UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
-----------
FORM 10-Q
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the Quarter Ended June 30, 1998
-----------
Commission File Number 0-20872
ST. MARY LAND & EXPLORATION COMPANY
(Exact name of Registrant as specified in its charter)
Delaware 41-0518430
(State or other Jurisdiction (I.R.S. Employer Identification No.)
of incorporation or organization)
1776 Lincoln Street, Suite 1100, Denver, Colorado 80203
(Address of principal executive offices) (Zip Code)
(303) 861-8140
(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 [ ]
Indicate the number of shares outstanding of each of the Registrant's classes of
common stock as of the latest practicable date.
As of August 10, 1998, the registrant had 10,992,447 shares of Common Stock,
$.01 par value, outstanding.
ST. MARY LAND & EXPLORATION COMPANY
INDEX
Part I. FINANCIAL INFORMATION PAGE
Item 1. Financial Statements (Unaudited)
Consolidated Balance
Sheets - June 30, 1998 and
December 31, 1997 ....................................... 3
Consolidated Statements of
Income - Three Months Ended
June 30, 1998 and 1997: Six Months
Ended June 30, 1998 and 1997 ............................ 4
Consolidated Statements of
Cash Flows - Six Months Ended
June 30, 1998 and 1997 .................................. 5
Notes to Consolidated Financial
Statements - June 30, 1998 .............................. 7
Item 2. Management's Discussion and Analysis
of Financial Condition and Results
of Operations .......................................... 11
Part II. OTHER INFORMATION
Item 4. Submission of Matters to a Vote of Security Holders .... 22
Item 6. Exhibits and Reports on Form 8-K ....................... 22
Exhibits
--------
Exhibit 3.3 Certificate of Amendment to Certificate
of Incorporation
Exhibit 27.6 Financial Data Schedule
Exhibit 10.52 Credit Agreement dated June 30, 1998
2
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
ST. MARY LAND & EXPLORATION COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS (UNAUDITED)
(In thousands, except share amounts)
ASSETS
June 30, December 31,
-------------- --------------
1998 1997
-------------- --------------
Current assets:
Cash and cash equivalents $ 4,537 $ 7,112
Accounts receivable 17,315 24,320
Prepaid expenses and other 532 480
-------------- --------------
Total current assets 22,384 31,912
-------------- --------------
Property and equipment (successful efforts method), at cost:
Proved oil and gas properties 269,638 246,468
Unproved oil and gas properties, net of impairment
allowance of $3,184 in 1998 and $3,032 in 1997 30,737 28,615
Other 3,531 3,386
-------------- --------------
303,906 278,469
Less accumulated depletion, depreciation, amortization and impairment (132,919) (120,988)
-------------- --------------
170,987 157,481
-------------- --------------
Other assets:
Khanty Mansiysk Oil Corporation receivable and stock 12,003 12,003
Summo Minerals Corporation investment and receivable 6,686 6,691
Other assets 3,789 2,943
-------------- --------------
22,478 21,637
-------------- --------------
$ 215,849 $ 211,030
============== ==============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable and accrued expenses $ 18,434 $ 21,943
Current portion of stock appreciation rights 358 351
-------------- --------------
Total current liabilities 18,792 22,294
-------------- --------------
Long-term liabilities:
Long-term debt 26,615 22,607
Deferred income taxes 17,999 16,589
Stock appreciation rights 691 989
Other noncurrent liabilities 1,083 619
-------------- --------------
46,388 40,804
-------------- --------------
Commitments and contingencies
Stockholders' equity:
Common stock, $.01 par value: authorized - 50,000,000 shares in 1998 and
15,000,000 shares in 1997; issued and outstanding - 10,984,023
shares in 1998 and 10,980,423 shares in 1997 110 110
Additional paid-in capital 67,589 67,494
Retained earnings 82,970 80,328
-------------- --------------
Total stockholders' equity 150,669 147,932
-------------- --------------
$ 215,849 $ 211,030
============== ==============
The accompanying notes are an integral part
of these consolidated financial statements.
3
ST. MARY LAND & EXPLORATION COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)
(In thousands, except per share amounts)
For the Three Months Ended For the Six Months Ended
June 30, June 30,
---------------------------- ----------------------------
1998 1997 1998 1997
------------ ------------ ------------ ------------
Operating revenues:
Oil and gas production $ 20,233 $ 15,302 $ 39,258 $ 36,332
Gain on sale of Russian joint venture - - - 9,691
Gain (loss) on sale of proved properties (14) 4,182 (14) 4,214
Other revenues 88 353 202 461
------------ ------------ ------------ ------------
Total operating revenues 20,307 19,837 39,446 50,698
------------ ------------ ------------ ------------
Operating expenses:
Oil and gas production 4,173 3,123 8,116 7,101
Depletion, depreciation and amortization 6,503 4,021 11,880 8,018
Impairment of proved properties 1,077 516 1,445 516
Exploration 3,052 1,630 6,473 3,019
Abandonment and impairment of unproved properties 312 332 615 482
General and administrative 1,477 1,547 4,424 4,568
Loss in equity investees 510 109 571 22
Other 57 71 92 36
------------ ------------ ------------ ------------
Total operating expenses 17,161 11,349 33,616 23,762
------------ ------------ ------------ ------------
Income from operations 3,146 8,488 5,830 26,936
Nonoperating income and (expense):
Interest income 371 289 526 467
Interest expense (360) (143) (754) (725)
------------ ------------ ------------ ------------
Income before income taxes 3,157 8,634 5,602 26,678
Income tax expense 1,121 3,041 1,896 9,490
------------ ------------ ------------ ------------
Income from continuing operations 2,036 5,593 3,706 17,188
Gain on sale of discontinued operations, net of taxes 34 296 34 296
------------ ------------ ------------ ------------
Net income $ 2,070 $ 5,889 $ 3,740 $ 17,484
============ ============ ============ ============
Basic earnings per common share:
Income from continuing operations $ .19 $ .51 $ .34 $ 1.68
Gain on sale of discontinued operations - .03 - .03
============ ============ ============ ============
Basic net income per common share $ .19 $ .54 $ .34 $ 1.71
============ ============ ============ ============
Diluted earnings per common share:
Income from continuing operations $ .18 $ .51 $ .33 $ 1.66
Gain on sale of discontinued operations - .03 - .03
============ ============ ============ ============
Diluted net income per common share $ .18 $ .54 $ .33 $ 1.69
============ ============ ============ ============
Basic weighted average common shares outstanding 10,984 10,945 10,984 10,255
============ ============ ============ ============
Diluted weighted average common shares outstanding 11,079 11,054 11,102 10,352
============ ============ ============ ============
Cash dividend declared per share $ 0.05 $ 0.05 $ 0.10 $ 0.10
============ ============ ============ ============
The accompanying notes are an integral part
of these consolidated financial statements.
