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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
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FORM 10-Q
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[X] Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange
Act of 1934
For the quarterly period ended June 30, 1999
or
[ ] Transition Report Pursuant to Section 13 or 15(d) of the Securities
Exchange Act of 1934
For the transition period from _____ to _____
Commission File Number: 000-21843
TITAN EXPLORATION, INC.
(Exact name of Registrant as specified in its charter)
Delaware 75-2671582
(State or other jurisdiction (I.R.S. Employer
of incorporation or Identification No.)
organization
500 W. Texas, Suite 200 79701
Midland, Texas (Zip Code)
(Address of principal executive offices)
(915) 498-8600
(Registrant's telephone number, including area code)
Indicate by check mark whether the Registrant (1) has filed all
reports required to be filed by Section 13 or 15(d) of the Securities Exchange
Act of 1934 during the preceding 12 months (or for such shorter period that the
Registrant was required to file such reports) and (2) has been subject to such
filing requirements for the past 90 days. Yes X No
--- ---
As of August 2, 1999, 37,680,675 shares of common stock, par value
$.01 per share of Titan Exploration, Inc. were outstanding.
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TABLE OF CONTENTS
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Forward Looking Information and Risk Factors................. 1
PART I -- FINANCIAL INFORMATION
Item 1. Financial Statements
--------------------
Consolidated Balance Sheets as of June 30, 1999 (Unaudited)
and December 31, 1998....................................... 2
Unaudited Consolidated Statements of Operations for the Three
and Six Months Ended June 30, 1999 and 1998................. 3
Unaudited Consolidated Statements of Cash Flows for the Three
and Six Months Ended June 30, 1999 and 1998................. 4
Notes to Consolidated Financial Statements................... 5
Item 2. Management's Discussion and Analysis of Financial Condition
-----------------------------------------------------------
and Results of Operations................................... 11
-------------------------
Item 3. Quantitative and Qualitative Disclosures About Market Risk... 20
----------------------------------------------------------
PART II -- OTHER INFORMATION
Item 1. Legal Proceedings............................................ 22
-----------------
Item 4. Submission of Matters to a Vote of Security Holders.......... 22
---------------------------------------------------
Item 5. Other Information............................................ 22
-----------------
Item 6. Exhibits and Reports on Form 8-K............................. 23
--------------------------------
Signatures................................................... 24
TITAN EXPLORATION, INC.
FORWARD LOOKING INFORMATION AND RISK FACTORS
Titan Exploration, Inc. (the "Company") or its representatives may make
forward looking statements, oral or written, including statements in this
report's Management's Discussion and Analysis of Financial Condition and Results
of Operations, press releases and filings with the Securities and Exchange
Commission, regarding estimated future net revenues from oil and natural gas
reserves and the present value thereof, planned capital expenditures (including
the amount and nature thereof), increases in oil and gas production, the number
of wells the Company anticipates drilling through 1999, potential reserves and
the Company's financial position, business strategy and other plans and
objectives for future operations. Although the Company believes that the
expectations reflected in these forward looking statements are reasonable, there
can be no assurance that the actual results or developments anticipated by the
Company will be realized or, even if substantially realized, that they will have
the expected effects on its business or operations. Among the factors that could
cause actual results to differ materially from the Company's expectations are
general economic conditions, inherent uncertainties in interpreting engineering
data, operating hazards, delays or cancellations of drilling operations for a
variety of reasons, competition, fluctuations in oil and gas prices, government
regulations and other factors set forth in the Company's Annual Report on Form
10-K. All subsequent oral and written forward looking statements attributable
to the Company or persons acting on its behalf are expressly qualified in their
entirety by these factors. The Company assumes no obligation to update any of
these statements.
1
Item 1. Financial Statements
TITAN EXPLORATION, INC.
Consolidated Balance Sheets
(in thousands, except share data)
June 30, December 31,
ASSETS 1999 1998
-------------------- --------------------
(unaudited)
Current assets:
Cash and cash equivalents $ 1,572 $ 610
Accounts receivable:
Oil and gas 7,567 13,497
Other 417 761
Inventories 704 1,276
Assets held for sale 9,468 109,452
Prepaid expenses and other current assets 294 316
--------- --------
Total current assets 20,022 125,912
--------- --------
Property, plant and equipment, at cost:
Oil and gas properties, using the successful efforts method of accounting:
Proved properties 306,900 299,412
Unproved properties 7,784 6,699
Other property and equipment 6,921 6,340
Accumulated depletion, depreciation and amortization (108,620) (98,095)
--------- --------
212,985 214,356
--------- --------
Other assets, net of accumulated amortization of $762 in 1999 and $639 in
1998 364 754
--------- --------
$ 233,371 $341,022
========= ========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued liabilities:
Trade $ 6,431 $ 14,097
Accrued interest 1,181 466
Other (Note 6) 7,370 5,652
--------- --------
Total current liabilities 14,982 20,215
--------- --------
Long-term debt 76,300 144,200
Other liabilities (Note 6) 1,170 5,253
Deferred income tax payable - -
Stockholders' equity:
Preferred Stock, $.01 par value, 10,000,000 shares authorized; none issued
and outstanding - -
Common Stock, $.01 par value, 60,000,000 shares authorized; 40,534,675 shares
issued and outstanding at June 30, 1999 and December 31, 1998 405 405
Additional paid-in capital 278,109 278,109
Treasury stock, at cost; 2,854,000 and 2,600,000 shares at June 30, 1999 and
December 31, 1998, respectively (21,204) (20,020)
Deferred compensation (2,526) (5,053)
Retained deficit (113,865) (82,087)
--------- --------
Total stockholders' equity 140,919 171,354
--------- --------
Commitments and contingencies (Note 3)
$ 233,371 $341,022
========= ========
See accompanying notes to consolidated financial statements.
2
TITAN EXPLORATION, INC.
Unaudited Consolidated Statements of Operations
(in thousands, except per share data)
Three Months Ended Six Months Ended
June 30, June 30,
-------------------------------------- --------------------------------------
1999 1998 1999 1998
------------------ ------------------ ------------------ ------------------
Revenues:
Gas sales $ 8,649 $ 10,862 $ 17,060 $ 24,380
Oil sales 8,792 7,499 15,161 16,088
------- -------- -------- --------
Total revenues 17,441 18,361 32,221 40,468
------- -------- -------- --------
Expenses:
Oil and gas production 4,838 7,117 9,791 15,177
Production and other taxes 1,365 1,473 2,572 3,092
General and administrative 1,877 2,594 4,046 5,325
Amortization of stock option awards 1,264 1,263 2,527 2,527
Exploration and abandonments (Note 7) 2,994 2,107 5,539 4,201
Depletion, depreciation and amortization 4,379 6,212 9,205 12,975
Impairment of long-lived assets - 8,017 25,900 8,017
------- -------- -------- --------
Total expenses 16,717 28,783 59,580 51,314
------- -------- -------- --------
Operating income (loss) 724 (10,422) (27,359) (10,846)
------- -------- -------- --------
Other income (expense):
Interest income 8 36 19 101
Interest expense (2,029) (1,984) (4,580) (3,691)
Loss on sale of assets (230) (8) (28) (11)
Equity in net loss of affiliates (22) (109) (137) (241)
Other (204) 211 329 367
------- -------- -------- --------
Loss before income taxes (1,753) (12,276) (31,756) (14,321)
Income tax expense (benefit) 22 (4,377) 22 (5,097)
------- -------- -------- --------
Net loss $(1,775) $ (7,899) $(31,778) $ (9,224)
======= ======== ======== ========
Net loss per share $(.05) $(.20) $(.84) $(.23)
======= ======== ======== ========
Net loss per share - assuming dilution
$(.05) $(.20) $(.84) $(.23)
======= ======== ======== ========
See accompanying notes to consolidated financial statements.
