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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, 1997 COMMISSION FILE NO. 0-25214
KELLEY OIL & GAS CORPORATION
(EXACT NAME OF REGISTRANT AS SPECIFIED IN ITS CHARTER)
DELAWARE 76-0082502
(STATE OR OTHER JURISDICTION OF (I.R.S. EMPLOYER
INCORPORATION OR ORGANIZATION) IDENTIFICATION NO.)
601 JEFFERSON ST.
SUITE 1100
HOUSTON, TEXAS 77002
(ADDRESS OF PRINCIPAL EXECUTIVE OFFICES) (ZIP CODE)
Registrant's telephone number, including area code: (713) 652-5200
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 issuer's
classes of common stock, as of the latest practicable date.
TITLE OF CLASS OUTSTANDING AT JULY 31, 1997
-------------- ----------------------------
Common Stock 98,556,094
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<PAGE>
KELLEY OIL & GAS CORPORATION AND SUBSIDIARIES
INDEX
PART I. FINANCIAL INFORMATION PAGE
----
Consolidated Balance Sheets as of June 30, 1997
(unaudited) and December 31, 1996 ...................................... 2
Consolidated Statements of Income (Loss) for the three
months and six months ended June 30, 1997 and 1996 (unaudited).......... 3
Consolidated Statements of Cash Flows for the six months ended
June 30, 1997 and 1996 (unaudited)...................................... 4
Notes to Consolidated Financial Statements (unaudited).................... 5
Management's Discussion and Analysis of Financial
Condition and Results of Operations..................................... 7
PART II. OTHER INFORMATION................................................. 11
1
<PAGE>
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
KELLEY OIL & GAS CORPORATION AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(IN THOUSANDS, EXCEPT SHARE DATA)
<TABLE>
<CAPTION>
JUNE 30, DECEMBER 31,
1997 1996
-------- ------
(UNAUDITED)
<S> <C> <C>
ASSETS:
Cash and cash equivalents.............................................$ 80 $ 4,070
Accounts receivable................................................... 17,472 22,519
Accounts receivable - drilling programs............................... 668 1,533
Prepaid expenses and other current assets............................. 1,228 1,347
-------- --------
Total current assets................................................ 19,448 29,469
-------- --------
Oil and gas properties, successful efforts method:
Unproved properties, net............................................ 10,712 12,521
Properties subject to amortization.................................. 362,306 338,794
Pipelines and other transportation assets, at cost ................... 4,689 4,689
Furniture, fixtures and equipment..................................... 2,089 1,700
-------- --------
379,796 357,704
Less: Accumulated depreciation, depletion and amortization...........(211,301) (199,236)
-------- --------
Total property and equipment, net................................... 168,495 158,468
-------- --------
Other non-current assets, net......................................... 1,455 1,290
-------- --------
TOTAL ASSETS........................................................$189,398 $189,227
======== ========
LIABILITIES:
Accounts payable and accrued expenses.................................$ 28,952 $ 31,093
Accounts payable - drilling programs.................................. 689 4,416
-------- --------
Total current liabilities........................................... 29,641 35,509
-------- --------
Long term debt........................................................ 194,216 184,253
-------- --------
TOTAL LIABILITIES................................................... 223,857 219,762
-------- --------
STOCKHOLDERS' DEFICIT:
Preferred stock, $1.50 par value, 20,000,000 shares
authorized at June 30, 1997 and December 31, 1996;
1,745,431 and 1,745,500 shares outstanding at
June 30, 1997 and December 31, 1996, respectively
(liquidation value at June 30, 1997 and December 31, 1996
of $45,927 and $48,219, respectively)............................... 2,618 2,618
Common stock, $.01 par value, 200,000,000 shares authorized
at June 30, 1997 and December 31, 1996, respectively;
98,495,094 and 98,293,458 shares outstanding at June 30, 1997
and December 31, 1996, respectively................................. 985 983
Additional paid-in capital............................................ 273,297 273,096
Accumulated deficit...................................................(311,359) (307,232)
-------- --------
TOTAL STOCKHOLDERS' DEFICIT......................................... (34,459) (30,535)
-------- --------
TOTAL LIABILITIES AND STOCKHOLDERS' DEFICIT...........................$189,398 $189,227
======== ========
</TABLE>
See Notes to Consolidated Financial Statements.