4
ST. MARY LAND & EXPLORATION COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)
(In thousands)
For the Six Months Ended
June 30,
--------------------------------
1998 1997
------------ ------------
Reconciliation of net income to net cash provided by operating activities:
Net income $ 3,740 $ 17,484
Adjustments to reconcile net income to net
cash provided by operating activities:
Gain on sale of Russian joint venture - (9,691)
Loss (gain) on sale of proved properties 14 (4,214)
Depletion, depreciation and amortization 11,880 8,018
Impairment of proved properties 1,445 516
Exploration 2,945 (341)
Abandonment and impairment of unproved properties 615 482
Loss in equity investees 571 22
Deferred income taxes 1,410 8,435
Other 239 256
------------ ------------
22,859 20,967
Changes in current assets and liabilities:
Accounts receivable 7,081 1,453
Prepaid expenses and other (986) 253
Accounts payable and accrued expenses (1,600) 2,552
Stock appreciation rights 7 (1,567)
------------ ------------
Net cash provided by operating activities 27,361 23,658
------------ ------------
Cash flows from investing activities:
Proceeds from sale of oil and gas properties 59 7,144
Capital expenditures (29,391) (23,688)
Acquisition of oil and gas properties (2,026) (7,386)
Sale of Russian joint venture - 5,608
Investment in and loans to Summo Minerals Corporation (566) (251)
Receipts from restricted cash - 7,854
Deposits to restricted cash - (6,551)
Other (922) (164)
------------ ------------
Net cash used in investing activities (32,846) (17,434)
------------ ------------
Cash flows from financing activities:
Proceeds from long-term debt 24,395 4,975
Repayment of long-term debt (20,387) (41,149)
Proceeds from sale of common stock, net of offering costs - 51,190
Dividends paid (1,098) (985)
Other - (9)
------------ ------------
Net cash provided by financing activities 2,910 14,022
------------ ------------
Net (decrease) increase in cash and cash equivalents (2,575) 20,246
Cash and cash equivalents at beginning of period 7,112 3,338
------------ ------------
Cash and cash equivalents at end of period $ 4,537 $ 23,584
============ ============
The accompanying notes are an integral part of
these consolidated financial statements.
5
ST. MARY LAND & EXPLORATION COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)
(Continued)
Supplemental schedule of additional cash flow information and noncash
activities:
For the Six Months Ended
June 30,
1998 1997
------------ ------------
(In thousands)
Cash paid for interest $ 771 $ 936
Cash paid for income taxes 444 809
Cash paid for exploration expenses 6,425 2,541
Interest income included in restricted cash - 32
In February 1997, the Company sold its interest in the Russian joint venture for
$17,609,000, receiving $5,608,000 of cash, $1,869,000 of Khanty Mansiysk Oil
Corporation common stock, and a $10,134,000 receivable in a form equivalent to a
retained production payment.
The accompanying notes are an integral part of
these consolidated financial statements.
6
ST. MARY LAND & EXPLORATION COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)
June 30, 1998
Note 1 - Basis of Presentation
The accompanying unaudited condensed consolidated financial statements have been
prepared in accordance with generally accepted accounting principles for interim
financial information. They do not include all information and notes required by
generally accepted accounting principles for complete financial statements.
However, except as disclosed herein, there has been no material change in the
information disclosed in the notes to consolidated financial statements included
in the Annual Report on Form 10-K of St. Mary Land & Exploration Company and
Subsidiaries (the "Company") for the year ended December 31, 1997. In the
opinion of Management, all adjustments (consisting of normal recurring accruals)
considered necessary for a fair presentation have been included. Operating
results for the periods presented are not necessarily indicative of the results
that may be expected for the full year.
The accounting policies followed by the Company are set forth in Note 1 to the
Company's financial statements in Form 10-K for the year ended December 31,
1997. It is suggested that these financial statements be read in conjunction
with the financial statements and notes included in the Form 10-K.
Certain amounts in the 1997 consolidated financial statements have been
reclassified to correspond to the 1998 presentation.
Note 2 - Investments
The Company, through subsidiaries, owned an 18% interest in a venture that is
developing the Chernogorskoye oil field in western Siberia (the "Russian joint
venture"). The Company accounted for its investment in the Russian joint venture
under the equity method of accounting. In February 1997, the Company sold its
interest in the Russian joint venture to Khanty Mansiysk Oil Corporation
("KMOC"), formerly known as Ural Petroleum Corporation. In accordance with the
Acquisition Agreement, the Company received cash consideration of $5,608,000
before transaction costs, KMOC common stock valued at $1,869,000, and a
receivable in a form equivalent to a retained production payment of $10,134,000
plus interest at 10% per annum from the limited liability company formed to hold
the Russian joint venture interest. The Company's receivable is collateralized
by the partnership interest sold. The Company has the right, subject to certain
conditions, to require KMOC to purchase the Company's receivable from the net
proceeds of an initial public offering of KMOC common stock or alternatively,
the Company may elect to convert all or a portion of its receivable into KMOC
common stock immediately prior to an initial public offering of KMOC common
stock. The Company recorded a gain on the sale of the Russian joint venture
interest of $9,671,000. The Company's equity in income for the Russian joint
venture for 1997 through the date of sale was $203,000.
The Company accounts for its 37% ownership interest in Summo Minerals
Corporation ("Summo") under the equity method of accounting. For the six months
ended June 30, 1998, the Company recorded a loss of $571,000 as its equity in
the losses of Summo. In May 1997, the Company entered into an agreement to
receive a 55% interest in Summo's Lisbon Valley Copper Project (the "Project")
in return for the Company contributing $4,000,000 in cash, all of its
outstanding stock in Summo, and $8,600,000 in letters of credit to a single
purpose company, Lisbon Valley Mining Company LLC, formed to own and operate the
Project. Summo will contribute the property, all project permits and contracts,
7
$3,200,000 in cash, and a commitment for $45,000,000 of senior debt financing in
return for a 45% interest in the new company. The agreement is subject to
certain conditions, including final resolution of regulatory approvals and
project financing. Summo has completed tests of the ground water quality to
address concerns raised on appeal during the permitting process. The results of
these tests support the original conclusions and recommendations made by the
Bureau of Land Management when the Project was initially approved. A decision
from the Interior Board of Land Appeals is expected before the end of 1998. The
Company has agreed to provide interim financing of up to $2,950,000 for the
Project in the form of a loan to Summo due in June 1999. Interest accrues on the
amounts outstanding at the prime rate plus 1%. As of June 30, 1998, $2,647,000
was outstanding under this loan. Additional amounts totaling $48,000 have been
advanced to Summo under this loan since June 30, 1998. At the Company's option,
any principal and interest amounts outstanding are convertible into shares of
Summo common stock anytime after December 31, 1998, at a conversion price equal
to the weighted average trading price of Summo's common shares for the twenty
trading days leading up to and including December 31, 1998. Upon capitalization
of the new company the outstanding loan principal shall constitute a capital
contribution in partial satisfaction of the Company's capital commitments set
out in the May 1997 agreement, and any accrued interest on the loan shall be
forgiven. Although current copper prices are not sufficient to warrant
development of the Project at this time, management believes the long-term
outlook for copper prices is favorable and plans to continue providing interim
financing during 1998 until Summo receives regulatory approval and copper prices
recover adequately to justify construction using permanent financing. There can
be no assurance that the Company will realize a return on its investment in
Summo or the Project.
Note 3 - Capital Stock
On February 26, 1997, the Company closed the sale of 2,000,000 shares of common
stock at $25.00 per share. On March 12, 1997, the Company closed the sale of an
additional 180,000 shares pursuant to the underwriters' exercise of the
over-allotment option. These transactions resulted in aggregate net proceeds of
$51,200,000. The proceeds were used to fund the Company's exploration,
development and acquisition programs and to repay borrowings under its credit
facility.