3
TITAN EXPLORATION, INC.
Unaudited Consolidated Statements of Cash Flows
(in thousands)
Three Months Ended Six Months Ended
June 30, June 30,
-------------------- ---------------------
1999 1998 1999 1998
--------- --------- ---------- ---------
Cash flows from operating activities:
Net loss $ (1,775) $ (7,899) $(31,778) $ (9,224)
Adjustments to reconcile net loss to net cash provided
by operating activities:
Depletion, depreciation and amortization 4,379 6,212 9,205 12,975
Impairment of long-lived assets 8,017 25,900 8,017
Amortization of stock option awards 1,264 1,263 2,527 2,527
Exploration and abandonments 2,566 1,436 4,581 2,532
Equity in net loss of affiliates 22 109 137 241
Loss on sale of assets 230 8 28 11
Deferred income taxes (4,377) (5,097)
Other items 3 199 140 199
Changes in assets and liabilities:
Accounts receivable 2,442 1,894 5,903 4,123
Prepaid expenses and other current assets 369 249 174 (1,191)
Other assets 185 76 183 (18)
Accounts payable and accrued liabilities (2,906) (3,619) (7,064) (6,846)
-------- -------- -------- --------
Total adjustments 8,554 11,467 41,714 17,473
-------- -------- -------- --------
Net cash provided by operating activities 6,779 3,568 9,936 8,249
-------- -------- --------- --------
Cash flows from investing activities:
Redemption of restricted investment - - - 2,331
Investing in oil and gas properties (5,061) (13,423) (11,981) (24,011)
Additions to other property and equipment (211) (294) (224) (3,695)
Capital contribution in equity investments (81) (485) (696) (563)
Proceeds from sale of assets 72,316 (2) 73,121 15
-------- -------- -------- --------
Net cash provided by (used in) investing
activities 66,963 (14,204) 60,220 (25,923)
-------- -------- -------- --------
Cash flows from financing activities:
Proceeds (payments) from revolving debt, net (72,000) 11,800 (67,900) 28,900
Payments of debt - - - (1,350)
Exercise of stock options - 201 - 215
Purchase of treasury stock (1,184) (4,954) (1,184) (10,330)
Other financing activities (72) (217) (110) (234)
-------- -------- -------- --------
Net cash provided by (used in) financing
activities (73,256) 6,830 (69,194) 17,201
-------- -------- -------- --------
Net increase (decrease) in cash and cash
equivalents 486 (3,806) 962 (473)
Cash and cash equivalents, beginning of period 1,086 4,936 610 1,603
-------- -------- -------- --------
Cash and cash equivalents, end of period $ 1,572 $ 1,130 $ 1,572 $ 1,130
======== ======== ======== ========
See accompanying notes to consolidated financial statements.
4
TITAN EXPLORATION, INC.
Notes to Consolidated Financial Statements
June 30, 1999 and 1998
(Unaudited)
(1) Basis of Presentation
In the opinion of management, the unaudited consolidated financial
statements of Titan Exploration, Inc. (the "Company") as of June 30, 1999 and
for the three and six months ended June 30, 1999 and 1998 include all
adjustments and accruals, consisting only of normal recurring accrual
adjustments, which are necessary for a fair presentation of the results for the
interim period. These interim results are not necessarily indicative of results
for a full year.
Certain information and footnote disclosures normally included in financial
statements prepared in accordance with generally accepted accounting principles
have been condensed or omitted in this Form 10-Q pursuant to the rules and
regulations of the Securities and Exchange Commission. These consolidated
financial statements should be read in conjunction with the audited consolidated
financial statements and notes thereto included in the Company's 1998 Form 10-K.
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 consolidated financial statements and the reported amounts of revenues and
expenses during the reporting period. Actual results could differ from those
estimates.
Reclassifications
Certain reclassifications have been made to the 1998 amounts to conform to
the 1999 presentations.
(2) Debt
Line of Credit
In June 1999, the Company entered into an amended and restated credit
agreement (the "Credit Agreement") with Chase Bank of Texas, N.A., which
established a revolving credit facility of $250 million subject to a borrowing
base. All amounts outstanding are due and payable in full on January 1, 2001.
The borrowing base, which is $175 million at June 30, 1999, is subject to
redetermination annually each April by the lenders based on certain proved oil
and gas reserves and other assets of the Company. At June 30, 1999, the
outstanding principal was $75 million and the available capacity was
approximately $100 million.
Unsecured Credit Agreement
In April 1997, the Company entered into a credit agreement, as amended (the
"Unsecured Credit Agreement"), with Chase Bank of Texas, N.A. (the "Bank"),
which establishes a revolving credit facility, up to the maximum of $5 million.
Individual borrowings may be made for up to a three week period. The Unsecured
Credit Agreement has no maturity date and is cancellable at anytime by the Bank.
The interest rate of each loan under the Unsecured Credit Agreement is at a rate
determined by agreement between the Company and the Bank. The rate shall not
exceed the maximum interest rate permitted under applicable law. Interest rates
generally are at the Bank's cost of funds plus 1% per annum. At June 30, 1999,
the outstanding principal balance was $1.3 million.
5
(3) Commitments and Contingencies
Litigation
The following is a brief description of certain litigation to which the
Company is subject, as a result of assuming the obligations of Offshore Energy
Development Corporation ("OEDC"). Both cases have reached a settlement pending
court approval. The amount of the settlement related to the Company is not
material and does not exceed any existing reserves. The settlement agreement is
being finalized by the parties.
OEDC and certain of its officers and directors, as well as Natural Gas
Partners, L.P. ("NGP"), the managing underwriters of OEDC's initial public
offering and an analyst from each of the managing underwriters, have been named
as defendants in a suit styled Eric Baron and Edward C. Allen, On behalf of
Themselves and all Others Similarly Situated, v. David B. Strassner, Douglas H.
Kiesewetter, David R. Albin, Natural Gas Partners, L.P., David Garcia, John J.
Myers, Offshore Energy Development Corporation, Morgan Keegan & Company, Inc.
and Principal Securities Inc., which was filed October 20, 1997, in the Texas
State District Court of Harris County, Texas 270th Judicial District.
OEDC and certain of its officers and directors, as well as NGP, have also
been named defendants in a suit styled John W. Robertson, et al. v. David B.
Strassner, Douglas H. Kiesewetter, David R. Albin, Natural Gas Partners, L.P.
and Offshore Energy Development Corporation, which was filed February 6, 1998,
in the United States Southern District of Texas, Houston Division.
The Company is involved in other various claims and legal actions arising
in the ordinary course of business. In the opinion of management, the ultimate
disposition of these matters will not have a material adverse effect on the
Company's financial position, results of operations or liquidity.
