PROSPECTUS SUPPLEMENT DATED FEBRUARY 22, 2002 TO PROSPECTUS DATED JUNE 21, 1999
Filed Pursuant to Rule 424(b)(5)
File No. 333-67667
[KEY ENERGY SERVICES, INC. LOGO]
477,043 SHARES
KEY ENERGY SERVICES, INC.
COMMON STOCK
----------------------
This prospectus relates to 477,043 shares of our common stock issued in
connection with the acquisition of substantially all of the assets of Mosley
Well Service, L.L.C. The terms of this acquisition were determined by direct
negotiations with the owners of the business, and the shares of common stock
issued are valued at prices reasonably related to current market prices. Our
common stock is listed on the New York Stock Exchange under the symbol "KEG."
The last reported sale price of our common stock on February 21, 2002 was $8.50
per share.
We will pay all expenses of this offering. No underwriting discounts or
commissions will be paid in connection with the issuance of common stock in
business combination transactions or acquisitions, although finder's fees may be
paid with respect to specific acquisitions. Any person receiving a finder's fee
may be deemed to be an underwriter within the meaning of Section 2(11) of the
Securities Act of 1933.
INVESTING IN OUR COMMON STOCK INVOLVES RISKS. SEE "RISK FACTORS" ON PAGE
S-2 OF THIS PROSPECTUS SUPPLEMENT AND PAGE 6 OF THE PROSPECTUS DATED JUNE 21,
1999.
Neither the Securities and Exchange Commission nor any state securities
commission has approved or disapproved of these securities or passed upon the
adequacy or accuracy of this prospectus supplement or the prospectus. Any
representation to the contrary is a criminal offense.
The date of this prospectus supplement is February 22, 2002
TABLE OF CONTENTS
PROSPECTUS SUPPLEMENT
Page
The Offering S-1
Risk Factors S-2
Use Of Proceeds S-4
Price Range Of Common Stock And Dividend Policy S-4
Selected Financial Data S-5
Cautionary Note Regarding Forward-Looking Statements S-6
Management's Discussion And Analysis Of Financial Condition And Results Of Operations S-6
Liquidity and Capital Resources S-12
Interest Rate Risk S-14
Foreign Currency Risk S-14
Commodity Price Risk S-14
Business S-15
Management S-22
Certain Relationships And Related Transactions S-29
Ownership Of Capital Stock S-29
Plan Of Distribution S-31
Legal Matters S-31
Experts S-31
Index to Consolidated Financial Statements F-1
PROSPECTUS
Where You Can Find More Information 3
Key Energy Services, Inc. 4
The Offering 4
Ratio of Earnings of Fixed Charges 5
Forward-Looking Statements 6
Risk Factors 6
Acquisition Terms 11
Selling Security Holders and Plan of Distribution 12
Description of Debt Securities 13
Description of Capital Stock 17
Description of Warrants 18
Legal Matters 18
Experts 19
-----------------------------
You should rely only on the information contained in this prospectus and
prospectus supplement. We have not authorized anyone to provide you with
information that is different. This prospectus supplement and the prospectus may
only be used where it is legal to sell these securities. The information in this
prospectus and prospectus supplement is only accurate as of the date of this
document.
i
THE OFFERING
Common stock offered........................ 477,043 shares
Common stock to be outstanding
after the Offering (1)...................... 108,587,238 shares
Use of proceeds............................. The shares of common stock offered by this prospectus are being
issued in exchange for substantially all the assets of Mosley Well
Service, L.L.C. The Company intends to use the assets in the
operation of its business. The Company will not receive any cash
proceeds in exchange for issuance of the shares.
New York Stock Exchange symbol............. KEG
(1) Based on 108,110,195 shares of common stock outstanding as of February
21, 2002. Excludes shares of common stock reserved for future issuance
S-1
RISK FACTORS
YOUR INVESTMENT IN THE NOTES WILL INVOLVE RISK. YOU SHOULD CAREFULLY
CONSIDER THE FOLLOWING RISK FACTORS AND THE OTHER INFORMATION SET FORTH OR
INCORPORATED BY REFERENCE IN THIS PROSPECTUS BEFORE DECIDING TO PURCHASE ANY
NOTES.
RISKS RELATING TO OUR BUSINESS
OUR BUSINESS IS DEPENDENT ON CONDITIONS IN THE OIL AND GAS INDUSTRY, ESPECIALLY
THE CAPITAL EXPENDITURES OF OIL AND NATURAL GAS COMPANIES.
The demand for our services is primarily influenced by current and
anticipated oil and natural gas prices. Prices for oil and natural gas
historically have been extremely volatile and have reacted to changes in the
supply of and demand for oil and natural gas (including changes resulting from
the ability of the Organization of Petroleum Exporting Countries to establish
and maintain production quotas for oil prices), domestic and worldwide economic
conditions and political instability in oil producing countries. Weakness in oil
and natural gas prices may cause lower day rates and lower utilization of
available well service equipment. In addition when oil and natural gas prices
are weak, fewer wells are drilled, resulting in less drilling and less
maintenance work for us. Additional factors that effect demand for our services
include:
- the level of development, exploration and production activity of,
and corresponding spending by, oil and natural gas companies;
- oil and natural gas production costs;
- government regulation; and
- conditions in the worldwide oil and natural gas industry.
In addition, we anticipate prices for oil and natural gas will continue
to be volatile and affect the demand for and pricing of our services. Reductions
in oil and natural gas prices can result in a reduction in the trading prices
and value of our common stock, even if the reduction in oil and natural gas
prices does not affect our business generally. However, a material decline in
oil or natural gas prices or activities over a sustained period of time could
materially adversely affect the demand for our services and, therefore, our
results of operations and financial condition.
Periods of diminished or weakened demand for our services have occurred
in the past. Since the end of the first quarter of fiscal 2002 and continuing
through the third quarter, we have experienced a decrease in the demand for our
services. We believe this trend is due to an overall weakening of demand for
onshore well services, which is attributable to lower prices for oil and natural
gas and general economic uncertainty. If these conditions continue, or worsen,
they could have a material adverse effect on our financial condition and results
of operation. In light of these and other factors relating to the oil and
natural gas industry, our historical operating results may not be indicative of
future performance.
AN ECONOMIC DOWNTURN MAY ADVERSELY AFFECT OUR BUSINESS.
The United States economy is currently believed to be in a recession. An
economic downturn may cause reduced demand for petroleum-based products and
natural gas. In addition, many companies during these periods often reduce or
delay expenditures to reduce costs. This in turn may cause a reduction in the
demand for our services. Accordingly to industry data, in July 2001, there were
approximately 1,293 active drilling rigs in North America. As of December 2001,
the number of active drilling rigs had decreased to 928. The number of active
drilling rigs may be indicative of demands for services such as those we
provide. If the economic environment worsens, our business may be further
adversely impacted.
S-2
WE HAVE PURSUED, AND MAY CONTINUE TO PURSUE, STRATEGIC ACQUISITIONS. OUR
BUSINESS MAY BE ADVERSELY AFFECTED IF WE CANNOT EFFECTIVELY INTEGRATE ACQUIRED
OPERATIONS.
A component of our strategy includes acquiring complementary businesses.
Acquisitions, including recent acquisitions and any acquisitions we make in the
future, involve a number of risks and challenges including:
- our ability to integrate acquired operations;
- potential loss of key employees and customers of the acquired
companies; and
- an increase in our expenses and working capital requirements.
Any of these factors could adversely affect our ability to achieve
anticipated levels of cash flows from our recent or future acquisitions or
realize other anticipated benefits. Furthermore, competition from other
potential buyers could reduce our acquisition opportunities or cause us to pay a
higher price than we otherwise might pay.
OUR BUSINESS INVOLVES CERTAIN OPERATING RISKS, AND OUR INSURANCE MAY NOT BE
ADEQUATE TO COVER ALL LOSSES OR LIABILITIES WE MIGHT INCUR IN OUR OPERATIONS.
Our operations are subject to many hazards and risks, including the
following:
- blow-outs;
- reservoir damage;
- loss of well control;
- cratering;
- fires;
- damage to the environment; and
- liabilities from accident or damage by our fleet of trucks.
If these hazards occur they could result in suspensions of operations,
damage to or destruction of our equipment and the property of others and injury
or death to personnel.
We self-insure to cover a portion of these liabilities. For losses in
excess of our self-insurance limits, we maintain insurance from unrelated
commercial carriers. However, our insurance may not be adequate to cover all
losses or liabilities that we might incur in our operations. There can be no
assurance that our insurance will adequately protect us against liability from
all of the hazards of our business. Moreover, we also are subject to the risk
that we may not be able to maintain or obtain insurance of the type and amount
we desire at a reasonable cost. If we were to incur a significant liability for
which we were not fully insured it would have a material adverse effect on our
financial position and results of operations.
S-3
USE OF PROCEEDS
We will not receive any proceeds of this offering other than the value of
the businesses or properties we acquire in the proposed acquisitions.
PRICE RANGE OF COMMON STOCK AND DIVIDEND POLICY
Our common stock is currently traded on the New York Stock Exchange,
under the symbol "KEG." The following tables sets forth, for the periods
indicated, the high and low sales prices of our common stock on the New York
Stock Exchange for the first and second quarters of fiscal 2002, fiscal 2001,
fiscal 2000 and fiscal 1999, as derived from published sources.
HIGH LOW
--------------- -------------
Fiscal Year Ending 2002:
Third Quarter (as of 2/21/02)..................... 9.30 7.20
Second Quarter.................................... 9.70 5.99
First Quarter..................................... 11.01 5.58
Fiscal Year Ending 2001:
Fourth Quarter.................................... 15.33 9.55
Third Quarter..................................... 13.52 8.8125
Second Quarter.................................... 10.50 6.8125
First Quarter..................................... 11 7/16 7 1/16
Fiscal Year Ending 2000:
Fourth Quarter.................................... 11 7/8 8 1/16
Third Quarter..................................... 12 1/4 5
Second Quarter.................................... 6 7/8 3 7/8
First Quarter..................................... $ 5 13/16 $ 3 3/8
Fiscal Year Ending 1999:
Fourth Quarter.................................... 4 1/2 2 15/16
Third Quarter..................................... 5 5/8 3 1/16
Second Quarter.................................... 11 3/8 3 5/16
First Quarter..................................... $ 14 15/16 6 1/8
We did not pay dividends on our common stock during the fiscal years
ended June 30, 2001, 2000 or 1999. We do not intend, for the foreseeable future,
to pay dividends on our common stock. In addition, we are contractually
restricted from paying dividends under the terms of our existing credit
facilities.
On February 21, 2002 the last reported sale price for our Common Stock
was $8.50 per share.
S-4
SELECTED FINANCIAL DATA
FISCAL YEAR ENDED JUNE 30,
----------------------------------------------------------------------
2001 2000 1999(1) 1998 1997
----------- ---------- ----------- ----------- ----------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
OPERATING DATA:
Revenues....................................... $ 837,262 $ 637,732 $ 491,817 $ 424,543 $ 165,773
Operating costs:
Direct costs................................. 574,938 462,386 371,428 293,448 114,598
Depreciation, depletion and amortization..... 75,147 70,972 62,074 31,001 11,076
General and administrative................... 66,071 58,772 53,108 38,987 17,447
Bad debt expense............................. 1,263 1,648 5,928 826 98
Debt issuance costs.......................... -- -- 6,307 -- --
Restructuring charge......................... -- -- 4,504 -- --
Interest..................................... 56,560 71,930 67,401 21,476 7,879
Income before income taxes and minority
interest..................................... 99,283 (27,976) (78,933) 38,805 14,675
Net income..................................... 62,710 (18,959) (53,258) 24,175 9,098
INCOME PER COMMON SHARE:
Basic........................................ 0.63 $ (0.23) $ (1.94) $ 1.41 $ 0.81
Diluted...................................... 0.61 $ (0.23) $ (1.94) $ 1.23 $ 0.66
Average common shares outstanding:
Basic........................................ 98,195 83,815 27,501 17,153 11,216
Assuming full dilution....................... 102,271 83,815 27,501 24,024 17,632
Common shares outstanding at period end........ 101,440 97,210 82,738 18,267 12,298
Market price per common share at period end.... 10.84 $ 9.64 $ 3.56 13.12 17.81
Cash dividends paid on common shares........... -- $ -- $ -- $ -- $ --
BALANCE SHEET DATA:
Cash......................................... 2,098 $ 109,873 $ 23,478 $ 25,265 $ 41,704
Current assets............................... 206,150 253,589 132,543 127,557 93,333
Property and equipment....................... 1,014,675 920,437 871,940 547,537 227,255
Property and equipment, net.................. 793,716 760,561 769,562 499,152 208,186
Total assets................................. 1,228,284 1,246,265 1,148,138 698,640 320,095
Current liabilities.......................... 115,553 92,848 73,151 48,029 33,142
Long-term debt, including current
portion.................................... 493,907 666,600 699,978 399,779 174,167
Stockholders' equity......................... 476,878 382,887 288,094 154,928 73,179
OTHER DATA:
Adjusted EBITDA(2)........................... 232,253 $ 116,574 $ 67,281 $ 92,108 $ 33,728
Net cash (used in) provided by:
Operating activities....................... 142,717 37,051 (13,427) 40,925 843
Investing activities....................... (83,350) (37,766) (294,654) (306,339) (80,749)
Financing Activities....................... (167,142) 87,110 306,294 248,975 117,399
Working capital............................ 90,597 155,965 59,392 79,528 60,191
Book value per common share(3)............. $ 4.70 $ 3.94 $ 3.47 $ 8.48 $ 5.95
(1) THE FINANCIAL DATA FOR THE YEAR ENDED JUNE 30, 1999 INCLUDES THE
ALLOCATED PURCHASE PRICE OF DAWSON PRODUCTION SERVICES, INC. AND THE
RESULTS OF THEIR OPERATIONS BEGINNING SEPTEMBER 15, 1998.
(2) ADJUSTED EBITDA IS NET INCOME BEFORE INTEREST EXPENSE, INCOME TAXES,
DEPRECIATION, DEPLETION AND AMORTIZATION, BAD DEBT EXPENSE, DEBT ISSUANCE
COSTS CHARGED TO EARNINGS, RESTRUCTURING CHARGE AND EXTRAORDINARY ITEMS.
ADJUSTED EBITDA IS PRESENTED BECAUSE OF ITS ACCEPTANCE AS A COMPONENT OF
A COMPANY'S POTENTIAL VALUATION IN COMPARISON TO COMPANIES IN THE SAME
INDUSTRY AND OF A COMPANY'S ABILITY TO SERVICE OR INCUR DEBT. MANAGEMENT
INTERPRETS TRENDS INDICATED BY CHANGES IN ADJUSTED EBITDA AS AN INDICATOR
OF THE EFFECTIVENESS OF ITS STRATEGIES IN ACHIEVING REVENUE GROWTH AND
CONTROLLING DIRECT AND INDIRECT COSTS OF SERVICES PROVIDED. INVESTORS
SHOULD CONSIDER THAT THIS MEASURE DOES NOT TAKE INTO CONSIDERATION DEBT
SERVICE, INTEREST EXPENSES, COSTS OF CAPITAL, IMPAIRMENTS OF LONG LIVED
ASSETS, DEPRECIATION OF PROPERTY, THE COST OF REPLACING EQUIPMENT OR
INCOME TAXES. ADJUSTED EBITDA SHOULD NOT BE CONSIDERED AS AN ALTERNATIVE
TO NET INCOME, INCOME BEFORE INCOME TAXES, CASH FLOWS FROM OPERATING
ACTIVITIES OR ANY OTHER MEASURE OF FINANCIAL PERFORMANCE PRESENTED IN
ACCORDANCE WITH GENERALLY ACCEPTED ACCOUNTING PRINCIPLES. ADJUSTED EBITDA
IS NOT A MEASURE OF FINANCIAL PERFORMANCE UNDER GENERALLY ACCEPTED
ACCOUNTING PRINCIPLES AND IS NOT INTENDED TO REPRESENT CASH FLOW.
ADJUSTED EBITDA MAY NOT BE COMPARABLE TO SIMILARLY TITLED MEASURES OF
OTHER COMPANIES.
(3) BOOK VALUE PER COMMON SHARE IS STOCKHOLDERS' EQUITY AT PERIOD END DIVIDED
BY THE NUMBER OF OUTSTANDING COMMON SHARES AT PERIOD END.
S-5
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
The statements in this document that relate to matters that are not
historical facts are "forward-looking statements" within the meaning of Section
27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act
of 1934. When used in this document and the documents incorporated by reference,
words such as "anticipate," "believe," "expect," "plan," "intend," "estimate,"
"project," "will," "could," "may," "predict" and similar expressions are
intended to identify forward-looking statements. Further events and actual
results may differ materially from the results set forth in or implied in the
forward-looking statements. Factors that might cause such a difference include:
- fluctuations in world-wide prices and demand for oil and natural
gas;
- fluctuations in the level of oil and natural gas exploration and
development activities;
- fluctuations in the demand for well servicing, contract drilling and
ancillary oilfield services;
- the existence of competitors, technological changes and developments
in the industry;
- the existence of operating risks inherent in well servicing,
contract drilling and ancillary oilfield services; and
- general economic conditions, the existence of regulatory
uncertainties, the possibility of political instability in any of
the countries in which we conduct business, in addition to the other
matters discussed herein.
The following discussion provides information to assist in the
understanding of our financial condition and results of operations. It should be
read in conjunction with the consolidated financial statements and related notes
appearing elsewhere in this prospectus supplement. Please note that certain
reclassifications have been made to the fiscal 1999 and 1998 financial data
presented below to conform to the fiscal 2000 presentation. The
reclassifications consist primarily of reclassifying as drilling revenues and
expenses, revenues and expenses from the limited drilling operations conducted
by certain of our well servicing divisions that were previously included in well
servicing revenues and expenses in order to report the results of all drilling
operations separately.
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS
SIX MONTHS ENDED DECEMBER 31, 2001 VERSUS SIX MONTHS ENDED DECEMBER 31, 2000
Our revenue for the six months ended December 31, 2001 increased
$66,984,000, or 16.9%, to $462,574,000 from $395,590,000 for the six months
ended December 31, 2000. The increase in the current period reflects higher
activity levels and improved rates. Our net income for the first six months of
fiscal 2002 totaled $48,635,000, or $0.46 per dilutive share, versus a net
income of $19,869,000, or $0.20 per dilutive share, for the prior year period.
OPERATING REVENUES
WELL SERVICING. Well servicing revenues for the six months ended December
31, 2001 increased $53,624,000, or 15.5%, to $398,839,000 from $345,215,000 for
the six months ended December 31, 2000. The increase in revenues was primarily
due to higher levels of activity and higher rig and fluid hauling rates.
CONTRACT DRILLING. Contract drilling revenues for the six months ended
December 31, 2001 increased $12,967,000, or 28.0%, to $59,290,000 from
$46,323,000 for the six months ended December 31, 2000. The increase in revenues
was primarily due to higher rig rates despite lower activity levels.
S-6
OPERATING EXPENSES
WELL SERVICING. Well servicing expenses for the six months ended December
31, 2001 increased $20,063,000, or 8.7%, to $249,872,000 from $229,809,000 for
the six months ended December 31, 2000. The increase was primarily due to a
higher level of activity and increased wages. Well servicing expenses, as a
percentage of well servicing revenue, decreased to 62.6% for the six months
ended December 31, 2001 from 66.6% for the six months ended December 31, 2000.
CONTRACT DRILLING. Contract drilling expenses for the six months ended
December 31, 2001 increased $2,710,000, or 7.6%, to $38,528,000 from $35,818,000
for the six months ended December 31, 2000. The increase was primarily due to
higher wages. Contract drilling expenses, as a percentage of contract drilling
revenues, decreased to 65.0% for the six months ended December 31, 2001 from
77.3% for the six months ended December 31, 2000.
DEPRECIATION, DEPLETION AND AMORTIZATION EXPENSE
Our depreciation, depletion and amortization expense for the six months
ended December 31, 2001 increased $1,136,000, or 3.1%, to $37,593,000 from
$36,457,000 for the six months ended December 31, 2000. The increase is due to
recent acquisitions and increased capital expenditures during the past twelve
months as we continued major refurbishments of well servicing and contract
drilling equipment partially offset by discontinued amortization of goodwill
because of our adoption of SFAS 142.
GENERAL AND ADMINISTRATIVE EXPENSES
Our general and administrative expenses for the six months ended December
31, 2001 increased $5,008,000, or 16.9%, to $34,639,000 from $29,631,000 for the
six months ended December 31, 2000. The increase was due to higher
administrative costs related to growth of our operations and reflects additional
resources in technology and internal control functions. General and
administrative expenses, as a percentage of revenues, remained constant at 7.5%
for the six months ended December 31, 2001 and December 31, 2000.
INTEREST EXPENSE
Our interest expense for the six months ended December 31, 2001
decreased $7,646,000, or 24.9%, to $23,046,000, from $30,692,000 for the six
months ended December 31, 2000. The decrease was primarily due to a significant
reduction in our long-term debt using operating cash flow, and to a lesser
extent, lower interest rates. Included in the interest expense was the
amortization of debt issuance costs of $1,393,000 and $2,044,000 for the six
months ended December 31, 2001 and 2000, respectively.
BAD DEBT EXPENSE
Our bad debt expense for the six months ended December 31, 2001 decreased
$595,000, or 65.9%, to $308,000 from $903,000 for the six months ended December
31, 2000. We continue to carefully monitor credit risk associated with our
customers.
FOREIGN CURRENCY TRANSACTION LOSS
During the six months ended December 31, 2001, we recorded an Argentine
foreign currency transaction loss of approximately $1,844,000 related to
dollar-denominated receivables resulting from the recent devaluation of
Argentina's currency.
EXTRAORDINARY GAIN
During the six months ended December 31, 2001, we retired $114,858,000 of
our long-term debt, and expensed the related unamortized debt issuance costs
which resulted in a net after-tax extraordinary gain of $2,271,000. During the
six months ended December 31, 2000, we retired $81,544,000 of our long-term
debt, and
S-7
expensed the related unamortized debt issuance costs which resulted in a net
after-tax extraordinary gain of $1,265,000.
INCOME TAXES
Our income tax expense for the six months ended December 31, 2001
increased $16,357,000 to an expense of $28,045,000 from a expense of $11,688,000
for the six months ended December 31, 2000. The increase in income tax expense
is due to the increase in pretax income. Our effective tax rate for the six
months ended December 31, 2001 and December 31, 2000 was 38% and 39%,
respectively. The effective tax rates vary from the statutory rate of 35%
because of the disallowance of certain goodwill amortization (for the six months
ended December 31, 2000), and other non-deductible expenses and the effects of
state and local taxes.
FISCAL YEAR ENDED JUNE 30, 2001 VERSUS FISCAL YEAR ENDED JUNE 30, 2000
Our results of operations for the year ended June 30, 2001 reflect the
impact of favorable industry conditions resulting from increased commodity
prices which in turn caused increased demand for our equipment and services
during fiscal 2001 (see Part I--Item--Major Developments During Fiscal
2001--Favorable Industry Conditions). The positive impact of this increased
demand on our operating results was partially offset by increased operating
expenses incurred as a result of the increase in our business activity.
THE COMPANY
Revenues for the year ended June 30, 2001 increased $235,530,000, or
36.9%, to $873,262,000 from $637,732,000 in fiscal 2000, while net income for
fiscal 2001 increased $81,669,000 to $62,710,000 from a net loss of $18,959,000
in fiscal 2000. The increase in revenues and net income is due to improved
operating conditions, higher rig hours, and increased pricing, with lower
interest expense from debt reduction also contributing to net income.
OPERATING REVENUES
WELL SERVICING. Well servicing revenues for the year ended June 30, 2001
increased $198,781,000, or 35.5%, to $758,273,000 from $559,492,000 in fiscal
2000. The increase was due to increased demand for our well servicing equipment
and services and higher pricing.
CONTRACT DRILLING. Contract drilling revenues for the year ended June 30,
2001 increased $39,211,000, or 57.3%, to $107,639,000 from $68,428,000 in fiscal
2000. The increase was due to increased demand for our contract drilling
equipment and services and higher pricing.
OPERATING EXPENSES
WELL SERVICING. Well servicing expenses for the year ended June 30, 2001
increased $93,168,000, or 23.3%, to $493,108,000 from $339,940,000 in fiscal
2000. The increase in expenses is due to higher utilization of our well
servicing equipment, higher labor costs and the overall increase in our well
servicing business. Despite the increased costs, well servicing expenses as a
percentage of well servicing revenues decreased from 71.5% for fiscal 2000 to
65% for fiscal 2001. The margin improvement is due to improved operating
efficiencies and the effects of higher pricing.
CONTRACT DRILLING. Contract drilling expenses for the year ended June 30,
2001, increased $19,067,000, or 32.7%, to $77,366,000 from $58,299,000 in fiscal
2000. The increase is due to higher utilization of our contract drilling
equipment, higher labor costs and the overall increase in our contract drilling
business. Despite the increased costs, contract drilling expenses as a
percentage of contract drilling revenues decreased from 85.2% in fiscal 2000 to
71.9% in fiscal 2001. The margin improvement is due to improved operating
efficiencies and the effects of higher pricing.
S-8
DEPRECIATION, DEPLETION AND AMORTIZATION EXPENSE
Our depreciation, depletion and amortization expense for the year ended
June 30, 2001 increased $4,175,000, or 5.9%, to $75,147,000 from $70,972,000 in
fiscal 2000. The increase is due to higher capital expenditures incurred during
fiscal 2001 as our refurbished equipment and increased utilization of its
contract drilling equipment (which it depreciates partially based on
utilization).
GENERAL AND ADMINISTRATIVE EXPENSES
Our general and administrative expenses for the year ended June 30, 2001
increased $7,299,000, or 12.4%, to $66,071,000 from $58,772,000 in fiscal 2000.
