PAGE
- -----------------------------------
Bobby W. Page
ATTORNEY-IN-FACT
II-4
<PAGE>
INDEX TO EXHIBITS
<TABLE>
<CAPTION>
EXHIBIT SEQUENTIALLY
NUMBER DESCRIPTION OF EXHIBIT NUMBERED PAGE
- ---------- ---------------------------------------------------------------------------------------- ---------------
<C> <S> <C>
*1.1 Form of Underwriting Agreement
***3.1 Certificate of Incorporation of the Company
***3.2 Bylaws of the Company
***4.1 Form of Notes or Global Certificate (included as Exhibit A to the form of Indenture
filed as Exhibit Number 4.2 to the Registration Statement on Form S-1, File No.
333-08909, filed with respect to the Notes)
***4.2 Form of Indenture
*4.3 Form of Stock Certificate
*5.1 Opinion of Cotton, Bledsoe, Tighe & Dawson, a Professional Corporation
***10.1 Commitment Letter dated September 20, 1996 between NationsBank of Texas, N.A. and the
Company
***10.2 Lease Agreement dated January 12, 1996 between Independence Plaza, Ltd. and Costilla
Energy, L.L.C.
***10.3 Concession Agreement dated July 6, 1995 between the Government of the Republic of
Moldova and the Resource Development Company, Limited
***10.4 Purchase and Joint Exploration Agreement dated February 21, 1996 between the Company and
Resources Development Limited, L.L.C. (DE)
***10.5 Form of Consolidation Agreement to be effective contemporaneously with closing of the
Offerings to consummate the Corporate Reorganization
***10.6 Form of 1996 Stock Option Plan
***10.7 Form of Outside Directors Stock Option Plan
***10.8 Employment Agreement between the Company and Bobby W. Page effective June 30, 1996
***10.9 Employment Agreement between the Company and Cadell S. Liedtke to be effective
contemporaneously with the closing of the Offerings
***10.10 Employment Agreement between the Company and Michael J. Grella to be effective
contemporaneously with the closing of the Offerings
***10.11 Employment Agreement between the Company and Henry G. Musselman to be effective
contemporaneously with the closing of the Offerings
***10.12 Exchange Agreement dated January 5, 1995 between Costilla Petroleum Corporation and Koch
Oil Company
***10.13 Agreement dated January 2, 1996 between Costilla Petroleum Corporation and Frontier Oil
and Refining Company
***10.14 Purchase and Sale Agreement dated April 3, 1995 by and between Parker & Parsley
Development L.P. and Parker & Parsley Producing L.P. and Parker & Parsley Gas
Processing Co. as Seller and Costilla Petroleum Corporation and Costilla Energy, L.L.C.
as Purchaser
***10.15 Purchase and Sale Agreement dated March 8, 1996 by and between Parker & Parsley
Development L.P. and Parker & Parsley Producing L.P. and Parker & Parsley Gas
Processing Co. as Seller and Costilla Petroleum Corporation and Costilla Energy, L.L.C.
as Purchaser
***10.16 Supplemental Agreement to Purchase and Joint Exploration Agreement dated August 7, 1996
among the Company, Costilla Redeco Energy, L.L.C. and Resource Development Company
Limited, L.L.C. (DE)
***10.17 Form of Bonus Incentive Plan
***12.1 Computation of Ratio of Adjusted EBITDA to Interest Expense
***12.2 Computation of Ratio of Earnings to Fixed Charges
</TABLE>
<PAGE>
<TABLE>
<CAPTION>
EXHIBIT SEQUENTIALLY
NUMBER DESCRIPTION OF EXHIBIT NUMBERED PAGE
- ---------- ---------------------------------------------------------------------------------------- ---------------
<C> <S> <C>
*16.1 Letter Regarding Change of Accountants
***21.1 Subsidiaries of the Registrant
**23.1 Consent of KPMG Peat Marwick LLP
*23.2 Consent of Williamson Petroleum Consultants, Inc.
**23.3 Consent of Elms, Faris & Co., P.C.
*23.4 Consent of Cotton, Bledsoe, Tighe & Dawson, a Professional Corporation (such consent is
included in the opinion filed as Exhibit 5.1 to this Registration Statement)
*24.1 Power of Attorney
*24.2 Certified copy of resolution of Board of Directors of Costilla Energy, Inc. authorizing
signature pursuant to Power of Attorney
*27.1 Financial Data Schedule
</TABLE>
- ------------------------
* Previously filed
** Filed herewith
*** Incorporated by reference to Registration Statement on Form S-1, File No.
333-08909, filed with respect to the Notes.
<PAGE>
EXHIBIT 23.1
CONSENT OF INDEPENDENT AUDITORS
The Members
Costilla Energy, L.L.C.
We consent to the use of our reports included herein and to the reference to
our firm under the heading "Experts" in the Prospectus.
KPMG PEAT MARWICK LLP
Midland, Texas
October 2, 1996
<PAGE>
EXHIBIT 23.3
CONSENT OF INDEPENDENT AUDITORS
The Members
Costilla Energy, L.L.C.
We consent to the use of our reports included herein and to the reference to
our firm under the heading "Experts" in the Prospectus.
ELMS, FARIS & CO., P.C.
Midland, Texas
October 2, 1996