Letters of Credit
At June 30, 1999, the Company had outstanding letters of credit of
$144,000, which were issued through the Credit Agreement.
6
(4) Earnings per Common Share
The following table sets forth the computation of basic and diluted
earnings per common share:
Three Months Ended Six Months Ended
June 30, June 30,
-------------------- ---------------------
1999 1998 1999 1998
--------- --------- ---------- ---------
(in thousands, except per share data)
Numerator:
Net loss and numerator for basic and diluted net
loss per common share - income available to common
stockholders $(1,775) $(7,899) $(31,778) $(9,224)
-------- -------- --------- --------
Denominator:
Denominator for basic net loss per common share -
weighted average common shares 37,876 39,242 37,905 39,555
Effect of dilutive securities - employee stock - - - -
options -------- -------- --------- --------
Denominator for diluted net loss per common share -
adjusted weighted average common shares and
assumed conversions 37,876 39,242 37,905 39,555
======== ======== ========= ========
Basic net loss per common share $ (.05) $ (.20) $ (.84) $ (.23)
======== ======== ========= ========
Diluted net loss per common share $ (.05) $ (.20) $ (.84) $ (.23)
======== ======== ========= ========
Employee stock options to purchase 4,470,904, 4,470,904, 4,580,332, and
4,580,332 shares of common stock were outstanding during the three and six
months ended June 30, 1999 and 1998, respectively, but were not included in the
computation of diluted net loss per common share because either (i) the employee
stock options' exercise price was greater than the average market price of the
common stock of the Company or (ii) the Company had a loss from continuing
operations and, therefore, the effect would be antidilutive.
(5) Derivative Financial Instruments
The Company utilizes various option and swap contracts and other financial
instruments to hedge the effect of price changes on future oil and gas
production. The index price for the natural gas collars settles based on El
Paso/ Permian Index, while the oil collar settles based on the prices for West
Texas Intermediate on the NYMEX.
The following table sets forth the future volumes hedged by year and the
range of prices to be received based upon the fixed price of the individual
option and swap contracts and other financial instruments outstanding at June
30, 1999:
1999 2000
--------------- ---------------
Gas related derivatives:
Collar options:
Volume (MMBTU) 4,508,000 1,365,000
Index price per MMBTU (floor - ceiling prices) $ 1.92 - $2.43 $ 1.98 - $2.33
Oil related derivatives:
Collar options (a):
Volume (Bbls) 460,000 455,000
Index price per Bbl (floor - ceiling prices) $16.50 - $20.48 $16.50 - $20.48
________________
(a) The counterparty has the option to extend an additional year on volumes of
2,500 Bbls per day at a floor and ceiling price of $16.50 and $20.48 per
barrel, respectively. The option period is from July 1, 2000 to June 30,
2001.
7
(6) Other Liabilities
The other current and noncurrent liabilities consist of the following (in
thousands):
June 30, December 31,
1999 1998
--------------------- --------------------
(unaudited)
Other current liabilities:
Capital costs and operating expenses $3,752 $2,220
Gas processing obligation - 564
Restructuring costs 150 625
Oil and gas payables 525 1,106
Asset sales related 971 -
Other 1,972 1,137
------ ------
$7,370 $5,652
====== ======
Other noncurrent liabilities:
Gas processing obligation $ - $1,130
Environmental reserve 818 824
Plugging and abandonment reserve 80 2,483
Gas and pipeline imbalances - 225
Other 272 591
------ ------
$1,170 $5,253
====== ======
(7) Exploration and Abandonment
Exploration and abandonment expense consist of the following (in
thousands):
Three months ended Six months ended
June 30, June 30,
-------------------------------- --------------------------------
1999 1998 1999 1998
--------------- --------------- --------------- ---------------
Geological and geophysical staff $ 167 $ 313 $ 438 $ 665
Uneconomical exploratory wells 856 843 2,770 1,368
Seismic costs 1,710 218 1,811 625
Delay rentals 56 331 136 787
Plugging and abandonment reserve - 282 - 526
Other 205 120 384 230
------ ------ ------ ------
$2,994 $2,107 $5,539 $4,201
====== ====== ====== ======
8
(8) Impairment of Long-Lived Assets
In the fourth quarter of 1998, the Company approved a plan to dispose of
non-strategic assets, including its Gulf of Mexico, Gulf Coast and certain
Permian Basin assets. The Company's reason to dispose of these assets varied
depending on the portfolio of assets being considered. The disposition would
allow the Company to (a) realize full value for certain assets whose value is
not fully reflected in the public valuation of the Company in the capital
markets, (b) redeploy capital to higher return projects or acquisitions, (c)
invest in projects that will accelerate cash flow to the Company, (d) eliminate
certain administrative costs and (e) reduce the Company's debt obligations.
In the first quarter of 1999, the Company recognized an impairment of $25.9
million on the assets held for sale. The impairment was the result of comparing
the estimated sales proceeds, less costs to sell, to the underlying net cost
basis of each specific portfolio of assets.
In the second quarter of 1998, the Company recognized an impairment of $8.0
million. The impairment was a consequence of the book value of certain
properties being greater than the estimated net cash flows from those
properties.
(9) Stock Option Plans
1999 Stock Option Plan
On June 10, 1999, the board of directors of the Company adopted the 1999
Stock Option Plan (the "1999 Plan"). The 1999 Plan allows for up to 200,000
options to be granted to non-officer employees, as defined in the 1999 Plan. On
June 10, 1999, the Company granted 84,000 options to purchase shares of the
Company's common stock at an exercise price equal to the price of the Company's
common stock on the date of grant.
1996 Incentive Plan
On June 10, 1999, the board of directors of the Company extended the
expiration date two years for all the options outstanding at June 9, 1999, under
the 1996 Incentive Plan. There were no other changes to the terms of the
related options. The board of directors also granted to the officers of the
Company 183,266 options to purchase shares of the Company's common stock at an
exercise price equal to the price of the Company's common stock on the date of
grant.
Stock Option Plan
On June 10, 1999, the board of directors of the Company extended the
expiration date of all the options outstanding at June 9, 1999, under the
Company's original stock option plan, to December 31, 2003. There were no other
changes to the terms of the related options.
9
(10) Rights Agreement
On June 10, 1999, the board of directors of the Company authorized and
declared a dividend to the holders of record on July 1, 1999 of one Right (a
"Right") for each outstanding share of the Company's common stock. When
exercisable, each Right will entitle the holder to purchase one one-hundredth of
a share of a Series A Junior Participating Preferred Stock, par value $.01 per
share, of the Company (the "Preferred Shares") at an exercise price of $30.00
per Right. The rights are not currently exercisable and will become exercisable
only if a person or group acquires beneficial ownership of 15% or more of the
Company's outstanding common stock or announces a tender offer or exchange offer
the consummation of which would result in attaining the triggering percentage.
The Rights are subject to redemption by the Company for $.01 per Right at any
time prior to the tenth day after the first public announcement of a triggering
acquisition.
If the Company is acquired in a merger or other business combination
transaction after a person has acquired beneficial ownership of 15% or more of
the Company's common stock, each Right will entitle its holder to purchase, at
the Right's then current exercise price, a number of the acquiring company's
shares of common stock having a market value of two times such price. In
addition, if a person or group acquires beneficial ownership of 15% or more of
the Company's common stock, each Right will entitle its holder (other than the
acquiring person or group) to purchase, at the Right's then current exercise
price, a number of the Company's shares of common stock having a market value of
two times the exercise price.