The increase was due to higher administrative costs necessitated by the growth
of our operations as a result of improved industry conditions. Despite the
increased costs, general and administrative expenses as a percentage of total
revenues declined from 9.2% in fiscal 2000 to 7.6% in fiscal 2001.
INTEREST EXPENSE
Our interest expense for the year ended June 30, 2001 decreased
$15,370,000, or 21.4%, to $56,560,000 from $71,930,000 in fiscal 2000. The
decrease was primarily due to the impact of the long-term debt reduction during
fiscal 2001 and, to a lesser extent, lower short-term interest rates and
borrowing margins on floating rate debt.
BAD DEBT EXPENSE
Our bad debt expense for the year ended June 30, 2001 decreased $385,000,
or 23.4%, to $1,263,000 from $1,648,000 in fiscal 2000. The decrease was
primarily due to improved industry conditions for our customers and, to a lesser
extent, the centralization of our internal credit approval process.
EXTRAORDINARY GAIN
During fiscal 2001, we repurchased $257,115,000 of our long-term debt at
various discounts and premiums to par value and expensed related unamortized
debt issuance costs, all of which resulted in an after-tax extraordinary gain of
$429,000.
INCOME TAXES
Our income tax benefit for the year ended June 30, 2001 increased
$44,408,000 to $37,002,000 from a benefit of $7,406,000 in fiscal 2000. The
increase in income tax expense is due to the increased pre-tax income. Our
effective tax rate for fiscal 2001 and 2000 was 37.28% and 26.5%, respectively.
The effective tax rates vary from the statutory rate of 35% principally because
of certain non-deductible goodwill amortization, other non-deductible expenses
and state and local taxes.
CASH FLOW
Our net cash provided by operating activities for the year ended June 30,
2001 increased $107,857,000 to $142,717,000 from a $34,860,000 in fiscal 2000.
The increase is due to higher revenues resulting from increased demand for our
equipment and services and higher pricing, partially offset by higher operating
and general and administrative expenses resulting from increased business
activity.
Our net cash used in investing activities for the year ended June 30,
2001 increased $45,584,000 to $83,350,000 from $37,766,000 in fiscal 2000. The
increase is due primarily to higher capital expenditures.
Our net cash used by financing activities for the year ended June 30,
2001 increased $256,443,000 to a use of $167,142,000 from cash provided of
$89,301,000 in fiscal 2000. The increase is primarily the result of significant
debt reduction during fiscal 2001, partially offset by proceeds from the Debt
Offering and the exercise of stock options and warrants.
S-9
FISCAL YEAR ENDED JUNE 30, 2000 VERSUS FISCAL YEAR ENDED JUNE 30, 1999
Our results of operations for the year ended June 30, 2000 reflect the
impact of the industry recovery during such period resulting from increased
commodity prices which in turn caused increased demand for our equipment and
services during fiscal 2000. The positive impact of this increased demand on our
operating results was partially offset by increased operating expenses incurred
as a result of the increase in our business activity.
THE COMPANY
Revenues for the year ended June 30, 2000 increased $145,915,000, or
29.7%, to $637,732,000 from $491,817,000 in fiscal 1999, while net income for
fiscal 2000 increased $34,299,000 to a net loss of $18,959,000 from a net loss
of $53,258,000 in fiscal 1999. The increase in revenues is due to improved
operating conditions and higher rig hours, the full year effect of the
acquisitions completed during the early portion of fiscal 1999 and, to a lesser
extent, higher pricing. The decrease in net loss is the result of improved
operating conditions, higher pricing, and cost reduction initiatives. In
addition, fiscal 1999 included non-recurring charges for debt issuance costs and
restructuring initiatives as well as higher bad debt expense.
OPERATING REVENUES
WELL SERVICING. Well servicing revenues for the year ended June 30, 2000
increased $125,835,000 or 29%, to $559,492,000 from $433,656,000 in fiscal 1999.
The increase was due to increased demand for our well servicing equipment and
services, the full year effect of the acquisitions completed during the early
portion of fiscal 1999 and, to a lesser extent, higher pricing.
CONTRACT DRILLING. Contract drilling revenues for the year ended June 30,
2000 increased $17,815,000, or 35.2%, to $68,428,000 from $50,613,000 in fiscal
1999. The increase was due to increased demand for our contract drilling
equipment and services, the full year effect of the acquisition completed during
the early portion of fiscal 1999 and, to a lesser extent, higher pricing.
OPERATING EXPENSES
WELL SERVICING. Well servicing expenses for the year ended June 30, 2000
increased $74,975,000, or 23.1%, to $399,940,000 from $324,965,000 in fiscal
1999. The increase in expenses is due to higher utilization of our well
servicing equipment, higher labor costs and the overall increase in our well
servicing business. Despite the increased costs, well servicing expenses as a
percent of well servicing revenues decreased from 74.9% for fiscal 1999 to 71.5%
for fiscal 2000. The margin improvement is due to improved operating
efficiencies and the effects of higher pricing.
CONTRACT DRILLING. Contract drilling expenses for the year ended June 30,
2000, increased $14,743,000, or 33.8%, to $58,299,000 from $43,556,000 in fiscal
1999. The increase is due to higher utilization of our contract drilling
equipment, higher labor costs and the overall increase in our contract drilling
business. Despite the increased costs, contract drilling expenses as a
percentage of contract drilling revenues decreased from 86.1% in fiscal 1999 to
85.2% in fiscal 2000. The margin improvement is due to improved operating
efficiencies and the effects of higher pricing.
DEPRECIATION, DEPLETION AND AMORTIZATION EXPENSE
Our depreciation, depletion and amortization expense for the year ended
June 30, 2000 increased $8,898,000, or 14.3%, to $70,972,000 from $62,074,000 in
fiscal 1999. The increase is due to higher capital expenditures incurred during
fiscal 2000 as we refurbished equipment and increased utilization of its
contract drilling equipment (which it depreciates partially based on
utilization).
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GENERAL AND ADMINISTRATIVE EXPENSES
Our general and administrative expenses for the year ended June 30, 2000
increased $5,664,000, or 10.7%, from $53,108,000 to $58,772,000 in fiscal 2000.
The increase was due to higher administrative costs necessitated by the growth
of our operations as a result of the fiscal 1999 acquisitions and improved
industry conditions. Despite the increased costs, general and administrative
expenses as a percentage of total revenues declined from 10.8% in fiscal 1999 to
9.2% in fiscal 2000.
INTEREST EXPENSE
Our interest expense for the year ended June 30, 2000 increased
$4,529,000, or 6.7%, to $71,930,000 from $67,401,000 in fiscal 1999. The
increase was primarily due to the full year effect of the debt incurred in
connection with the acquisitions completed during the early portion of fiscal
1999, and, to a lesser extent, higher interest rates during fiscal 2000
partially offset by the impact of the long-term debt reduction during fiscal
2000.
BAD DEBT EXPENSE
Our bad debt expense for the year ended June 30, 2000 decreased
$4,280,000, or 72.2%, to $1,648,000 from $5,928,000 in fiscal 1999. The decrease
was primarily due to improved industry conditions for our customers and, to a
lesser extent, the centralization of our internal credit approval process.
EXTRAORDINARY GAIN
During the fourth quarter of fiscal 2000, we repurchased $10,190,000 of
our 5% Convertible Subordinated Notes which resulted in an after-tax gain of
$1,611,000.
INCOME TAXES
Our income tax benefit for the year ended June 30, 2000 decreased
$18,269,000 to $7,406,000 from $25,675,000 in fiscal 1999. The decrease in
income tax benefit is due to the decrease in pretax loss. Our effective tax
benefit rate for fiscal 2000 and 1999 was 26.5% and 32.5%, respectively. The
fiscal 2000 effective tax benefit rate is different from the statutory rate of
35% principally because of certain non-deductible goodwill amortization, other
non-deductible expenses and state and local taxes. The decrease in the fiscal
2000 effective tax benefit rate was due to an increase in the amount of
non-deductible expenses, primarily as a result of the full year effect of the
goodwill amortization of the acquisitions completed during the early portion of
fiscal 1999.
CASH FLOW
Our net cash provided by operating activities for the year ended June 30,
2000 increased $48,287,000 to a $34,860,000 from a use of $13,427,000 in fiscal
1999. The increase is due to higher revenues resulting from increased demand for
our equipment and services, the full year effect of the acquisitions completed
during the early portion of fiscal 1999 and, to a lesser extent, higher pricing,
partially offset by higher operating and general and administrative expenses
resulting from increased business activity.
Our net cash used in investing activities for the year ended June 30,
2000 decreased $256,888,000, or 87.2%, to $37,766,000 from $294,654,000 in
fiscal 1999. The decrease is due to no acquisitions having occurred during
fiscal 2000 partially offset by higher capital expenditures.
Our net cash provided by financing activities for the year ended June 30,
2000 decreased $216,993,000, or 70.8%, to $89,301,000 from $306,294,000 in
fiscal 1999. The decrease is primarily the result of significantly decreased
borrowings during fiscal 2000 and, to a lesser extent, the repayment of
long-term debt partially offset by proceeds from the equity offering and the
volumetric production payment completed in fiscal 2000.
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LIQUIDITY AND CAPITAL RESOURCES
We have historically funded our operations, acquisitions, capital
expenditures and working capital requirements using cash flow from operations,
bank borrowings and the issuance of equity and long-term debt. We believe that
the current reserves of cash and cash equivalents, access to our existing credit
lines, access to capital markets and internally generated cash flow from
operations are and will be sufficient to finance the cash requirements of our
current and future operations.
CAPITAL EXPENDITURES
Capital expenditures for fiscal 2002 have been and will be directed
toward selectively refurbishing our assets as business conditions warrant. We
will continue to evaluate opportunities to acquire or divest assets or
businesses to enhance our primary operations. Such capital expenditures,
acquisitions and divestitures are at our discretion of and will depend on
management's view of market conditions as well as other factors.
LONG-TERM DEBT
SENIOR CREDIT FACILITY
As of December 31, 2001, we had a senior credit facility (the "Senior
Credit Facility") with a syndicate of banks led by PNC Bank, N.A. which
consisted of a $100,000,000 revolving loan facility. In addition, up to
$20,000,000 of letters of credit can be issued under the Senior Credit Facility,
but any outstanding letters of credit reduce the borrowing availability under
the revolving loan facility. The commitment to make revolving loans will reduce
to $75,000,000 on September 14, 2002. The revolving loan commitment will
terminate on September 14, 2003, and all revolving loans must be paid on or
before that date. As of December 31, 2001, approximately $25,000,000 was drawn
under the revolving loan facility and approximately $12,000,000 of letters of
credit related to workman's compensation insurance were outstanding. We drew
down approximately $43 million on January 14, 2002 in order to redeem the 14%
Senior Subordinated Notes.
14% SENIOR SUBORDINATED NOTES
The revolving loan bears interest based upon, at our option, the prime
rate plus a variable margin of 0.75% to 2.00% or a Eurodollar rate plus a
variable margin of 2.25% to 3.50%. The Senior Credit Facility has customary
affirmative and negative covenants including a maximum debt to capitalization
ratio, a minimum interest coverage ratio, a maximum senior leverage ratio, a
minimum net worth and minimum EBITDA as well as restrictions on capital
expenditures, acquisitions and dispositions.
8 3/8% SENIOR NOTES
On March 6, 2001, we completed a private placement of $175,000,000 of 8
3/8% Senior Notes due 2008 (the "8 3/8% Senior Notes"). The cash proceeds from
the private placement, net of fees and expenses, were used to repay all of the
remaining balance of the Tranche B term loan under the Senior Credit Facility,
and a portion of the revolving loan facility under the Senior Credit Facility.
The 8 3/8% Senior Notes are subordinate to our senior indebtedness which
includes borrowings under the Senior Credit Facility and the Dawson 9 3/8%
Senior Notes.
14% SENIOR SUBORDINATED NOTES
On January 22, 1999, we completed the private placement of 150,000 units
(the "Units") consisting of $150,000,000 of 14% Senior Subordinated Notes due
2009 (the "14% Senior Subordinated Notes") and 150,000 warrants to purchase (as
subsequently adjusted) 2,173,433 shares of our common stock at an exercise price
of $4.88125 per share (the "Unit Warrants"). The net cash proceeds from the
private placement were used to repay substantially all of the remaining
$148,600,000 principal amount (plus accrued interest) owed under our bridge loan
facility arranged in connection with the acquisition of Dawson Production
Services, Inc. ("Dawson"). The 14% Senior Subordinated Notes are subordinate to
our senior indebtedness which includes borrowings under the Senior Credit
Facility, the Dawson 9 3/8% Senior Notes and the 8 3/8% Senior Notes. The Unit
Warrants have separated
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from the 14% Senior Subordinated Notes and became exercisable on January 25,
2000. At December 31, 2001, $132,903,000 principal amount of the 14% Senior
Subordinated Notes remained outstanding. As of December 31, 2001, 63,500 Unit
Warrants had been exercised leaving 86,500 Unit Warrants outstanding.
On and after January 15, 2004, we may redeem some or all of the 14%
Senior Subordinated Notes at any time at varying redemption prices in excess of
par, plus accrued interest. In addition, before January 15, 2002, we may redeem
up to 35% of the aggregate principal amount of the 14% Senior Subordinated Notes
with the proceeds of certain sales of equity at 114% of par plus accrued
interest. On January 14, 2002 we exercised our right of redemption for
$35,403,000 principal amount of the 14% Senior Subordinated Notes at a price of
114% of the principal amount plus accrued interest, leaving $97,500,000
principal amount outstanding as of January 15, 2002. This transaction resulted
in an extraordinary loss before taxes of approximately $8,468,000.
5% CONVERTIBLE SUBORDINATED NOTES
In late September and early October 1997, we completed a private
placement of $216,000,000 of 5% Convertible Subordinated Notes due 2004 (the "5%
Convertible Subordinated Notes"). The 5% Convertible Subordinated Notes are
subordinate to our senior indebtedness which includes borrowings under the
Senior Credit Facility, the 14% Senior Subordinated Notes, the Dawson 9 3/8%
Senior Notes, and the 8 3/8% Senior Notes. The 5% Convertible Subordinated Notes
are convertible, at the holder's option, into shares of our common stock at a
conversion price of $38.50 per share, subject to certain adjustments. During the
quarter ended December 31, 2001, we repurchased (and canceled) $61,581,000
principal amount of the 5% Convertible Subordinated Notes, leaving $50,352,000
principal amount of the 5% Convertible Subordinated Notes outstanding at
December 31, 2001.
CRITICAL ACCOUNTING POLICIES
We follow certain significant accounting policies when preparing its
consolidated financial statements. A complete summary of these policies is
included in Note 1 to the consolidated financial statements included in the
Company's Annual Report on Form 10-K.
Certain of the policies require management to make significant and
subjective estimates which are sensitive to deviations of actual results from
management's assumptions. In particular, management makes estimates regarding
the fair value of our reporting units in assessing potential impairment of
goodwill. In addition, we make estimates regarding future undiscounted cash
flows from the future use of long-lived assets whenever events or changes in
circumstances indicate that the carrying amount of a long-lived asset may not be
recoverable.
In assessing impairment of goodwill, we have used estimates and
assumptions in estimating the fair value of its reporting units. Actual future
results could be different than the estimates and assumptions used. Events or
circumstances which might lead to an indication of impairment of goodwill would
include, but might not be limited to, prolonged decreases in expectations of
long-term well servicing and/or drilling activity or rates brought about by
prolonged decreases in oil or natural gas prices, changes in government
regulation of the oil and natural gas industry or other events which could
affect the level of activity of exploration and production companies.
In assessing impairment of long-lived assets other than goodwill where
there has been a change in circumstances indicating that the carrying amount of
a long-lived asset may not be recoverable, we have estimated future undiscounted
net cash flows from use of the asset based on actual historical results and
expectations about future economic circumstances including oil and natural gas
prices and operating costs. The estimate of future net cash flows from use of
the asset could change if actual prices and costs differ due to industry
conditions or other factors affecting our performance.
RECENTLY ISSUED FINANCIAL ACCOUNTING STANDARDS
Recently the Financial Accounting Standards Board, ("FASB") issued
Statement of Financial Accounting Standards No. 143, Accounting for Asset
Retirement Obligations ("SFAS 143"), and Statement of Financial Accounting
Standards No. 144, Accounting for the Impairment of Disposal of Long-Lived
Assets ("SFAS 144"). SFAS 143 establishes requirements for the accounting for
removal costs associated with asset retirements and SFAS
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144 addresses financial accounting and reporting for the impairment of disposal
of long-lived assets. SFAS 143 is effective for fiscal years beginning after
June 15, 2002, with earlier adoption encouraged, and SFAS 144 is effective for
fiscal years beginning after December 15, 2001 and interim periods within those
fiscal years. We are currently assessing the impact of these standards on its
consolidated financial statements.
INTEREST RATE RISK
At December 31, 2001, we had long-term debt and capital lease obligations
outstanding of $403,711,000. Of this amount $354,634,000 or 88%, bears interest
at fixed rates as follows:
BALANCE AT
DECEMBER 31,
2001
-------------
(THOUSANDS)
8 3/8% Senior Notes Due 2008....................................... $ 175,000
14% Senior Subordinated Notes Due 2009............................. 128,263
5% Convertible Subordinated Notes Due 2004......................... 50,352
Other (rates generally ranging from 8.0% to 8.5%).................. 1,019
-------------
$ 354,634
=============
The remaining $49,077,000 of long-term debt and capital lease obligations
outstanding as of December 31, 2001 bears interest at floating rates which
averaged approximately 5.9% at December 31, 2001. A 10% increase in short-term
interest rates on the floating-rate debt outstanding at December 31, 2001 would
equal approximately 59 basis points. Such an increase in interest rates would
increase our fiscal 2002 interest expense by approximately $300,000 assuming
borrowed amounts remain outstanding.
The above sensitivity analysis for interest rate risk excludes accounts
receivable, accounts payable and accrued liabilities because of the short-term
maturity of such instruments.
FOREIGN CURRENCY RISK
Recently, the Argentine government suspended the law tying the Argentine
peso to the U.S. dollar at the conversion ratio of 1:1 and created a dual
currency system in Argentina. Our net assets from its Argentina subsidiaries are
based on the U.S. dollar equivalent of such amounts measured in Argentine pesos
as of December 31, 2001. Assets and liabilities of the Argentine operations were
translated to U.S. dollars at December 31, 2001, using the applicable free
market conversion ratio of 1.6:1. Our net earnings and cash flows from its
Argentina subsidiaries were tied to the U.S. dollar for the six months ended
December 31, 2001 and will be based on the U.S. dollar equivalent of such
amounts measured in Argentine pesos for periods after December 31, 2001.
Revenues, expenses and cash flow will be translated using the average exchange
rates during the periods after December 31, 2001. See Note 10 to the
consolidated financial statements.
A 10% change in the Argentine peso to the U.S. dollar exchange rate would
not be material to our net assets, net earnings or cash flows. Our net assets,
net earnings and cash flows from its Canadian subsidiary are based on the U.S.
dollar equivalent of such amounts measured in Canadian dollars. Assets and
liabilities of the Canadian operations are translated to U.S. dollars using the
applicable exchange rate as of the end of a reporting period. Revenues, expenses
and cash flow are translated using the average exchange rate during the
reporting period.
A 10% change in the Canadian-to-U.S. Dollar exchange rate would not be
material to our net assets, net earnings or cash flows.
COMMODITY PRICE RISK
Our major market risk exposure for its oil and natural gas production
operations is in the pricing applicable to its oil and natural gas sales.
Realized pricing is primarily driven by the prevailing worldwide price for crude
oil
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and spot market for natural gas. Pricing for oil and natural gas production has
been volatile and unpredictable for several years.
We periodically hedge a portion of its oil and natural gas production
through collar and option agreements. The purpose of the hedges is to provide a
measure of stability in the volatile environment of oil and natural gas prices
and to manage exposure to commodity price risk under existing sales commitments.
Our risk management objective is to lock in a range of pricing for expected
production volumes. This allows us to forecast future earnings within a
predictable range. We meet this objective by entering into collar and option
arrangements which allow for acceptable cap and floor prices.
As of December 31, 2001, we had oil and natural gas price collars and put
options in place, as detailed in the following table. The total fiscal 2002
hedged oil and natural gas volumes represent 37% and 30%, respectively, of 2001
calendar year total production. A 10% variation in the market price of oil or
natural gas from their levels at December 31, 2001 would have no material impact
on our net assets, net earnings or cash flows (as derived from the commodity
option contracts).
The following table sets forth the future volumes hedged by year and the
weighted-average strike price of the option contracts at December 31, 2001:
MONTHLY VOLUMES
----------------------- STRIKE PRICE
NATURAL PER BBL/MMBTU
OIL GAS -------------------
(BBLS) (MMBTUS) TERM FLOOR CAP FAIR VALUE
--------- ---------- -------------------- -------- -------- -----------
At December 31, 2001
Oil Collars............ 5,000 -- Mar 2001 - Feb 2002 $ 19.70 $23.70 $ 7,000
Oil Puts............... 5,000 -- Mar 2002 - Feb 2003 22.00 -- 169,000
Natural Gas Collars.... -- 40,000 Mar 2001 - Feb 2002 2.40 2.91 3,000
Natural Gas Puts....... -- 75,000 Mar 2002 - Feb 2003 3.00 -- 746,000
(The strike prices for oil are based on the NYMEX spot price for West
Texas Intermediate; the strike prices for the natural gas collars are based on
the Inside FERC-West Texas Waha spot price; the strike prices for the natural
gas puts are based on the Inside FERC-El Paso Permian spot price.)
BUSINESS
THE COMPANY
We are the largest onshore, rig-based well servicing contractor in the
world, with approximately 1,477 well service rigs and 1,455 oilfield service
vehicles as of June 30, 2001. We provide a complete range of well services to
major oil companies and independent oil and natural gas production companies,
including: rig-based well maintenance, workover, completion, and recompletion
services (including horizontal recompletions); oilfield trucking services; and
ancillary oilfield services. We conduct well servicing operations onshore the
continental United States in the following regions: Gulf Coast (including South
Texas, Central Gulf Coast of Texas and South Louisiana), Permian Basin of West
Texas and Eastern New Mexico, Mid-Continent (including the Anadarko, Hugoton and
Arkoma Basins and the ArkLaTex region), Four Corners (including the San Juan,
Piceance, Uinta, and Paradox Basins), Eastern (including the Appalachian,
Michigan and Illinois Basins), Rocky Mountains (including the Denver-Julesberg,
Powder River, Wind River, Green River and Williston Basins), and California (the
San Joaquin Basin), and internationally in Argentina and Ontario, Canada. We are
also a leading onshore drilling contractor, with 79 land drilling rigs as of
June 30, 2001. We conduct land drilling operations in a number of major domestic
producing basins, as well as in Argentina and in Ontario, Canada. We also
produce and develop oil and natural gas reserves in the Permian Basin region and
Texas Panhandle.
Our principal executive office is located at 6 Desta Drive, Midland,
Texas 79705. Our phone number is (915) 620-0300 and website address is
www.keyenergy.com.
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BUSINESS STRATEGY
We have built our leadership position through the consolidation of
smaller, less viable competitors. This consolidation, together with a continuing
decline in the number of available domestic well service rigs due to attrition,
cannibalization and transfers outside of the United States, has given us the
opportunity to capitalize on improved market conditions which existed during
fiscal 2001. We have focused on maximizing results by reducing debt, building
strong customer alliances, refurbishing rigs and related equipment, and training
personnel to maintain a qualified and safe employee base.
REDUCING DEBT. Over the past fiscal year, we have significantly reduced
debt and strengthened our balance sheet. At June 30, 2001, our long-term funded
debt net of cash and capitalized leases ("net funded debt") was approximately
$468,845,000 and its net funded debt to capitalization ratio was approximately
50% as compared to approximately $534,816,000 and 58%, respectively, at June 30,
2000. We expect to be able to continue to reduce debt from available cash flow
from operations and from anticipated interest savings resulting from prior and
future debt reductions and future debt refinancings.
BUILDING STRONG CUSTOMER ALLIANCES. We seek to maximize customer
satisfaction by offering a broad range of equipment and services in conjunction
with highly trained and motivated employees. As a result, we are able to offer
proactive solutions for most of its customer's wellsite needs. We ensure
consistent high standards of quality and customer satisfaction by continually
evaluating its performance. We maintain strong alliances with major oil
companies as well as numerous independent oil and natural gas production
companies and believes that such alliances improve the stability of demand for
its oilfield services.
REFURBISHING RIGS AND RELATED EQUIPMENT. We intend to continue actively
refurbishing its rigs and related equipment to maximize the utilization of its
rig fleet. The increase in our cash flow, both from operations and from
anticipated interest savings from reduced levels of debt, combined with our
borrowing availability under its revolving credit facility, has provided ample
liquidity and resources necessary to make the capital expenditures to refurbish
such equipment.
TRAINING AND DEVELOPING EMPLOYEES. We have, and will continue to, devote
significant resources to the training and professional development of our
employees with a special emphasis on safety. We currently have two training
centers in Texas and one training center in California to improve its employees'
understanding of operating and safety procedures. We recognize the historically
high turn-over rate in the industry and is committed to offering compensation,
benefits and incentive programs for its employees that are attractive and
competitive in its industry, in order to ensure a steady stream of qualified,
safe personnel to provide quality service to its customers.
MAJOR DEVELOPMENTS DURING FISCAL 2001
FAVORABLE INDUSTRY CONDITIONS
Operating conditions improved significantly during fiscal 2001 as capital
spending by oil and natural gas producers for well servicing and contract
drilling services increased over prior year levels. The increased spending was
primarily due to higher commodity prices with WTI Cushing prices for light sweet
crude averaging approximately $26.97 per barrel and Nymex Henry Hub natural gas
prices averaging approximately $5.09 per MMbtu during fiscal 2001, as compared
to an average WTI Cushing price for light sweet crude of $25.97 per barrel and
an average Nymex Henry Hub natural gas price of $3.04 per MMbtu during fiscal
2000.