2
<PAGE>
KELLEY OIL & GAS CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME (LOSS)
(IN THOUSANDS, EXCEPT PER SHARE DATA)
(UNAUDITED)
<TABLE>
<CAPTION>
THREE MONTHS ENDED SIX MONTHS ENDED
JUNE 30, JUNE 30,
--------------------- ---------------------
1997 1996 1997 1996
-------- -------- -------- --------
<S> <C> <C> <C> <C>
Oil and gas revenues...........................$ 15,642 $ 12,619 $ 34,040 $ 25,323
Gas marketing revenues, net.................... 536 314 1,085 708
Interest and other income...................... 71 215 234 529
-------- -------- -------- --------
Total revenues............................... 16,249 13,148 35,359 26,560
-------- -------- -------- --------
Production expenses............................ 2,561 2,595 4,931 5,167
Exploration costs.............................. 833 1,413 1,882 3,053
General and administrative expenses............ 1,807 2,193 3,987 4,826
Interest and other debt expenses............... 6,211 5,911 12,039 12,309
Restructuring expense.......................... -- 2,000 -- 2,000
Depreciation, depletion and amortization....... 6,085 3,872 12,065 9,553
-------- -------- -------- --------
Total expenses............................... 17,497 17,984 34,904 36,908
-------- -------- -------- --------
Net income (loss) before income taxes.......... (1,248) (4,836) 455 (10,348)
Income taxes................................... -- -- -- --
-------- -------- -------- --------
Net income (loss).............................. (1,248) (4,836) 455 (10,348)
Less: Preferred stock dividends................ (4,582) -- (4,582) --
--------- -------- -------- --------
Net loss applicable to common stock............$ (5,830) $ (4,836) $ (4,127) $(10,348)
======== ======== ======== ========
Loss per share:
Primary and assuming full dilution:
Net loss...................................$ (.06) $ (.05) $ (.04) $ (.13)
======== ======== ======== ========
Average common and common equivalent shares
outstanding:
Primary and assuming full dilution........... 98,338 95,391 98,316 81,848
</TABLE>
See Notes to Consolidated Financial Statements.
3
<PAGE>
KELLEY OIL & GAS CORPORATION AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(IN THOUSANDS)
(UNAUDITED)
<TABLE>
<CAPTION>
SIX MONTHS ENDED JUNE 30,
------------------------
1997 1996
--------- ---------
<S> <C> <C>
OPERATING ACTIVITIES:
Net income (loss)....................................................$ 455 $(10,348)
Adjustments to reconcile net income (loss) to net cash
provided by (used in) operating activities:
Depreciation, depletion and amortization........................... 12,065 9,553
Dry hole and impairment costs...................................... -- 201
Accretion and amortization of debt expenses........................ 2,128 2,684
Restructuring expense.............................................. -- 1,716
Changes in operating assets and liabilities:
Decrease (increase) in accounts receivable......................... 5,912 (1,708)
Decrease (increase) in prepaid expenses and other current assets... 119 (1,313)
Increase in other non-current assets............................... (330) (1,629)
Decrease in accounts payable and accrued expenses.................. (5,868) (4,297)
-------- --------
Net cash provided by (used in) operating activities.................. 14,481 (5,141)
-------- --------
INVESTING ACTIVITIES:
Capital expenditures................................................. (22,092) (16,346)
Proceeds from sale of equipment...................................... -- 293
-------- --------
Net cash used in investing activities................................ (22,092) (16,053)
-------- --------
FINANCING ACTIVITIES:
Proceeds from long term borrowings................................... 42,000 8,000
Principal payments on long term borrowings........................... (34,000) (30,000)
Proceeds from sale of common stock, net.............................. 203 43,961
Dividends on preferred stock......................................... (4,582) --
-------- --------
Net cash provided by financing activities............................ 3,621 21,961
-------- --------
Increase (decrease) in cash and cash equivalents....................... (3,990) 767
Cash and cash equivalents, beginning of period......................... 4,070 6,352
-------- --------
Cash and cash equivalents, end of period...............................$ 80 $ 7,119
======== ========
</TABLE>
See Notes to Consolidated Financial Statements.