Subsequent to the acquisition by a person or group of beneficial ownership
of 15% or more of the Company's common stock and prior to the acquisition of
beneficial ownership of 50% or more of the Company's common stock, the board of
directors of the Company may exchange the Rights (other than Rights owned by
such acquiring person or group, which will by null and void and
nontransferable), in whole or in part, at an exchange ratio of one share of the
Company's common stock (or one one-hundredth of a Preferred Share) per Right.
The Rights dividend distribution will be made on July 1, 1999, payable to
shareholders of record at the close of business on that date. The Rights will
expire on June 9, 2009.
(11) Severance Agreements
On June 10, 1999, the board of directors of the Company approved the form
of an Officer Severance and Retention Bonus Agreement (the "Severance
Agreement") to be entered into with each of the officers of the Company. The
triggering event of the Severance Agreement would involve a "change of control"
of the Company as defined in the Severance Agreement.
Upon a termination event as defined in the Severance Agreement, each
officer will be entitled to receive, among other benefits, (a) three times such
officer's base salary, (b) continuation of life insurance for an eighteen month
period, (c) payment of all medical and dental insurance premiums until the
officer obtains other employment and (d) reimbursement of all reasonable legal
fees and other expenses incurred in seeking to obtain or enforce any right or
benefit provided by the Severance Agreement. If the payments under the Severance
Agreement and other benefit plans from a termination event cause the officer to
be subject to federal excise tax, the officer will receive a grossed-up amount
to pay the officer's federal excise taxes.
(12) Common Stock
In May 1997, the Company announced a plan to repurchase up to $25 million
of the Company's common stock. The repurchases will be made periodically,
depending on market conditions, and will be funded with cash flow from
operations and, as necessary, borrowings under the Credit Agreement. At June 30,
1999 and December 31, 1998, the Company had purchased, pursuant to the
repurchase plan, 2,801,000 and 2,547,000 shares of its common stock for
approximately $20.8 million and $19.6 million, respectively.
10
Item 2. Management's Discussion and Analysis of Financial Condition and Results
of Operations
General
The Company is an independent energy company engaged in the
exploitation, development, exploration and acquisition of oil and gas
properties. The Company's strategy is to grow reserves, production and net
income per share through (i) the exploitation and development of its reserve
base, (ii) the acquisition of producing properties that provide significant
development and exploratory drilling potential, (iii) the exploration for oil
and gas reserves, (iv) capitalization on advanced technology to identify,
explore and exploit projects, (v) financial flexibility, and (vi) a low overhead
and operating cost structure. The Company has grown rapidly through the
acquisition and exploitation of oil and gas properties.
The Company's growth from acquisitions has impacted its financial
results in a number of ways. Acquired properties may not have received focused
attention prior to sale. After acquisition, certain of these properties required
extensive maintenance, workovers, recompletions and other remedial activity that
while not constituting capital expenditures may initially increase lease
operating expenses. The Company may dispose of certain of the properties it
determines are outside the Company's strategic focus. The increased production
and revenue resulting from the rapid growth of the Company has required it to
recruit and develop operating, accounting and administrative personnel
compatible with its increased size. As a result, the Company has incurred
increases in its general administrative expense levels in prior periods.
The Company uses the successful efforts method of accounting for its
oil and gas producing activities. Costs to acquire mineral interest 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, and geological
and geophysical costs are expensed. Costs of significant nonproducing
properties, wells in the process of being drilled and significant development
projects are excluded from depletion until such time as the related project is
developed and proved reserves are established or impairment is determined.
Recent Developments
Asset Divestitures
In the fourth quarter of 1998, the Company approved a plan to dispose
of non-strategic assets, including its Gulf of Mexico, Gulf Coast and certain
Permian Basin assets. The Company's reason to dispose of these assets varied
depending on the portfolio of assets being considered. The disposition would
allow the Company to (a) realize full value for certain assets whose value is
not fully reflected in the public valuation of the Company in the capital
markets, (b) redeploy capital to higher return projects or acquisitions, (c)
invest in projects that will accelerate cash flow to the Company, (d) eliminate
certain administrative costs and (e) reduce the Company's debt obligations.
In May 1999, the Company sold its assets in the Gulf of Mexico to
Coastal Oil & Gas Corporation for $71.3 million in cash. In the first quarter of
1999, the Company wrote down its cost in these assets by $24.5 million based on
the then expected proceeds.
The Company closed the sale of its Gulf Coast properties in April 1999
for $5.4 million in cash. In the first quarter of 1999, the Company wrote down
its cost in these assets by $1.4 million based on the then expected proceeds.
In July 1999, the Company terminated a purchase and sale agreement to
sell a small package Permian Basin oil and gas properties. The agreement was
terminated due to the purchaser's inability to close the transaction under the
terms of the agreement. The Company's plan remains to dispose of this group of
assets and expects the completion of such disposal before the end of 1999.
11
Equity Offering
In July 1999, Natural Gas Partners, L.P. and Natural Gas Partners II, L.P.
(collectively, "NGP"), the Company's largest single shareholder group then
owning approximately 30.6% of the Company's common stock, completed the sale of
11,517,629 shares of its common stock holdings in the Company in an underwritten
public offering. No single person or group received more that 715,000 shares in
the offering. NGP's sale of the Company's common stock was due to the
requirements of their limited partnership agreements. The Company received no
proceeds from the offering.
Paragon Joint Venture
In June 1999, the Company completed the Phase I 3-D seismic program and began
the Phase II 3-D seismic program. The Company will pay 25% of the Phase II
seismic costs. It is anticipated that the acquisition of the Phase II 3-D
seismic data will be completed by mid-2000. The Company commenced drilling its
first Paragon exploratory well in July 1999.
Impact of Crude Oil Prices
During 1998 and through the first quarter of 1999, the posted price of West
Texas intermediate crude oil (the "West Texas Crude Oil Price") ranged from
$15.75 to $8.00 per barrel. These low prices are thought to be caused
primarily by an oversupply of crude oil inventory created, in part, by an
unusually warm winter in the United States and Europe, the apparent
unwillingness of Organization of Petroleum Exporting Countries ("OPEC") to abide
by their respective crude oil production quotas and a decline in demand in
certain Asian markets. The prices for crude oil during the second quarter of
1999 have shown significant improvement over that of the previous fifteen
months.
If the West Texas Crude Oil Price worsens or persists, as it did in 1998 and
early 1999, for a protracted period, it will adversely affect the Company's
revenues, net income and cash flows from operations and the Company may delay or
postpone certain of its capital projects. It is the Company's expectation that
it will not have positive earnings in 1999.
Year 2000 Issues
Many computer software systems, as well as certain hardware and equipment
using date-sensitive data, were structured to use a two-digit date field meaning
that they may not be able to properly recognize dates in the year 2000. The
Company is addressing this issue through a process that entails evaluation of
the Company's critical software and, to the extent possible, its hardware and
equipment to identify and assess year 2000 issues and to remediate, replace or
establish alternative procedures addressing non-Year 2000 compliant systems,
hardware and equipment.