This increase in commodity prices during fiscal 2001 led to a steady,
sequential increase in the demand for our services and equipment during fiscal
2001 as our customers increased their exploration and development activity in
our primary market areas, enabling us to increase the rates it charges for its
services. This increase in demand and rates resulted in sequential increases in
revenues, cash flow and net income in each quarter of fiscal 2001 over the same
quarter of fiscal 2000. We expect demand for its services to remain at or above
current levels as long as capital spending by our customers remains at or near
their current levels.
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During fiscal 2001, crude oil prices continued to trade at healthy levels
due largely to the ability of the Organization of Petroleum Exporting Countries
("OPEC") to adhere to its production quotas designed to keep crude oil prices in
the range of $22.00 to $28.00 per barrel. The adherence to the production quotas
brought more stability to crude oil prices. Since June 30, 2001, however, both
crude oil and natural gas prices have weakened significantly, falling below
$22.00 per barrel and $2.00 per Mmbtu, respectively. While management believes
that many of its customers generally base their capital spending budgets on a
crude oil price of $18.00 to $22.00 per barrel and a natural gas price of $2.00
to $2.75 per MMbtu, there can be no assurances that its customers will not
postpone and/or reduce their capital spending plans if crude oil prices and
natural gas prices continue to remain at or below their current levels. In
addition, the terrorist attacks on the World Trade Center and the Pentagon that
occurred on September 11, 2001 threaten to increase the downward pressure on
commodity prices as U.S. fuel consumption decreases due to significantly reduced
air and other travel, the general demand for energy decreases as consumer
anxiety further weakens the U.S. economy, and OPEC faces political pressure to
reduce its price targets for crude oil.
The level of our revenues, cash flows, losses and earnings are
substantially dependent upon, and affected by, the level of domestic and
international oil and gas exploration and development activity (see Part II-Item
7-Management's Discussion and Analysis of Results of Operations and Financial
Condition).
RECENT DEVELOPMENTS
Most of our foreign revenues are derived from our operations in
Argentina. For fiscal 2001, revenues from operations in Argentina were $48.5
million, which accounted for 5.5% of our total revenues for such period. For
fiscal 2001, net income from operations in Argentina was $4.5 million. For the
six months ended December 31, 2001, revenues from operations in Argentina were
$21.3 million, which accounted for 4.6% of our total revenue for such period. We
incurred a net loss of $1.3 million from our operations in Argentina for the
same six-month period. Recently, Argentina has been negatively affected by
volatile economic and political conditions. In December 2001, the Argentine
government announced that it would restrict bank account withdrawals and would
not service its public sector debt. In addition, in January 2002, the Argentine
government abandoned its decade-old fixed peso-dollar exchange rate and created
a dual exchange rate system. As a result of this abandonment of the fixed
peso-dollar exchange rate system, at December 31, 2001 we recorded a $1.8
million foreign currency transaction loss on our dollar-denominated accounts
receivable and reduced our stockholders' equity by an additional $24.2 million
due to foreign currency translation related to our net investment in our
Argentine subsidiary. The Argentine government has also recently announced its
intent to impose a 20% tax on oil exports effective March 1, 2002 or other taxes
on production that would produce comparable tax revenues.
We believe that all of these events will negatively affect oil production
in Argentina, and accordingly will have a negative effect on demand for our
services. The economic conditions in Argentina continue to be unstable and
further devaluation of the Argentine peso may occur. We continue to evaluate the
structure of our operations in Argentina, but we are currently unable to predict
the effects that further instability in Argentina will have on our financial
position.
DEBT REDUCTION
During fiscal 2001, we significantly reduced our long-term debt and
strengthened our balance sheet. At June 30, 2001, our net funded debt was
approximately $468,845,000 and its net funded debt to capitalization ratio was
approximately 50% as compared to approximately $534,816,000 and 58%,
respectively, at June 30, 2000. Proceeds from the Debt Offering (defined below)
and from the exercise of options and warrants, as well as cash flow from
operations were used to accomplish this reduction in net funded debt (see Part
II-Item 7-Management's Discussion and Analysis of Results of Operations and
Financial Condition-Long-Term Debt).
DEBT OFFERING
On March 6, 2001, we completed the public offering of $175,000,000 of 8
3/8% Senior Notes Due 2008 (the "Debt Offering"). Net proceeds from the Debt
Offering were approximately $170.0 million, which was used to
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immediately repay the term loans in full and to repay a portion of the revolver
outstanding under our senior credit facility.
DESCRIPTION OF BUSINESS SEGMENTS
We operate in two primary business segments which are well servicing and
contract drilling. Our operations are conducted domestically and in Argentina
and Canada. The following is a description of each of these business segments
(for financial information regarding these business segments, see Note 15 to
Consolidated Financial Statements-Business Segment Information).
WELL SERVICING
We provide a full range of well services, including rig-based services,
oilfield trucking services and ancillary oilfield services, necessary to
maintain and workover oil and natural gas producing wells. Rig-based services
include: maintenance of existing wells, workovers of existing wells, completion
of newly drilled wells, recompletion of existing wells (including horizontal
recompletions) and plugging and abandonment of wells at the end of their useful
lives.
WELL SERVICE RIGS
We use our well service rig fleet to perform four major categories of rig
services for oil and natural gas producers.
MAINTENANCE SERVICES. We estimate that there are approximately 600,000
producing oil wells and approximately 300,000 producing natural gas wells in the
United States. We provide the well service rigs, equipment and crews for
maintenance services, which are performed on both oil and natural gas wells, but
which are more commonly required on oil wells. While some oil wells in the
United States flow oil to the surface without mechanical assistance, most
require pumping or some other method of artificial lift. Oil wells that require
pumping characteristically require more maintenance than flowing wells due to
the operation of the mechanical pumping equipment installed. Few natural gas
wells have mechanical pumping systems in the wellbore, and, as a result,
maintenance work on natural gas wells is less frequent.
Maintenance services are required throughout the life of most producing
oil and natural gas wells to ensure efficient and continuous operation. These
services consist of routine mechanical repairs necessary to maintain production
from the well, such as repairing inoperable pumping equipment in an oil well or
replacing defective tubing in an oil or natural gas well, and removing debris
such as sand and paraffin from the well. Other services include pulling the
rods, tubing, pumps and other downhole equipment out of the wellbore to identify
and repair a production problem.
Maintenance services are often performed on a series of wells in
proximity to each other and typically require less than 48 hours per well to
complete. The general demand for maintenance services is closely related to the
total number of producing oil and natural gas wells in a geographic market, and
maintenance services are generally the most stable type of well service
activity.
WORKOVER SERVICES. In addition to periodic maintenance, producing oil and
natural gas wells occasionally require major repairs or modifications, called
"workovers." Workover services are performed to enhance the current production
of existing wells. Such services include extensions of existing wells to drain
new formations either through deepening wellbores to new zones or through
drilling of horizontal lateral wellbores to improve reservoir drainage patterns.
In less extensive workovers, our rigs are used to seal off depleted zones in
existing wellbores and access previously bypassed productive zones. Our workover
rigs are also used to convert former producing wells to injection wells through
which water or carbon dioxide is then pumped into the formation for enhanced
recovery operations. Other workover services include: major subsurface repairs
such as casing repair or replacement, recovery of tubing and removal of foreign
objects in the wellbore, repairing downhole equipment failures, plugging back
the bottom of a well to reduce the amount of water being produced with the oil
and natural gas, cleaning out and recompleting a well if production has
declined, and repairing leaks in the tubing and casing. These extensive
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workover operations are normally performed by a well service rig with a workover
package, which may include rotary drilling equipment, mud pumps, mud tanks and
blowout preventers depending upon the particular type of workover operation.
Most of our well service rigs are designed for and can be equipped to perform
complex workover operations.
Workover services are more complex and time consuming than routine
maintenance operations and consequently may last from a few days to several
weeks. These services are almost exclusively performed by well service rigs.
The demand for workover services is more sensitive to expectations
relating to, and changes in, oil and natural gas prices than the demand for
maintenance services. As oil and natural gas prices increase, the level of
workover activity tends to increase as operators seek to increase production by
enhancing the efficiency of their wells at higher commodity prices with
correspondingly higher rates of return.
COMPLETION SERVICES. Our completion services prepare a newly drilled oil
or natural gas well for production. The completion process may involve
selectively perforating the well casing to access producing zones, stimulating
and testing these zones and installing downhole equipment. We typically provide
a well service rig and may also provide other equipment such as a workover
package to assist in the completion process. Producers use well service rigs to
complete their wells because the rigs have specialized equipment, properly
trained employees and the experience necessary to perform these services.
However, during periods of weak drilling rig demand, drilling contractors may
compete with service rigs for completion work.
The completion process typically requires a few days to several weeks,
depending on the nature and type of the completion, and generally requires
additional auxiliary equipment that can be provided for an additional fee. The
demand for well completion services is directly related to drilling activity
levels, which are highly sensitive to expectations relating to, and changes in,
oil and natural gas prices. As the number of newly drilled wells decreases, the
number of completion jobs correspondingly decreases.
PLUGGING AND ABANDONMENT SERVICES. Well service rigs and workover
equipment are also used in the process of permanently closing oil and natural
gas wells at the end of their productive lives. Plugging and abandonment work
can be performed with a well servicing rig along with wireline and cementing
equipment. The services generally include the sale or disposal of equipment
salvaged from the well as part of the compensation received and require
compliance with state regulatory requirements. The demand for oil and natural
gas does not significantly affect the demand for plugging and abandonment
services, as well operators are required by state regulations to plug a well
that it is no longer productive. The need for these services is also driven by
lease and/or operator policy requirements.
OILFIELD TRUCKING
We provide liquid/vacuum truck services and fluid transportation and
disposal services for operators whose wells produce saltwater and other fluids,
in addition to oil and natural gas. These trucks are also utilized in connection
with drilling and workover projects, which tend to produce and use large amounts
of various oilfield fluids. We also own a number of salt water disposal wells.
In addition, we provide haul/ equipment trucks that are used to move large
pieces of equipment from one wellsite to the next. Demand and pricing for these
services are generally related to demand for our well service and drilling rigs.
ANCILLARY OILFIELD SERVICES
We provide ancillary oilfield services, which include among others: hot
oiling; wireline; frac tank rentals; well site construction; roustabout
services; fishing and other tool rentals; blowout preventers (BOPs); and foam
units and air drilling services. Demand and pricing for these services are
generally related to demand for our well service and drilling rigs.
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CONTRACT DRILLING
We provide contract drilling services to major oil companies and
independent oil and natural gas producers onshore the continental United States
in the Permian Basin, the Four Corners region, Michigan, the Northeast, and the
Rocky Mountains and internationally in Argentina and Ontario, Canada. Contract
drilling services are primarily provided under standard dayrate, and, to a
lesser extent, footage or turnkey contracts. Drilling rigs vary in size and
capability and may include specialized equipment. The majority of our drilling
rigs are equipped with mechanical power systems and have depth ratings ranging
from approximately 4,500 to 12,000 feet. We have one drilling rig with a depth
rating of approximately 18,000 feet. Like workover services, the demand for
contract drilling is directly related to expectations relating to, and changes
in, oil and natural gas prices which in turn, are driven by the supply of and
demand for these commodities.
FOREIGN OPERATIONS
We also operate each of our business segments discussed above in
Argentina and Ontario, Canada. Our foreign operations currently own 26 well
servicing rigs, 57 oilfield trucks and eight drilling rigs in Argentina and
three well servicing rigs, four oilfield trucks and three drilling rigs in
Ontario, Canada.
CUSTOMERS
Our customers include major oil companies, independent oil and natural
gas production companies, and foreign national oil and natural gas production
companies. No single customer in fiscal 2001 accounted for 10% or more of our
consolidated revenues.
COMPETITION AND OTHER EXTERNAL FACTORS
Despite the significant consolidation in the domestic well servicing
industry, there are numerous smaller companies that compete in our well
servicing markets. Nonetheless, we believe that our performance, equipment,
safety, and availability of equipment to meet customer needs and availability of
experienced, skilled personnel is superior to that of its competitors.
In the well servicing markets, an important competitive factor in
establishing and maintaining long-term customer relationships is having an
experienced, skilled and well-trained work force. In recent years, many of our
larger customers have placed increased emphasis on the safety records and
quality of the crews, equipment and services provided by their contractors. We
have, and will continue to devote substantial resources toward employee safety
and training programs. Management believes that many of our competitors,
particularly small contractors, have not undertaken similar training programs
for their employees. Management believes that our safety record and reputation
for quality equipment and service are among the best in the industry.
In the contract drilling market, we compete with other regional and
national oil and natural gas drilling contractors, some of which have larger rig
fleets with greater average depth capabilities and a few that have better
capital resources than us. Management believes that the contract drilling
industry is less consolidated than the well servicing industry, resulting in a
contract drilling market that is more price competitive. Nonetheless, we believe
that it is competitive in terms of drilling performance, equipment, safety,
pricing, availability of equipment to meet customer needs and availability of
experienced, skilled personnel in those regions in which we operate.
The need for well servicing and contract drilling fluctuates, primarily,
in relation to the price of oil and natural gas which, in turn, is driven by the
supply of and demand for oil and natural gas. As supply of those commodities
decreases and demand increases, service and maintenance requirements increase as
oil and natural gas producers attempt to maximize the producing efficiency of
their wells in a higher priced environment.
EMPLOYEES
As of June 30, 2001, we employed approximately 9,300 persons
(approximately 9,220 in well servicing and contract drilling and 80 in
corporate). Our employees are not represented by a labor union and are not
covered by
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collective bargaining agreements. We have not experienced work stoppages
associated with labor disputes or grievances and considers its relations with
its employees to be satisfactory.
ENVIRONMENTAL REGULATIONS
Our operations are subject to various local, state and federal laws and
regulations intended to protect the environment. Our operations routinely
involve the handling of waste materials, some of which are classified as
hazardous substances. Consequently, the regulations applicable to our operations
include those with respect to containment, disposal and controlling the
discharge of any hazardous oilfield waste and other non-hazardous waste material
into the environment, requiring removal and cleanup under certain circumstances,
or otherwise relating to the protection of the environment. Laws and regulations
protecting the environment have become more stringent in recent years, and may
in certain circumstances impose "strict liability," rendering a party liable for
environmental damage without regard to negligence or fault on the part of such
party. Such laws and regulations may expose us to liability for the conduct of,
or conditions caused by, others, or for our acts, which were in compliance with
all applicable laws at the times such acts were performed. Cleanup costs and
other damages arising as a result of environmental laws, and costs associated
with changes in environmental laws and regulations could be substantial and
could have a material adverse effect on our financial condition. From time to
time, claims have been made and litigation has been brought against us under
such laws. However, the costs incurred in connection with such claims and other
costs of environmental compliance have not had any material adverse effect on
our operations or financial statements in the past, and management is not
currently aware of any situation or condition that it believes is likely to have
any such material adverse effect in the future. Management believes that it
conducts our operations in substantial compliance with all material federal,
state and local regulations as they relate to the environment. Although we have
incurred certain costs in complying with environmental laws and regulations,
such amounts have not been material to our financial results during the past
three fiscal years.
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MANAGEMENT
DIRECTORS AND EXECUTIVE OFFICERS
The following table sets forth the names and ages, as of October 25,
2001, of each of our executive officers and directors and includes their current
positions.
NAME AGE POSITION
Francis D. John...................... 47 Chairman of the Board, President, Chief Executive Officer and
Chief Operating Officer
David J. Breazzano................... 45 Director
Kevin P. Collins..................... 51 Director
William D. Fertig.................... 45 Director
William D. Manly..................... 78 Director
W. Phillip Marcum.................... 57 Director
Morton Wolkowitz..................... 73 Director
Thomas K. Grundman................... 41 Executive Vice President of International Operations, Chief
Financial Officer and Chief Accounting Officer
James J. Byerlotzer................... 55 Executive Vice President of Domestic Operations
Francis D. John has been the President and Chief Executive Officer since
October 1989. In addition, Mr. John has been Chairman of the Board since August
1996. Mr. John re-assumed the duties of Chief Operating Officer in April 1999.
He has been a Director and President since June 1988 and served as the Chief
Financial Officer from October 1989 through July 1997. Before joining the
Company, he was Executive Vice President of Finance and Manufacturing of
Fresenius U.S.A., Inc. Mr. John previously held operational and financial
positions with Unisys, Mack Trucks and Arthur Andersen. He received a BS from
Seton Hall University and an MBA from Fairleigh Dickinson University.
David J. Breazzano has been a Director since October 1997. Mr. Breazzano
is one of the founding principals at DDJ Capital Management, LLC, an investment
management firm established in 1996. Mr. Breazzano previously served as a Vice
President and Portfolio Manager at Fidelity Investments ("Fidelity") from 1990
to 1996. Prior to joining Fidelity, Mr. Breazzano was President and Chief
Investment Officer of the T. Rowe Price Recovery Fund. He is also a director of
Waste Systems International, Inc. and Samuels Jewelers, Inc. He holds a BA from
Union College and an MBA from Cornell University.
Kevin P. Collins has been a Director since March 1996. Mr. Collins has
been a managing member of the Old Hill Company LLC since 1997. From 1992 to
1997, he served as a principal of JHP Enterprises, Ltd., and from 1985 to 1992,
as Senior Vice President of DG Investment Bank, Ltd., both of which were engaged
in providing corporate finance and advisory services. Mr. Collins was a director
of WellTech, Inc. ("WellTech") from January 1994 until March 1996 when WellTech
was merged into the Company. Mr. Collins is also a director of The Penn Traffic
Company, Metretek Technologies, Inc. and London Fog Industries, Inc. He holds a
BS and an MBA from the University of Minnesota.
William D. Fertig has been a Director since April 2000. Mr. Fertig has
been a Principal, Manager of Sales and Training at McMahan Securities Co. L.P.
since 1990. Mr. Fertig previously served as a Senior Vice President and Manager
of Convertible Sales at Drexel Burnham Lambert prior to joining McMahan
Securities in 1990, and from 1979 to 1989, served as Vice President and
Convertible Securities Sales Manager at Credit Suisse First Boston. He holds a
BS from Allegheny College and an MBA from NYU Graduate Business School.
William D. Manly has been a Director since December 1989. He retired from
his position as an Executive Vice President of Cabot Corporation in 1986, a
position he had held since 1978. Mr. Manly is a director of Metallamics, Inc.
and CitiSteel, Inc. He holds a BS and an MS from the University of Notre Dame.
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W. Phillip Marcum has been a Director since March 1996. Mr. Marcum was a
director of WellTech from January 1994 until March 1996 when WellTech was merged
into the Company. From October 1995 until March 1996, Mr. Marcum was the acting
Chairman of the Board of Directors of WellTech. He has been Chairman of the
Board, President and Chief Executive Officer of Metretek Technologies, Inc.,
formerly known as Marcum Natural Gas Services, Inc. ("Metretek Technologies"),
since January 1991 and is a director of TestAmerica, Inc. He holds a BBA from
Texas Tech University.
Morton Wolkowitz has been a Director since December 1989. Mr. Wolkowitz
served as President and Chief Executive Officer of Wolkow Braker Roofing
Corporation, a company that provided a variety of roofing services, from 1958
through 1989. Mr. Wolkowitz has been a private investor since 1989. He holds a
BS from Syracuse University.
Thomas K. Grundman has been an Executive Vice President and the Chief
Financial Officer since July 1999 and the Chief Accounting Officer since
November 1999. Effective December 1999, Mr. Grundman became Executive Vice
President of International Operations. Mr. Grundman also served as Treasurer
from July 1999 through August 2000. He joined the Company in April 1999 as Sr.
Vice President of Strategic and Business Development. From late 1996 through
April 1999, Mr. Grundman was Senior Vice President at PNC Bank, N.A. where he
ran the Oil and Gas Corporate Finance Group and was responsible for providing
financing and advisory services in all sectors of the energy industry. From 1984
through 1996, Mr. Grundman held several positions at Chase Manhattan Bank and
its predecessor institutions, most recently as a Managing Director in the oil
and gas group. Mr. Grundman holds a BS in Finance from Syracuse University.
James J. Byerlotzer has been Executive Vice President of Domestic Well
Service and Drilling Operations since July 1999. Effective December 1999, Mr.
Byerlotzer's title was changed to Executive Vice President of Domestic
Operations. He joined the Company in September 1998 as Vice President--Permian
Basin Operations after the Company's acquisition of Dawson Production Services,
Inc. ("Dawson"). From February 1997 to September 1998, he served as the Senior
Vice President and Chief Operating Officer of Dawson. From 1981 to 1997, Mr.
Byerlotzer was employed by Pride Petroleum Services, Inc. ("Pride"). Beginning
in February 1996, Mr. Byerlotzer served as the Vice President--Domestic
Operations of Pride. Prior to that time, he served as Vice President--Permian
Basin of Pride and in various other operating positions in Pride's Gulf Coast
and California operations. Mr. Byerlotzer holds a BA from the University of
Missouri in St. Louis.
Directors are elected at the Company's annual meeting of stockholders and
serve until the next annual meeting of stockholders and until their successors
are elected and qualified. Each executive officer holds office until the first
meeting of the Board of Directors following the annual meeting of stockholders
and until his successor has been duly elected and qualified.
DIRECTOR COMPENSATION
No director who is also an employee of our or any of its subsidiaries
received any fees from us for his services as a Director or as a member of any
committee of the Board. During the fiscal year ended June 30, 2001 all other
Directors ("Non-employee Directors") received a fee equal to $3,000 per month
for each month of service and are reimbursed for travel and other expenses
directly associated with Company business. Additionally, during fiscal 2001we
paid the premiums with respect to life insurance for the benefit of Messrs.
Collins and Marcum in the amount of $2,906 and $5,389, respectively.
EXECUTIVE COMPENSATION
SUMMARY COMPENSATION TABLE. The following table reflects the compensation
for services to the Company for the years ended June 30, 2001, 2000 and 1999 for
(i) the Chief Executive Officer of the Company and (ii) the other two executive
officers of the Company other than the Chief Executive Officer who were serving
as executive officers at June 30, 2001 (the "Named Executive Officers").
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LONG TERM
COMPENSATION
ANNUAL AWARDS
COMPENSATION -------------- ---------
------------ OTHER ANNUAL SHARES ALL OTHER
FISCAL COMPENSATION UNDERLYING COMPENSATION
NAME AND PRINCIPAL POSITION YEAR SALARY($) BONUS($) ($) OPTIONS(1) ($)
--------------------------- ------- -------- -------- ----------- ---------- ------------
Francis D. John............................. 2001 594,885 835,000 67,211(2) 1,460,000 74,998(3)
President, Chief Executive Officer and 2000 589,519 307,776 -- 2,000,000 --
Chief Operating Officer 1999 429,000 -- -- 1,200,000 --
Thomas K. Grundman......................... 2001 274,966 315,000 -- 135,000 78,519(4)
Executive Vice President of International 2000 203,845 100,000 -- 500,000 24,975(5)
Operations, Chief Financial Officer, and 1999 35,259(6) -- -- 300,000 --
Chief Accounting Officer
James J. Byerlotzer........................ 2001 249,324 275,000 -- 115,000 101,000(7)
Executive Vice President of Domestic 2000 185,000 89,000 -- 300,000 100,250(8)
Operation 1999 121,153(9) -- -- 260,000 75,000(10)
(1) Represents the number of shares issuable pursuant to vested and non-vested
stock options granted during the applicable fiscal year.
(2) Represents reimbursement of (i) medical expenses of $12,186, (ii)
professional fees of $45,025, and (iii) other miscellaneous personal
expenses of $10,000.
(3) Represents premium payments by the Company for life and health insurance.
(4) Represents (i) forgiveness of relocation loan indebtedness and interest to
Mr. Grundman of $52,794, (ii) premium payments made by the Company for life
insurance of $24,725 and (iii) contributions by the Company on behalf of
Mr. Grundman to the Key Energy Services, Inc. 401(k) Savings & Retirement
Plan of $1,000.
(5) Represents (i) premium payments by the Company for life insurance of
$24,725 and (ii) contributions by the Company on behalf of Mr. Grundman to
the Key Energy Services, Inc. 401(k) Savings & Retirement Plan of $250.
(6) Mr. Grundman joined the Company as an executive officer in April 1999.
(7) Represents (i) payments to Mr. Byerlotzer pursuant to a non-competition
agreement entered into in connection with the Company's acquisition of
Dawson Production Services, Inc. of $100,000, and (ii) contributions by the
Company on behalf of Mr. Byerlotzer to the Key Energy Services, Inc. 401(k)
Savings & Retirement Plan of $1,000.
(8) Represents (i) payments to Mr. Byerlotzer pursuant to a non-competition
agreement entered into in connection with the Company's acquisition of
Dawson Production Services, Inc. of $100,000, and (ii) contributions by the
Company on behalf of Mr. Byerlotzer to the Key Energy Services, Inc. 401(k)
Savings & Retirement Plan of $250.
(9) Mr. Byerlotzer joined the Company as an executive officer in September
1998.
(10) Represents payments to Mr. Byerlotzer pursuant to a non-competition
agreement entered into in connection with the Company's acquisition of
Dawson Production Services, Inc.
OPTION GRANTS IN LAST FISCAL YEAR
The following table sets forth certain information relating to options
granted under the Key Energy Group, Inc. 1997 Incentive Plan (the "Plan") and
outside the Plan to the Named Executive Officers during fiscal 2001. The Company
did not grant any stock appreciation rights during fiscal 2001.