In June 1998, the Company's shareholders approved an amendment to the Company's
Certificate of Incorporation to increase the number of authorized shares of
Common Stock from 15,000,000 to 50,000,000.
Note 4 - Recently Issued Accounting Standards
In June 1997, the Financial Accounting Standards Board ("FASB") issued Statement
of Financial Accounting Standards ("SFAS") No. 130, "Reporting Comprehensive
Income," effective for financial statements for fiscal years beginning after
December 15, 1997. The Statement establishes standards for reporting and display
of comprehensive income and its components in financial statements. The adoption
of this statement will not have a material impact on the Company's financial
statements.
In June 1997, the FASB issued SFAS No. 131, "Disclosures about Segments of an
Enterprise and Related Information," effective for financial statements for
fiscal years beginning after December 15, 1997. The Statement requires companies
to report certain information about operating segments in their financial
statements and certain information about their products and services, the
geographic areas in which they operate and their major customers. The Company is
currently reviewing the effects of the disclosure requirements of the Statement.
8
In February 1998, the FASB issued SFAS No. 132, "Employer's Disclosures about
Pensions and Other Postretirement Benefits," effective for fiscal years
beginning after December 15, 1997. The Statement standardizes the disclosure
requirements for pensions and other postretirement benefits to provide
information that is more comparable and concise. The Company is currently
reviewing the effects of the disclosure requirements of the Statement.
In June 1998, the FASB issued SFAS No. 133, "Accounting for Derivative
Instruments and Hedging Activities," effective for all fiscal quarters of fiscal
years beginning after June 15, 1999. The Statement establishes accounting and
reporting standards for derivative instruments, including certain derivative
instruments embedded in other contracts, and for hedging activities. The Company
is currently reviewing the effects this Statement will have on the financial
statements in relation to the Company's hedging activities.
Note 5 - Earnings per Share
In February 1997, the FASB issued SFAS No. 128, "Earnings Per Share," which
requires a dual presentation of basic and diluted earnings per share. The
Company adopted SFAS No. 128 effective December 31, 1997. Under SFAS No. 128
basic net income per share of common stock is calculated by dividing net income
by the weighted average of common shares outstanding during each period, and
diluted net income per common share of stock is calculated by dividing net
income by the weighted average of outstanding common shares and other dilutive
securities. Dilutive securities of the Company consist entirely of outstanding
options to purchase the Company's common stock. The outstanding dilutive
securities for the three-month periods ended June 30, 1998 and 1997 were 95,255
and 108,421, respectively, and the outstanding dilutive securities for the
six-month periods ended June 30, 1998 and 1997 were 118,861 and 97,361,
respectively. All net income of the Company is available to common stockholders.
The adoption of SFAS No. 128 had no effect on diluted net income per share
compared to fully diluted net income per share as reported for the six months
ended June 30, 1997. Restated diluted net income per share for the three months
ended June 30, 1997 was $0.54 compared to fully diluted net income per share of
$0.53 as reported. Restated basic net income per share for the six months ended
June 30, 1997 was $1.71 compared to primary net income per share of $1.69 as
reported. Restated basic net income per share for the three months ended June
30, 1997 was $0.54 compared to primary net income per share of $0.53 as
reported.
Note 6 - Income Taxes
Federal income tax expense for 1998 and 1997 differs from the amount that would
be provided by applying the statutory U.S. Federal income tax rate to income
before income taxes primarily due to Section 29 credits and percentage depletion
in 1998 and the effect of state income taxes partially offset by Section 29 tax
credits and percentage depletion in 1997.
Note 7 - Long-Term Debt and Notes Payable
On June 30, 1998, the Company entered into a new long-term revolving credit
agreement that replaced the agreement dated March 1, 1993 and amended in April
1996. The new credit agreement specifies a maximum loan amount of $200,000,000
and has an initial aggregate borrowing base of $115,000,000. The lender may
periodically re-determine the aggregate borrowing base. The initial accepted
borrowing base is $40,000,000. The credit agreement has a maturity date of
December 31, 2005, and includes a revolving period that matures on December 31,
2000. The Company can elect to allocate up to 50% of available borrowings to a
short-term tranche due in 364 days. The Company must comply with certain
covenants including maintenance of stockholders' equity at a specified level and
limitations on additional indebtedness. As of June 30, 1998 $19,200,000 was
outstanding under this credit agreement.
9
Effective June 30, 1998, interest on borrowings during the revolving period and
commitment fees on the unused portion of the accepted borrowing base are
calculated as follows:
INTEREST RATES:
Debt to Capitalization Ratio Interest Rate
- ---------------------------- -------------
Less than 0.3 to 1.0 The Company's option of (a) LIBOR + 0.50%
or (b) the higher of the Federal Funds
Rate + 0.5% or the Prime Rate
Greater than or equal to 0.3 to The Company's option of (a) LIBOR + 0.75%
1.0 but less than 0.4 to 1.0 or (b) the higher of the Federal Funds
Rate + 0.5% or the Prime Rate
Greater than or equal to 0.4 to The Company's option of (a) LIBOR + 1.00%
1.0 but less than 0.5 to 1.0 or (b) the higher of the Federal Funds
Rate + 0.5% or the Prime Rate
Greater than or equal to The Company's option of (a) LIBOR + 1.25%
0.5 to 1.0 or (b) the higher of the Federal Funds
Rate + 0.625% or the Prime Rate + 0.125%
COMMITMENT FEES:
Debt to Capitalization Ratio Short-Term Tranche Long-Term Tranche
---------------------------- ------------------ -----------------
Less than 0.5 to 1.0 0.125% 0.25%
Greater than or equal to 0.5 to 1.0 0.375% 0.50%
At June 30, 1998, the Company's debt to capitalization ratio as defined under
the credit agreement was 0.18 to 1.0.
Panterra, in which the Company has a 74% general partnership ownership interest,
has a separate credit facility with a $25,000,000 borrowing base as of July 1,
1998, and $10,000,000 and $11,000,000 outstanding as of June 30, 1998 and
December 31, 1997, respectively. In June 1997, Panterra entered into a credit
agreement replacing a previous agreement, which was due March 31, 1999. The new
credit agreement includes a two-year revolving period converting to a five-year
amortizing loan on June 30, 1999. During the revolving period of the loan, loan
balances accrue interest at Panterra's option of either the bank's prime rate or
LIBOR plus 3/4% when the Partnership's debt to partners' capital ratio is less
than 30%, up to a maximum of either the bank's prime rate or LIBOR plus 1-1/4%
when the Partnership's debt to partners' capital ratio is greater than 100%.
10
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
Overview
St. Mary Land & Exploration Company ("St. Mary" or the "Company") was founded in
1908 and incorporated in Delaware in 1915. The Company is engaged in the
exploration, development, acquisition and production of crude oil and natural
gas with operations focused in five core operating areas in the United States:
The Mid-Continent region; the ArkLaTex region; south Louisiana; the Williston
Basin; and the Permian Basin.
Internal exploration, drilling and production personnel conduct the Company's
activities in the Mid-Continent and ArkLaTex regions and in south Louisiana.
Activities in the Williston Basin are conducted through Panterra Petroleum
("Panterra") in which the Company owns a 74% general partnership interest. The
Company proportionally consolidates its interest in Panterra. Activities in the
Permian Basin are primarily contracted through an oil and gas property
management company with extensive experience in the basin.