The Company substantially completed an inventory of its systems and equipment
including computer systems and business applications. Based upon this review,
the Company currently believes that all of its critical software and computer
hardware systems are Year 2000 compliant. The Company continues to inventory
its equipment and facilities to determine if they contain embedded date-
sensitive technology. If problems are discovered, remediation, replacement or
alternative procedures for noncompliant equipment and facilities will be
undertaken on a business priority basis. This process will continue and,
depending upon the equipment and facilities, is scheduled for completion during
the first three quarters of 1999. As of June 30, 1999, the Company had not
incurred any material amount of expense related to its Year 2000 compliance
efforts. These costs are currently being expensed as they are incurred.
However, in certain instances the Company may determine that replacing existing
equipment may be more efficient, particularly where additional functionality is
available. These replacements may be capitalized and therefore would reduce the
estimated 1999 expenses associated with the Year 2000 issue. The Company
currently expects total out-of-pocket costs to become Year 2000 compliant to be
less than $100,000. The Company currently expects that such costs will not have
a material adverse effect on the Company's financial condition, operations or
liquidity.
12
The foregoing timetable and assessment of costs to become Year 2000 compliant
reflect management's current best estimates. These estimates are based on many
assumptions, including assumptions about the costs availability and ability of
resources to locate, remediate and modify affected systems, equipment and
facilities. Based upon its activities to date, the Company does not currently
believe that these factors will cause results to differ significantly from those
estimated. However, the Company cannot reasonably estimate the potential impact
on its financial condition and operations if key third parties including, among
others, suppliers, contractors, joint venture partners, financial institutions,
customers and governments do not become Year 2000 compliant on a timely basis.
The Company is contacting many of these third parties to determine whether they
will be able to resolve in timely fashion their Year 2000 issues as they may
affect the Company.
In the event that those with whom the Company conducts business are
unsuccessful in implementing timely solutions, Year 2000 issues could have a
material adverse effect in the Company's liquidity and results of operations.
At this time, the potential effect in the event third parties are unable to
timely resolve their Year 2000 problems is not determinable; however, the
Company currently believes it has resolved its significant Year 2000 issues.
The disclosure set forth in this section is provided pursuant to Securities
Act Release No. 33-7558. As such it is protected as a forward-looking statement
under the Private Securities Litigation Reform Act of 1995. See "Forward-
Looking Statements." This disclosure is also subject to protection under the
Year 2000 Information and Readiness Disclosure Act of 1998, Public Law 105-271,
as a "Year 2000 Statement" and "Year 2000 Readiness Disclosure" as defined
therein.
13
Operating Data
The following table sets forth the Company's historical operating data for
the periods indicated.
Three Months Ended Six Months Ended
June 30, June 30,
-------------------------------------- --------------------------------------
1999 1998 1999 1998
------------------ ------------------ ------------------ ------------------
Production:
Oil (MBbls) 578 630 1,176 1,259
Gas (MMcf) 5,529 6,798 11,721 14,124
Total (MMcfe) 8,997 10,578 18,777 21,678
Average sales price per unit
(excluding the effects of hedging):
Oil (per Bbl) $15.23 $ 11.91 $ 12.90 $ 12.62
Gas (per Mcf) $ 1.55 $ 1.57 $ 1.39 $ 1.58
Total (per Mcfe) $ 1.93 $ 1.72 $ 1.67 $ 1.76
Average sales prices per unit
(includes the effects of hedging):
Oil (per Bbl) $15.23 $ 11.91 $ 12.90 $ 12.78
Gas (per Mcf) $ 1.56 $ 1.60 $ 1.46 $ 1.73
Total (per Mcfe) $ 1.94 $ 1.74 $ 1.72 $ 1.87
Expenses per Mcfe:
Production costs, excluding
production and other taxes $ .54 $ .67 $ .52 $ .70
Production and other taxes $ .15 $ .14 $ .14 $ .14
General and administrative $ .21 $ .25 $ .22 $ .25
Depletion, depreciation and
amortization $ .49 $ .59 $ .49 $ .60
14
Results of Operations
Three Months Ended June 30, 1999 Compared to the Three Months Ended June 30,
1998
The Company's revenues from the sale of oil and gas (excluding the effects
of hedging) were $8.8 million and $8.6 million in 1999 and $7.5 million and
$10.7 million in 1998, respectively. Realized oil prices increased $3.32 per
Bbl and gas prices decreased $.02 per Mcf between comparable quarters. Assuming
1998 prices in 1999 (excluding the effects of hedging), the Company's revenues
would have decreased by approximately $2.2 million. Oil and gas production
decreased 52,000 barrels and 1,269 MMcf, respectively, between comparable
quarters. Excluding the production from the two significant dispositions
previously discussed, oil and gas production decreased 71,000 barrels and 693
MMcf, respectively, between comparable quarters. The decrease in the oil
production is principally due to normal production declines and the Company
deferring some of its 1998 projects due to the then uncertainties over future
commodity price levels. The decrease in gas production is partially due to
normal production declines and loss and/or curtailment of production on wells
due to mechanical and/or reservoir problems, offset by increased gas production
from the Company's recent drilling activities.
The Company's hedging activities in 1999 increased gas revenues by $56,000
($.01 per Mcf), as compared to 1998 when the hedging activities increased gas
revenues by $196,000 ($.03 per Mcf). At June 30, 1999, the Company has
5,864,000 MMBtu of gas hedged which will allow the Company to realize an average
minimum price of $1.92 per MMBtu on the hedged volumes. The current gas hedges
extend through March of 2000, through a commodity price collar. The Company
hedged, for a one year period beginning with July 1999 production, 2,500 barrels
per day of its oil production, through a commodity price collar, which will
allow the Company to realize, at a minimum, $16.50 per barrel on the hedged
volumes. The oil hedge is extendable one additional year at the option of the
counterparty under the same price and volume terms.
The Company's production costs were $4.8 million ($.54 per Mcfe) and $7.1
million ($.67 per Mcfe) in 1999 and 1998, respectively. Excluding the
production costs from the two significant dispositions previously discussed the
Company's production costs would have been $4.4 million ($.52 per Mcfe) and $5.9
million ($.62 per Mcfe) in 1999 and 1998, respectively. A portion of the
decrease is due to the second quarter 1998 rework expenses (over $.07 per Mcfe)
associated with the 1997 acquired properties. Initially, acquired properties
generally incur significant rework expenses, which are costs incurred to perform
required maintenance, workovers and other remedial activities. Also, the
decrease is due to the sale of properties and the Company performing only
routine and necessary expenditures in certain fields due to depressed commodity
prices.
Depletion, depreciation and amortization expense (DD&A) was $4.4 million
($.49 per Mcfe) and $6.2 million ($.59 per Mcfe) for the comparable quarters of
1999 and 1998, respectively. The decrease in the absolute and per unit amounts
is attributable to (a) the second quarter of 1999 not including DD&A for the
assets classified as assets held for sale and (b) increased proved reserves,
between comparable quarters, resulting from increased commodity prices and
recent drilling activities.
The Company recognized an impairment of $8.0 million in 1998. The
impairment was due to loss of proved reserves attributable to (a) downhole
mechanical problems with an offshore well and (b) lower than expected drilling
results on three onshore wells. The Company had no impairment in the comparable
quarter in 1999.