4
<PAGE>
KELLEY OIL & GAS CORPORATION AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)
NOTE 1 - BASIS OF PRESENTATION
The accompanying unaudited interim consolidated financial statements of
Kelley Oil & Gas Corporation (the "Company") have been prepared by the Company
pursuant to the rules and regulations of the Securities and Exchange Commission
in accordance with generally accepted accounting principles for interim
financial information. These financial statements reflect all adjustments
(consisting of normal recurring adjustments) necessary for a fair statement in
all material respects of the results for the interim periods presented. The
results of operations for the periods ended June 30, 1997 are not necessarily
indicative of results to be expected for the full year. The accounting policies
followed by the Company are set forth in Note 1 to the financial statements in
its Annual Report on Form 10-K for the year ended December 31, 1996. These
unaudited consolidated interim financial statements should be read in
conjunction with the audited financial statements and notes thereto included in
the Company's 1996 Annual Report on Form 10-K.
Certain 1996 financial statement items have been reclassified to conform
to the 1997 presentation.
NOTE 2 - PREFERRED STOCK
In January 1996, the Company suspended the payment of the quarterly
dividend on its $2.625 Convertible Exchangeable Preferred Stock (the "Preferred
Stock") scheduled for February 1, 1996. On April 15, 1997, the Board of
Directors of the Company declared a dividend of $2.625 per preferred share
(approximately $4.6 million) which was paid on May 1, 1997. Future dividends on
the Preferred Stock are prohibited under the Company's existing credit facility.
As of June 30, 1997, $2.3 million or $1.31 per share in dividends were in
arrears, increasing the total liquidation value to $45.9 million or $26.31 per
share.
NOTE 3 - EARNINGS PER SHARE
In February 1997, the Financial Accounting Standards Board issued
Statement of Financial Accounting Standards No. 128 ("SFAS 128") "Earnings Per
Share." SFAS 128 establishes standards for computing and presenting earnings per
share ("EPS") and applies to entities with publicly held common stock or
potential common stock. This statement simplifies the standards for computing
EPS previously found in Accounting Principles Board Opinion No. 15, "Earnings
Per Share," and makes them comparable to international EPS standards. This
statement is effective for financial statements issued for periods ending after
December 15, 1997, including interim periods; earlier application is not
permitted. This statement requires restatement of all prior-period EPS data
presented. Considering the guidelines as prescribed by SFAS 128, management
believes that the adoption of this statement will not have a material effect on
EPS and thus pro forma EPS, as suggested for all interim and annual periods
prior to required adoption, have been omitted.
NOTE 4 - LEGAL PROCEEDINGS
As previously disclosed, following Kelley Oil's announcement of the
initial proposal for the consolidation in August 1994, four separate lawsuits
were filed against Kelley Oil and its directors relating to the consolidation.
In November 1994, Kelley Oil entered into a memorandum of understanding with the
plaintiffs in three of the lawsuits, providing for a proposed settlement based
on a revised consolidation proposal negotiated by a special committee of Kelley
Oil's non-management directors and the settling plaintiffs. A stipulation and
agreement of compromise, settlement and release reflecting the terms of the
proposed settlement was filed in the United States District Court for the
Southern District of Texas on November 23, 1994. At a hearing held on the same
date, the court approved the consolidation of all four lawsuits and the
certification of a Unitholder class requested by the settling parties. On March
3, 1995, following a hearing on the fairness of the settlement, the court
entered a final order approving the settlement, dismissing the consolidated
lawsuits with prejudice and reducing the award of attorneys' fees and
5
<PAGE>
disbursements contemplated by the stipulation to $1.5 million, plus interest
from March 3, 1995 through the payment date. On April 29, 1997, the U.S. Court
of Appeals for the Fifth Circuit affirmed the final judgment and order of the
District Court. On August 4, 1997, the Company made a cash payment of $1.7
million which included $0.2 million of interest (fully accrued at June 30,
1997).