St. Mary has two principal equity investments, Summo Minerals Corporation
("Summo"), a North American copper mining company of which the Company owns 37%,
and until early 1997, the Company's Russian joint venture. The Company accounts
for its investments in Summo and the Russian joint venture under the equity
method and includes its share of the income or loss from these entities in its
consolidated results of operations. Effective February 12, 1997, the Company
sold its Russian joint venture.
The Company receives significant royalty income from its south Louisiana fee
lands. Management believes the Company's royalty income may increase in 1998
with the completion of the St. Mary Land & Exploration No. 3 well at South
Horseshoe Bayou in January 1998 which followed the completion of the discovery
well in the prospect in February 1997 and its subsequent recompletion in April
1998. The Company owns a 25% working interest and royalty interests between
approximately 19% and 22% in this field for combined net revenue interests of
between approximately 37% and 40%, depending on the depth of production. The
Company and the lessees have identified several geologic objectives for testing
in future years.
During 1995, 1996 and 1997 the Company acquired proved oil and gas properties
for a total of $56.4 million. The results of operations include these
acquisitions and the subsequent development of the properties. In December 1995,
the Company acquired two different interests in the Box Church Field in its
ArkLaTex region for $2.2 million and several additional interests in 1996 for
$580,000. Development of the field has occurred with the drilling and completion
of three wells in 1996 and eleven wells in 1997. In the first half of 1998 the
Company completed two of the three wells in progress at year-end 1997. Two of
the five wells anticipated to be drilled in 1998 to complete the development of
the field were in progress as of June 30, 1998. The Company purchased a 90%
interest in the producing properties of Siete Oil & Gas Corporation for $10.0
million in June 1996 and completed a series of follow-on acquisitions of smaller
interests in these properties totaling $5.8 million during 1996, 1997 and the
first two quarters of 1998. These properties are located in the Permian Basin of
New Mexico and west Texas. The successful implementation of a secondary recovery
plan during the first half of 1998 was completed as part of the Company's plan
to further develop these properties. Management expects to acquire additional
interests in the Siete properties as they become available. In May 1997, the
Company acquired an 85% working interest in certain Louisiana properties of
Henry Production Company for $3.8 million. In November 1997, the Company
acquired the interests of Conoco, Inc. in the Southwest Mayfield area in
Oklahoma for $20.3 million. Management anticipates drilling several wells in
1998 to test the geologic ideas identified at the time of acquisition of this
field, one such well was in progress at June 30, 1998. During the second quarter
of 1998, the Company entered into an exploration and development joint venture
in east Texas, which included the acquisition of interests in existing
properties for $521,000. Several smaller acquisitions were also completed during
1997 and 1996 totaling $560,000 and $2.8 million, respectively.
11
In February 1997, the Company sold its interest in the Russian joint venture to
Khanty Mansiysk Oil Corporation ("KMOC"), formerly known as Ural Petroleum
Corporation, for $17.6 million. The Company received $5.6 million in cash before
transaction costs, $1.9 million of KMOC common stock and a convertible
receivable in a form equivalent to a retained production payment of $10.1
million plus interest at 10% per annum from the limited liability company formed
to hold the Russian joint venture interest.
In February 1997, the Company closed the sale of 2,000,000 shares of common
stock at $25.00 per share and closed the sale of an additional 180,000 shares in
March 1997, pursuant to the underwriters' exercise of the over-allotment option.
These transactions resulted in aggregate net proceeds of $51.2 million.
In May 1997, the Company sold its non-operated interests in south Texas for $5.4
million as part of its continuing strategy to focus and rationalize its
operations.
The Company seeks to protect its rate of return on acquisitions of producing
properties by hedging up to the first 24 months of an acquisition's production
at prices approximately equal to those used in the Company's acquisition
evaluation and pricing model. The Company also periodically uses hedging
contracts to hedge or otherwise reduce the impact of oil and gas price
fluctuations on production. The Company's strategy is to ensure certain minimum
levels of operating cash flow and to take advantage of windows of favorable
commodity prices. The Company generally limits its aggregate hedge position to
no more than 50% of its total production. The Company seeks to minimize basis
risk and indexes the majority of its oil hedges to NYMEX prices and the majority
of its gas hedges to various regional index prices associated with pipelines in
proximity to the Company's areas of gas production. The Company has hedged
approximately 3.2 million MMBtu of its remaining 1998 gas production at an
average fixed price of $2.20 per MMBtu. The Company has also purchased options
resulting in price collars and price floors on 840,000 MMBtu of the Company's
remaining 1998 gas production with price ceilings between $2.65 and $2.80 per
MMBtu and price floors between $1.95 and $2.00 per MMBtu. All of the Company's
existing oil hedges matured during the second quarter of 1998. The company has
not hedged any of its remaining 1998 oil production as of June 30, 1998.
This Quarterly Report on Form 10-Q includes certain statements that may be
deemed to be "forward-looking statements" within the meaning of Section 27A of
the Securities Act of 1933, as amended, and Section 21E of the Securities
Exchange Act of 1934, as amended. All statements, other than statements of
historical facts, included in this Form 10-Q that address activities, events or
developments that the Company expects, believes or anticipates will or may occur
in the future, including such matters as future capital, development and
exploration expenditures (including the amount and nature thereof), drilling of
wells, reserve estimates (including estimates of future net revenues associated
with such reserves and the present value of such future net revenues), future
production of oil and gas, repayment of debt, business strategies, expansion and
growth of the Company's operations and other such matters are forward-looking
statements. These statements are based on certain assumptions and analyses made
by the Company in light of its experience and its perception of historical
trends, current conditions, expected future developments and other factors it
believes are appropriate in the circumstances. Such statements are subject to a
number of assumptions, risks and uncertainties, general economic and business
conditions, the business opportunities (or lack thereof) that may be presented
to and pursued by the Company, changes in laws or regulations, and other
factors, many of which are beyond the control of the Company. Readers are
cautioned that any such statements are not guarantees of future performance and
that actual results or developments may differ materially from those projected
in the forward-looking statements.
12
Results of Operations
The following table sets forth selected operating and financial information for
the Company:
Three Months Six Months
Ended June 30, Ended June 30,
---------------------------- ----------------------------
1998 1997 1998 1997
------------ ------------ ------------ ------------
(In thousands, except BOE data)
Oil and gas production
Revenues:
Working interests $ 17,862 $ 13,323 $ 34,872 $ 31,834
Louisiana royalties 2,371 1,979 4,386 4,498
============ ============ ============ ============
Total $ 20,233 $ 15,302 $ 39,258 $ 36,332
============ ============ ============ ============
Net production:
Oil (MBbls) 370 276 692 572
Gas (MMcf) 7,255 5,529 13,614 10,999
============ ============ ============ ============
MBOE 1,579 1,197 2,961 2,405
============ ============ ============ ============
Average sales price (1):
Oil (per Bbl) $ 13.55 $ 18.91 $ 14.18 $ 19.67
Gas (per Mcf) 2.10 1.82 2.16 2.28
Oil and gas production costs:
Lease operating expense $ 3,118 $ 2,339 $ 5,959 $ 4,762
Production taxes 1,055 784 2,157 2,339
============ ============ ============ ============
Total $ 4,173 $ 3,123 $ 8,116 $ 7,101
============ ============ ============ ============
Additional per BOE data:
Sales price $ 12.81 $ 12.78 $ 13.26 $ 15.10
Lease operating expense 1.97 1.95 2.01 1.98
Production taxes .67 .65 .73 .97
------------ ------------ ------------ ------------
Operating margin $ 10.17 $ 10.18 $ 10.52 $ 12.15
Depreciation, depletion and
amortization $ 4.12 $ 3.36 $ 4.01 $ 3.33
Impairment of proved
properties .68 .43 .49 .21
General and administrative .94 1.29 1.49 1.90
- ----------
(1) Includes the effects of the Company's hedging activities.