The Company's exploration and abandonment expense was $3.0 million and $2.1
million for the comparable quarters of 1999 and 1998, respectively. In the
second quarter of 1999, the Company incurred over $1.7 million in seismic costs
in addition to approximately $850,000 of costs associated with two uneconomical
exploratory wells. The seismic costs are primarily attributable to the
Company's share of the Phase I 3-D seismic acquisition in the Paragon Joint
Venture.
The Company's general and administrative expense (G&A) was $1.9 million
($.21 per Mcfe) and $2.6 million ($.25 per Mcfe) for the comparable quarters of
1999 and 1998, respectively. Excluding the G&A from the two significant
dispositions previously discussed, the Company's G&A would have been $1.6
million ($.19
15
per Mcfe) and $2.0 million ($.20 per Mcfe) in 1999 and 1998, respectively. The
decrease in G&A is due to the integration in 1998 of the 1997 acquisitions and
the Company's previously announced cost cutting measures.
The Company's interest expense was $2.0 million for both the 1999 and 1998
comparable quarters. In 1998, the Company incurred increased levels of debt as
a result of its 1997 acquisitions and 1998 capital spending. In 1999, the
higher initial debt levels as compared to the 1998 period were reduced by the
paydown of debt as a result of the two previously discussed dispositions. The
Company's debt at June 30, 1999 was at its lowest level since September 30,
1997.
In 1999, the Company did not record a deferred income tax benefit related
to the loss from operations. No deferred tax benefit was recorded due to it
being more likely than not that the Company may not be able to utilize all of
its available loss carryforwards prior to their ultimate expiration.
Six Months Ended June 30, 1999 Compared to the Six Months Ended June 30, 1998
The Company's revenues from the sale of oil and gas (excluding the effects
of hedging) were $15.2 million and $16.3 million in 1999 and $15.9 million and
$22.3 million in 1998, respectively. Realized oil prices increased $.28 per
Bbl and gas prices decreased $.19 per Mcf, respectively, between comparable
periods. Assuming 1998 prices in 1999 (excluding the effects of hedging), the
Company's revenues would have decreased by approximately $1.9 million. Oil and
gas production decreased 83,000 barrels and 2,403 MMcf, respectively, between
comparable periods. Excluding the production from the two significant
dispositions previously discussed, oil and gas production decreased 127,000
barrels and 1,548 MMcf, respectively, between comparable periods. The decrease
in the oil production is principally due to normal production declines and the
Company deferring some of its 1998 projects due to the then uncertainties over
future commodity price levels. The decrease in gas production is partially due
to normal production declines and loss and/or curtailment of production on wells
due to mechanical and/or reservoir problems, offset by increased gas production
from the Company's recent drilling activities.
The Company's hedging activities in 1999 increased gas revenues by $773,000
($.07 per Mcf), as compared to 1998 when the hedging activities increased oil
and gas revenues by $206,000 ($.16 per barrel) and $2.1 million ($.15 per Mcf),
respectively.
The Company's production costs were $9.8 million ($.52 per Mcfe) and $15.2
million ($.70 per Mcfe) in 1999 and 1998, respectively. Excluding the
production costs from the two significant dispositions previously discussed the
Company's production costs would have been $8.5 million ($.49 per Mcfe) and
$12.8 million ($.65 per Mcfe) in 1999 and 1998, respectively. A portion of the
decrease is due to the first half of 1998 rework expenses (over $.10 per Mcfe)
associated with the 1997 acquired properties. Initially, acquired properties
generally incur significant rework expenses, which are costs incurred to perform
required maintenance, workovers and other remedial activities. Also, the
decrease is due to the sale of properties and the Company performing only
routine and necessary expenditures in certain fields due to depressed commodity
prices.
Depletion, depreciation and amortization expense (DD&A) was $9.2 million
($.49 per Mcfe) and $13.0 million ($.60 per Mcfe) for the comparable periods of
1999 and 1998, respectively. The decrease in the absolute and per unit amounts
is attributable to (a) the first half of 1999 not including DD&A for the assets
classified as assets held for sale and (b) increased proved reserves, between
comparable periods, resulting from increased commodity prices and recent
drilling activities.
The Company recognized an impairment of $25.9 million and $8.0 million in
1999 and 1998, respectively. The 1999 impairment relates to the write-down of
the net cost of the assets held for sale based on the expected net proceeds from
the sale of these assets. The 1998 impairment was due to loss of proved
reserves attributable to (a) downhole mechanical problems with an offshore well
and (b) lower than expected drilling results on three onshore wells.
The Company's exploration and abandonment expense was $5.5 million and $4.2
million for the comparable periods of 1999 and 1998, respectively. In the first
half of 1999, the Company incurred over $1.7
16
million in seismic costs in addition to approximately $2.8 million of costs
associated with three uneconomical exploratory wells. The seismic costs are
primarily attributable to the Company's share of the Phase I 3-D seismic
acquisition in the Paragon Joint Venture. The uneconomical exploratory wells
relate primarily to the Jalapeno No. 1, Webb County, Texas and the Titan No. 1
in the Brenham Dome area of South Central Texas.
The Company's general and administrative expense (G&A) was $4.0 million
($.22 per Mcfe) and $5.3 million ($.25 per Mcfe) for the comparable periods of
1999 and 1998, respectively. Excluding the G&A from the two significant
dispositions previously discussed the Company's G&A would have been $3.4 million
($.20 per Mcfe) and $4.0 million ($.20 per Mcfe) in 1999 and 1998, respectively.
The decrease in G&A is due to the integration in 1998 of the 1997 acquisitions
and the Company's previously announced cost cutting measures.
The Company's interest expense was $4.6 million and $3.7 million in the
1999 and 1998 comparable periods, respectively. The increase in the interest
expense is due to higher average debt levels between the comparable periods. As
previously discussed the Company has significant reduced its debt levels in the
second quarter of 1999.
In 1999, the Company did not record a deferred income tax benefit related
to the loss from operations. No deferred tax benefit was recorded due to it
being more likely than not that the Company may not be able to utilize all of
its available loss carryforwards prior to their ultimate expiration.
Liquidity and Capital Resources
The Company's primary sources of capital have been its initial
capitalization, private equity sales, bank financing, cash flow from operations
and the Company's initial public offering. 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.
Net Cash Provided by Operating Activities. Net cash provided by operating
activities, before changes in operating assets and liabilities, was $6.7 and
$10.7 million for the three and six months ended June 30, 1999 compared to $5.0
and $12.2 million for the three and six months ended June 30, 1998. The
increase in the three-month periods is due to increased overall commodity prices
and decreased cash operating expenses, partially offset by lower production.
The decrease in the six-month periods was primarily attributable to the decrease
in overall commodity prices and production offset by a significant decrease in
cash operating expenses.
Capital Expenditures. For 1999, the Company originally budgeted $49.5 million
for capital expenditures and incurred actual expenditures of $13.6 million
through June 30, 1999. Approximately $8.0 million of the annual budget related
to assets in the Gulf of Mexico which the Company sold in May 1999. Through
June 30, 1999, the Company had spent approximately $1.6 million associated with
the Gulf of Mexico assets.