S-24
INDIVIDUAL GRANTS
NUMBER OF % OF TOTAL
SECURITIES OPTIONS
OF GRANTED TO
UNDERLYING EMPLOYEES EXERCISE GRANT
OPTIONS IN FISCAL YEAR PRICE EXPIRATION DATE PRESENT
NAME GRANTED (1) PER SHARE DATE VALUE (2)
---- ------------- ----------------- ---------- ------------ -----------
Francis D. John................. 960,000(3) 37.9% $ 8.25 08/07/10 $4,339,000
500,000(4) 19.7% $ 8.25 12/11/10 2,260,000
Thomas K. Grundman.............. 135,000(5) 5.3% $ 8.25 12/11/10 620,000
James J. Byerlotzer............. 115,000(6) 4.5% $ 8.25 12/11/10 520,000
(1) Based on options to purchase a total of 2,533,000 of Common Stock granted
during fiscal 2001.
(2) The grant date value of stock options was estimated using the
Black-Scholes option pricing model with the following assumptions:
expected volatility--59%; risk-free interest rate--4.3%; time of
exercise--5 years; and no dividend yield.
(3) These options were granted on August 7, 2000, and vested immediately on
the date of grant.
(4) These options were granted on December 11, 2000 and vested immediately on
the date of grant.
(5) These options were granted on December 11, 2000 and vest in three equal
annual installments commencing on July 1, 2001 as follows: 45,000 on July
1, 2001; 45,000 on July 1, 2002; and 45,000 on July 1, 2003.
(6) These options were granted on December 11, 2000 and vest in three equal
annual installments commencing on July 1, 2001 as follows: 38,333 on July
1, 2001; 38,333 on July 1, 2002; and 38,334 on July 1, 2003.
AGGREGATED OPTION EXERCISES AND VALUES AS OF FISCAL YEAR END
The following table sets forth certain information as of June 30, 2001
relating to the number and value of (i) options exercised by the Named Executive
Officers and (ii) unexercised options held by the Named Executive Officers.
NUMBER OF UNEXERCISED OPTIONS AT VALUE OF UNEXERCISED IN-THE MONEY-
SHARES JUNE 30, 2001 OPTIONS AT JUNE 30, 2000(2)
ACQUIRED ON VALUE REALIZED ------------------------- ---------------------------------
EXERCISE(#) ($) (1) EXERCISABLE UNEXERCISABLE EXERCISABLE UNEXERCISABLE
---------- ----------- ---------- ----------- ----------- ------------
Francis D. John............ 1,825,000 12,850,875 2,418,333 791,667 $ 5,148,066 $ 1,732,709
Thomas K. Grundman......... 200,000 1,934,000 250,000 485,000 $ 585,000 $ 1,718,650
James J. Byerlotzer........ 165,000 1,595,550 159,167 350,833 $ 391,931 $ 1,311,469
(1) The dollar values in this column are calculated by determining the
difference between the fair market value of the Company's common stock on
the date of exercise of the relevant options and the exercise price of
such options. The fair market value on the date of exercise is based on
the last sale price of the Company's common stock on the NYSE on such
date.
(2) The dollar values in this column are calculated by determining the
difference between the fair market value of the Common Stock for which
the relevant options are exercisable as of the end of the fiscal year and
the exercise price of the options. The fair market value is based on the
last sale price of the Common Stock on the NYSE on June 29, 2001 which
was $10.84.
EMPLOYMENT AGREEMENTS WITH EXECUTIVE OFFICERS
Effective as of October 16, 2001, we entered into second amended and
restated employment agreement with Mr. John, which provides that Mr. John will
serve as our Chairman of the Board, President and Chief Executive Officer for a
five-year term commencing July 1, 2001 and continuing until June 30, 2006, with
an automatic one-year renewal on each June 30, commencing on June 30, 2006,
unless terminated by us or by Mr. John with proper notice. Under this employment
agreement, Mr. John's annual base salary is $595,000 per year until December 31,
2002 and $695,000 per year thereafter, in each case subject to increase after
annual reviews by the Board of
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Directors. This employment agreement also provides that Mr. John will be
entitled to (i) participate in our Performance Compensation Plan, with
performance criteria to be approved by the Compensation Committee, (ii) receive
additional bonuses at the discretion of the Compensation Committee, and (iii)
participate in stock option grants made to our executives. In addition to salary
and bonus, Mr. John is entitled to medical, dental, accident and life insurance,
reimbursement of expenses and various other benefits. To the extent Mr. John is
taxed on any such reimbursement or benefit, we will pay Mr. John an amount
which, on an after-tax basis, equals the amount of these taxes.
In the event that we terminate Mr. John's employment voluntarily or by
nonrenewal, or by Mr. John for "Good Reason," or if Mr. John's employment is
terminated by us or by Mr. John following a "Change in Control" (in each case as
defined in the employment agreement), Mr. John will be entitled to receive: (i)
his accrued but unpaid salary and bonuses to the date of termination, and a PRO
RATA bonus for the year in which termination occurs; (ii) a severance payment in
an amount equal to five times his average total annual compensation (i.e.,
salary plus bonus) for the preceding three years; (iii) immediate vesting and
exercisability of all stock options held by him (to the extent not already
vested and exercisable) for the remainder of the original terms of the options;
(iv) any other amounts or benefits earned, accruing or owing to him, but not yet
paid; and (v) continued participation in medical, dental and life insurance
coverage, as well as the receipt of other benefits to which he was entitled,
until the first to occur of the third year anniversary of the date his
employment was terminated or the date on which he receives equivalent coverage
and benefits under the plans and programs of a subsequent employer (or, in the
event of a "Change in Control," an amount in cash equal to the reasonable
expenses that we would incur if it were to provide these benefits for three
years). In the event that Mr. John's employment is terminated as a result of Mr.
John's disability, Mr. John will be entitled to receive (i) through (v) above,
except that his severance compensation will be an amount equal to three times
his average total annual compensation for the preceding three years, reduced by
the amount of any company-paid disability insurance proceeds paid to Mr. John.
In the event that we terminate Mr. John's employment for "Cause," as defined in
the employment agreement, or by Mr. John voluntarily or by nonrenewal, he will
be entitled to receive only (i) and (v) above and will forfeit any restricted
stock or options not previously vested. In the event Mr. John's employment is
terminated by reason of his death, he will be entitled to receive (i), (iii),
(iv) and (v) above, except that his family will be entitled to receive the
medical and dental insurance coverage provided in (v) above until the death of
Mr. John's spouse. In addition, if any of the above benefits are subject to the
tax imposed by Section 4999 of the Internal Revenue Code, we will reimburse Mr.
John for such tax on an after-tax basis.
The employment agreement specifies that Mr. John may not engage in any
activities that are competitive with ours for a period of three years after the
termination of his employment.
Pursuant to the employment agreement, we will pay to Mr. John, on or
prior to December 31, 2001, a one-time retention incentive bonus equal to the
aggregate amount of all principal and interest on loans we previously made to
Mr. John that were to be forgiven over a ten year period beginning July 1, 2001,
as well as the amount, on an after-tax basis, required to pay the taxes incurred
Mr. John in connection with such payment. The after-tax proceeds of the bonus
will be used to repay such loans. The employment agreement goes on to provide
that if, prior to June 30, 2011, we terminate Mr. John for Cause, or by Mr. John
voluntarily or by nonrenewal, Mr. John will repay us a percentage of the
retention incentive bonus beginning at 100% during the first year and declining
at the rate of 10% each year to 0% on and after June 30, 2011.
Mr. Grundman entered into an employment agreement with us effective as of
July 1, 1999, which was amended effective July 1, 2000. This agreement is for a
three-year term and thereafter for successive one-year terms unless terminated
60 days prior to the commencement of an extension term. Under this agreement,
Mr. Grundman initially receives an annual base compensation of $200,000, which
can be increased but not decreased, and is eligible for additional annual
incentive bonuses. If, during the term of his employment agreement, we terminate
Mr. Grundman for any reason other than for cause, or if he terminates his
employment because of a material breach by the company or following a change of
control of the company, he will be entitled to severance compensation equal to
his base compensation in effect at the time of termination payable in equal
installments over a 36-month period following termination; PROVIDED, HOWEVER,
that if termination results from a change of control of the company, severance
compensation will be payable in a lump sum on the date of termination. Also, if
Mr. Grundman
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is subject to the tax imposed by Section 4999 of the Internal Revenue code, we
have agreed to reimburse him for such tax on an after-tax basis.
Effective as of December 31, 2001, we entered into an employment
agreement with Royce Mitchell, which provides that Mr. Mitchell will serve as
our Executive Vice President and Chief Financial Officer for a three-year term
commencing January 1, 2002 and continuing until December 31, 2004, with an
automatic twelve-month renewal on each December 31, commencing on December 31,
2004, unless terminated by us or by Mr. Mitchell with proper notice. Under this
employment agreement, Mr. Mitchell's annual base salary is $295,000 per year and
subject to increase after annual reviews by the Board of Directors. This
employment agreement also provides that Mr. Mitchell will be entitled to (i)
participate in the our Performance Compensation Plan, with performance criteria
to be approved by the Compensation Committee, (ii) receive additional bonuses at
the discretion of the Compensation Committee which it, after consultation with
the Chief Executive Officer, deems appropriate; and (iii) participate in stock
option grants made to our executives. In addition to salary and bonus, Mr.
Mitchell is entitled to medical, dental, accident and life insurance,
reimbursement of expenses and various other benefits.
In the event that Mr. Mitchell's employment is terminated by Mr. Mitchell
for "Good Reason" or by us for reasons other than "Cause" (as defined in the
employment agreement) or "Disability" (as defined in the employment agreement),
or if Mr. Mitchell's employment is terminated by either party following a Change
in Control (as defined in the employment agreement), Mr. Mitchell will be
entitled to receive: (i) severance compensation in the aggregate amount of three
times his base salary at the rate in effect on the termination date, payable in
thirty six equal installments, provided, however, that if Mr. Mitchell's
employment is terminated within one year following a Change in Control or if we
terminate Mr. Mitchell for other than Cause or Disability in anticipation of a
Change in Control, the severance payment shall be increased by an amount equal
to three times the average annual total bonuses we paid to Mr. Mitchell during
the three year period (or shorter period as Mr. Mitchell may have been employed)
preceding the date on which the notice of termination is given and shall be
payable in one lump sum on the effective date of the termination; (ii) immediate
vesting and exercisability of all stock options held by him (to the extent not
already vested and exercisable); (iii) continued participation in medical,
dental and life insurance coverage, as well as the receipt of other benefits to
which he was entitled, until the first to occur of the third anniversary of the
date his employment was terminated or the date on which he received equivalent
coverage and benefits under the plans and programs of a subsequent employer. In
the event Mr. Mitchell's employment is terminated by reason of disability, in
addition to the other severance and benefits to which he is entitled, he shall
also be entitled to three times his base salary at the rate in effect at the
time of termination and payable in 36 equal monthly installments reduced by the
amount of any disability proceeds paid to Mr. Mitchell. In the event there is a
Change of Control following Mr. Mitchell's termination and while Mr. Mitchell is
entitled to severance payments, any severance payments which remain unpaid as of
the Change of Control shall be paid in one lump sum as of the Change in Control.
Notwithstanding the above, in the event of the termination of Mr. Mitchell's
employment for any reason, Mr. Mitchell (or his estate) is entitled to receive:
(i) any unpaid portion of his base salary through the effective date of
termination; (ii) accrued but unused vacation (payable in an amount equal to the
base salary divided by 255 and multiplied by the number of accrued but unused
vacation days; (iii) any prior fiscal year bonus earned but not paid; (iv)
provided that Mr. Mitchell's employment was not terminated for Cause, a pro-rata
portion of any bonus for the current fiscal year (so long as certain performance
objectives have been met or it is reasonably likely such performance goals would
have been met had Mr. Mitchell remained employed by us); and (v) any amounts for
expense reimbursement and similar items which have been properly incurred prior
to termination and have not yet been paid. Also, if Mr. Mitchell is subject to
the tax imposed by Section 4999 of the Internal Revenue Code, we have agreed to
pay him an amount equal to the tax , plus any amounts necessary to "gross up"
Mr. Mitchell for additional taxes resulting from the payments to him.
The employment agreement specifies that Mr. Mitchell may not engage in
any activities that are competitive with ours so long as Mr. Mitchell is
employed by us and for a period thereafter (a) as Mr. Mitchell is entitled to
receive severance payments under the employment agreement; or (b) for a period
of 3 years if Mr. Mitchell's severance payment is accelerated due to a Change in
Control; or (c) for a period of 12 months if we terminate Mr. Mitchell's
employment for Cause or if Mr. Mitchell terminates his employment for any
reason, other than Good Reason
S-27
Pursuant to the employment agreement, we will pay to Mr. Mitchell, on or
prior to December 31, 2001, a one-time bonus of $100,000. The employment
agreement goes on to provide that if, prior to December 31, 2004, we terminate
Mr. Mitchell for Cause, or by Mr. Mitchell for Good Reason, Mr. Mitchell will
repay us a percentage of the bonus beginning at 100% during the first year and
declining at the rate of 33 1/3% each year to 0% on and after December 31,
2004.
Effective as of December 31, 2001, we entered into an employment
agreement with Jim Byerlotzer, which provides that Mr. Byerlotzer will serve as
our Executive Vice President and Chief Operating Officer for a term commencing
January 1, 2002 and continuing until June 30, 2004, with an automatic
twelve-month renewal on each June 30, commencing on June 30, 2004, unless
terminated by us or by Mr. Byerlotzer with proper notice. Under this employment
agreement, Mr. Byerlotzer's annual base salary is $275,000 until July 1,2002 and
$340,000 per year thereafter, in each case subject to increase after annual
reviews by the Board of Directors. This employment agreement also provides that
Mr. Byerlotzer will be entitled to (i) participate in the our Performance
Compensation Plan, with performance criteria to be approved by the Compensation
Committee, (ii) receive additional bonuses at the discretion of the Compensation
Committee which it, after consultation with the Chief Executive Officer, deems
appropriate; and (iii) participate in stock option grants made to our
executives. In addition to salary and bonus, Mr. Byerlotzer is entitled to
medical, dental, accident and life insurance, reimbursement of expenses and
various other benefits.
In the event that Mr. Byerlotzer's employment is terminated by Mr.
Byerlotzer for "Good Reason" or by us for reasons other than "Cause" (as defined
in the employment agreement) or "Disability" (as defined in the employment
agreement), or if Mr. Byerlotzer's employment is terminated by either party
following a Change in Control (as defined in the employment agreement), Mr.
Byerlotzer will be entitled to receive: (i) severance compensation in the
aggregate amount of three times his base salary at the rate in effect on the
termination date, payable in thirty six equal installments, provided, however,
that if Mr. Byerlotzer's employment is terminated within one year following a
Change in Control or if we terminate Mr. Byerlotzer for reasons other than Cause
or Disability in anticipation of a Change in Control, the severance payment
shall be increased by an amount equal to three times the average annual total
bonuses we paid to Mr. Byerlotzer during the three year period (or shorter
period as Mr. Byerlotzer may have been employed) preceding the date on which the
notice of termination is given and shall be payable in one lump sum on the
effective date of the termination; (ii) immediate vesting and exercisability of
all stock options held by him (to the extent not already vested and
exercisable); (iii) continued participation in medical, dental and life
insurance coverage, as well as the receipt of other benefits to which he was
entitled, until the first to occur of the third anniversary of the date his
employment was terminated or the date on which he received equivalent coverage
and benefits under the plans and programs of a subsequent employer. In the event
Mr. Byerlotzer's employment is terminated by reason of disability, in addition
to the other severance and benefits to which he is entitled, he shall also be
entitled to three times his base salary at the rate in effect at the time of
termination and payable in thirty six equal monthly installments reduced by the
amount of any disability proceeds paid to Mr. Byerlotzer. In the event there is
a Change of Control following Mr. Byerlotzer's termination and while Mr.
Byerlotzer is entitled to severance payments, any severance payments which
remain unpaid as of the Change of Control shall be paid in one lump sum as of
the Change in Control. Notwithstanding the above, in the event of the
termination of Mr. Byerlotzer's employment for any reason, Mr. Byerlotzer (or
his estate) is entitled to receive: (i) any unpaid portion of his base salary
through the effective date of termination; (ii) accrued but unused vacation
(payable in an amount equal to the base salary divided by 255 and multiplied by
the number of accrued but unused vacation days; (iii) any prior fiscal year
bonus earned but not paid; (iv) provided that Mr. Byerlotzer's employment was
not terminated for Cause, a pro-rata portion of any bonus for the current fiscal
year (so long as certain performance objectives have been met or it is
reasonably likely such performance goals would have been met had Mr. Byerlotzer
remained employed by us); and (v) any amounts for expense reimbursement and
similar items which have been properly incurred prior to termination and have
not yet been paid. Also, if Mr. Byerlotzer is subject to the tax imposed by
Section 4999 of the Internal Revenue Code, we have agreed to pay him an amount
equal to the tax, plus any amounts necessary to "gross up" Mr. Byerlotzer for
additional taxes resulting from the payments to him.
The employment agreement specifies that Mr. Byerlotzer may not engage
in any activities that are competitive with ours so long as Mr. Byerlotzer is
employed by us and for a period thereafter (a) as Mr. Byerlotzer is entitled to
receive severance payments under the employment agreement; or (b) for a period
of 3 years if Mr. Byerlotzer's severance payment is accelerated due to a Change
in Control; or (c) for a period of 12 months if we
S-28
terminate Mr. Byerlotzer's employment for Cause or if Mr. Byerlotzer terminates
his employment for any reason, other than Good Reason.
CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
In connection with the negotiation of the terms of a five-year employment
agreement with Mr. Francis D. John, our Chairman of the Board, President and
Chief Executive Officer, and as an inducement to Mr. John to enter into such
employment agreement, we entered into a separate agreement with Mr. John dated
as of August 2, 1999, which as amended through June 30, 2001, provides that $6.5
million in loans we previously made to Mr. John, together with the accrued
interest payable thereon (accruing at a rate equal to 125 basis points above
LIBOR, adjusted monthly) will be forgiven ratably during the ten year period
commencing on July 1, 2001 and ending on June 30, 2011. The agreement provides
that the foregoing forgiveness of indebtedness is predicated and conditioned
upon Mr. John remaining employed by us during such period. In addition, in the
event that Mr. John is terminated by us for "Cause" (as defined in the
agreement), or in the event that Mr. John voluntarily terminates his employment
with us, the agreement further provides that the entire remaining principal
balance of these loans, together with accrued interest payable thereon, will
become immediately due and payable by Mr. John. However, in the event that Mr.
John's employment is terminated for "Good Reason", or as a result of Mr. John's
death or "Disability", or as a result of a "Change in Control" (all as defined
in that agreement), the agreement stipulates that the remaining principal
balance outstanding on the loans, together with accrued interest thereon will be
forgiven. This agreement further provides that with respect to any forgiveness
of the payment of principal and interest on the loans, Mr. John will be entitled
to receive a "gross-up" payment in an amount sufficient for him to pay any
federal, state, or local income taxes that may be due and payable by him with
respect to the forgiveness of such indebtedness (principal and interest). The
agreement has been effectively superseded by Mr. John's new employment agreement
that provides for a one-time retention incentive bonus used to repay all amounts
owed under the agreement (see Item 11--Executive Compensation--Employment
Agreements with Executive Officers).
In connection with the negotiation of an employment agreement with Thomas
K. Grundman, our Executive Vice President of International Operations, Chief
Financial Officer and Chief Accounting Officer, we made a $240,000 short-term
loan and a $150,000 relocation loan to assist Mr. Grundman's relocation to our
executive offices. Interest on these loans accrues at a rate of 6.125% per
annum. The short-term loan has been repaid. The relocation loan together with
accrued interest will be forgiven in three installments of $50,000 each on July
1, 2000, 2001 and 2002; PROVIDED, HOWEVER, that if Mr. Grundman's employment is
terminated during such period in a way that (i) triggers severance obligations,
all amounts owed shall be immediately forgiven or (ii) does not trigger
severance obligations, all amounts owed shall be immediately due and payable.
This agreement further provides that with respect to any forgiveness of the
payment of principal and interest on the loans, Mr. Grundman will be entitled to
receive a "gross-up" payment in an amount sufficient for him to pay any federal,
state, or local income taxes that may be due and payable by him with respect to
the forgiveness of such indebtedness (principal and interest).
OWNERSHIP OF CAPITAL STOCK
MANAGEMENT
The following table sets forth as of October 25, 2001, the number of
shares of Common Stock beneficially owned by each (i) each Director, (ii) each
Named Executive Officer, and (iii) all Directors and executive officers of the
Company as a group. Except as noted below, each holder has sole voting and
investment power with respect to all shares of Common Stock listed as owned by
such person.
PERCENTAGE OF
NUMBER OF OUTSTANDING
NAME OF BENEFICIAL OWNER SHARES(1) SHARES(2)
------------------------ --------- ---------
Francis D. John (3)......................................... 2,613,833 2.5%
Kevin P. Collins (4)........................................ 223,405 *
William D. Fertig (5)....................................... 30,000 *
William D. Manly (6)........................................ 221,042 *
W. Philip Marcum (7)........................................ 223,405 *
S-29
PERCENTAGE OF
NUMBER OF OUTSTANDING
NAME OF BENEFICIAL OWNER SHARES(1) SHARES(2)
------------------------ --------- ---------
David J. Breazzano (8)...................................... 208,333 *
Morton Wolkowitz (9)........................................ 608,302 *
Thomas K. Grundman (10).................................... 355,000 *
James J. Byerlotzer (11).................................... 263,667 *
Directors and Executive Officers as a group (9 persons)..... 4,716,987 4.4%
* Less than 1%
(1) Includes all shares with respect to which each Director or executive
officer directly or indirectly, through any contract, arrangement,
understanding, relationship or otherwise, has or shares the power to vote
or to direct voting of such shares and/or to dispose or to direct the
disposition of such shares. Includes shares that may be purchased under
currently exercisable stock options and warrants.
(2) Based on 102,357,547 shares of Common stock outstanding at October 25,
2001, plus, for each beneficial owner, those number of shares underlying
currently exercisable options held by each executive officer or Director.
(3) Includes 2,543,333 shares issuable upon exercise of vested options. Does
not include 666,667 shares issuable pursuant to options that have not
vested.
(4) Includes 218,333 shares issuable upon the exercise of vested options.
Does not include 51,667 shares issuable pursuant to options that have not
vested.
(5) Includes 25,000 shares issuable upon the exercise of vested options. Does
not include 25,000 shares issuable pursuant to options that have not
vested.
(6) Includes 218,333 shares issuable upon the exercise of vested options.
Does not include 51,667 shares issuable pursuant to options that have not
vested.
(7) Includes 218,333 shares issuable upon the exercise of vested options.
Does not include 51,667 shares issuable pursuant to options that have not
vested.
(8) Includes 148,333 shares issuable upon the exercise of vested options.
Does not include 51,667 shares issuable pursuant to options that have not
vested.
(9) Includes 118,000 shares issuable upon the exercise of vested options.
Does not include 57,000 shares issuable pursuant to options that have not
vested.
(10) Includes 345,000 shares issuable upon the exercise of vested options.
Does not include 390,000 shares issuable pursuant to options that have
not vested.
(11) Includes 241,667 shares issuable upon the exercise of vested options.
Does not include 268,333 shares issuable pursuant to options that have
not vested.
CERTAIN BENEFICIAL OWNERS
The following table sets forth, as of October 25, 2001, certain
information regarding the beneficial ownership of Common Stock by each person,
other than the Company's directors or executive officers, who is known by the
Company to own beneficially more than 5% of the outstanding shares of Common
Stock.
SHARES BENEFICIALLY OWNED AT
OCTOBER 19, 2001
-----------------------------------
NAME AND ADDRESS OF BENEFICIAL OWNER, IDENTITY OF GROUP NUMBER PERCENT
-------------------------------------------------------
--------------- ---------------
Perkins, Wolf, McDonnell and Company (1).......................... 11,036,014(2) 10.8%
53 W. Jackson Blvd., Suite 722
Chicago, III 60604
Berger, L.L.C. (3)................................................ 9,810,240(2) 9.6%
210 University Boulevard
Suite 900
Denver, CO 80206
S-30
SHARES BENEFICIALLY OWNED AT
OCTOBER 19, 2001
-----------------------------------
NAME AND ADDRESS OF BENEFICIAL OWNER, IDENTITY OF GROUP NUMBER PERCENT
------------------------------------------------------- --------------- ---------------
Mellon Financial Corporation (4).................................. 6,183,414 6.0%
One Mellon Center
Pittsburgh, PA 15258
T. Rowe Price Associates, Inc. (5)................................ 6,735,600 6.6%
100 E. Pratt Street
Baltimore, MD 21202
----------
(1) As reported on Schedule 13G filed with the Commission on October 11,
2001.
(2) The Company believes that Perkins, Wolf, McDonell & Co. shares voting
power with respect to 9,810,240 of its shares with Berger, LLC and that,
therefore, the 9,810,240 shares shown as being beneficially owned by
Berger, LLC are the same securities shown as being beneficially owned by
Perkins, Wolf, McDonnell & Co.
(3) As reported on Schedule 13F filed with the Commission on August 14, 2001.
(4) As reported on Schedule 13G filed with the Commission on January 26,
2001.
(5) As reported on Schedule 13G (Amendment No. 1) filed with the Commission
on February 8, 2001.
PLAN OF DISTRIBUTION
Well will issue common stock from time to time in connection with
acquisitions by us or our subsidiaries of other businesses, assets or
securities. We expect that the terms of the acquisitions involving the issuance
of securities covered by this prospectus will be determined by direct
negotiations with the owners or controlling persons of the businesses, assets or
securities to be acquired by us or our subsidiaries. No underwriting discounts
or commissions will be paid in connection with the issuance of our common stock,
although finders' fees may be paid from time to time with respect to specific
mergers or acquisitions. Any person receiving such fees may be deemed to be an
underwriter within the meaning of the Securities Act.
LEGAL MATTERS
Certain legal matters in connection with this offering will be passed
upon for us by Porter & Hedges, L.L.P.