13
Oil and Gas Production Revenues. Oil and gas production revenues increased $4.9
million, or 32% to $20.2 million for the second quarter 1998 compared to $15.3
million for the second quarter 1997. Oil production volumes increased 34% and
gas production volumes increased 31% for the second quarter 1998 compared to
1997. Average net daily production reached 17.4 MBOE in the second quarter 1998
compared to 13.2 MBOE in the comparable quarter of 1997. This production
increase resulted from new properties acquired and drilled during the past year.
Major acquisitions included the Southwest Mayfield properties purchased from
Conoco, the acquisition of Louisiana properties from Henry Production Company,
and the additional interests purchased in the Siete properties. Successful
drilling results in the Box Church Field in Texas, the Haynesville Field in
Louisiana and in the Company's Oklahoma drilling program also contributed to the
second quarter 1998 production increase. Also contributing to the second quarter
1998 production increase were gas balancing adjustments and other non-recurring
adjustments which increased average daily production for the quarter by 1.1MBOE.
The average realized oil price for the second quarter 1998 decreased 28% to
$13.55 per Bbl, while realized gas prices increased 15% to $2.10 per Mcf, from
their respective 1997 levels.
Oil and gas production revenue increased $2.9 million, or 8% to $39.2 million
for the six months ended June 30, 1998 compared to $36.3 million in 1997. Oil
production volumes increased 21% and gas production volumes increased 24% for
the first six months of 1998 compared with the comparable 1997 period. Average
net daily production was 16.4 MBOE for the six months ended June 30, 1998
compared to 13.3 MBOE in 1997. This production increase resulted from new
properties acquired and drilled during the past year, including the acquisition
of the Southwest Mayfield properties in Oklahoma and the Louisiana properties
purchased from Henry Production Company. Successful drilling results in the Box
Church Field in Texas, the South Horseshoe Bayou and Haynesville fields in
Louisiana and the Company's Oklahoma drilling program contributed to the first
half of 1998 production increases. The average oil price for the six months
ended June 30, 1998 decreased 28% to $14.18 per barrel, and gas prices decreased
5% to $2.16 per Mcf, from their respective 1997 levels.
The Company hedged 30,000 Bbls of its oil production during the second quarter
1998 at an average NYMEX price of $17.95 per Bbl. The Company purchased options
resulting in price collars and price floors on 22,000 Bbls of its second quarter
1998 oil production with a price ceiling of $24.00 per Bbl and a price floor of
$20.00 per Bbl. The Company realized a $313,000 increase in oil revenue or $.45
per Bbl for 1998 on these contracts compared to a $219,000 decrease or $.38 per
Bbl in 1997. The Company also hedged 2.0 million MMBtu of its second quarter
1998 gas production at an average indexed price of $2.21 per MMBtu and purchased
options resulting in price collars and price floors on 1.1 million MMBtu of its
second quarter 1998 gas production with price ceilings between $2.55 and $3.00
per MMBtu and price floors between $1.95 and $2.00 per MMBtu. The Company
realized a $324,000 increase in gas revenues or $.02 per Mcf for 1998 from hedge
contracts compared to a $1.0 million or $.10 per Mcf decrease in 1997.
Oil and Gas Production Costs. Oil and gas production costs consist of lease
operating expense and production taxes. Total production costs increased $1.1
million or 34% for the second quarter 1998 from comparable 1997 levels. Higher
lease operating expenses were partially offset by lower production taxes on
wells drilled in 1998 qualifying for reduced production tax rates. Total oil and
gas production costs per BOE increased 1% to $2.64 in 1998 compared to $2.60 per
BOE in the second quarter 1997.
Total production costs increased $1.0 million or 14% for the six months ended
June 30, 1998 to $8.1 million as a result of new properties acquired and drilled
during the past year. However, total production costs per BOE declined 7% to
$2.74 for the six months ended June 30, 1998 compared to $2.95 for the six
months ended June 30, 1997, primarily due to lower lease operating expenses per
BOE from high volume properties such as South Horseshoe Bayou.
Depreciation, Depletion, Amortization and Impairment. Depreciation, depletion
and amortization expense ("DD&A") increased $2.5 million, or 62% to $6.5 million
in the second quarter 1998 compared with $4.0 million in 1997. DD&A per BOE
increased 23% to $4.12 in the second quarter 1998 compared to $3.36 in 1997.
This increase resulted from increased production volumes of new properties
acquired and drilled in the last half of 1997 and the first half of 1998 with a
higher cost basis, and from increased water production at South Horseshoe Bayou
and the adverse impact of low oil prices in the Williston Basin. The Company
recorded impairments of proved oil and gas properties of $1.1 million in the
second quarter 1998 compared with $516,000 in the comparable 1997 period. These
second quarter 1998 charges resulted from a high cost marginal well in Oklahoma
and another in Louisiana, as well as $580,000 of impairments associated with the
Company's properties in the Williston Basin due to low oil prices.
14
DD&A increased 48% to $11.9 million for the six months ended June 30, 1998
compared with $8.0 million in 1997 because of increased production and reserve
declines from low oil prices and water production at South Horseshoe Bayou, and
due to higher cost properties in four fields in Oklahoma. DD&A per BOE increased
to $4.01 in the six months ended June 30, 1998 compared to $3.33 in 1997.
Impairment of producing oil and gas properties was $1.4 million for the six
months ended June 30, 1998 compared to $516,000 for the six months ended June
30, 1997, due to marginal wells drilled in Oklahoma and Louisiana and the
adverse affects of low oil prices in the Williston Basin.
Abandonment and impairment of unproved properties decreased $20,000 to $312,000
in the second quarter 1998 compared to $332,000 in 1997.
Abandonment and impairment of unproved properties increased $133,000 to $615,000
in the six months ended June 30, 1998 compared to $482,000 in the comparable
period in 1997 due to additional lease expirations during the first half of
1998.
Exploration. Exploration expense increased $1.4 million or 87% to $3.1 million
for the second quarter 1998 compared with $1.6 million in 1997 primarily as a
result of three unsuccessful exploratory wells in south Louisiana and Oklahoma.
Exploration expense increased $3.5 million or 114% to $6.5 million for the six
months ended June 30, 1998 compared to $3.0 million in 1997 due to six
unsuccessful exploratory tests in south Louisiana and Oklahoma and the payment
of $795,000 for delay rentals in the Company's Atchafalaya prospect area in the
six months ended June 30, 1998 compared with 1997.
General and Administrative. General and administrative expenses declined $70,000
or 5% to $1.5 million for the second quarter 1998 as compared to 1997. Increased
compensation and rent expenses were offset by declines in charitable
contributions, insurance and general corporate expenses.