6
<PAGE>
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS
GENERAL
INTRODUCTION. Kelley Oil & Gas Corporation and its consolidated
subsidiaries (the "Company") are engaged in oil and natural gas exploration,
development, production and acquisition. The Company's activities are
concentrated primarily in two geographic areas: north Louisiana and south
Louisiana. The Company's core natural gas properties in north Louisiana are
located in the Sailes, Sibley, West Bryceland and Ada fields of Webster and
Bienville Parishes, while its core properties in south Louisiana are
concentrated in Terrebonne Parish. Production is primarily from the Hosston
(north Louisiana) and Miocene (south Louisiana) formations.
HEDGING ACTIVITIES. The Company periodically has used forward sales
contracts, natural gas swap agreements and options to reduce exposure to
downward price fluctuations on its natural gas production. The swap agreements
generally provide for the Company to receive or make counterparty payments on
the differential between a fixed price and a variable indexed price for natural
gas. Gains and losses realized by the Company from hedging activities are
included in oil and gas revenues and average sales prices. The Company's hedging
activities also cover the oil and gas production attributable to the interest in
such production of the public unitholders in its subsidiary partnerships.
Through natural gas swap agreements, approximately 64% and 65% of the Company's
natural gas production for the second quarter of 1997 and first half of 1997,
respectively, were affected by its hedging transactions at an average NYMEX
quoted price of $2.31 per MMBtu and $2.44 per MMBtu, respectively, before
transaction and transportation costs. As of June 30, 1997, approximately 43% of
the Company's anticipated natural gas production for the remainder of 1997 had
been hedged by natural gas swap agreements at an average NYMEX quoted price of
$2.19 per MMBtu before transaction and transportation costs. Hedging activities
increased revenues by approximately $0.9 million in the second quarter of 1997
and reduced revenues by approximately $1.3 million in the first half of 1997, as
compared to estimated revenues had no hedging activities been conducted. At June
30, 1997, the fair market value of the Company's existing hedging instruments
for future production months approximated $0.2 million.
The credit risk exposure from counterparty nonperformance on natural gas
forward sales contracts and derivative financial instruments is generally the
amount of unrealized gains under the contracts. The Company has not experienced
counterparty nonperformance on these agreements and does not anticipate any in
future periods.
RESULTS OF OPERATIONS
The following table sets forth certain operating data regarding net
production, average sales prices, production expenses and revenues associated
with the Company's oil and natural gas operations for the periods indicated.
<TABLE>
<CAPTION>
THREE MONTHS ENDED SIX MONTHS ENDED
JUNE 30, JUNE 30,
------------------ ------------------
1997 1996 1997 1996
-------- ------- ------- -------
<S> <C> <C> <C> <C>
NET PRODUCTION DATA:
Oil and other liquid hydrocarbons (Mbbls)........... 54 55 101 120
Natural gas (Mmcf).................................. 7,225 5,036 14,301 9,904
Natural gas equivalent (Mmcfe)...................... 7,549 5,366 14,907 10,624
AVERAGE SALES PRICE PER UNIT:
Oil and other liquid hydrocarbons (per Bbl).........$ 19.37 $ 23.21 $ 20.25 $ 21.34
Natural gas (per Mcf)............................... 2.02 2.25 2.24 2.32
Natural gas equivalent (per Mcfe)................... 2.07 2.35 2.28 2.40
COST PER MCFE:
Lifting costs.......................................$ .23 $ .39 $ .22 $ .38
Severance taxes and ad valorem taxes................ .11 .10 .11 .10
General and administrative expenses................. .24 .41 .27 .45
Depreciation, depletion and amortization
(oil and gas activities)........................... .80 .71 .80 .89
Interest expense, excluding accretion
and amortization.................................. .68 .87 .67 .91
</TABLE>
7
<PAGE>
THREE MONTHS ENDED JUNE 30, 1997 AND 1996. The Company's oil and gas
revenues of $15.6 million for the second quarter of 1997 increased 24% compared
to $12.6 million in the same period of 1996 primarily as a result of an increase
in gas production of 43%, partially offset by decreases in both gas and oil
prices of 10% and 17%, respectively. The increase in gas production is primarily
due to the Company's drilling activities in north Louisiana somewhat offset by
the sale to Williams Production - Gulf Coast Company, L.P. ("Williams") of
one-half of its interest in 23 wells and related facilities in the Houma
Embayment in Terrebonne Parish, Louisiana in the fourth quarter of 1996.