EXPERTS
Our consolidated financial statements as of December 31, 2001 and 2000,
and for each of the years in the three-year period ended December 31, 2001, have
been included or incorporated by reference herein in reliance upon the report of
KPMG LLP, independent certified public accountants, incorporated by reference
herein, and upon the authority of such firm as experts in accounting and
auditing.
S-31
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
PAGE
AUDITED FINANCIAL STATEMENTS
Consolidated Balance Sheets........................................................................ F-2
Consolidated Statement of Operations............................................................... F-3
Consolidated Statements of Comprehensive Income.................................................... F-4
Consolidated Statements of Cash Flows.............................................................. F-5
Consolidated Statements of Stockholders' Equity.................................................... F-6
Notes to Consolidated Financial Statements......................................................... F-7
Independent Auditors' Report....................................................................... F-37
UNAUDITED FINANCIAL STATEMENTS
Consolidated Balance Sheets as of December 31, 2001 (unaudited) and June 30, 2001................ F-38
Unaudited Consolidated Statements of Operations for the Three and Six Months Ended December 31, 2001 F-40
and 2000.........................................................................................
Unaudited Consolidated Statements of Cash Flows for the Three and Six Months Ended December 31, 2001 F-41
and 2000.........................................................................................
Unaudited Consolidated Statements of Comprehensive Income for the Three and Six Months Ended December F-42
31, 2001 and 2000................................................................................
Notes to Consolidated Financial Statements....................................................... F-43
F-1
KEY ENERGY SERVICES, INC.
CONSOLIDATED BALANCE SHEETS
JUNE 30, 2001 JUNE 30, 2000
--------------- ---------------
(THOUSANDS, EXCEPT SHARE DATA)
ASSETS
Current Assets:
Cash and cash equivalents......................................................... $ 2,098 $ 109,873
Accounts receivable, net of allowance for doubtful accounts ($4,082--2001,
$3,189--2000).................................................................... 177,016 123,203
Inventories....................................................................... 16,547 10,028
Income taxes receivable........................................................... -- 5,588
Prepaid expenses and other current assets......................................... 10,489 4,897
--------------- ---------------
Total current assets................................................................ 206,150 253,589
--------------- ---------------
Property and equipment:
Well servicing equipment.......................................................... 723,724 670,392
Contract drilling equipment....................................................... 119,122 105,454
Motor vehicles.................................................................... 64,907 55,011
Oil and gas properties and other related equipment, successful efforts method..... 44,245 43,855
Furniture and equipment........................................................... 24,865 11,013
Buildings and land................................................................ 37,812 34,712
--------------- ---------------
Total property and equipment........................................................ 1,014,675 920,437
Accumulated depreciation & depletion................................................ (220,959) (159,876)
-------------- ---------------
Net property and equipment.......................................................... 793,716 760,561
--------------- ---------------
Goodwill, net of accumulated amortization ($28,168--2001, $18,849--2000).......... 189,875 198,633
Deferred costs, net............................................................... 17,624 18,855
Notes receivable -- related parties............................................... 6,050 5,150
Other assets...................................................................... 14,869 9,477
--------------- ---------------
Total assets........................................................................ $ 1,228,284 $ 1,246,265
=============== ===============
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable.................................................................. $ 42,544 $ 35,801
Other accrued liabilities......................................................... 48,923 26,398
Accrued interest.................................................................. 16,140 15,994
Current portion of long-term debt................................................. 7,946 14,655
--------------- ---------------
Total current liabilities........................................................... 115,553 92,848
--------------- ---------------
Long-term debt, less current portion................................................ 485,961 651,945
Deferred revenue.................................................................... 14,104 17,031
Non-current accrued expenses........................................................ 8,388 1,847
Deferred tax liability.............................................................. 127,400 99,707
Commitments and contingencies....................................................... -- --
Stockholders' equity:
Common stock, $0.10 par value; 200,000,000 shares authorized, 101,440,166
and 97,209,504 shares issued, respectively at June 30, 2001 and June 30,
2000, respectively................................................................ 10,144 9,723
Additional paid-in capital........................................................ 444,768 413,962
Treasury stock, at cost; 416,666 shares at June 30, 2001 and June 30, 2000........ (9,682) (9,682)
Accumulated other comprehensive income............................................ 62 8
Retained earnings (deficit)....................................................... 31,586 (31,124)
--------------- ---------------
Total stockholders' equity.......................................................... 476,878 382,887
--------------- ---------------
Total liabilities and stockholders' equity.......................................... $ 1,228,284 $ 1,246,265
=============== ===============
SEE THE ACCOMPANYING NOTES WHICH ARE AN INTEGRAL PART OF
THESE CONSOLIDATED FINANCIAL STATEMENTS.
F-2
KEY ENERGY SERVICES, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS
YEAR ENDED JUNE 30,
------------------------------------------------
2001 2000 1999
-------------- -------------- --------------
(THOUSANDS, EXCEPT PER SHARE DATA)
REVENUES:
Well servicing........................................ $ 758,273 $ 559,492 $ 433,657
Contract drilling..................................... 107,639 68,428 50,613
Other, net............................................ 7,350 9,812 7,547
-------------- -------------- --------------
Total revenues.......................................... 873,262 637,732 491,817
-------------- -------------- --------------
COSTS AND EXPENSES:
Well servicing........................................ 493,108 399,940 324,965
Contract drilling..................................... 77,366 58,299 43,556
Depreciation, depletion and amortization.............. 75,147 70,972 62,074
General and administrative............................ 66,071 58,772 53,108
Bad debt expense...................................... 1,263 1,648 5,928
Debt issuance costs................................... -- -- 6,307
Interest.............................................. 56,560 71,930 67,401
Other expenses........................................ 4,464 4,147 2,907
Corporate restructuring............................... -- -- 4,504
-------------- -------------- --------------
Total costs and expenses................................ 773,979 665,708 570,750
Income (loss) before income taxes....................... 99,283 (27,976) (78,933)
Income tax benefit (expense)............................ (37,002) 7,406 25,675
-------------- -------------- --------------
INCOME (LOSS) BEFORE EXTRAORDINARY GAIN (LOSS) $ 62,281 $ (20,570) $ (53,258)
Extraordinary gain (loss) on retirement of debt, less
applicable income taxes of $255--23001 and
$580--2000............................................ 429 1,611 --
-------------- -------------- --------------
NET INCOME (LOSS)....................................... $ 62,710 $ (18,959) $ (53,258)
============== ============== ==============
EARNINGS (LOSS) PER SHARE:
Basic - before extraordinary gain (loss).............. $ 0.63 $ (0.25) $(1.94)
Extraordinary gain (loss) on retirement of debt,
net of tax........................................... -- 0.02 --
-------------- -------------- --------------
Basic - after extraordinary gain...................... $ 0.63 $ (0.23) $ (1.94)
============== ============== ==============
Diluted--before extraordinary gain.................... $ 0.61 $ (0.25) $ (1.94)
Extraordinary gain on retirement of debt, net of tax.. -- 0.02 --
-------------- -------------- --------------
Diluted - after extraordinary gain.................... $ 0.61 $ (0.23) $ (1.94)
============== ============== ==============
WEIGHTED AVERAGE SHARES OUTSTANDING:
Basic................................................. 98,195 83,815 27,501
Diluted............................................... 102,271 83,815 27,501
SEE THE ACCOMPANYING NOTES WHICH ARE AN INTEGRAL PART OF
THESE CONSOLIDATED FINANCIAL STATEMENTS.
F-3
KEY ENERGY SERVICES, INC.
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
YEAR ENDED JUNE 30,
--------------------------------------------
2001 2000 1999
------------ ------------ ------------
(THOUSANDS)
NET INCOME (LOSS)................................................ $ 62,710 $ (18,959) $ (53,258)
OTHER COMPREHENSIVE INCOME (LOSS), NET OF TAX:
Derivative transition adjustment (See Note 8).................. (778) -- --
Oil and natural gas derivatives adjustment (See Note 8)........ 306 -- --
Amortization of oil and natural gas derivatives (See Note 8)... 558 -- --
Reversal of unrealized gains on available-for-sale securities -- -- (1,525)
Currency translation gain (loss)............................... (32) (1) 9
------------- ------------- ------------
COMPREHENSIVE INCOME (LOSS), NET OF TAX.......................... $ 62,764 $ (18,960) $ (54,774)
============= ============= ============
SEE THE ACCOMPANYING NOTES WHICH ARE AN INTEGRAL PART OF
THESE CONSOLIDATED FINANCIAL STATEMENTS.
F-4
KEY ENERGY SERVICES, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS
YEAR ENDED JUNE 30,
-------------------------------------------
2001 2000 1999
------------ ------------ ------------
(THOUSANDS)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income/(loss)............................................ $ 62,710 $ (18,959) $ (53,258)
ADJUSTMENTS TO RECONCILE INCOME FROM OPERATIONS TO
NET CASH PROVIDED BY (USED IN) OPERATIONS:
Depreciation, depletion and amortization..................... 75,147 70,972 62,074
Bad debt expense............................................. 1,263 1,648 5,928
Amortization of deferred debt issuance costs................. 4,317 5,919 5,216
Restructuring charge......................................... -- -- 233
Deferred income taxes........................................ 34,698 (1,818) (25,675)
(Gain) loss on sale of assets................................ 173 25 111
Extraordinary (gain) loss, net of tax........................ (429) (1,611) --
Other non-cash items......................................... -- -- 13
CHANGE IN ASSETS AND LIABILITIES NET OF EFFECTS FROM THE
ACQUISITIONS:
(Increase) decrease in accounts receivable................... (55,076) (32,853) 9,741
(Increase) decrease in other current assets.................. (4,485) (5,483) (432)
Increase (decrease) in accounts payable, accrued interest
and accrued expenses....................................... 29,414 18,875 (17,378)
Other assets and liabilities................................. (5,015) (1,855) --
------------ ------------ ------------
Net cash provided by (used in) operating activities.......... 142,717 34,860 (13,427)
------------ ------------ ------------
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures--well servicing......................... (50,799) (26,469) (26,776)
Capital expenditures--contract drilling...................... (15,884) (8,282) (1,063)
Capital expenditures--other.................................. (15,437) (3,422) (3,468)
Proceeds from sale of fixed assets........................... 3,415 2,722 7,110
Notes receivable from related parties........................ (1,500) (2,315) (2,835)
Cash received in acquisitions................................ -- -- 27,008
Acquisitions--well servicing................................. (2,345) -- (292,638)
Acquisitions--contract drilling.............................. (800) -- --
Other assets and liabilities................................. -- -- (1,992)
------------ ------------ ------------
Net cash provided by (used in) investing activities.......... (83,350) (37,766) (294,654)
------------ ------------ ------------
CASH FLOWS FROM FINANCING ACTIVITIES:
Repayment of long-term debt and capital lease obligations.... (382,540) (51,077) (487,376)
Borrowings under line-of-credit.............................. 30,000 12,000 328,411
Proceeds from equity offerings, net of expenses.............. -- 100,571 180,441
Proceeds from long-term debt................................. 175,210 -- 142,566
Proceeds paid for debt issuance costs........................ (4,958) -- (15,274)
Proceeds from other long-term debt........................... -- -- 150,000
Proceeds from forward sale, net of expenses.................. -- 18,236 --
Proceeds from issuance of warrants........................... -- -- 7,434
Proceeds from exercise of warrants........................... 847 8,473 --
Proceeds from exercise of stock options...................... 14,617 1,098 92
Other........................................................ (318) -- --
------------ ------------ ------------
Net cash provided by (used in) financing activities.......... (167,142) 89,301 306,294
------------ ------------ ------------
Net increase (decrease) in cash.............................. (107,775) 86,395 (1,787)
Cash and cash equivalents at beginning of period............. 109,873 23,478 25,265
------------ ------------ ------------
Cash and cash equivalents at end of period................... $ 2,098 $ 109,873 $ 23,478
============ ============ ============
SEE THE ACCOMPANYING NOTES WHICH ARE AN INTEGRAL PART OF
THESE CONSOLIDATED FINANCIAL STATEMENTS.
F-5
KEY ENERGY SERVICES, INC.
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY
(THOUSANDS)
COMMON STOCK ACCUMULATED
---------------------- ADDITIONAL OTHER
NUMBER AMOUNT AT PAID-IN TREASURY RETAINED COMPREHENSIVE
OF SHARES PAR CAPITAL STOCK EARNINGS INCOME TOTAL
---------- ---------- ------------ ----------- ----------- ----------- ---------
BALANCE AT JUNE 30, 1998.............. 18,685 $ 1,868 $ 119,303 $ (9,682) $ 41,093 $ 1,525 $ 154,107
---------- ---------- ----------- ---------- ---------- ----------- ---------
Reversal of unrealized gain on
available for sale securities....... -- -- -- -- -- (1,525) (1,525)
Foreign currency translation
adjustment, net of tax.............. -- -- -- -- -- 9 9
Issuance of warrants with 14%
Notes............................... -- -- 7,434 -- -- -- 7,434
Issuance of common stock in
equity offering, net of
offering costs...................... 64,245 6,425 174,016 -- -- -- 180,441
Issued to lender in lieu of fee....... 200 20 980 -- -- -- 1,000
Exercise of options................... 15 2 92 -- -- -- 94
Other .............................. 10 2 (210) -- -- -- (208)
Net income (loss)..................... -- -- -- -- (53,258) -- (53,258)
---------- ---------- ----------- ---------- ---------- ----------- ----------
BALANCE AT JUNE 30, 1999.............. 83,155 $ 8,317 $ 301,615 $ (9,682) $ (12,165) $ 9 $ 288,094
---------- ---------- ----------- ---------- ---------- ----------- ----------
Foreign currency translation
adjustment, net of tax.............. -- -- -- -- -- (1) (1)
Exercise of warrants.................. 2,431 243 8,230 -- -- -- 8,473
Exercise of options................... 241 24 1,074 -- -- -- 1,098
Conversion of 7% Debentures........... 380 38 3,568 -- -- -- 3,606
Issuance of common stock in equity
offering, net of offering costs... 11,000 1,100 99,471 -- -- -- 100,571
Other .............................. 3 1 4 -- -- -- 5
Net income (loss)..................... -- -- -- -- (18,959) -- (18,959)
---------- ---------- ----------- ---------- ---------- ----------- ----------
BALANCE AT JUNE 30, 2000.............. 97,210 $ 9,723 $ 413,962 $ (9,682) $ (31,124) $ 8 $ 382,887
========== ========== =========== ========== ========== =========== ==========
Derivative transition adjustment
(see Note 8)........................ -- -- -- -- -- (778) (778)
Oil and natural gas derivatives
Adjustment, net of tax (See Note 8). -- -- -- -- -- 306 306
Amortization of oil and natural gas
Derivatives (see Note 8)............ -- -- -- -- -- 558 558
Foreign currency translation
adjustment, Net of tax.............. -- -- -- -- -- (32) (32)
Exercise of warrants.................. 185 19 828 -- -- -- 847
Exercise of options................... 3,106 308 14,309 -- -- -- 14,617
Conversion of 7% Debentures........... 101 10 947 -- -- -- 957
Issuance of common stock for
acquisitions........................ 838 84 8,036 -- -- -- 8,120
Deferred tax benefit--compensation
Expense............................. -- -- 7,004 -- -- -- 7,004
Other .............................. -- -- (318) -- -- -- (318)
Net income (loss)..................... -- -- -- -- 62,710 -- 62,710
---------- ---------- ----------- ---------- ---------- ----------- ----------
BALANCE AT JUNE 30, 2001.............. 101,440 $ 10,144 $444,768 $ (9,682) $ 31,586 $ 62 $ 476,878
========== ========== =========== ========== ========== =========== ==========
SEE THE ACCOMPANYING NOTES WHICH ARE AN INTEGRAL PART OF
THESE CONSOLIDATED FINANCIAL STATEMENTS.
F-6
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
1. ORGANIZATION AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
THE COMPANY
Key Energy Services, Inc. (the "Company" or "Key"), is the largest
onshore, rig-based well servicing contractor in the world, with approximately
1,477 well service rigs and 1,455 oilfield service vehicles as of June 30, 2001.
The Company provides a complete range of well services to major oil companies
and independent oil and natural gas production companies, including: rig-based
well maintenance, workover, completion, and recompletion services (including
horizontal recompletions); oilfield trucking services; and ancillary oilfield
services. Key conducts well servicing operations onshore the continental United
States in the following regions: Gulf Coast (including South Texas, Central Gulf
Coast of Texas, and South Louisiana), Permian Basin of West Texas and Eastern
New Mexico, Mid-Continent (including the Anadarko, Hugoton and Arkoma Basins,
and the ArkLaTex region), Four Corners (including the San Juan, Piceance, Uinta,
and Paradox Basins), Eastern (including the Appalachian, Michigan and Illinois
Basins), Rocky Mountains (including the Denver-Julesberg, Powder River, Wind
River, Green River and Williston Basins), and California (the San Joaquin
Basin), and internationally in Argentina and Ontario, Canada. The Company is
also a leading onshore drilling contractor, with 79 land drilling rigs as of
June 30, 2001. Key conducts land drilling operations in a number of major
domestic producing basins, as well as in Argentina and in Ontario, Canada. Key
also produces and develops oil and natural gas reserves in the Permian Basin
region and Texas Panhandle.
BASIS OF PRESENTATION
The Company's consolidated financial statements include the accounts of
the Company and its wholly-owned subsidiaries. All significant inter-company
transactions and balances have been eliminated. The accounting policies
presented below have been followed in preparing the accompanying consolidated
financial statements.
ESTIMATES AND UNCERTAINTIES
Preparation of the accompanying consolidated financial statements in
conformity with generally accepted accounting principles requires management to
make estimates and assumptions that affect the reported amount of assets and
liabilities and disclosures of contingent assets and liabilities at the date of
the consolidated financial statements and the reported amounts of revenues and
expenses during the reporting period. Actual results could differ from those
estimates.
INVENTORIES
Inventories, which consist primarily of oilfield service parts and
supplies held for consumption and parts and supplies held for sale at the
Company's various retail supply stores, are valued at the lower of average cost
or market.
PROPERTY AND EQUIPMENT
The Company provides for depreciation and amortization of oilfield
service and related equipment using the straight-line method, excluding its
drilling rigs, over the following estimated useful lives of the assets:
F-7
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
DESCRIPTION YEARS
----------- -----
Well service rigs.................................... 25
Motor vehicles....................................... 5
Furniture and equipment.............................. 3-7
Buildings and improvements........................... 10-40
Gas processing facilities............................ 10
Disposal wells....................................... 15-30
Trucks, trailers and related equipment............... 7-15
The components of a well service rig that generally require replacement
during the rig's life are depreciated over their estimated useful lives, which
range from three to 15 years. The basic rigs, excluding components, have
estimated useful lives from date of original manufacture ranging from 25 to 35
years. Salvage values are assigned to the rigs based on an estimate of 10%.
Effective July 1, 1998, the Company made certain changes in the estimated
useful lives of its well service rigs, increasing the lives from 17 years to 25
years. This change decreased the net loss for the twelve months ended June 30,
1999 by approximately $3,100,000 ($0.11 per share-basic). This change was made
to better reflect the expected utilization of these assets over time, to better
provide matching of revenues and expenses and to better reflect the industry
standard in regards to estimated useful lives of workover rigs.
The Company uses the units-of-production method to depreciate its
drilling rigs. This method takes into consideration the number of days the rigs
are actually in service each month and depreciation is recorded for at least 15
days each month for each rig that is available for service. The Company believes
that this method appropriately reflects its financial results by matching
revenues with expenses and appropriately reflects how the assets are to be used
over time.
The Company uses the successful efforts method of accounting for its oil
and gas properties. Under this method, all costs associated with productive
wells and nonproductive development wells are capitalized, while nonproductive
exploration costs and geological and geophysical costs (if any), are expensed.
Capitalized costs relating to proved properties are depleted using the
units-of-production method.
The Company follows the provisions of FASB Statement No. 121, Accounting
for the Impairment of Long-Lived Assets and for Long-Lived Assets to Be Disposed
Of. This statement requires that long-lived assets including certain
identifiable intangibles, held and used by the Company, be reviewed for
impairment whenever events or changes in circumstances indicate that the
carrying amount of an asset may not be recoverable. For purposes of applying
this statement, the Company groups its long-lived assets, including goodwill, on
a yard-by-yard basis and compares the estimated future cash flows of each yard
to the yard's net carrying value including allocable goodwill. The Company would
record an impairment charge, reducing the yard's net carrying value to an
estimated fair value, if the estimated future cash flows were less than the
yard's net carrying value. Since adoption of this statement no impairment
charges have been required.
HEDGING AND DERIVATIVE FINANCIAL INSTRUMENTS
The Company uses derivative financial instruments, primarily commodity
option contracts to reduce the exposure of its oil and gas producing operations
to changes in the market price of natural gas and crude oil and to fix the price
for natural gas and crude oil independently of the physical sale.
F-8
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
The financial instruments that the Company accounts for as hedging
contracts must meet the following criteria: the underlying asset or liability
must expose the Company to price risk that is not offset in another asset or
liability, the hedging contract must reduce that price risk, and the instrument
must be designated as a hedge at the inception of the contract and throughout
the contract period. In order to qualify as a hedge, there must be clear
correlation between changes in the fair value of the financial instrument and
the fair value of the underlying asset or liability such that changes in the
market value of the financial instrument will be offset by the effect of price
rate changes on the exposed items.
Prior to the adoption of SFAS 133, premiums paid for commodity option
contracts, which qualify as hedges, are amortized to oil and natural gas sales
over the terms of the contracts. Unamortized premiums are included in other
assets in the consolidated balance sheet. Amounts receivable under the commodity
option contracts are accrued as an increase in oil and natural gas sales for the
applicable periods.
Effective July 1, 2000, the Company adopted SFAS No. 133, "Accounting for
Derivative Instruments and Hedging Activities" ("SFAS 133") as amended by SFAS
No. 137 and No. 138 ("SFAS 138"). SFAS 133 establishes accounting and reporting
standards for derivative instruments, including certain derivative instruments
embedded in other contracts and hedging activities. It requires the recognition
of all derivative instruments as assets and liabilities in the Company's balance
sheet and measurement of those instruments at fair value. The accounting
treatment of changes in fair value is dependent upon whether or not a derivative
instrument is designated as a hedge and if so, the type of hedge. For
derivatives designated as cash flow hedges, changes in fair value are recognized
in other comprehensive income until the hedged item is recognized in earnings.
See Note 8.
COMPREHENSIVE INCOME
The Company follows the provisions of Statement of Financial Accounting
Standards No. 130, "Reporting Comprehensive Income" ("SFAS 130"). SFAS 130
establishes standards for reporting and presentation of comprehensive income and
its components. SFAS 130 requires that all items that are required to be
recognized under accounting standards as components of comprehensive income be
reported in a financial statement that is displayed with the same prominence as
other financial statements. In accordance with the provisions of SFAS 130, the
Company has presented the components of comprehensive income in its Consolidated
Statements of Comprehensive Income.
ENVIRONMENTAL
The Company is subject to extensive federal, state and local
environmental laws and regulations. These laws, which are constantly changing,
regulate the discharge of materials into the environment and may require the
Company to remove or mitigate the adverse environmental effects of the disposal
or release of petroleum or chemical substances at various sites. Environmental
expenditures are expensed or capitalized depending on their future economic
benefit. Expenditures that relate to an existing condition caused by past
operations and that have no future economic benefits are expensed. Liabilities
for expenditures of a non-capital nature are recorded when environmental
assessment and/or remediation is probable, and the costs can be reasonably
estimated.
GOODWILL
Net goodwill, totaling $189.9 million and $198.6 million at June 30, 2001
and 2000, respectively, represents the cost in excess of fair value of the net
tangible and identifiable intangible assets acquired and liabilities assumed in
purchase transactions. Goodwill is being amortized on a straight-line basis over
periods ranging from ten to 25 years. Amortization of goodwill for fiscal 2001,
2000 and 1999 was approximately $9,322,000, $9,840,000 and $9,202,000,
respectively. The carrying amount of unamortized goodwill is reviewed for
potential
F-9
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
impairment loss whenever events or changes in circumstances indicate that the
carrying amount of goodwill may not be recoverable (see Property and Equipment
above, for further discussion).
DEFERRED COSTS
Deferred costs totaling $31,052,000 and $30,998,000 at June 30, 2001 and
2000, respectively, represent debt issuance costs and are recorded net of
accumulated amortization of $13,428,000 and $12,143,000 at June 30, 2001 and
2000, respectively. Deferred costs are amortized to interest expense using the
straight-line method over the life of each applicable debt instrument or to
extraordinary loss as related debt is retired early. This method approximates
the amortization which would be recorded using the effective interest method.
Amortization of deferred costs totaled approximately $3,578,000, $5,176,000 and
$4,664,000 for fiscal 2001, 2000 and 1999, respectively. Unamortized debt
issuance costs included in the determination of the extraordinary gain (loss) on
retirement of debt, net of tax, totaled approximately $1,620,000 for fiscal
2001.
INCOME TAXES
The Company accounts for income taxes based upon Statement of Financial
Accounting Standards No. 109, "Accounting for Income Taxes" ("SFAS 109"). Under
SFAS 109, deferred tax assets and liabilities are recognized for the future tax
consequences attributable to differences between the financial statement
carrying amounts of existing assets and liabilities and their respective tax
bases. Deferred tax assets and liabilities are measured using statutory tax
rates expected to apply to taxable income in the years in which those temporary
differences are expected to be recovered or settled. The effect on deferred tax
assets and liabilities of a change in tax rate is recognized in income in the
period that includes the statutory enactment date. A valuation allowance for
deferred tax assets is recognized when it is more likely than not that the
benefit of deferred tax assets will not be realized.
The Company and its eligible subsidiaries file a consolidated U.S.
federal income tax return. Certain subsidiaries that are consolidated for
financial reporting purposes are not eligible to be included in the consolidated
U. S. federal income tax return and separate provisions for income taxes have
been determined for these entities or groups of entities.