General and administrative expenses decreased $144,000 or 3% to $4.4 million for
the six months ended June 30, 1998 compared to $4.6 million in 1997. Increased
compensation and rent expenses were offset by declines in charitable
contributions, insurance and general corporate expenses and increases in
overhead reimbursements from outside interest owners in properties operated by
the Company.
Other operating expenses consist of legal expenses in connection with ongoing
oil and gas activities and oversight of the Company's mining investments. This
expense decreased $13,000 to $58,000 in the second quarter 1998 compared with
the second quarter 1997.
Other operating expenses increased $56,000 to $92,000 in the first half of 1998
compared to the comparable 1997 period, primarily due to legal expenses in 1998
associated with the pending litigation that seeks to recover damages from the
drilling contractor for the St. Mary Land & Exploration No. 1 well at South
Horseshoe Bayou, and due to the benefit of a non-recurring insurance recovery of
$68,000 in 1997.
Equity in Income of Russian Joint Venture. The Company accounted for its
investment in the Russian joint venture under the equity method and included its
share of income from the venture in its results of operations up to the point of
sale. Therefore no equity in the net income of the Russian joint venture was
recorded in 1998 compared to $203,000 recorded in 1997. As discussed under
Outlook, the Company sold this investment in February 1997 resulting in a
partial year of equity income recorded in 1997.
15
Equity in Loss of Summo Minerals Corporation. The Company accounts for its
investment in Summo under the equity method and includes its share of Summo's
income or loss in its results of operations. The Company's equity in the net
loss of Summo was $509,000 in the second quarter 1998 and $110,000 in 1997. This
increase is primarily due to the $447,000 impact of Summo's decision to
write-off its investment in its Cashin and Champion properties.
The Company's equity in the net loss of Summo was $571,000 for the six months
ended June 30, 1998 compared to $209,000 in 1997, primarily due to Summo's
decision to write-off its investment in its Cashin and Champion properties in
the second quarter 1998.
Non-Operating Income and Expense. Interest income increased $83,000 or 29% to
$372,000 for the second quarter 1998 from $289,000 for the second quarter 1997
due to $312,000 of interest income resulting from a favorable gas balancing
decision by the Oklahoma Supreme Court. Interest expense increased $218,000 or
152% to $361,000 for the second quarter 1998 compared to $143,000 in the 1997
period due to increased borrowings under the Company's and Panterra's credit
facilities in 1998. Debt under the Company's credit facility had been repaid in
the first quarter 1997 with the proceeds from the sale of the Company's common
stock in February 1997.
Interest income increased $59,000 or 13% to $526,000 in the six month period
ended June 30, 1998 compared to $467,000 for the comparable 1997 period due to
$312,000 of interest income from the favorable gas balancing decision in 1998.
Interest was earned in the six-month period ended June 30, 1997 on funds
available from the sale of the Company's common stock. Interest expense for the
six months ended June 30, 1998 increased $29,000 or 4% to $754,000 compared to
$725,000 for 1997 due to borrowings under Panterra's and the Company's credit
facilities.
Income Taxes. Income tax expense was $1.1 million in the second quarter 1998 and
$3.0 million in 1997, resulting in effective tax rates of 35.5% and 35.2%,
respectively. This reduced expense reflects lower net income from operations
before income taxes for 1998 due to lower oil prices, increased exploration and
DD&A expenses and a $4.2 million pre-tax gain on the sale of non-core properties
in south Texas in the second quarter 1997.
Income tax expense decreased $7.6 million to $1.9 million for the six months
ended June 30, 1998, primarily resulting from lower oil and gas prices,
increased exploration expense and DD&A expenses in 1998, and the $9.7 million
and $4.2 million gains on the sales of the Company's Russian joint venture and
non-core properties, respectively, in 1997. The effective tax rate for the six
months ended June 30, 1998 decreased to 33.8% compared to 35.6% in the 1997
period.
Net Income. Net income for the second quarter 1998 decreased $3.8 million or 65%
to $2.1 million compared to $5.9 million in 1997. Increases of 31% and 34% in
gas and oil volumes, respectively, partially offset by a 28% decrease in oil
prices resulted in a $4.9 million increase in oil and gas production revenues
for the second quarter 1998. A $4.2 million gain on the sale of non-core
properties in the second quarter 1997, increases in exploration expenses and
DD&A associated with increased production volumes and impairments of producing
properties in the second quarter 1998, contributed to a $3.6 million decrease in
income from continuing operations.
Net income for the six months ended June 30, 1998 decreased $13.7 million to
$3.7 million compared to $17.5 million in 1997. This decrease resulted from
increased oil and gas production, offset by lower oil and gas prices and
increases in exploration expense, DD&A and impairments of producing properties
in 1998, and from the $9.7 million gain on the sale of the Company's interest in
the Russian joint venture and the $4.2 million gain on the sale of the Company's
non-core south Texas properties in 1997.
16
Liquidity and Capital Resources
The Company's primary sources of liquidity are the cash provided by operating
activities, debt financing and access to the capital markets. The Company's cash
needs are for the acquisition, exploration and development of oil and gas
properties and for the payment of debt obligations, trade payables, stockholder
dividends and for the repurchase of the Company's common stock. The company
generally finances its exploration and development programs from internally
generated cash flow, bank debt and cash and cash equivalents on hand. The
Company continually reviews its capital expenditure budget based on changes in
cash flow and other factors.
Cash Flow. The Company's net cash provided by operating activities increased
$3.7 million or 16% to $27.4 million in the six months ended June 30, 1998
compared to $23.7 million in 1997. Increased receipts for oil and gas revenues
due to higher production volumes, despite reduced oil and gas prices, were
offset by increased payments for lease operating expenses and significantly
higher payments related to exploration expenses. Also, in the first half of 1997
the Company made a cash payment of approximately $1.6 million in satisfaction of
liabilities previously accrued by the Company under its SAR plan compared to a
corresponding payment of $351,000 in the first half 1998.
Net cash used in investing activities in the six months ended June 30, 1998
increased $15.4 million or 88% to $32.8 million compared to $17.4 million in
1997. This increase was primarily due to a $5.7 million increase in capital
expenditures for the Company's drilling programs in 1998, a $5.4 million
decrease in acquisition expenditures in 1998, $ 5.6 million in cash received
from the sale of the Company's Russian joint venture in the first quarter 1997
and $7.1 million received in 1997 from the sale of oil and gas properties. Total
first half 1998 capital expenditures, including acquisitions of oil and gas
properties, were $31.4 million compared to $31.1 million in 1997.
The Company was able to apply the majority of the proceeds from the sales of oil
and gas properties in 1997 to acquisitions of oil and gas properties in 1997
allowing tax-free exchanges of these properties for income tax purposes. In a
tax-free exchange of properties the tax basis of the sold property carries over
to the new property. Gains or losses for tax purposes are recognized by
amortization of the tax basis of the new property throughout its remaining life
or when the new property is sold or abandoned.
Net cash provided by financing activities was $2.9 million in the six month
period ended June 30, 1998 resulting from net borrowing of long-term debt and
payments of dividends to shareholders compared to net cash provided by financing
activities of $14.0 million in the comparable 1997 period. The Company received
$51.2 million from the sale of common stock and had a net reduction of
borrowings of $35.7 million in the first quarter of 1997. The Company increased
its quarterly dividend 25% to $.05 per share effective with the quarterly
dividend declared in January 1997 and paid in February 1997.