For 1999, after giving effect to assets sold and other adjustments, the
Company currently expects to spend approximately $46.2 million on oil and gas
projects as follows: (i) approximately $15.5 million on developmental projects,
(ii) approximately $7.8 million on exploratory projects, (iii) approximately
$17.2 million on probable and possible projects and (iv) approximately $5.7
million to acquire additional acreage and seismic data. The final determination
with respect to the drilling of any well, including those currently budgeted,
will depend on a number of factors, including (i) the results of exploration
efforts and the review and analysis of the seismic data, (ii) the availability
of sufficient capital resources by the Company and other participants for
drilling prospects, (iii) economic and industry conditions at the time of
drilling, including prevailing and anticipated prices for natural gas and oil
and the availability and costs of drilling rigs and crews, (iv) the financial
resources and results of the Company, and (v) the availability of leases on
reasonable terms and permitting for the potential drilling location. There can
be no assurance that the budgeted wells will encounter, if drilled, recompleted
or worked over, reservoirs of commercial quantities of natural gas or oil.
Cash expenditures for investing in oil and gas properties were $12.0
million for the six months ended June 30, 1999. This includes $2.5 million for
the acquisition of oil and gas leases and proved properties and $9.5 million for
development, probable and possible and exploratory projects.
17
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.
While the Company regularly engages in discussions relating to potential
acquisitions of oil and gas properties, the Company has no present agreement,
commitment or understanding with respect to any such acquisition, other than the
acquisition of oil and gas properties and interest in its normal course
business. Any future acquisitions may require additional financing and will be
dependent upon financing which may be required in the future to fund the
Company's acquisition and drilling programs.
Capital Resources. The Company's primary capital resources are net cash
provided by operating activities and the availability under the Credit
Agreement, of which approximately $100 million was available at June 30, 1999.
Credit Agreement. In June 1999, the Company entered into an amended and
restated credit agreement (the "Credit Agreement") with Chase Bank of Texas,
N.A., which established a revolving credit facility of $250 million subject to a
borrowing base. The borrowing base, which is $175 million at June 30, 1999, is
subject to redetermination annually each April by the lenders based on certain
proved oil and gas reserves and other assets of the Company. To the extent the
borrowing base is less than the aggregate principal amount of all outstanding
loans and letters of credit under the Credit Agreement, such deficiency must be
cured by the Company ratably within 180 days, by either prepaying a portion of
the outstanding amounts under the Credit Agreement or pledging additional
collateral to the lenders. A portion of the credit facility is available for
the issuance of up to $15.0 million of letters of credit, of which $144,000 was
outstanding at June 30, 1999. All amounts outstanding are due and payable in
full on January 1, 2001. At June 30, 1999, the outstanding principal was $75
million and the available capacity was approximately $100 million.
At the Company's option, borrowings under the Credit Agreement bear interest
at either the "Base Rate" (i.e., the higher of the applicable prime commercial
lending rate, or the federal funds rate plus .5% per annum) or the Eurodollar
rate, plus 1% to 1.50% per annum, depending on the level of the Company's
aggregate outstanding borrowings. In addition, the Company is committed to pay
quarterly in arrears a fee of .300% to .375% of the unused borrowing base.
The Credit Agreement contains certain covenants and restrictions that are
customary in the oil and gas industry. In addition, the line of credit is
secured by substantially all of the Company's oil and gas properties.
Liquidity and Working Capital. At June 30, 1999, the Company had $1.6 million
of cash and cash equivalents as compared to $610,000 at December 31, 1998. The
Company's ratio of current assets to current liabilities was 1.34 at June 30,
1999, compared to 6.23 at December 31, 1998. The positive working capital is
due to the assets held for sale. Excluding the assets held for sale, the
Company would have a working capital deficit of $4.4 million and $3.8 million at
June 30, 1999 and December 31, 1998, respectively. The working capital is due
to the Company's efforts to maintain low cash levels for cash management
purposes. The working capital deficit at June 30, 1999 is adequately covered by
the Company's ability to borrow under its Credit Agreement.
Unsecured Credit Agreement. In April 1997, the Company entered into a credit
agreement, as amended (the "Unsecured Credit Agreement"), with Chase Bank of
Texas, N.A. (the "Bank"), which establishes a revolving credit facility, up to
the maximum of $5.0 million. Individual borrowings may be made for up to a
three week period. The Unsecured Credit Agreement has no maturity date and is
cancellable at anytime by the Bank. Proceeds of the Unsecured Credit Agreement
are utilized to fund short-term needs (less than thirty days). The Company owed
$1.3 million under the Unsecured Credit Agreement at June 30, 1999.
The interest rate of amounts outstanding under the Unsecured Credit Agreement
is at a rate determined by agreement between the Company and the Bank. The rate
shall not exceed the maximum interest rate permitted under applicable law.
Interest rates generally are the Bank's cost of funds plus 1% per annum.
18
OTHER MATTERS
Hedging Activities
The Company uses swap agreements and other financial instruments in an
attempt to reduce the risk of fluctuating oil and gas prices and interest rates.
The Company is party to various agreements with numerous counterparties for
purposes of utilizing financial instruments, of which the Company assesses the
creditworthiness of its counterparties. Among other counterparties, the Company
has utilized Enron Capital & Trade Resources Corp. (an affiliate of a
significant stockholder of the Company) as a counterparty. Settlement of gains
or losses on the hedging transactions are generally based on the difference
between the contract price and a formula using New York Mercantile Exchange
("NYMEX") or other major indices related prices and is reported as a component
of oil and gas revenues as the associated production occurs. The Company, at
June 30, 1999, had entered into hedging transactions with respect to
approximately 4,508,000 and 1,365,000 MMBtu of its 1999 and 2000, respectively,
estimated natural gas production and 460,000 and 455,000 barrels of its 1999 and
2000, respectively, estimated crude oil production.
Recently Issued Accounting Pronouncements
In June 1998, the FASB issued SFAS No. 133 "Accounting for Derivative
Instruments and Hedging Activities" which establishes standards for derivative
instruments, including certain derivative instruments embedded in other
contracts, and for hedging activities. It requires that an entity recognize all
derivatives as either assets or liabilities in the statement of financial
position and measure those instruments at fair value. It establishes conditions
under which a derivative may be designated as a hedge, and establishes standards
for reporting changes in the fair value of a derivative. SFAS No. 133 is
required to be implemented for the first quarter of the fiscal year ended 2000.
Early adoption is permitted. Recently, the FASB deferred the implementation
requirements of SFAS No. 133 for one year. The Company has not evaluated the
effects of implementing SFAS No. 133.
19
Item 3. Quantitative and Qualitative Disclosures About Market Risk
The following quantitative and qualitative information is provided about
financial instruments to which the Company is a party as of June 30, 1999, and
from which the Company may incur future earnings gains or losses from changes in
market interest rates and commodity prices. The Company does not enter into
derivative or other financial instruments for trading purposes.
Quantitative Disclosures
Commodity Price Sensitivity:
The following table provides information about the Company's derivative
financial instruments that are sensitive to changes in natural gas and crude oil
commodity prices. See note 5 of Notes to Consolidated Financial Statements
included in "Item 1. Financial Statements" for specific information regarding
the terms of the Company's commodity derivative financial instruments that are
sensitive to natural gas and crude oil commodity prices.