For the second quarter of 1997, revenues from natural gas marketing, net
of cost of gas sold, increased 67% to $0.5 million from $0.3 million for the
same period in 1996.
Production expenses for the second quarter of 1997 remained level with
same period last year at $2.6 million. Lifting costs (production expenses less
ad valorem and severance taxes) per Mcfe for the second quarter of 1997
decreased 41% from the same period last year to $0.23. This primarily reflects
lower average costs on new production in north Louisiana relative to existing
production.
Exploration costs totaled $0.8 million in the second quarter of 1997 and
$1.4 million in the corresponding period of 1996, a decrease of 43%, primarily
the result of a reduction in lease rental expense reflecting the joint
exploration agreement effective December 1996 in south Louisiana with Williams.
General and administrative expenses of $1.8 million in the second
quarter of 1997 decreased 18% compared to $2.2 million in the corresponding
period last year, reflecting efficiencies obtained in the realignment of the
workforce. This decrease is somewhat offset by a reduction in 1997 in the level
of general and administrative expenses either being capitalized or allocated to
exploration expense. On a unit basis, general and administrative expenses were
$0.24 per Mcfe in the second quarter of 1997 compared to $0.41 per Mcfe in the
corresponding quarter of 1996.
Interest and other debt expenses of $6.2 million in the current quarter
increased 5% from $5.9 million in the same period of 1996. The increase in
interest expense resulted primarily from interest accrued in the second quarter
of 1997 related to the settlement of a lawsuit and higher average debt
outstanding. These were partially offset by lower effective interest rates under
the 10 3/8% Senior Subordinated Notes than under the 13 1/2% Senior Notes
retired in October 1996, and lower debt amortization expenses as a result of the
refinancing of the 13 1/2% Senior Notes and the bank credit facility. See
"Liquidity and Capital Resources." In addition to its second quarter 1997
interest expense of $5.2 million, the Company recorded non-cash charges in the
second quarter of 1997 of $0.3 million for amortization of debt issuance costs,
$0.2 million for accretion of note discount and $0.5 million for accretion of
debt valuation discount.
Restructuring expense in the second quarter of 1996 was $2.0 million.
There was no restructuring expense in the second quarter of 1997.
Depreciation, depletion and amortization ("DD&A") increased 56% from
$3.9 million in the second quarter of 1996 to $6.1 million in the current
period, primarily as a result of higher second quarter 1997 production and an
adjustment to first quarter 1996 DD&A expense that was recorded in the second
quarter of 1996.
The Company recognized a net loss of $1.2 million in the second quarter
of 1997 and a net loss of $4.8 million in the same period last year. The reasons
for the earnings improvement are described in the foregoing discussion.
SIX MONTHS ENDED JUNE 30, 1997 AND 1996. The Company's oil and gas
revenues of $34.0 million for the first half of 1997 increased 34% compared to
$25.3 million in the same period of 1996 primarily as a result of an increase in
gas production (44%), partially offset by lower gas prices (3%) and oil
production (16%). The increase in gas production is primarily due to the
Company's drilling activities in north Louisiana somewhat offset by the sale to
Williams of one-half of its interest in 23 wells and related facilities in the
Houma Embayment in Terrebonne Parish, Louisiana in the fourth quarter of 1996.