The Company had $4.5 million in cash and cash equivalents and working capital of
$3.6 million as of June 30, 1998 compared to $7.1 million of cash and cash
equivalents and working capital of $9.6 million at December 31, 1997. The
reduction in cash and cash equivalents is primarily the result of payments for
capital expenditures, property acquisitions and exploration expenses, and to
reduce debt levels. Working capital decreased due to the reduction in cash and
cash equivalents and decreased accounts receivable, primarily for oil and gas
sales due to price declines, offset by a smaller decrease in accounts payable
and accrued expenses resulting from drilling activity.
17
Credit Facility. On June 30, 1998, the Company entered into a new long-term
revolving credit agreement replacing its credit facility dated March 1, 1993 and
amended April 1, 1996. The new credit facility provides a maximum loan amount of
$200.0 million. The amount that may be borrowed from time to time will depend
upon the value of the Company's oil and gas properties and other assets. The
Company's borrowing base, which is redetermined annually, was increased from
$40.0 million to $60.0 million in February 1997 and further increased in May
1998 to $115.0 million based on increases in the Company's estimated net proved
reserves in 1996 and 1997. The initial accepted borrowing base is $40.0 million.
The maturity date of the new credit agreement is December 31, 2005, which
includes a revolving period maturing on December 31, 2000. The Company may elect
to allocate up to 50% of the available borrowings to a short-term tranche due in
364 days. Outstanding revolving loan balances under the Company's credit
facility, which were $19.2 million and $14.5 million at June 30, 1998 and
December 31, 1997, respectively, accrue interest at rates determined by the
Company's debt to total capitalization ratio. During the revolving period of the
loan, loan balances accrue interest at the Company's option of either (a) the
higher of the banks' prime rate or the Federal Funds Rate plus 1/2% or (b) LIBOR
plus 1/2% when the Company's debt to total capitalization is less than 30%, up
to a maximum of the Company's option of either (a) the higher of the banks'
prime rate plus 1/8% or the Federal Funds Rate plus 5/8% or (b) LIBOR plus
1-1/4% when the Company's debt to total capitalization ratio is equal to or
exceeds 50%. The credit facility provides for, among other things, covenants
requiring maintenance of stockholders' equity at a specified level and limits on
additional indebtedness of the Company.
Panterra, in which the Company has a 74% general partnership ownership interest,
has a separate credit facility with a $25.0 million borrowing base as of July 1,
1998, and $10.0 million and $11.0 million outstanding as of June 30, 1998 and
December 31, 1997, respectively. In June 1997, Panterra entered into a credit
agreement replacing a previous agreement, which was due March 31, 1999. The new
credit agreement includes a two-year revolving period converting to a five-year
amortizing loan on June 30, 1999. During the revolving period of the loan, loan
balances accrue interest at Panterra's option of either the bank's prime rate or
LIBOR plus 3/4% when the Partnership's debt to partners' capital ratio is less
than 30%, up to a maximum of either the bank's prime rate or LIBOR plus 1-1/4%
when the Partnership's debt to partners' capital ratio is greater than 100%. The
Company intends to use the available credit under the Panterra credit facility
to fund a portion of its 1998 capital expenditures in the Williston Basin.
Common Stock. In February 1997, the Company closed the sale of 2,000,000 shares
of common stock at $25.00 per share and closed the sale of an additional 180,000
shares in March 1997, pursuant to the underwriters' exercise of the
over-allotment option. These transactions resulted in aggregate net proceeds of
$51.2 million. The proceeds of these sales were used to fund the Company's
exploration, development and acquisition programs, and pending such use were
used to repay borrowings under its credit facility.
In June 1998, the Company's shareholders approved an increase in the number of
authorized shares of the Company's common stock from 15 million to 50 million
shares.
In August 1998, the Company's Board of Directors authorized a stock repurchase
program whereby the Company may purchase from time-to-time, in open market
purchases or negotiated sales, up to one million shares of its common stock.
Management anticipates that such purchases of shares by the Company may commence
at any time and will be funded with internal cash flow and borrowings under the
Company's credit facility.
Outlook. The Company believes that its existing capital resources, cash flow
from operations and available borrowings are sufficient to meet its anticipated
capital and operating requirements for 1998.
18
The Company has reduced its 1998 capital budget by approximately $11.0 million
to a revised total of approximately $83.0 million. The reduction reflects a
reallocation of capital to the Company's stock repurchase program as well as a
response to lower oil prices and drilling results. Reductions of $3.0 million
arise from postponement of new drilling activities in the Williston Basin due to
low oil prices; $4.0 million due to suspension, pending further evaluation, of a
previously scheduled second deep test at the Company's Atchafalaya prospect; and
$4.0 million from re-balancing of the drilling program in the Anadarko Basin to
emphasize less costly and lower risk prospects.
The amount and allocation of future capital and exploration expenditures will
depend upon a number of factors including the number of available acquisition
opportunities, the Company's ability to assimilate such acquisitions, the impact
of oil and gas prices on investment opportunities, the availability of capital
and the success of its development and exploratory activity which could lead to
funding requirements for further development.
The Company continuously evaluates opportunities in the marketplace for oil and
gas properties and, accordingly, may be a buyer or a seller of properties at
various times.
The Company has added several new prospects to its pipeline of large target
exploration ideas and expects to commence the drilling of three significant
tests by the first quarter of 1999 at its Patterson, Stallion and South
Horseshoe Bayou projects in South Louisiana.
Volatile industry conditions and several exploration disappointments early in
the year are combining to make 1998 a particularly challenging year for the
Company as it consolidates the rapid growth in reserves and production achieved
during the past several years. Modest continued growth in production volumes is
expected during the balance of the year as the Company's Atchafalaya discovery
is brought online in August and additional wells in the Mid-Continent and
ArkLaTex regions are completed
The St. Mary Land & Exploration No. 3 (40 percent net revenue interest) at South
Horseshoe Bayou was completed in January 1998 in the 17,300-foot sand and has
experienced increasing water production since early June. Cumulative gross
production to date totals approximately 6.6 BCF of gas and 47,000 barrels of
condensate (approximately 2.6 BCF of gas and 18,800 barrels of condensate net to
the Company). Through early August 1998 the well has continued to produce
approximately 34 MMCF of gas and 200 barrels of condensate per day. However,
water production has continued to increase and presently exceeds 900 barrels per
day. The cause of this water production is unknown and the well's production
trends are being closely monitored.
The net proved reserves assigned to the 17,300-foot sand in the No. 3 well at
year-end 1997 were 33.1 BCF of gas and 177,000 barrels of condensate. Although
to date the water production has not adversely affected the well's productive
capacity, the ultimate impact on the Company's production and reserves at South
Horseshoe Bayou can not be determined at this time. Should water production
continue to increase substantially, the No. 3 well's future production and
recoverable reserves could be materially impaired.
The Company's depreciation, depletion and amortization rate per BOE is expected
to be somewhat higher than historical amounts as the Atchafalaya production
comes online beginning in August 1998.