EARNINGS PER SHARE
The Company presents earnings per share information in accordance with
the provisions of Statement of Financial Accounting Standards No. 128, "Earnings
per Share" ("SFAS 128"). Under SFAS 128, basic earnings per common share are
determined by dividing net earnings applicable to common stock by the weighted
average number of common shares actually outstanding during the year. Diluted
earnings per common share is based on the increased number of shares that would
be outstanding assuming conversion of dilutive outstanding convertible
securities using the "as if converted" method.
F-10
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
YEAR ENDED JUNE 30,
----------------------------------------------
2001 2000 1999
------------ ------------ -------------
(THOUSANDS, EXCEPT PER SHARE DATA)
BASIC EPS COMPUTATION:
NUMERATOR
Net Income (loss) before extraordinary gain (loss)........... $ 62,281 $ (20,570) $ (53,258)
Extraordinary gain (loss), net of tax........................ 429 1,611 --
----------- ---------- -----------
Net income (loss)............................................ $ 62,710 $ (18,959) $ (53,258)
=========== ========== ===========
DENOMINATOR
Weighted average common shares outstanding................... 98,195 83,815 27,501
----------- ---------- -----------
BASIC EPS:
Before extraordinary gain (loss)............................. $ 0.63 $ (0.25) $ (1.94)
Extraordinary gain (loss), net of tax........................ -- (0.02) --
----------- ---------- -----------
Net income (loss)............................................ $ 0.63 $ (0.23) $ (1.94)
=========== ========== ===========
DILUTED EPS COMPUTATION:
NUMERATOR
Net income (loss) before extraordinary gain (loss) and
effect of dilutive securities, tax effected................ $ 62,281 $ (20,570) $ (53,258)
Convertible securities....................................... 5 -- --
----------- ---------- -----------
Net income (loss) before extraordinary gain (loss)........ $ 62,286 $ (20,570) $ (53,258)
Extraordinary gain (loss), net of tax..................... 429 1,611 --
----------- ---------- -----------
Net income (loss)......................................... $ 62,715 $ (18,959) $ (53,258)
=========== ========== ===========
DENOMINATOR
Weighted average common shares outstanding................... 98,195 83,815 27,501
Warrants..................................................... 205 -- --
Stock options................................................ 3,853 -- --
7% Convertible Debentures.................................... 18 -- --
----------- ---------- -----------
102,271 83,815 27,501
F-11
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
YEAR ENDED JUNE 30,
----------------------------------------------
2001 2000 1999
------------ ------------ -------------
(THOUSANDS, EXCEPT PER SHARE DATA)
DILUTED EPS:
Before extraordinary gain (loss)............................. $ 0.61 $ (0.25) $ (1.94)
Extraordinary gain (loss), net of tax........................ -- 0.02 --
------------ ------------ -------------
Net income (loss)............................................ $ 0.61 $ (0.23) $ (1.94)
============ ============ =============
The diluted earnings per share calculation for the year ended June 30,
2001 excludes the effect of the exercise of 360,000 stock options and the
conversion of the Company's 5% Convertible Subordinated Notes because the
effects of such instruments on earnings per share would be anti-dilutive.
The diluted earnings per share calculation for the years ended June 30,
2000 and 1999 excludes the effect of the conversion of all of the Company's then
outstanding convertible debt and the exercise of all of the Company's then
outstanding warrants and stock options because the effects of such instruments
on loss per share would be anti-dilutive.
CONCENTRATION OF CREDIT RISK
Financial instruments, which potentially subject the Company to
concentrations of credit risk, consist primarily of temporary cash investments
and trade receivables. The Company restricts investment of temporary cash
investments to financial institutions with high credit standing and, by policy,
limits the amount of credit exposure to any one financial institution. The
Company's customer base consists primarily of multi-national and independent oil
and natural gas producers. This may affect the Company's overall exposure to
credit risk either positively or negatively in as much as its customers are
affected by economic conditions in the oil and gas industry, which have
historically been cyclical. However, account receivables are well diversified
among many customers and a significant portion of the receivables are from major
oil companies, which management believes minimizes potential credit risk.
Historically, credit losses have been insignificant. Receivables are generally
not collateralized, although the Company may generally secure a receivable at
any time by filing a mechanic's or material-man's lien on the well serviced. The
Company maintains reserves for potential credit losses, and such losses have
been within management's expectations.
The Company did not have any one customer who represented 10% or more
of consolidated revenues for the fiscal year ended June 30, 2001, 2000 or 1999.
STOCK-BASED COMPENSATION
The Company accounts for stock option grants to employees using the
intrinsic value method of accounting prescribed by APB Opinion No. 25,
Accounting for Stock Issued to Employees ("APB 25"). Under the Company's stock
incentive plans, the price of the stock on the grant date is the same as the
amount an employee must pay to exercise the option to acquire the stock;
accordingly, the options have no intrinsic value at grant date, and in
accordance with the provisions of APB 25, no compensation cost is recognized.
Statement of Financial Accounting Standards No. 123 ("SFAS 123"),
"Accounting for Stock-Based Compensation," sets forth alternative accounting and
disclosure requirements for stock-based compensation arrangements. Companies may
continue to follow the provisions of APB 25 to measure and recognize employee
F-12
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
stock-based compensation; however, SFAS 123 requires disclosure of pro forma net
income and earnings per share that would have been reported under the fair value
based recognition provisions of SFAS 123. The Company has disclosed in Note 10
the pro forma information required under SFAS 123.
FOREIGN CURRENCY GAINS AND LOSSES
The local currency is the functional currency for all of the Company's
foreign operations (Argentina and Canada). The cumulative translation gains and
losses, resulting from translating each foreign subsidiary's financial
statements from the functional currency to U.S. dollars, is included in other
comprehensive income and accumulated in stockholders' equity until a partial or
complete sale or liquidation of the Company's net investment in the foreign
entity.
CASH AND CASH EQUIVALENTS
The Company considers all unrestricted highly liquid investments with
less than a three-month maturity when purchased, as cash equivalents.
RECLASSIFICATIONS
Certain reclassifications have been made to the fiscal 2000 and 1999
consolidated financial statements to conform to the fiscal 2001 presentation.
The reclassifications consist primarily of reclassifying oil and natural gas
productions revenues and expenses. Oil and natural gas production revenues and
related expenses have been reclassified to other revenues and other expenses
because the Company does not believe this business segment is material to the
Company's consolidated financial statements.
2. RESTRUCTURING CHARGE
In response to an industry downturn caused by historically low oil and
gas prices and the resulting slowdown in business, on December 7, 1998, the
Company announced a company-wide restructuring plan to reduce operating costs
beyond those achieved through the Company's consolidation efforts. The plan
involved a reduction in the size of management and on-site work force, salary
reductions averaging 21% for senior management, the combination of previously
separate operating divisions and the elimination of redundant overhead and
facilities. The restructuring plan resulted in pretax charges to earnings of
approximately $6.7 million in the second quarter ending December 31, 1998 and
$1.5 million in the third quarter ending March 31, 1999. However, due to an
increase in oil and gas prices beginning during the quarter ended March 31,1999,
the Company amended its restructuring plan to decrease the number of planned
employee terminations.
Increased demand for the Company's services made such terminations
unnecessary and would have, in management's opinion, restricted the Company's
ability to provide services to its customers. Consequently, the Company did not
utilize approximately $3.7 million of the pretax charges. Essentially all of the
unutilized portion of the restructuring charge was reversed in the fourth
quarter ending June 30, 1999 resulting in a total pretax charge for the fiscal
year ended June 30, 1999 of approximately $4.5 million. The charges included
severance payments and other termination benefits for approximately 97
employees, lease commitments related to closed facilities and environmental
studies performed on closed leased yard locations.
F-13
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
The Company completed the plan at June 30, 2000. There remained
approximately $180,000 for COBRA benefits to terminated employees and $53,000
for contractual payments to an employee at June 30, 1999. The major components
of the restructuring charge and costs incurred through June 30, 1999 were as
follows:
COST INCURRED
RESTRUCTURING THROUGH BALANCE AS OF
DESCRIPTION CHARGE JUNE 30, 1999 JUNE 30, 1999
----------- --------------- ---------------- ---------------
(IN THOUSANDS)
Severance/Employee costs............................. $ 4,457 $ (4,224) $ 233
Lease commitments.................................... 27 (27) --
Environmental clean-up............................... 20 (20) --
--------------- ---------------- ---------------
Total................................................ $ 4,504 $ (4,271) $ 233
=============== ================ ===============
3. BUSINESS AND PROPERTY ACQUISITIONS
ACQUISITIONS COMPLETED IN FISCAL 2001 AND 2000
There were no acquisitions completed by the Company during fiscal 2000.
During fiscal 2001, the Company completed several small acquisitions for a total
consideration of $11,965,000, which was paid using a combination of cash, notes
and shares of the Company's common stock. Through these acquisitions, the
Company acquired 34 well service rigs, 8 trucking vehicles, ancillary equipment
and five salt water disposal facilities. Each of the acquisitions was accounted
for using the purchase method and the results of the operations generated from
the acquired assets are included in the Company's results of operations as of
the completion date of each acquisition.
DAWSON PRODUCTION SERVICES, INC.
In September 1998, the Company completed the acquisition of all of the
capital stock of Dawson Production Services, Inc. (Dawson) for an aggregate
consideration of approximately $382.6 million, including approximately $207.1
million of cash paid for the Dawson stock and for transactional fees and
approximately $175.5 million of net liabilities assumed.
Expenditures for the Dawson acquisition, including acquisition costs,
less cash acquired were as follows (in thousands):
Fair value of assets acquired, including goodwill............................................. $ 409,722
Liabilities assumed........................................................................... (199,439)
Liabilities for employee termination costs and lease termination costs........................ (3,162)
--------------
Cash paid, including acquisition related expenditures and the cost of Dawson common
stock previously held.................................................................... 207,121
Less: Cash acquired........................................................................... (27,008)
--------------
Net cash used for the acquisition............................................................. $ 180,113
==============
At the time of the closing, Dawson owned approximately 527 well service
rigs, 200 oilfield trucks, and 21 production testing units in South Texas and
the Gulf Coast, East Texas and Louisiana, the Permian Basin of West
F-14
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
Texas and New Mexico, the Anadarko Basin of Texas and Oklahoma, California, and
in the inland waters of the Gulf of Mexico.
In connection with the Dawson acquisition, the Company recognized
liabilities for the estimated costs to involuntarily terminate employees of
Dawson and to exit certain activities of Dawson, primarily Dawson's lease
liability for its corporate offices. As of June 30, 1999, the Company had
completed its severance plan, terminating 44 former Dawson employees. At June
30, 1999, the Company had $592,000 accrued, representing the estimated lease
termination costs of Dawson's former corporate offices.
OTHER FISCAL 1999 ACQUISITIONS
In addition to its acquisition of Dawson, the Company acquired the
assets and/or capital stock of six well servicing and contract drilling
businesses during fiscal 1999, increasing its rig and truck fleet by a total of
approximately 93 well service rigs, 4 drilling rigs and 185 oilfield trucks (and
related equipment) for an aggregate purchase price of approximately $93.7
million in cash. Each of the acquisitions was accounted for using the purchase
method and the results of the operations, generated from the acquired assets,
are included in the Company's results of operations as of the completion date of
each acquisition.
PRO FORMA RESULTS OF OPERATIONS--(UNAUDITED)
The following unaudited pro forma results of operations have been
prepared as though the Dawson acquisition had been acquired on July 1, 1998 with
adjustments to record specifically identifiable decreases in direct costs and
general and administrative expenses related to the termination of individual
employees. Pro forma amounts are not necessarily indicative of the results that
may be reported in the future.
YEAR ENDED
JUNE 30, 1999
--------------------------------------
(IN THOUSANDS, EXCEPT PER SHARE DATA)
Revenue..................................................... $ 524,924
Net income (loss)........................................... (58,211)
Basic earnings (loss) per share............................. (2.12)
4. COMMITMENTS AND CONTINGENCIES
Various suits and claims arising in the ordinary course of business are
pending against the Company. Management does not believe that the disposition of
any of these items will result in a material adverse impact to the consolidated
financial position, results of operations or cash flows of the Company.
In order to retain qualified senior management, the Company enters into
employment agreements with its executive officers. These employment agreements
run for periods ranging from three to five years, but can be automatically
extended on a yearly basis unless terminated by the Company or the executive
officer. In addition to providing a base salary for each executive officer, the
employment agreements provide for severance payments for each executive officer
varying from 1 to 3 years of the executive officer's base salary. At June 30,
2001 the annual base salaries for the executive officers covered under such
employment agreements totaled $1,125,000. The Company also enters into
employment agreements with other key employees as it deems necessary in order to
retain qualified personnel.
F-15
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
The components of long-term debt are as follows:
JUNE 30,
--------------------------------
2001 2000
------------- ---------------
(THOUSANDS)
Senior Credit Facility(i)
Revolving Loans................................................... $ 2,000 $ 93,000
Tranche A Term Loan............................................... -- 22,987
Tranche B Term Loan............................................... -- 175,961
8 3/8% Senior Subordinated Notes Due 2009(iii)......................... 134,466 143,650
5% Convertible Subordinated Notes Due 2004(iv)......................... 158,426 205,810
7% Convertible Subordinated Debentures Due 2003(v)..................... -- 1,000
Capital Leases......................................................... 22,964 21,911
Other notes payable.................................................... 805 1,175
------------- ---------------
493,907 666,600
Less current portion................................................... 7,946 14,655
------------- ---------------
Total long-term debt................................................... $ 485,961 $ 651,945
============= ===============
(I) SENIOR CREDIT FACILITY
At June 30, 2001, the Company's senior credit facility (the "Senior
Credit Facility") consisted of a $125 million revolving credit facility. In
addition, up to $20 million of letters of credit can be issued under the Senior
Credit Facility, but any outstanding letters of credit reduces borrowing
availability under the revolver. The commitment to make revolving loans reduced
to $100 million, on September 14, 2001 and will reduce to $75 million on
September 14, 2002. The revolving commitment will terminate on September 14,
2003, and all the revolving loans must be paid on or before that date.
The revolving loans bear interest at rates based upon, at the Company's
option, either the prime rate plus a margin ranging from 0.75% to 2.00% or a
Eurodollar rate plus a margin ranging from 2.25% to 3.50%, in each case
depending upon the ratio of the Company's total debt (less cash on hand over $5
million) to the Company's trailing 12-month EBITDA, as adjusted. The Company
pays commitment fees on the unused portion of the revolving loan at a varying
rate (depending upon the pricing ratio) of between 0.25% and 0.50%.
The Senior Credit Facility contains various financial covenants,
including: (i) consolidated debt-to-capitalization ratio at generally decreasing
levels varying between 79% and 65%, (ii) consolidated interest coverage ratio at
generally increasing levels varying between 2.00-to-1.00 and 3.50-to-1.00, (iii)
consolidated senior leverage ratio at generally decreasing levels varying
between 2.50-to-1.00 and 2.00-to-1.00, and (iv) trailing 12-month EBITDA, as
adjusted, at generally increasing levels varying between $50 million and $150
million. In addition, the Company must maintain a consolidated fixed charge
coverage ratio at generally decreasing levels varying between 1.25-to-1.00 and
1.00 to 1.00. The covenants for consolidated senior leverage ratio and
consolidated interest coverage ratio are not imposed until the quarter ending
March 31, 2001, and the covenant levels for consolidated debt-to-capitalization
and trailing 12-month EBITDA, as adjusted, will remain fixed at 79% and $50
million, respectively, for the same period. The Company is also required to
maintain a consolidated liquidity level of at least $30 million.
F-16
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2000, 1999 AND 1998
The Senior Credit Facility subjects the Company to other restrictions,
including restrictions upon the Company's ability to incur additional debt,
liens and guarantee obligations, to merge or consolidate with other persons, to
sell assets, to make dividends, purchases of our stock or subordinated debt, to
make capital expenditures in excess of levels ranging from $37.5 million in
fiscal 1999 to $65 million in fiscal 2004, or to make investments, loans and
advances or changes to debt instruments and organizational documents. The
Company will not be permitted to make acquisitions unless (i) its consolidated
debt to capitalization ratio is not more than 60% or (ii) its consolidated debt
to capitalization ratio is not increased and the acquisition is funded solely
with capital stock. The Company must also maintain consolidated net worth not
less than, $195 million plus (i) 75% of consolidated net income for each fiscal
quarter beginning with the period ending December 31, 1998, (ii) 75% of the net
cash proceeds from issuance of capital stock after September 14, 1998 and (iii)
75% of the increase in consolidated net worth resulting from the conversion of
the 5% Convertible Subordinated Notes or other convertible debt issued after
September 14, 1998. All obligations under the Senior Credit Facility are
guaranteed by most of the Company's subsidiaries and are secured by
substantially all the Company's assets, including the Company's accounts
receivable, inventory and equipment.
During fiscal 2001, a portion of the net proceeds from the Equity
Offering (see Note 10) was used to repay the entire outstanding balance of the
Tranche A term loan then outstanding under the Senior Credit Facility and $2.3
million of the Tranche B term loan then outstanding under the Senior Credit
Facility. In addition, $65 million of the net proceeds from the Equity Offering
were used to reduce the principal amount outstanding under the revolver. The
remainder of the net proceeds of the Equity Offering was used to retire other
long-term debt. A portion of the proceeds from the Company's 8 3/8% Senior Note
offering in fiscal 2001 was used to repay the entire outstanding balance of the
Tranche B term loan then outstanding under the Senior Credit Facility and
approximately $59.1 million under the revolver.
At June 30, 2001, there was approximately $2,000,000 outstanding under
the revolving loans. Additionally, the Company had outstanding letters of credit
of $11,995,000 and $15,132,000 as of June 30, 2001 and 2000, respectively,
related to its workers compensation insurance.
(II) 8 3/8% SENIOR NOTES
On March 6, 2001 the Company completed a private placement of
$175,000,000 of 8 3/8% Senior Notes due 2008 (the "8 3/8% Senior Notes"). The
net cash proceeds from the private placement were used to repay all of the
remaining balance of the original term loans under the Senior Credit Facility
and a portion of the revolving loan facility under the Senior Credit Facility.
The 8 3/8% Senior Notes are senior unsecured obligations, ranking equally with
the Company's senior unsecured indebtedness. The 8 3/8% Senior Notes are
effectively subordinated to Key's secured indebtedness which includes borrowings
under the Senior Credit Facility and the Dawson 9 3/8% Senior Notes.
On and after March 1, 2005, the Company may redeem some or all of the 8
3/8% Senior Notes at any time at varying redemption prices in excess of par,
plus accrued interest. In addition, before March 1, 2004, the Company may redeem
up to 35% of the aggregate principal amount of the 8 3/8% Senior Notes with the
proceeds of certain sales of equity at 108.375% of par plus accrued interest.
At June 30, 2001, $175,000,000 principal amount of the 8 3/8% Senior
Notes remained outstanding. The 8 3/8% Senior Notes pay interest semi-annually
on March 1 and September 1 of each year.
F-17
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2000, 1999 AND 1998
(III) 14% SENIOR SUBORDINATED NOTES
On January 22, 1999, the Company completed the private placement of
150,000 units ("the Units") consisting of $150,000,000 of 14% Senior
Subordinated Notes due 2009 (the "14% Senior Subordinated Notes") and 150,000
warrants to purchase 2,173,433 shares of common stock at an exercise price of
$4.88125 per share (the "Unit Warrants"). The net cash proceeds from the private
placement were used to repay substantially all of the remaining $148.6 million
principal amount (plus accrued interest) owed under the Company's bridge loan
facility arranged in connection with the acquisition of Dawson Production
Services, Inc. ("Dawson").
On and after January 15, 2004, the Company may redeem some or all of the
14% Senior Subordinated Notes at any time at varying redemption prices in excess
of par, plus accrued interest. In addition, before January 15, 2002, the Company
may redeem up to 35% of the aggregate principal amount of the 14% Senior
Subordinated Notes with the proceeds of certain sales of equity at 114% of par,
plus accrued interest. On June 11, 2001, the Company exercised its right of
redemption for $10,313,000 principal amount of the 14% Senior Subordinated Notes
at a price of 114% of the principal amount plus accrued interest, leaving
$139,687,000 principal amount outstanding as of June 30, 2001.
The Unit Warrants have separated from the 14% Senior Subordinated Notes
and became exercisable on January 25, 2000. On the date of issuance, the value
of the Unit Warrants was estimated at $7,434,000 and is classified as a discount
to the 14% Senior Subordinated Notes on the Company's consolidated balance
sheet. The discount is being amortized to interest expense over the term of the
14% Senior Subordinated Notes. The 14% Senior Subordinated Notes mature and the
Unit Warrants expire on January 15, 2009. The 14% Senior Subordinated Notes are
subordinate to the Company's senior indebtedness, which includes borrowings
under the Current Senior Credit Facility, the Dawson 9 3/8% Senior Notes and the
8 3/8% Senior Notes.
In the event of a change in control of the Company, as defined in the
indenture under which the 14% Senior Subordinated Notes were issued, each holder
of 14% Senior Subordinated Notes will have the right, at the holder's option, to
require the Company to repurchase all or any part of the holder's 14% Senior
Subordinated Notes, within 60 days of such event, at a price equal to 100% of
the principal amount thereof, together with accrued and unpaid interest thereon.
During fiscal 2001, the Company repurchased (and cancelled) $10,313,000
principal amount of the 14% Senior Subordinated Notes and paid a premium of
approximately $1,444,000. At June 30, 2001, $139,687,000 principal amount of the
14% Senior Subordinated Notes remained outstanding. The 14% Senior Subordinated
Notes pay interest semi-annually on January 15 and July 15 of each year,
beginning July 15, 1999. Interest of approximately $10,500,000 was paid on July
15, 2000 and January 15, 2001. As of June 30, 2001, 62,500 Unit Warrants had
been exercised, producing approximately $4,173,000 of proceeds to the Company
and leaving 87,500 Unit Warrants outstanding.
(IV) 5% CONVERTIBLE SUBORDINATED NOTES
In late September and early October 1997, the Company completed a private
placement of $216 million of 5% Convertible Subordinated Notes due 2004 (the "5%
Convertible Subordinated Notes"). The 5% Convertible Subordinated Notes are
subordinate to the Company's senior indebtedness, which includes borrowings
under the Senior Credit Facility, the 14% Senior Subordinated Notes, the Dawson
9 3/8% Senior Notes and the 8 3/8% Senior Notes. The 5% Convertible Subordinated
Notes are convertible, at the holder's option, into shares of the Company's
common stock at a conversion price of $38.50 per share, subject to certain
adjustments.
F-18
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2000, 1999 AND 1998
The 5% Convertible Subordinated Notes are redeemable, at the Company's
option, on and after September 15, 2000, in whole or part, together with accrued
and unpaid interest. The initial redemption price is 102.86% for the year
beginning September 15, 2000 and declines ratably thereafter on an annual basis.
During fiscal 2001, the Company repurchased (and cancelled) $47,384,000
principal amount of the 5% Convertible Subordinated Notes, leaving $158,426,000
principal amount of the 5% Convertible Subordinated Notes outstanding at June
30, 2001. These repurchases resulted in an after tax gain of approximately $3.2
million. Interest on the 5% Convertible Subordinated Notes is payable on March
15 and September 15. Interest of approximately $4,890,000 was paid on September
15, 2000 and $4,815,000 was paid on March 15, 2001, respectively.
(V) DAWSON 9 3/8% SENIOR NOTES
As a result of the Dawson acquisition (see Note 3), the Company, its
subsidiaries and U.S. Trust Company of Texas, N.A., as trustee ("U.S. Trust"),
entered into a Supplemental Indenture dated September 21, 1998 (the
"Supplemental Indenture"), pursuant to which the Company assumed the obligations
of Dawson under the Indenture dated February 20, 1997 (the "Dawson Indenture")
between Dawson and U.S. Trust. The senior notes due 2007 (the "Dawson 9 3/8%
Senior Notes") issued pursuant to the Dawson Indenture were equally and ratably
secured with the obligations under the Senior Credit Facility. As a result of a
mandatory tender offer made in connection with the Dawson acquisition and
subsequent repurchases, only $1,106,000 principal amount of Dawson 9 3/8% Senior
Notes remained outstanding at June 30, 2000.
During fiscal 2001, the Company repurchased $860,000 principal amount
of the Dawson 9 3/8% Senior Notes, leaving $246,000 principal amount outstanding
as of June 30, 2001. Interest on the Dawson 9 3/8% Senior Notes is payable on
February 1 and August 1 of each year. Interest of approximately $52,000 and
approximately $14,000 was paid on August 1, 2000 and February 1, 2001,
respectively.
(VI) 7% CONVERTIBLE SUBORDINATE DEBENTURES
In July 1996, the Company completed a private placement of $52,000,000
principal amount of 7% Convertible Subordinated Debentures due 2003 (the "7%
Convertible Subordinated Debentures"). During the quarter ended September 30,
2000, $985,000 principal amount of the 7% Convertible Subordinated Debentures
were surrendered for conversion by the holders thereof and 101,025 shares of
common stock were issued on September 1, 2000 in connection with the conversion.
On September 1, 2000, the remaining $15,000 principal amount of the outstanding
7% Convertible Subordinated Debentures was redeemed at 103% of the principal
amount plus accrued interest, leaving none outstanding. Interest on the 7%
Convertible Subordinated Debentures was payable on January 1 and July 1 of each
year. Interest of approximately $35,000 was paid on July 1, 2000.
CAPITALIZED DEBT ISSUANCE COSTS, REPAYMENT SCHEDULE AND INTEREST EXPENSE
The Company capitalized a total of approximately $4,958,000 and
$16,370,000 in fees and costs in connection with its various financings during
fiscal 2001 and 1999 respectively. The Company did not incur any fees or costs
in connection with financing activities in fiscal 2000.