Fair
1999 2000 2001 Total Value
---------- ---------- -------- --------- ------
(dollars in thousands, except volumes and prices)
Natural Gas Hedge Derivatives (a):
Collar option contracts:
Notional volumes (MMBtu) 4,508,000 1,365,000 - 5,873,000 $(560)
Weighted average short call MMBtu strike price (b) $ 2.142 $ 2.200 $ -
Weighted average long put MMBtu strike price (b) $ 2.651 $ 2.550 $ -
Basis differential contracts (c):
Notional volumes (MMBtu) 4,508,000 1,365,000 - 5,873,000 $(413)
Weighted average MMBtu strike price $ 0.225 $ 0.218 $ -
Crude Oil Hedge Derivatives (a):
Collar option contract (d):
Notional volume (Bbls) 460,000 915,000 452,000 1,827,000 $(660)
Weighted average short call strike price per Bbl (b) $ 16.500 $ 16.500 $ 16.500
Weighted average long put strike price per Bbl (b) $ 20.480 $ 20.480 $ 20.480
___________________________________
(a) See note 5 of Notes to Consolidated Financial Statements included in "Item
1. Financial Statements" for additional information related to hedging
activities.
(b) The strike prices are based on the prices traded on the New York Mercantile
("NYMEX").
(c) The basis differential relates to the spread between the NYMEX price and an
El Paso/Permian price.
(d) The counterparty has the option to extend an additional year on volumes of
2,500 Bbl/d at a floor and ceiling price of $16.50 and $20.48 per barrel,
respectively. The option period is from July 1, 2000 to June 30, 2001.
The fair value assumes the extension is exercised by the counterparty.
20
Interest Rate Sensitivity:
The following table provides information about the Company's financial
instruments that are sensitive to interest rates. The debt obligations are
presented in the table at their contractual maturity dates together with the
weighted average interest rates expected to be paid on the debt. The weighted
average interest rates for the variable debt represents the weighted average
interest paid and/or accrued in June 1999. See note 2 of Notes to Consolidated
Financial Statements included in "Item 1. Financial Statements" for specific
information regarding the terms of the Company's debt obligations that are
sensitive to interest rates.
Fair
1999 2000 2001 Total Value
------ ------ -------- -------- --------
(in thousands, except interest rates)
Debt (a)
Variable rate debt:
Chase Bank of Texas, N.A. (Secured) $ - $ - $75,000 $75,000 $75,000
Average interest rate 6.604% 6.604% 6.604%
Chase Bank of Texas, N.A. (Unsecured) $ - $ - $ 1,300 $ 1,300 $ 1,300
Average interest rate 6.251% 6.251% 6.251%
__________________________
(a) See note 2 of Notes to Consolidated Financial Statements included in "Item
1. Financial Statements" for additional information related to debt.
Qualitative Disclosures
The Company, from time to time, enters into interest rate and commodity
price derivative contracts as hedges against interest rate and commodity price
risk. See note 5 of Notes to Consolidated Financial Statements included in "Item
1. Financial Statements" for discussions relative to the Company's objectives
and general strategies associated with it hedging instruments. The Company is a
borrower under variable rate debt instruments that give rise to interest rate
risk. See note 2 of Notes to Consolidated Financial Statements included in "Item
1. Financial Statements" for specific information regarding the terms of the
Company's debt obligations. The Company's policy and strategy, as of June 30,
1999, is to only enter into interest rate and commodity price derivative
instruments that qualify as hedges of its existing interest rate or commodity
price risks.
As of June 30, 1999, the Company's primary risk exposures associated with
financial instruments to which it is a party include natural gas price
volatility and interest rate volatility. The Company's primary risk exposures
associated with financial instruments have not changed significantly since
December 31, 1998.
21
PART II - OTHER INFORMATION
Item 1. Legal Proceedings
The two lawsuits related to OEDC, disclosed in Note 3 of notes to
consolidated financial statements, have reached a settlement pending court
approval. The settlement agreement is being finalized by the parties. See Note
3 of notes to consolidated financial statements for additional discussion.
Item 4. Submission of Matters to a Vote of Security Holders
(a) The Annual Meeting of Stockholders of the Company was held at 10:00
a.m., local time, on Wednesday, May 26, 1999.
(b) Proxies were solicited by the Board of Directors of the Company
pursuant to Regulation 14A under the Securities Exchange Act of 1934.
There were no solicitations in opposition to the Board of Directors'
nominees as listed in the proxy statement and all of such nominees were
duly elected.
(c) Out of a total of 37,934,675 shares of common stock of the Company
outstanding and entitled to vote, 34,519,103 shares were present in
person or by proxy, representing approximately 91%. The only matters
voted on by the stockholders, as fully described in the definitive
proxy materials for the annual meeting, were the election of directors
of the Company and the approval of the selection of the independent
auditors for the Company for 1999. The results were as follows:
1. To elect a Board of Directors to hold office until the next
annual meeting of stockholders and until their successors are
elected and qualified.
Number of Shares Voting
----------------------------------------------------------
Withholding
For Against Authority to Vote
Election as Election as for
Nominees Director Director Election as Director
-------- ----------------- ----------------- --------------------
Jack Hightower 34,269,614 - 249,489
George G. Staley 34,269,614 - 249,489
David R. Albin 34,278,455 - 240,648
Kenneth A. Hersh 34,278,455 - 240,648
William J. Vaughn, Jr. 34,269,614 - 249,489
2. To approve the selection by the Board of Directors, of the firm
of KPMG LLP as independent auditors for the Company for 1999.
For 34,505,124
Against 5,047
Abstain 8,932
(d) Inapplicable.
Item 5. Other Information
None
22
Item 6. Exhibits and Reports on Form 8-K
(a) Exhibits
--------
10.10 Amended and Restated Credit Agreement, dated June 24, 1999,
among Titan Exploration, Inc., the Chase Bank of Texas,
N.A., as Administrative Agent and Financial Institutions now
or thereafter parties thereto.
10.11 Master Promissory Note, dated July 1, 1999, between Titan
Exploration, Inc. and Chase Bank of Texas, N.A.
27 Financial Data Schedule
(b) Reports Submitted on Form 8-K:
(1) Form 8-K, date of report May 20, 1999, reported under Item 2.
Acquisition or Disposition of Assets. Filing reported
disposition of certain assets and included unaudited pro forma
combined financial statements reflecting the effects
disposition of the reported assets and other assets previously
sold or other assets for which there are disposal plans.
(2) Form 8-K, date of report June 10, 1999, reported under Item 5.
Other Events. Filing reported the (a) adoption of a rights
agreement and a rights dividend, (b) an amendment to the
Company's Bylaws, (c) severance agreements for officers of the
Company, (d) grants of new options to officers of the Company,
(e) extension of the term of all outstanding options and (f)
the adoption of the 1999 Non-Officer Stock Option Plan.
23
SIGNATURE
---------
Pursuant to the requirements of the Securities Exchange Act of 1934,
the Registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
TITAN EXPLORATION, INC.
By: /s/ Jack Hightower
--------------------
Jack Hightower
President and Chief Executive Officer
By: /s/ William K. White
----------------------
William K. White
Vice President and Chief Financial
Officer
Date: August 13, 1999
24