In May 1997, the Company entered into an agreement to receive a 55% interest in
Summo's Lisbon Valley Copper Project (the "Project") in return for the Company
contributing $4.0 million in cash, all of its outstanding stock in Summo, and
$8.6 million in letters of credit for development of the Project. The Company
has agreed to provide interim financing of up to $2.95 million for the Project
in the form of a loan to Summo due in June 1999. As of June 30, 1998, $2.65
million was outstanding under this loan. Additional amounts totaling $48,000
have been advanced to Summo under this loan since June 30, 1998. Any principal
and interest amounts outstanding are convertible into shares of Summo common
stock anytime after December 31, 1998 at the option of the Company. Upon
capitalization of the Project, the outstanding loan principal shall constitute a
19
capital contribution in partial satisfaction of the Company's capital
commitments set out in the May 1997 agreement. Future development and financial
success of the Project are largely dependent on the market price of copper,
which is determined in world markets and is subject to significant fluctuations.
Although current copper prices are not sufficient to warrant development of the
Project at this time, management believes the long-term outlook for copper
prices is favorable and plans to continue providing interim financing during
1998 until Summo receives final regulatory approval and copper prices recover
adequately to justify construction using permanent financing. There can be no
assurance that the Company will realize a return on its investment in Summo or
the Project.
In February 1997, the Company sold its Russian joint venture to KMOC. The
Company received approximately $5.6 million in cash consideration before
transaction costs, KMOC common stock valued at approximately $1.9 million, and a
receivable in a form equivalent to a retained production payment of
approximately $10.1 million plus interest at 10% per annum from the limited
liability company formed to hold the Russian joint venture interest. The
Company's receivable is collateralized by the partnership interest sold. The
Company has the right, subject to certain conditions, to require KMOC to
purchase the Company's receivable from the net proceeds of an initial public
offering of KMOC common stock or alternatively, the Company may elect to convert
all or a portion of its receivable into KMOC common stock immediately prior to
an initial public offering of KMOC common stock.
Impact of the Year 2000 Issue. The Year 2000 Issue is the result of computer
programs being written using two digits rather than four, or other methods, to
define the applicable year. Computer programs that have date-sensitive software
may recognize a date using "00" as the year 1900 rather than the year 2000. This
could result in a system failure or miscalculations causing disruptions of
operations, including, among other things, a temporary inability to process
transactions, send invoices or engage in similar normal business activities.
The Company has conducted a review of its computer systems and has determined
that the computer system used by Panterra will need to be replaced in order to
properly utilize dates beyond December 31, 1999. Panterra, after a review of
available replacement systems, is in contract negotiations to license a suitable
Year 2000 compliant system, and believes conversion can be completed, tested and
operational before December 31, 1999 at a cost that is not expected to have a
material effect on the Company's results of operations. If replacement of the
Panterra system is not completed timely, the Year 2000 Issue could have a
significant impact on the operations of Panterra. The Company presently believes
that other less significant systems can be upgraded to mitigate the Year 2000
Issue with modifications to existing software or conversions to new software.
Modifications or conversions to new software for the less significant systems,
if not completed timely, would have neither a material impact on the operations
of the Company nor on its results of operations.
The Company has initiated formal communications with its significant suppliers
and purchasers and transporters of oil and natural gas to determine the extent
to which the Company is vulnerable to those third parties' failure to remediate
their own Year 2000 Issues. There can be no guarantee that the systems of these
third parties will be converted timely, or that a failure to convert by another
company would not have a material adverse effect on the Company.
Accounting Matters
In February 1997, the Financial Accounting Standards Board ("FASB") issued
Statement of Financial Accounting Standards ("SFAS") No. 128, "Earnings Per
Share," which requires a dual presentation of basic and diluted earnings per
share. The Company adopted SFAS No. 128 effective December 31, 1997. Under SFAS
No. 128 basic net income per share of common stock is calculated by dividing net
income by the weighted average of common shares outstanding during each year,
and diluted net income per common share of common stock is calculated by
dividing net income by the weighted average of common shares and other dilutive
securities.
20
In June 1997, the FASB issued SFAS No. 130, "Reporting Comprehensive Income,"
effective for financial statements for fiscal years beginning after December 15,
1997. The Statement establishes standards for reporting and display of
comprehensive income and its components in financial statements. The adoption of
this statement will not have a material impact on the Company's financial
statements.
In June 1997, the FASB issued SFAS No. 131, "Disclosures about Segments of an
Enterprise and Related Information," effective for financial statements for
fiscal years beginning after December 15, 1997. The Statement requires companies
to report certain information about operating segments in their financial
statements and certain information about their products and services, the
geographic areas in which they operate and their major customers. The Company is
currently reviewing the effects of the disclosure requirements of the Statement.
In February 1998, The FASB issued SFAS No. 132, "Employer's Disclosures about
Pensions and Other Postretirement Benefits," effective for fiscal years
beginning after December 15, 1997. The Statement standardizes the disclosure
requirements for pensions and other postretirement benefits to provide
information that is more comparable and concise. The Company is currently
reviewing the effects of the disclosure requirements of the Statement.
In June 1998, the FASB issued SFAS No. 133, "Accounting for Derivative
Instruments and Hedging Activities," effective for all fiscal quarters of fiscal
years beginning after June 15, 1999. The Statement establishes accounting and
reporting standards for derivative instruments, including certain derivative
instruments embedded in other contracts, and for hedging activities. The Company
is currently reviewing the effects this Statement will have on the financial
statements in relation to the Company's hedging activities.
Effects of Inflation and Changing Prices
The Company's results of operations and cash flow are affected by changing oil
and gas prices. Within the United States inflation has had a minimal effect on
the Company. The Company cannot predict the extent of any such effect. If oil
and gas prices increase, there could be a corresponding increase in the cost to
the Company for drilling and related services, although offset by an increase in
revenues. Should oil and gas prices increase, the cost of acquisitions of
producing properties will increase, which could limit the Company's ability to
acquire properties that meet the Company's criteria.
During the first half of 1998 the Company experienced an increase in the cost to
the Company for drilling and related services resulting from shortages in
available drilling rigs, drilling and technical personnel, supplies and
services. However, since mid-year service costs appear to have stabilized or
begun to decline. If shortages persist, there could be continued increases in
the cost to the Company of exploration, drilling and production of oil and gas.
21
PART II. OTHER INFORMATION
Item 4. Submission of Matters to a Vote of Security Holders
At the Company's annual stockholders' meeting on June 3, 1998, the
shareholders approved management's current slate of directors,
approved the St. Mary Land & Exploration Company Employee Stock
Purchase Plan (adopted September 18, 1997 and previously submitted as
Exhibit 10.50), and approved an amendment to the Company's Certificate
of Incorporation to increase the number of authorized shares of Common
Stock from 15,000,000 to 50,000,000.
Item 6. Exhibits and Reports on Form 8-K
(a) Exhibits
Exhibit Description
------- -----------
3.3 Certificate of Amendment to Certificate
of Incorporation
27.6 Financial Data Schedule
10.52 Credit Agreement dated June 30, 1998
(b) There were no reports on Form 8-K filed during the quarter
ended June 30, 1998.
22
SIGNATURES
Pursuant to the requirements of the Securities and Exchange Act of 1934,
the Registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
St. Mary Land & Exploration Company
August 12, 1998 By /s/ MARK A. HELLERSTEIN
---------------------------
Mark A. Hellerstein
President and Chief Executive Officer
August 12, 1998 By /s/ DAVID L. HENRY
----------------------------
David L. Henry
Vice President - Finance and
Chief Financial Officer
August 12, 1998 By /s/ RICHARD C. NORRIS
---------------------------
Richard C. Norris
Vice President - Accounting and
Administration and Chief Accounting
Officer