Presented below is a schedule of the repayment requirements of long-term
debt for each of the next five years and thereafter as of June 30, 2001:
F-19
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2000, 1999 AND 1998
PRINCIPAL
FISCAL YEAR ENDED JUNE 30, AMOUNT
-------------------------- --------------
(IN THOUSANDS)
2002......................................................................... $ 7,946
2003......................................................................... 7,912
2004......................................................................... 9,911
2005......................................................................... 158,426
2006......................................................................... --
Thereafter........................................................................ 309,712
-------------
$ 493,907
=============
The Company's interest expense for the years ended June 30, 2001, 2000,
and 1999 consisted of the following:
2001 2000 1999
-------------- -------------- ------------
(IN THOUSANDS)
Cash payments for interest.......................... $ 51,524 $ 61,956 $ 52,397
Commitment and agency fees paid..................... 1,203 1,139 527
Accretion of discount on notes...................... 739 743 552
Amortization of debt issuance costs................. 3,578 5,176 4,664
Net change in accrued interest...................... 146 2,916 9,261
Other............................................... (630) -- --
-------------- -------------- ------------
$ 56,560 $ 71,930 $ 67,401
============== ============== ============
6. DEBT ISSUANCE COSTS
During fiscal 1999, the Company recorded an expense item of $6,307,000
which represented the write-off of debt issuance costs. The debt issuance costs
were associated with a bridge loan incurred in connection with the Dawson
acquisition, which was subsequently paid primarily with the proceeds from the
Company's private placement of 14% Senior Subordinated Notes (see Note 5).
During fiscal 2000, the Company expensed $338,000 of debt issuance costs related
to the conversion of 7% Convertible Subordinated Debentures and other
prepayments of debt.
7. FAIR VALUE OF FINANCIAL INSTRUMENTS
The following table presents the carrying amounts and estimated fair
values of the Company's financial instruments at June 30, 2001 and 2000. FASB
Statement No. 107, "Disclosures about Fair Value of Financial Instruments",
defines the fair value of a financial instrument as the amount at which the
instrument could be exchanged in a current transaction between willing parties.
F-20
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
2001 2000
------------------------------- -------------------------------
CARRYING FAIR CARRYING FAIR
VALUE VALUE VALUE VALUE
------------- ------------- ------------- -------------
Financial Assets:
Cash and cash equivalents................. $ 2,098 $ 2,098 $ 109,873 $ 109,873
Accounts receivable, net.................. 177,016 177,016 123,203 123,203
Notes receivable--related parties......... 6,050 6,600 5,150 5,150
Commodity option contracts................ 1,035 1,035 -- --
Financial Liabilities:
Accounts payable.......................... 42,544 42,544 34,091 34,091
Commodity option contracts................ 344 344 -- 778
Long-term debt
Senior Credit Facility.................. 2,000 2,000 291,948 291,948
8 3/8% Senior Notes..................... 175,000 176,094 -- --
5% Convertible Subordinated Notes....... 158,426 141,989 205,810 160,532
7% Convertible Subordinated Debentures.. -- -- 1,000 1,130
14% Senior Subordinated Notes........... 134,466 153,498 143,650 162,325
Dawson 9 3/8% Senior Notes.............. 246 246 1,106 1,029
Capital lease liabilities............... 22,964 22,964 21,911 21,911
Other debt.............................. 805 805 1,175 1,175
The following methods and assumptions were used to estimate the fair
value of each class of financial instruments:
Cash, trade receivables and trade payables: The carrying amounts
approximate fair value because of the short maturity of those instruments.
Commodity option contracts: For fiscal 2001, under SFAS 133, the carrying
amount of the commodity option contracts approximate fair value. For fiscal
2000, the carrying value is comprised of the unamortized premiums paid for the
option contracts. The fair value of the commodity option contracts is estimated
using the discounted forward prices of each options index price, for the term of
each option contract.
Notes receivable-related parties: The amounts reported relate to notes
receivable from officers of the Company.
Long-term debt: The fair value of the Company's long-term debt is based
upon the quoted market prices for the various notes and debentures at June 30,
2001 and 2000, and the carrying amounts outstanding under the Company's senior
credit facility.
8. DERIVATIVE FINANCIAL INSTRUMENTS
The Company utilizes derivative financial instruments to manage well
defined commodity price risks. The Company is exposed to credit losses in the
event of nonperformance by the counter-parties to its commodity hedges. The
Company only deals with reputable financial institutions as counter-parties and
anticipates that such counter-parties will be able to fully satisfy their
obligations under the contracts. The Company does not obtain collateral or other
security to support financial instruments subject to credit risk but monitors
the credit standing of the counter-parties.
F-21
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2000, 1999 AND 1998
The Company periodically hedges a portion of its oil and natural gas
production through collar and option agreements. The purpose of the hedges is to
provide a measure of stability in the volatile environment of oil and natural
gas prices and to manage exposure to commodity price risk under existing sales
commitments. The Company's risk management objective is to lock in a range of
pricing for expected production volumes. This allows the Company to forecast
future earnings within a predictable range. The Company meets this objective by
entering into collar and option arrangements which allow for acceptable cap and
floor prices.
The Company does not enter into derivative instruments for any purpose
other than for economic hedging. The Company does not speculate using derivative
instruments. The Company has identified the following derivative instruments:
FREESTANDING DERIVATIVES. On March 30, 2000 the Company entered into a
collar arrangement for a 22-month period whereby the Company will pay if the
specified price is above the cap index and the counter-party will pay if the
price should fall below the floor index. The hedge defines a range of cash flows
bounded by the cap and floor prices. On May 25, 2001 the Company entered into an
option arrangement for a 12-month period beginning March 2002. whereby the
counter-party will pay if the price should fall below the floor index. The
Company desires a measure of stability to ensure that cash flows do not fall
below a certain level.
Prior to the adoption of SFAS 133 as discussed in Note 1, these collars
and options were accounted for as cash flow type hedges. Accordingly, the
transition adjustment resulted in recording a $778,000 liability for the fair
value of the collars to accumulated other comprehensive income, of which
$520,000 was recognized in earnings during fiscal 2001. It is estimated that the
remaining $258,000 of this transition adjustment will be recognized in earnings
over the next fiscal year. While this arrangement was intended to be an economic
hedge, as of July 1, 2000, the Company had not documented the March 30, 2000 oil
and natural gas collars as cash flow hedges and therefore reported a charge to
operations of $565,000 for the increase in fair value of the liability as of
September 30, 2000 in other income. As of October 1, 2000, the Company
documented these collars as cash flow hedges. As of May 25, 2001, the Company
had not documented the May 25, 2001 oil and natural gas options as cash flow
hedges and therefore has included income of $768,000 for the increase in fair
value of the asset as of June 30, 2001 in other income. As of July 1, 2001, the
Company documented these options as cash flow hedges. During fiscal 2001, the
Company recorded a net increase of $999,000 in derivative assets, net of
derivative liabilities, of which $132,000 represented ineffectiveness and was
credited to earnings.
EMBEDDED DERIVATIVES. The Company is party to a volumetric production
payment that meets the definition of an embedded derivative under SFAS 133.
Effective July 1, 2000, the Company determined and documented that the
volumetric production payment is excluded from the scope of SFAS 133 under the
normal purchases/sales exclusion as set forth in SFAS 138.
For fiscal 2000 and 1999, gains and amortization of premiums paid on
option contracts are recognized as an adjustment to sales revenue when the
related transactions being hedged are finalized.
The net effect of the Company's commodity hedging activities decreased
oil and natural gas revenues for the year ended June 30, 2000 by $822,270 and
increased oil and natural gas revenues for the year ended June 30, 1999 by
$158,500.
F-22
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
The following table sets forth the future volumes hedged by year and the
weighted-average strike price of the option contracts at June 30, 2001 and 2000:
STRIKE PRICE
MONTHLY INCOME PER BBL/MMBTU
------------------------ ------------------------------------
NATURAL
OIL GAS FAIR
(BBLS) (MMBTU) TERM FLOOR CAP VALUE
--------- ----------- -------------------------- --------- -----------------------
At June 30, 2001
Oil Collars........... 5,000 -- Mar 2001 - Feb. 2002 $ 19.70 - $ 23.70 $ (115,000)
Oil Put............... 5,000 -- Mar 2002 - Feb. 2003 22.00 - -- 141,000
Natural Gas Collars... -- 40,000 Mar 2001 - Feb. 2002 2.40 - 2.91 $ 3.19
Natural Gas Put....... -- 75,000 Mar 2002 - Feb. 2003 3.00 - -- 894,000
At June 30, 2000
Oil Collars........... 4,000 -- May 2000 - Feb. 2001 $ 22.20 - $ 26.50 $ (118,000)
5,000 -- Mar 2001 - Feb. 2002 $ 19.70 - $ 23.70 (140,000)
Gas Collars........... 30,000 May 2000 - Feb. 2001 $ 2.60 - $ 3.19 (272,000)
40,000 Mar 2001 - Feb. 2002 $ 2.40 - $ 2.91 (248,000)
(The strike prices for the oil options are based on the NYMEX spot price
for West Texas Intermediate; the strike prices for the natural gas collars are
based on the Inside FERC-West Texas Waha spot price; the strike price for the
natural gas put is based on the Inside FERC-El Paso Permian spot price.)
9. OTHER ACCRUED LIABILITIES
Other accrued liabilities consist of the following:
JUNE 30,
-----------------------------
2001 2000
------------- ------------
(IN THOUSANDS)
Accrued payroll, taxes and employee benefits............. $ 31,242 $ 15,261
State sales, use and other taxes......................... 5,825 2,465
Oil and gas revenue distribution......................... 1,606 1,714
Other.................................................... 10,250 6,958
------------- ------------
Total.................................................... $ 48,923 $ 26,398
============= ============
10. STOCKHOLDERS' EQUITY
EQUITY OFFERINGS
On June 30, 2000, the Company closed the public offering of 11,000,000
shares of common stock at $9.625 per share, or approximately $106 million (the
"Equity Offering"). Net proceeds from the Equity Offering of approximately $101
million were used to repay a portion of the Company's term loan borrowings and
revolving line of credit under its senior credit facility and retire other
long-term debt.
On May 7, 1999, the Company closed the public offering of 55,300,000
shares of common stock (300,000 shares of which were sold pursuant to the
underwriters' over-allotment option discussed below) at $3.00 per share, or $166
million (the "Prior Public Offering"). Concurrently therewith, the Company
closed the offering of 3,508,772 shares of common stock at $2.85 per share, or
$10 million (the "Prior Concurrent Offering" and together with the Prior Public
Offering, the "Prior Equity Offerings"). In addition, on
F-23
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
June 7, 1999, the underwriters of the Prior Public Offering exercised an
over-allotment option to purchase an additional 5,436,000 million shares to
cover overallotments. Net proceeds from the Prior Equity Offerings of
approximately $180.4 million were used to repay a portion of the Company's term
loan borrowings under its senior credit facility.
STOCK INCENTIVE PLANS
On January 13, 1998 the Company's shareholders approved the Key Energy
Group, Inc. 1997 Incentive Plan, as amended (the "1997 Incentive Plan"). The
1997 Incentive Plan is an amendment and restatement of the plans formerly known
as the "Key Energy Group, Inc. 1995 Stock Option Plan" (the "1995 Option Plan")
and the "Key Energy Group, Inc. 1995 Outside Directors Stock Option Plan" (the
"1995 Directors Plan") (collectively, the "Prior Plans").
All options previously granted under the Prior Plans and outstanding as
of November 17, 1997 (the date on which the Company's board of directors adopted
the plan) were assumed and continued, without modification, under the 1997
Incentive Plan.
Under the 1997 Incentive Plan, the Company may grant the following awards
to key employees, directors who are not employees ("Outside Directors") and
consultants of the Company, its controlled subsidiaries, and its parent
corporation, if any: (i) incentive stock options ("ISOs") as defined in Section
422 of the Internal Revenue Code of 1986, as amended (the "Code"), (ii)
"nonstatutory" stock options ("NSOs"), (iii) stock appreciation rights ("SARs"),
(iv) shares of the restricted stock, (v) performance shares and performance
units, (vi) other stock-based awards and (vii) supplemental tax bonuses
(collectively, "Incentive Awards"). ISOs and NSOs are sometimes referred to
collectively herein as "Options".
The Company may grant Incentive Awards covering an aggregate of the
greater of (i) 3,000,000 shares of the Company's common stock and (ii) 10% of
the shares of the Company's common stock issued and outstanding on the last day
of each calendar quarter, provided, however, that a decrease in the number of
issued and outstanding shares of the Company's common stock from the previous
calendar quarter shall not result in a decrease in the number of shares
available for issuance under the 1997 Incentive Plan. As a result of the
Company's equity offering discussed above, as of June 30, 2001, the number of
shares of the Company's common stock that may be covered by Incentive Awards has
increased to approximately 10.1 million.
Any shares of the Company's common stock that are issued and are
forfeited or are subject to Incentive Awards under the 1997 Incentive Plan that
expire or terminate for any reason will remain available for issuance with
respect to the granting of Incentive Awards during the term of the 1997
Incentive Plan, except as may otherwise be provided by applicable law. Shares of
the Company's common stock issued under the 1997 Incentive Plan may be either
newly issued or treasury shares, including shares of the Company's common stock
that the Company receives in connection with the exercise of an Incentive Award.
The number and kind of securities that may be issued under the 1997 Incentive
Plan and pursuant to then outstanding Incentive Awards are subject to
adjustments to prevent enlargement or dilution of rights resulting from stock
dividends, stock splits, recapitalizations, reorganization or similar
transactions.
The maximum number of shares of the Company's common stock subject to
Incentive Awards that may be granted or that may vest, as applicable, to any one
Covered Employee (defined below) during any calendar year shall be 500,000
shares, subject to adjustment under the provisions of the 1997 Incentive Plan.
The maximum aggregate cash payout subject to Incentive Awards (including
SARs, performance units and performance shares payable in cash, or other
stock-based awards payable in cash) that may be granted to any one Covered
Employee during any calendar year is $2,500,000. For purposes of the 1997
Incentive Plan, "Covered Employees" means a named executive officer who is one
of the group covered employees as defined in Section 162(m) of the Code and the
regulation promulgated thereunder (i.e., generally the chief executive officer
and the other four most highly compensated executive officers for a given year.)
F-24
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
The 1997 Incentive Plan is administrated by the Compensation Committee
appointed by the Board of Directors (the "Committee") consisting of not less
than two directors each of whom is (i) an "outside director" under Section
162(m) of the Code and (ii) a "non-employee director" under Rule 16b-3 of the
Securities Exchange Act of 1934. In addition, subject to applicable shareholder
approval requirements, the Company may issue NSOs outside the 1997 Incentive
Plan.
The exercise price of options granted under the 1997 Incentive Plan and
outside the 1997 Incentive Plan is at or above the fair market value per share
on the date the options are granted. The exercise of NSOs results in a U.S. tax
deduction to the Company equal to the income tax effect of the difference
between the exercise price and the market price at the exercise date. The
following table summarizes the stock option activity related to the Company's
plans (shares in thousands):
FISCAL YEAR ENDING JUNE 30,
--------------------------------------------------------------------------
2001 2000 1999
------------------------- ----------------------- ----------------------
WEIGHTED- WEIGHTED- WEIGHTED-
AVERAGE AVERAGE AVERAGE
EXERCISE EXERCISE EXERCISE
SHARES PRICE SHARES PRICE SHARES PRICE
---------- ------------ ---------- ----------- ---------- ----------
Outstanding-beginning of fiscal year..... $ 9,470 $ 6.37 6,920 $ 5.55 2,292 $ 10.33
Granted............................... 2,533 8.08 3,688 8.61 5,443 4.32
Exercised............................. (3,107) 4.70 (241) 4.56 (15) 6.36
Forfeited............................. (193) 4.92 (897) 9.80 (800) 10.87
---------- --------- -------- ---------- ------- ---------
Outstanding--end of fiscal year.......... 8,703 7.49 9,470 6.37 6,920 5.55
========== ======== =======
Exercisable--end of fiscal year.......... 5,820 4,370 1,020
========== ======== =======
STOCK INCENTIVE PLANS
The foregoing stock option activity summary reflects that effective as of
September 4, 1998, the Committee authorized the cancellation and reissue of
stock options for employees that were not executive officers for the purpose of
changing the exercise price and vesting schedule of such options. A total of
473,556 stock options were cancelled, with a weighted average price of
approximately $13.09 per share, and reissued with an exercise price of $7.125
per share. The vesting of the new options is ratable over a three-year period
from the date of grant.
The following table summarizes information about the stock options
outstanding at June 30, 2001 (shares in thousands):
OPTIONS OUTSTANDING OPTIONS EXERCISABLE
----------------------------------------------- ------------------------------
NUMBER OF WEIGHTED- WEIGHTED- NUMBER OF WEIGHTED-
SHARES AVERAGE AVERAGE SHARES AVERAGE
OUTSTANDING AT REMAINING EXERCISE EXERCISABLE AT EXERCISE
RANGE OF EXERCISE PRICES JUNE 30, 2001 CONTRACTUAL LIFE PRICE JUNE 30, 2001 PRICE
------------------------ ---------------- ------------------ ----------- ----------------- -----------
$ 3.00 - $ 6.8125.................. 1,921 6.49 $ 3.65 1,802 $ 3.51
$ 6.00 - $ 7.4375.................. 1,252 7.82 7.25 439 7.13
$ 8.125 - $ 8.3125.................. 2,135 8.67 8.25 1,635 8.26
$ 8.50 - $ 13.50.................... 3,395 7.69 9.27 1,943 9.68
The Company applies the intrinsic value method of APB 25 in accounting
for its employee stock incentive plans. Accordingly, no compensation expense has
been recognized for any stock options issued under the employee plans. Had
compensation expense for stock options granted to employees been recognized
based on the fair value at the grant dates, using the methodology prescribed by
SFAS 123, the Company's net income (loss) and earnings per share would have been
reduced to pro forma amounts indicated below:
F-25
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
2001 2000 1999
-------------- ------------- -------------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
Net income (loss):
As reported.................................. $ 62,710 $ (18,959) $ (53,258)
Pro forma.................................... 52,338 (25,684) (57,057)
Basic earnings per share of common stock:
As reported.................................. $ 0.63 $ (0.23) $ (1.94)
Pro forma.................................... 0.53 (0.31) (2.07)
Diluted earnings per share of common stock:
As reported.................................. $ 0.61 $ (0.23) $ (1.94)
Pro forma.................................... 0.51 (0.31) (2.07)
SFAS 123 does not apply to options granted prior to January 1, 1995;
therefore, the pro forma effect disclosed above may not be representative of pro
forma amounts in future years.
The total fair value of stock options granted during fiscal 2001, 2000
and 1999 was approximately $11,217,000, $19,541,000 and $15,695,000,
respectively. The fair value of each stock option grant was estimated on the
date of grant using the Black-Sholes option-pricing model, based on the
following weighted-average assumptions.
FISCAL YEAR OF GRANT
------------------------------------------------------
2001 2000 1999
--------------- --------------- ---------------
Risk-free interest rate............................. 4.30% 6.40% 5.09%
Expected life of options............................ 5 years 5 years 5 years
Expected volatility of the Company's stock 59% 67% 98%
price.............................................
Expected dividends.................................. none none none
11. INCOME TAXES
Components of income tax expense (benefit) are as follows:
FISCAL YEAR ENDED JUNE 30,
---------------------------------------------------------------
2001 2000 1999
---------------- ----------------- ------------------
(IN THOUSANDS)
Federal and State:
Current............................... $ 2,304 $ (5,588) $ --
Deferred
U.S............................... 34,698 (1,818) (25,560)
Foreign........................... -- -- (115)
---------------- ----------------- ------------------
$ 37,002 $ (7,406) $ (25,675)
================ ================= ==================
F-26
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
No income tax payments were made for fiscal 2001, 2000 or 1999.
Additionally a deferred tax benefit of $7,004,000 has been allocated to
stockholders' equity in fiscal 2001 for compensation expense for income tax
purposes in excess of amounts recognized for financial reporting purposes.
Income tax expense (benefit) differs from amounts computed by applying
the statutory federal rate as follows:
FISCAL YEAR ENDED JUNE 30,
---------------------------------------------------------------
2001 2000 1999
---------------- ----------------- ------------------
Income tax computed at statutory rate..... 35.0% (35.0)% (35.0)%
Amortization of goodwill disallowance..... 2.2 7.0 2.0
State taxes............................... 1.4 -- --
Change in valuation allowance and other... (1.4) 1.5 0.5
---------------- ----------------- ------------------
37.2% (26.5)% (32.5)%
================ ================= ==================
Deferred tax assets (liabilities) are comprised of the following:
FISCAL YEAR ENDED JUNE 30,
------------------------------------------------
2001 2000
-------------------- -------------------
(IN THOUSANDS)
Net operating loss and tax credit carry forwards........... $ 69,376 $ 88,491
Property and equipment..................................... (182,442) (175,511)
Self insurance reserves.................................... 405 1,616
Allowance for bad debts.................................... 1,542 1,129
Acquisition expenses, expensed for tax..................... (626) (626)
Other...................................................... 148 862
-------------------- -------------------
Net deferred tax liability................................. (111,597) (84,039)
Valuation allowance of deferred tax assets................. (15,803) (15,668)
-------------------- -------------------
Net deferred tax liability, net of valuation allowance..... $ (127,400) $ (99,707)
==================== ===================
A valuation allowance is provided when it is more likely than not that
some portion of the deferred tax assets will not be realized. As described
below, due to annual limitations on certain net operating loss carryforwards, it
does not appear more likely than not that the Company will be able to utilize
all available carryforwards prior to their ultimate expiration.
The Company estimates that as of June 30, 2001, the Company will have
available approximately $185,474,305 of net operating loss carryforwards (which
will continue to expire in fiscal 2002). Approximately $53,570,522 of the net
operating loss carryforwards are subject to an annual limitation of
approximately $1,012,000, under Sections 382 and 383 of the Internal Revenue
Code.
12. LEASING ARRANGEMENTS
The Company leases certain property and equipment under non-cancelable
operating leases that generally expire at various dates through fiscal 2006. The
term of the operating leases generally run from 24 to 60 months with varying
payment dates throughout each month.
F-27
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
As of June 30, 2001, the future minimum lease payments under
non-cancelable operating leases are as follows (in thousands):
LEASE
FISCAL YEAR ENDING JUNE 30, PAYMENTS
------------------------------ -----------------
2002........................................... $ 4,689
2003........................................... 4,587
2004........................................... 4,493
2005........................................... 4,426
2006........................................... 2,626
------------------
$ 20,821
==================
Operating lease expense was approximately $6,072,000, $6,460,000 and
$7,313,000 for the fiscal years ended June 30, 2001, 2000 and 1999,
respectively.
13. EMPLOYEE BENEFIT PLANS
In order to retain quality personnel, the Company maintains 401(k) plans
as part of its employee benefits package. From July 1, 1998 through December 31,
1998, the Company matched 100% of employee contributions into its 401(k) plan up
to a maximum of $1,000 per participant per year. From January 1, 1999 through
March 31, 2000, the Company elected not to match employee contributions.
Commencing April 1, 2000, the Company matches, 100% of employee contributions
into its 401(k) plan up to a maximum of $250 per participant per year. The
maximum limit was increased to $500 effective October 1, 2000, $750 effective
January 1, 2001 and $1,000 effective July 1, 2001. The Company's matching
contributions for fiscal 2001, 2000 and 1999 were approximately $1,857,000,
$77,000 and $908,000, respectively.
14. TRANSACTIONS WITH RELATED PARTIES
In connection with the negotiation of the terms of a five-year employment
agreement with Mr. Francis D. John, Chairman of the Board, President and Chief
Executive Officer of the Company, and as an inducement to Mr. John to enter into
such employment agreement, the Company entered into a separate agreement with
Mr. John, dated as of August 2, 1999, which as amended through June 30, 2001,
provides that $6.5 million in loans previously made by the Company to Mr. John,
together with the accrued interest payable thereon, will be forgiven, ratably
during the ten year period commencing on July 1, 2001 and ending on June 30,
2010. The agreement provides that the foregoing forgiveness of indebtedness is
predicated and conditioned upon Mr. John remaining employed by the Company
during such period. In addition, in the event that Mr. John is terminated by the
Company for Cause (as defined in the agreement), or in the event that Mr. John
voluntarily terminates his employment with the Company, the agreement further
provides that the entire remaining principal balance of these loans, together
with accrued interest payable thereon, will become immediately due and payable
by Mr. John. However, in the event that Mr. John's employment is terminated for
"Good Reason", or as a result of Mr. John's death or "Disability", or as a
result of a "Change in Control" (all as defined in that agreement), the
agreement stipulates that the remaining principal balance outstanding on the
loans, together with accrued interest thereon will be forgiven.
In connection with the negotiation of an employment agreement with Thomas
K. Grundman, the Company's Executive Vice President, Chief Financial Officer and
Chief Accounting Officer, the Company made a $240,000 short-term loan and a
$150,000 relocation loan to assist Mr. Grundman's relocation to the Company's
executive offices. Interest on these loans accrues at a rate of 6.125% per
annum. The short-term loan has been repaid. The relocation loan together with
accrued interest will be forgiven in three installments of $50,000 each on July
1, 2000, 2001 and 2002; provided, however, that if Mr. Grundman's employment is
terminated during such period in a way that (i) triggers severance obligations,
all amounts owed shall be immediately forgiven or (ii) does not trigger
severance obligations, all amounts owed shall be immediately due and payable.
F-28
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
15. BUSINESS SEGMENT INFORMATION
The Company's reportable business segments are well servicing and
contract drilling. Oil and natural gas production operations previously were
presented separately as a reportable business segment and are now included in
"corporate/other."
WELL SERVICING: the Company's operations provide well servicing (ongoing
maintenance of existing oil and natural gas wells), workover (major repairs or
modifications necessary to optimize the level of production from existing oil
and natural gas wells) and production services (fluid hauling and fluid storage
tank rental).