For the first six months of 1997, revenues from natural gas marketing,
net of cost of gas sold, increased 57% to $1.1 million from $0.7 million for the
same period in 1996.
8
<PAGE>
Production expenses for the first six months of 1997 decreased 6% to
$4.9 million from $5.2 million in the same period last year, primarily
reflecting lower average costs on north Louisiana production, which is
increasing in proportion to other higher cost production, partially offset by
higher overall production levels. On a unit basis, lifting costs decreased to
$0.22 per Mcfe in the first six months of 1997 compared to $0.38 per Mcfe in the
corresponding period last year.
Exploration costs totaled $1.9 million in the first half of 1997 and
$3.1 million in the corresponding period of 1996, a decrease of 39%, primarily
the result of a reduction in lease rental expense reflecting the joint
exploration agreement effective December 1996 in south Louisiana with Williams.
General and administrative expenses of $4.0 million in the first six
months of 1997 decreased 17% compared to $4.8 million in the corresponding
period last year, reflecting efficiencies obtained in the realignment of the
workforce. This decrease is somewhat offset by a reduction in 1997 in the level
of general and administrative expenses either being capitalized or allocated to
exploration expense. On a unit basis, general and administrative expenses were
$0.27 per Mcfe in the first half of 1997 compared to $0.45 per Mcfe in the
corresponding period of 1996.
Interest and other debt expenses of $12.0 million in the first half of
1997 decreased 2% from $12.3 million in the same period of 1996. The decrease in
interest expense resulted primarily from lower interest rates under the 10 3/8%
Senior Subordinated Notes than under the 13 1/2% Senior Notes retired in October
1996, and lower debt amortization expenses as a result of the refinancing of the
13 1/2% Senior Notes and the bank credit facility. These were partially offset
by higher average debt levels during the current period and the accrual of
interest in the first half of 1997 related to the settlement of a lawsuit. See
"Liquidity and Capital Resources." In addition to its 1997 interest expense of
$9.9 million, the Company recorded non-cash charges in the first six months of
1997 of $0.6 million for amortization of debt issuance costs, $0.5 million for
accretion of note discount and $1.0 million for accretion of debt valuation
discount.
Restructuring expense in the first half of 1996 was $2.0 million. There
was no restructuring expense in the first half of 1997.
Depreciation, depletion and amortization ("DD&A") increased 26% from
$9.6 million in the first six months of 1996 to $12.1 million in the current
period, primarily as a result of higher first half 1997 production which was
partially offset by a reduction in the units-of-production DD&A rate for oil and
gas activities from $0.89 per Mcfe in the first half of 1996 to $0.80 per Mcfe
in the current period.
The Company recognized net income of $0.5 million in the first six
months of 1997 and a net loss of $10.3 million in the same period last year. The
reasons for the earnings improvement are described in the foregoing discussion.
The results of operations for the quarter and six months ended June 30,
1997 are not necessarily indicative of results to be expected for the full year.
LIQUIDITY AND CAPITAL RESOURCES
LIQUIDITY. Net cash provided by operating activities, before working
capital adjustments, during the first six months of 1997 aggregated $14.6
million. Funds used in investing activities were comprised of capital
expenditures of $22.1 million. Funds provided by financing activities were
comprised primarily of net principal borrowings of $8.0 million on the bank
credit facility, partially offset by the payment of $4.6 million of preferred
stock dividends. As a result of these activities, cash and cash equivalents
decreased from $4.1 million at December 31, 1996 to $0.1 million as of June 30,
1997. As of June 30, 1997, the Company had a working capital deficit of $10.2
million, compared to a working capital deficit of $6.0 million at the end of
1996. The balance of the working capital deficit will be funded through
operations and/or bank borrowings under existing lines of credit.
CAPITAL RESOURCES. The credit facility provides for a maximum $125
million revolving credit loan and matures, with all amounts owed thereunder
becoming due and payable, effective December 12, 2000. Borrowings under the
9
<PAGE>
credit facility are subject to a borrowing base to be determined semi-annually
by the lenders (based in part on the proved oil and gas reserves and other
assets of the Company) which may be redetermined more frequently at the election
of the lenders or the borrowers. Initially, the borrowing base was $57.5
million. On May 20, 1997, the borrowing base was increased to $70.0 million. At
June 30, 1997, $21.5 million was outstanding under the credit facility.
At June 30, 1997, the Company had $208.2 million face amount of debt
outstanding, requiring $19.7 million in annual cash interest payments. The
outstanding Preferred Stock is cumulative, requiring dividends to accumulate at
the rate of $4.6 million annually, and carries liquidation preferences over the
Common Stock totaling $45.9 million at June 30, 1997, including such dividend
arrearages. On April 15, 1997, the Board of Directors of the Company declared a
dividend of $2.625 per preferred share (approximately $4.6 million), which was
paid on May 1, 1997. The Company has not declared the quarterly dividends of
$0.65625 for February 1, 1997 and May 1, 1997, aggregating approximately $2.3
million. Further dividends are prohibited under the existing credit facility.
Pursuant to the second stage of Contour's equity investment in the
Company, Contour has committed to provide an additional $27.0 million in equity
financing upon satisfaction of certain conditions, including the absence of any
Company debt repurchase or redemption obligations, but in no event later than
January 2000. While exercise of such commitment cannot be assured prior to
January 2000, any proceeds received pursuant to such commitment will reduce the
Company's dependence on outside financing to support subsequent drilling and
acquisition activities.
CAPITAL COMMITMENTS. The Company's 1997 capital expenditure budget
provides for $36.4 million to be expended primarily on development drilling in
north Louisiana. In the first six months of 1997, the Company participated in
drilling 43 gross (18.13 net) wells, all of which were completed and found to be
productive. The 1997 drilling performance reflects lower risk operations in
north Louisiana and exploratory successes in south Louisiana. The Company, with
its partner, continues to explore in south Louisiana under an agreement which
allows it to retain exposure to this prolific region while minimizing the
capital cost associated with exploration. As of the end of the quarter, the
Company was participating in the drilling/completing of 15 gross (5.24 net)
wells.
In addition, the Company has an active program for ongoing evaluation of
opportunities meeting its acquisition criteria. There can be no assurance that
attractive acquisition candidates will be available to the Company on terms it
deems reasonable or that any completed acquisition will ultimately prove to be a
successful undertaking by the Company.
The Company anticipates that, except for any significant property
acquisitions, business combinations or development required by exploratory
success (and subject to price stability), cash flow from operations and
borrowings under the revolving credit facility will be adequate to fund its debt
service obligations, expected capital expenditure requirements and working
capital needs for the foreseeable future. To fully realize the Company's
objectives for property development and acquisitions, however, it may be
required to pursue additional financing alternatives.
INFLATION AND CHANGING PRICES. Oil and natural gas prices, as with most
commodities, are highly volatile, have fluctuated during recent years and
generally have not followed the same pattern as inflation.
FORWARD-LOOKING STATEMENTS
FROM TIME TO TIME, THE COMPANY MAY PUBLISH 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, RELATING TO
MATTERS SUCH AS ANTICIPATED OPERATING AND FINANCIAL PERFORMANCE, BUSINESS
PROSPECTS, DEVELOPMENTS AND RESULTS OF THE COMPANY. ACTUAL PERFORMANCE,
PROSPECTS, DEVELOPMENTS AND RESULTS MAY DIFFER MATERIALLY FROM ANY OR ALL
ANTICIPATED RESULTS DUE TO ECONOMIC CONDITIONS AND OTHER RISKS, UNCERTAINTIES
AND CIRCUMSTANCES PARTLY OR TOTALLY OUTSIDE THE CONTROL OF THE COMPANY,
INCLUDING RATES OF INFLATION, NATURAL GAS PRICES, RESERVE ESTIMATES, RATES AND
TIMING OF FUTURE PRODUCTION OF OIL AND GAS, AND CHANGES IN THE LEVEL AND TIMING
OF FUTURE COSTS AND EXPENSES RELATED TO DRILLING AND OPERATING ACTIVITIES.
10
<PAGE>
WORDS SUCH AS "ANTICIPATED," "EXPERT," "ESTIMATE," "PROJECT" AND SIMILAR
EXPRESSIONS ARE INTENDED TO IDENTIFY FORWARD-LOOKING STATEMENTS. FORWARD-LOOKING
STATEMENTS MAY BE MADE IN MANAGEMENT'S STATEMENTS (ORALLY OR IN WRITING)
INCLUDING PRESS RELEASES, AND IN FILINGS OF THE SEC, INCLUDING THIS REPORT.
PART II. OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
As previously reported, following Kelley Oil's announcement of the
initial proposal for the consolidation in August 1994, four separate lawsuits
were filed against Kelley Oil and its directors relating to the consolidation.
In November 1994, Kelley Oil entered into a memorandum of understanding with the
plaintiffs in three of the lawsuits, providing for a proposed settlement based
on a revised consolidation proposal negotiated by a special committee of Kelley
Oil's non-management directors and the settling plaintiffs. A stipulation and
agreement of compromise, settlement and release reflecting the terms of the
proposed settlement was filed in the United States District Court for the
Southern District of Texas on November 23, 1994. At a hearing held on the same
date, the court approved the consolidation of all four lawsuits and the
certification of a Unitholder class requested by the settling parties. On March
3, 1995, following a hearing on the fairness of the settlement, the court
entered a final order approving the settlement, dismissing the consolidated
lawsuits with prejudice and reducing the award of attorneys' fees and
disbursements contemplated by the stipulation to $1.5 million, plus interest
from March 3, 1995 through the payment date. On April 29, 1997, the U.S. Court
of Appeals for the Fifth Circuit affirmed the final judgment and order of the
District Court. On August 4, 1997, the Company made a cash payment of $1.7
million which included $0.2 million of interest (fully accrued at June 30,
1997).
ITEM 3. ARREARAGES IN PAYMENT OF DIVIDENDS
On April 15, 1997, the Company's Board of Directors declared a dividend
of $2.625 per share applicable to dividends for 1996 on its $2.625 Convertible
Exchangeable Preferred Stock to stockholders of record as of April 25, 1997,
which was paid May 1, 1997. The Company has not declared the quarterly dividends
of $0.65625 for February 1, 1997 and May 1, 1997, aggregating approximately $2.3
million.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
On May 29, 1997, the Company held its annual meeting of shareholders.
All of the incumbent directors listed in the Company's proxy statement for the
meeting were reelected. The number of votes cast for and against each nominee
are set forth below:
VOTES FOR VOTES WITHHELD
---------- --------------
John F. Bookout...................................91,445,354 1,231,470
John J. Conklin, Jr...............................91,559,126 1,117,698
Ralph P. Davidson.................................91,492,735 1,184,089
William J. Murray.................................91,522,643 1,154,181
Ogden M. Phipps...................................91,593,732 1,083,092
Michael B. Rothfeld...............................91,586,075 1,090,749
Ward W. Woods.....................................91,592,266 1,084,558
11
<PAGE>
The shareholders also approved the Company's 1997 Annual and Long-Term
Incentive-Performance Plan at the annual meeting. The number of votes cast are
set forth below:
VOTES FOR VOTES AGAINST VOTES ABSTAINED NO VOTE
---------- ------------- --------------- ---------
84,575,002 3,867,144 496,996 3,737,682
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits:
EXHIBIT
NUMBER EXHIBIT
------- -------
27 Financial Data Schedule (included only in the electronic
filing of this document)
(b) Reports on Form 8-K:
No reports on Form 8-K were filed by the Registrant during the
second quarter of 1997.
12
<PAGE>
SIGNATURES
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.
KELLEY OIL & GAS CORPORATION
Date: August 13, 1997 By: /s/ DAVID C. BAGGETT
David C. Baggett
Senior Vice President and
Chief Financial Officer
(Duly Authorized Officer)
(Principal Financial Officer)
13
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