CONTRACT DRILLING: the Company provides contract drilling services for
major and independent oil companies onshore the continental United States,
Argentina and Ontario, Canada.
The Company's management evaluates the performance of its operating
segments based on net income and operating profits (revenues less direct
operating expenses). Corporate expenses include general corporate expenses
associated with managing all reportable operating segments. Corporate assets
consist principally of cash and cash equivalents, deferred debt financing costs
and deferred income tax assets.
WELL CONTRACT CORPORATE
SERVICING DRILLING /OTHER TOTAL
------------ -------------- ------------ -------------
TWELVE MONTHS ENDED JUNE 30, 2001
Operating revenues.................................... $ 758,273 $ 107,639 $ 7,350 $ 873,262
Operating profit ..................................... 265,165 30,273 2,886 298,324
Depreciation, depletion and amortization.............. 63,578 7,947 3,622 75,147
Interest expense...................................... 1,831 -- 54,729 56,560
Net income (loss) before extraordinary gain (loss)*... 109,159 9,466 (56,344) 62,281
Identifiable assets................................... 664,611 95,473 278,325 1,038,409
Capital expenditures (excluding acquisitions)......... 50,799 15,884 15,437 82,120
TWELVE MONTHS ENDED JUNE 30, 2000
Operating revenues.................................... $ 559,492 68,428 $ 9,812 $ 637,732
Operating profit...................................... 159,552 10,129 5,665 175,346
Depreciation, depletion and amortization.............. 62,680 6,105 2,187 70,972
Interest expense...................................... 2,300 -- 69,630 71,930
Net income (loss) before extraordinary gain (loss)*... 48,062 (1,664) (56,968) (20,570)
Identifiable assets................................... 635,304 89,574 322,754 1,047,632
Capital expenditures (excluding acquisitions)......... 30,098 8,282 3,422 41,802
TWELVE MONTHS ENDED JUNE 30, 1999
Operating revenues.................................... $ 433,657 $ 50,613 $ 7,547 $ 491,817
Operating profit...................................... 108,692 7,057 4,640 120,389
Depreciation, depletion and amortization.............. 52,638 6,586 2,850 62,074
Interest expense...................................... 1,659 18 65,724 67,401
Net income (loss) before extraordinary gain (loss)*... 15,447 (4,093) (64,612) (53,258)
Identifiable assets................................... 651,781 81,074 209,860 942,715
Capital expenditures (excluding acquisitions)......... 26,776 1,063 3,468 31,307
* Net income (loss) before extraordinary gain (loss) for the contract drilling
segment includes a portion of well servicing general and administrative expenses
allocated on a percentage of revenue basis.
Operating revenues and operating profit for the Company's foreign
operations, which includes Argentina and Canada, were $54.5 million and $13.4
million, respectively, for the year ended June 30, 2001. Operating revenues and
operating profit for the Company's foreign operations, which includes Argentina
and Canada, were $37.7 million and $7.3 million, respectively, for the year
F-29
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
ended June 30, 2000. Operating revenues and operating profit for the Company's
foreign operations, which includes Argentina and Canada, were $26.9 million and
$5.4 million, respectively, for the year ended June 30, 1999.
The Company had $84.1 million and $66.9 million of identifiable assets as
of June 30, 2001 and 2000, respectively, related to its foreign operations.
16. SUPPLEMENTAL SCHEDULE OF NONCASH INVESTING AND FINANCING ACTIVITIES
FISCAL YEAR ENDED JUNE 30,
------------------------------------------------------
2001 2000 1999
---------------- --------------- --------------
Fair value of common stock issued in purchase
transactions.................................... $8,120 $ -- $ --
Fair value of common stock issued to lender in
lieu of fees.................................... -- -- 1
Fair value of common stock issued upon
conversion of long-term debt.................... 957 3,606 --
Capital lease obligations............................ 9,595 10,758 17,120
17. UNAUDITED SUPPLEMENTARY INFORMATION--QUARTERLY RESULTS OF OPERATIONS
Summarized quarterly financial data for fiscal 2001, 2000 and 1999 are as
follows:
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
------------- --------------- ------------- --------------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
2001
Revenues $ 191,679 $ 203,911 $ 227,370 $250,302
Income (loss) from operations................. 12,229 18,063 27,912 41,079
Net income (loss) before extraordinary gain
(loss)..................................... 7,510 11,094 17,587 26,090
Extraordinary gain (loss), net of tax......... 1,197 68 (167) (669)
------------- --------------- ------------- --------------
Net income (loss)............................. 8,707 11,162 17,420 25,421
============= =============== ============= ==============
Earnings (loss) per share:
Basic--before extraordinary gain (loss).... 0.08 0.11 0.18 0.26
Extraordinary gain (loss), net of tax...... 0.01 -- -- (0.01)
------------- --------------- ------------- --------------
Basic--after extraordinary gain (loss)..... 0.09 0.11 0.18 0.25
============= =============== ============= ==============
Diluted--before extraordinary gain (loss).. 0.08 0.11 0.17 0.25
Extraordinary gain (loss),................. 0.01 -- -- (0.01)
------------- --------------- ------------- --------------
Diluted--after extraordinary gain (loss)... 0.09 0.11 0.17 0.24
============= =============== ============= ==============
Weighted average shares outstanding:
Basic...................................... 96,880 97,534 98,211 100,179
Diluted.................................... 100,472 100,534 103,524 104,401
2000
Revenues...................................... $149,892 $159,389 $158,551 $169,900
Income (loss) from operations................. (13,191) (7,953) (5,730) (1,102)
F-30
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
------------- --------------- ------------- --------------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
Net income (loss) before extraordinary gain
(loss).................................... (9,451) (5,693) (4,150) (1,276)
Extraordinary gain (loss), net of tax........ -- -- -- 1,611
------------- --------------- ------------- --------------
Net income (loss)............................ (9,451) (5,693) (4,150) 335
============= =============== ============= ==============
FIRST SECOND THIRD FOURTH
QUARTER QUARTER QUARTER QUARTER
------------- --------------- ------------- --------------
(IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
Earnings (loss) per share:
Basic--before extraordinary gain (loss).... (0.11) (0.07) (0.05) (0.01)
Extraordinary gain (loss), net of tax...... -- -- -- 0.02
------------- --------------- ------------- --------------
Basic--after extraordinary gain (loss)..... (0.11) (0.07) (0.05) 0.01
============= =============== ============= ==============
Diluted--before extraordinary gain (loss).. (0.11) (0.07) (0.05) (0.01)
Extraordinary gain (loss), net of tax...... -- -- -- 0.02
------------- --------------- ------------- --------------
Diluted--after extraordinary gain (loss)... (0.11) (0.07) (0.05) 0.01
============= =============== ============= ==============
Weighted average shares outstanding:
Basic...................................... 82,738 82,738 84,633 85,567
Diluted.................................... 82,738 82,738 84,633 85,567
18. VOLUMETRIC PRODUCTION PAYMENT
In March 2000, Key sold a portion of its future oil and natural gas
production from Odessa Exploration Incorporated, its wholly owned subsidiary,
for gross proceeds of $20 million pursuant to an agreement under which the
purchaser is entitled to receive a share of the production from certain oil and
natural gas properties in amounts ranging from 3,500 to 10,000 barrels of oil
and 58,800 to 122,100 Mmbtus of natural gas per month over a six year period
ending February 2006. The total volume of the forward sale is approximately
486,000 barrels of oil and 6.135 million Mmbtus of natural gas.
19. CONDENSED CONSOLIDATING FINANCIAL INFORMATION
The Company's senior notes are guaranteed by all of the Company's
subsidiaries (except for the foreign subsidiaries), all of which are
wholly-owned. The guarantees are joint and several, full, complete and
unconditional. There are currently no restrictions on the ability of the
subsidiary guarantors to tranfer funds to the parent company.
The accompanying condensed consolidating financial information has been
prepared and presented pursuant to SEC Regulation S-X Rule 3-10 "Financial
Statements of Guarantors and Issuers of Guaranteed Securities Registered or
Being Registered." The information is not intended to present the financial
position, results of operations and cash flows of the individual companies or
groups of companies in accordance with generally accepted accounting principles.
F-31
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
CONDENSED CONSOLIDATING BALANCE SHEETS
JUNE 30, 2001
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Assets:
Current assets.............. $ 10,680 $ 165,653 $ 29,817 -- 206,150
Net property and equipment.. 21,418 717,989 54,309 -- 793,716
Goodwill, net .............. 3,374 184,379 2,122 -- 189,875
Deferred costs, net......... 17,624 -- -- -- 17,624
Intercompany receivables 664,592 -- -- (664,592) --
Other assets................ 15,303 5,616 -- -- 20,919
------------ ---------------- -------------------- ----------------- ---------------
Total assets.................... $ 732,991 1,073,637 $ 86,248 $ (664,592) $ 1,228,284
============ ================ ==================== ================= ===============
Liabilities and equity:
Current liabilities......... $ 35,671 $ 64,679 $ 15,203 -- $ 115,553
Long-term debt.............. 470,668 15,331 (38) -- 485,961
Intercompany payables....... -- 608,764 55,828 (664,592) --
Deferred tax liability...... 127,400 -- -- -- 127,400
Other long-term
liabilities.............. 8,240 14,252 -- -- 22,492
Stockholders' equity........ 91,012 370,611 15,255 -- 476,878
------------ ---------------- -------------------- ----------------- ---------------
Total liabilities and
stockholders' equity............ $ 732,991 $1,073,637 $ 86,248 $ (664,592) $ 1,228,284
============ ================ ==================== ================= ===============
JUNE 30,2000
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Assets:
Current assets.............. $ 120,216 $ 115,178 $ 18,195 $ -- $ 253,589
Net property and equipment.. 7,308 704,531 48,722 -- 760,561
Goodwill, net .............. 3,606 192,641 2,386 -- 198,633
Deferred costs, net......... 18,855 -- -- -- 18,855
Intercompany receivables.... 788,166 -- -- (664,592) --
Other assets................ 9,062 5,565 -- -- 14,627
------------ ---------------- -------------------- ----------------- ---------------
Total assets.................... $ 947,213 $1,017,915 $ 69,303 $ (664,592) $ 1,246,265
============ ================ ==================== ================= ===============
Liabilities and equity:
Current liabilities......... $ 33,637 $ 47,736 $ 11,475 $ -- $ 92,848
Long-term debt.............. 637,438 14,486 21 -- 651,945
Intercompany payables....... -- 740,268 47,898 (788,166) --
Deferred tax liability...... 99,707 -- -- -- 99,707
Other long-term
liabilities............. 1,751 17,127 -- -- 18,878
Stockholders' equity........ 174,680 198,298 9,909 -- 382,887
------------ ---------------- -------------------- ----------------- ---------------
Total liabilities and
stockholders' equity........ $ 947,213 $1,017,915 $ 69,303 $ (788,166) $ 1,246,265
============ ================ ==================== ================= ===============
F-32
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS
JUNE 30, 2001
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Revenues........................ $ 2,018 $816,724 $ 54,520 $ -- $873,262
Costs and expenses..............
Direct expenses............. -- 533,807 41,131 -- 574,938
Depreciation, depletion
and amortization expense 1,353 69,714 4,080 -- 75,147
General and administrative
expense.................. 18,991 43,644 3,436 -- 66,071
Interest.................... 54,464 1,275 821 -- 56,560
Other....................... 318 943 2 -- 1,263
------------ ---------------- -------------------- ----------------- ---------------
Total costs and expenses........ 75,126 649,383 49,470 -- 773,979
============ ================ ==================== ================= ===============
Income (loss) before income
taxes....................... (73,108) 167,341 5,050 -- 99,283
Income tax (expense) benefit.... 27,247 (62,367) (1,882) -- (37,002)
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss) before
extraordinary items ........ (45,861) 104,974 3,168 -- 62,281
Extraordinary items, net of
tax........................ 429 -- -- -- 429
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss)............... $ (45,432) $104,974 $ 3,168 $ -- $ 62,710
============ ================ ==================== ================= ===============
JUNE 30, 2000
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Revenues........................ $ 790 $ 599,225 $ 37,717 $ -- $637,732
Costs and expenses:
Direct expenses............. -- 431,997 30,389 -- 462,386
Depreciation, depletion and
amortization expense..... 1,162 66,453 3,357 -- 70,972
General and administrative
expense.................. 11,101 44,473 3,198 -- 58,772
Interest.................... 69,802 1,527 601 -- 71,930
Other....................... -- 1,648 -- -- 1,648
------------ ---------------- -------------------- ----------------- ---------------
Total costs and expenses........ 82,065 546,098 37,545 -- 665,708
============ ================ ==================== ================= ===============
Income (loss) before income
taxes....................... (81,275) 53,127 172 -- (27,976)
Income tax (expense) benefit.... 21,516 (14,064) (46) -- 7,406
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss) before
extraordinary items......... (59,759) 39,063 126 -- (20,570)
Extraordinary items, net of
tax........................ 1,611 -- -- -- 1,611
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss)............... $ (58,148) $ 39,063 $ 126 $ -- $(18,959)
============ ================ ==================== ================= ===============
F-33
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS (CONT'D)
JUNE 30, 1999
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR
COMPANY SUBSIDIARIES SUBSIDIARIES ELIMINATIONS CONSOLIDATED
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Revenues........................ $ 1,086 $463,813 $ 26,918 $ -- $ 491,817
Costs and expenses:
Direct expenses............. -- 349,936 21,492 -- 371,428
Depreciation, depletion
and amortization expense.. 428 58,403 3,243 -- 62,074
General and administrative
expense................... 14,962 34,490 3,656 -- 53,108
Interest.................... 65,724 1,559 118 -- 67,401
Other....................... 10,811 5,928 -- -- 16,739
------------ ---------------- -------------------- ----------------- ---------------
Total costs and expenses........ 91,925 450,316 28,509 -- 570,750
============ ================ ==================== ================= ===============
Income (loss) before income
taxes....................... (90,839) 13,497 (1,591) -- (78,933)
Income tax (expense) benefit.... 29,547 (4,390) 518 -- 25,675
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss) before
extraordinary items......... (61,292) 9,107 (1,073) -- (53,258)
Extraordinary items, net of
tax......................... -- -- -- -- --
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss)............... $ (61,292) $ 9,107 $ (1,073) $ -- $ (53,258)
============ ================ ==================== ================= ===============
F-34
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
FISCAL YEAR ENDED JUNE 30, 2001
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Net cash provided by (used
in) operating activities... $ 68,567 $ 64,408 $ 9,742 $ -- $ 142,717
Net cash provided by (used
in) investing activities... (19,459) (56,711) (7,180) -- (83,350)
Net cash provided by (used
in) financing activities... (158,627) (8,456) (59) -- (167,142)
------------ ---------------- -------------------- ----------------- ---------------
Net increase (decrease) in
cash....................... (109,519) (759) 2,503 -- (107,775)
Cash and cash equivalents at
beginning of period........ 111,166 (1,246) (47) -- 109,873
------------ ---------------- -------------------- ----------------- ---------------
Cash and cash equivalents at
end of period.............. $ 1,647 $ (2,005) $ 2,456 $ -- $ 2,098
============ ================ ==================== ================= ===============
FISCAL YEAR ENDED JUNE 30, 2000
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Net cash provided by (used
in) operating activities... $ 18,962 $ 10,434 $ 5,464 $ -- $ 34,860
Net cash provided by (used
in) investing activities... (4,468) (26,671) (6,627) -- (37,766)
Net cash provided by (used
in) financing activities... 80,070 9,287 (56) -- 89,301
------------ ---------------- -------------------- ----------------- ---------------
Net increase (decrease) in
cash....................... 94,564 (6,950) (1,219) -- 86,395
Cash and cash equivalents at
beginning of period........ 16,602 5,704 1,172 -- 23,478
------------ ---------------- -------------------- ----------------- ---------------
Cash and cash equivalents at
end of period.............. $ 111,166 $ (1,246) $ (47) $ -- $ 109,873
============ ================ ==================== ================= ===============
F-35
KEY ENERGY SERVICES INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
JUNE 30, 2001, 2000 AND 1999
FISCAL YEAR ENDED JUNE 30, 1999
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Net cash provided by (used
in) operating activities... $ (49,167) $ 26,508 $ 9,232 $ -- $ (13,427)
Net cash provided by (used
in) investing activities... (272,620) (13,986) (8,048) -- (294,654)
Net cash provided by (used
in) financing activities... 313,526 (7,196) (36) -- 306,294
------------ ---------------- -------------------- ----------------- ---------------
Net increase (decrease) in
cash....................... (8,261) 5,326 1,148 -- (1,787)
Cash and cash equivalents at
beginning of period........ 24,863 378 24 -- 25,265
------------ ---------------- -------------------- ----------------- ---------------
Cash and cash equivalents at
end of period.............. $ 16,602 $ 5,704 $ 1,172 $ -- $ 23,478
============ ================ ==================== ================= ===============
F-36
INDEPENDENT AUDITORS' REPORT
To The Board of Directors
Key Energy Services, Inc. :
We have audited the accompanying consolidated balance sheets of Key
Energy Services, Inc., and subsidiaries as of June 30, 2001 and 2000, and the
related consolidated statements of operations, comprehensive income, cash flows
and stockholders' equity for each of the years in the three-year period ended
June 30, 2001. In connection with our audits of the consolidated financial
statements, we also have audited the financial statement schedule listed in the
Index at Item 14. These consolidated financial statements and financial
statement schedule are the responsibility of the Company's management. Our
responsibility is to express an opinion on these consolidated financial
statements and financial statement schedule based on our audits.
We conducted our audits in accordance with auditing standards generally
accepted in the United States of America. Those standards require that we plan
and perform the audit to obtain reasonable assurance about whether the financial
statements are free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in the financial
statements. An audit also includes assessing the accounting principles used and
significant estimates made by management, as well as evaluating the overall
financial statement presentation. We believe that our audits provide a
reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above
present fairly, in all material respects, the consolidated financial position of
Key Energy Services, Inc. and subsidiaries as of June 30, 2001 and 2000, and the
results of their operations and their cash flows for each of the years in the
three-year period ended June 30, 2001, in conformity with accounting principles
generally accepted in the United States of America. Also, in our opinion, the
related financial statement schedule, when considered in relation to the basic
consolidated financial statements taken as a whole, presents fairly, in all
material respects, the information set forth therein.
As discussed in Note 8 to the consolidated financial statements, the
Company changed its method of accounting for derivative instruments and hedging
activities in 2001.
KPMG LLP
Midland, Texas
August 31, 2000
F-37
KEY ENERGY SERVICES, INC.
CONSOLIDATED BALANCE SHEETS
DECEMBER 31, 2001 JUNE 30, 2001
----------------------- -------------------
(Unaudited)
ASSETS (IN THOUSANDS, EXCEPT SHARE DATA)
Current assets:
Cash and cash equivalents........................................ $ 7,966 $ 2,098
Accounts receivable, net of allowance for doubtful
accounts of $4,590 and $4,082, at December 31, 2001
and June 30, 2001, respectively.............................. 149,312 177,016
Inventories...................................................... 12,249 16,547
Prepaid expenses and other current assets........................ 10,141 10,489
----------------------- -------------------
Total current assets.................................................. 179,668 206,150
----------------------- -------------------
Property and Equipment:
Well servicing equipment......................................... 747,848 723,724
Contract drilling equipment...................................... 123,022 119,122
Motor vehicles................................................... 68,554 64,907
Oil and natural gas properties and other related equipment,
successful efforts method.................................... 44,502 44,245
Furniture and equipment.......................................... 29,396 24,865
Building and land................................................ 37,970 37,812
----------------------- -------------------
Total property and equipment.......................................... 1,051,292 1,014,675
Accumulated depreciation and depletion................................ (250,790) (220,959)
----------------------- -------------------
Net property and equipment............................................ 800,502 793,716
----------------------- -------------------
Goodwill, net of accumulated amortization at $27,970
at December 31, 2001 and $28,168 at June 30, 2001............. 193,217 189,875
Deferred costs, net.............................................. 14,257 17,624
Notes and accounts receivable - related parties.................. 456 6,050
Other assets..................................................... 28,253 14,869
----------------------- -------------------
Total assets..................................................... $ 1,216,353 $ 1,228,284
======================= ===================
LIABILITIES AND STOCKHOLDERS' EQUITY
Current Liabilities:
Accounts payable................................................. $ 28,675 42,544
Other accrued liabilities........................................ 40,786 48,923
Accrued interest................................................. 14,434 16,140
Current portion of long-term debt and capital lease obligations.. 8,215 7,946
----------------------- -------------------
Total current liabilities............................................. 92,110 115,553
----------------------- -------------------
Long-term debt, less current portion.................................. 379,269 470,578
Capital lease obligations, less current portion....................... 16,227 15,383
Deferred revenue...................................................... 11,541 14,104
Non-current accrued expenses.......................................... 9,816 8,388
Deferred tax liability................................................ 151,305 127,400
Commitments and contingencies......................................... --- ---
Stockholders' equity:
Common stock, $.10 par value: 200,000,000 shares
authorized, 108,371,945 and 101,440, 166 shares issued, at
December 31, 2001 and June 30, 2001, respectively............ 10,837 10,144
Additional paid-in capital....................................... 498,702 444,768
Treasury stock, at cost; 416,666 shares at December 31, 2001
and June 30, 2001............................................ (9,682) (9,682)
F-38
Accumulated other comprehensive income (loss).................... (23,993) 62
Retained earnings (deficit)...................................... 80,221 31,586
----------------------- -------------------
Total stockholders' equity............................................ 556,085 476,878
----------------------- -------------------
Total liabilities and stockholders' equity............................ $ 1,216,353 $ 1,228,284
======================= ===================
SEE THE ACCOMPANYING NOTES WHICH ARE AN INTEGRAL PART OF THESE
CONSOLIDATED FINANCIAL STATEMENTS
F-39
KEY ENERGY SERVICES, INC.
UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS
THREE MONTHS ENDED SIX MONTHS ENDED
DECEMBER 31, DECEMBER 31,
--------------------------- --------------------------
2001 2000 2001 2000
------------ ---------- ----------- -----------
(IN THOUSANDS, EXCEPT PER SHARE DATA)
REVENUES
Well servicing........................................ $ 186,338 $ 178,650 $ 398,839 $ 345,215
Contract drilling..................................... 25,654 24,178 59,290 46,323
Other................................................. 1,345 1,083 4,445 4,052
------------ ----------- ----------- -----------
213,337 203,911 462,574 395,590
------------ ----------- ----------- -----------
COSTS AND EXPENSES:
Well servicing........................................ 117,092 118,123 249,872 229,809
Contract drilling..................................... 17,340 18,360 38,528 35,818
Depreciation, depletion and amortization.............. 19,724 18,146 37,593 36,457
General and administrative............................ 16,755 15,264 34,639 29,631
Bad debt expense...................................... 64 709 308 903
Interest.............................................. 11,097 14,581 23,046 30,692
Other expenses........................................ 1,150 665 2,335 1,988
Foreign currency transaction loss, Argentina
(see Note 10)....................................... 1,844 --- 1,844 ---
------------ ----------- ----------- -----------
185,066 185,848 388,165 365,298
------------ ----------- ----------- -----------
Income (loss) before income taxes..................... 28,271 18,063 74,409 30,292
Income tax (expense) benefit.......................... (10,903) (6,969) (28,045) (11,688)
------------ ----------- ----------- -----------
Income (loss) before extraordinary gain (loss)........ 17,368 11,094 46,364 18,604
Extraordinary gain (loss) on retirement of debt, less
applicable income taxes of $1,267 and $1,374 for the
three and six months ended December 31, 2001,
respectively, and income taxes of $41 and $793, for
the three and six months ended December 31, 2000,
respectively........................................ 2,091 68 2,271 1,265
------------ ----------- ----------- -----------
NET INCOME (LOSS)......................................... $ 19,459 $ 11,162 $ 48,635 $ 19,869
============ =========== =========== ===========
EARNINGS (LOSS) PER SHARE:
Basic - before extraordinary gain (loss).............. $ 0.17 $ 0.11 $ 0.45 $ 0.19
Extraordinary gain (loss), net of tax................. 0.02 --- 0.02 0.01
------------ ----------- ----------- -----------
Basic - after extraordinary gain (loss)................... $ 0.19 $ 0.11 $ 0.47 $ 0.20
============ =========== =========== ===========
Diluted - before extraordinary gain (loss)............ $ 0.17 $ 0.11 0.44 $ 0.19
Extraordinary gain (loss), net of tax................. 0.02 $ --- 0.02 0.01
------------ ----------- ----------- -----------
Diluted - after extraordinary gain (loss)............. $ 0.19 $ 0.11 $ 0.46 $ 0.20
============ =========== =========== ===========
WEIGHTED AVERAGE SHARES OUTSTANDING:
Basic................................................. 103,115 97,534 102,421 97,207
Diluted............................................... 104,811 100,496 104,357 100,336
SEE THE ACCOMPANYING NOTES WHICH ARE AN INTEGRAL PART OF THESE CONSOLIDATED
FINANCIAL STATEMENTS
F-40
KEY ENERGY SERVICES, INC.
UNAUDITED CONSOLIDATED STATEMENTS OF CASH FLOWS
THREE MONTHS ENDED SIX MONTHS ENDED
DECEMBER 31, DECEMBER 31,
--------------------------- --------------------------
2001 2000 2001 2000
------------ ---------- ----------- -----------
(IN THOUSANDS)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)..................................... $ 19,459 $ 11,162 $ 48,635 $ 19,869
ADJUSTMENTS TO RECONCILE INCOME FROM OPERATIONS
TO NET CASH PROVIDED BY (USED IN) OPERATIONS:........ 19,724 18,146 37,593 36,457
Depreciation, depletion and amortization.............. 64 709 308 903
Amortization of deferred debt issuance costs and other
deferred costs..................................... 398 1,008 989 2,416
Deferred income taxes................................. 7,731 6,969 22,331 11,688
(Gain) loss on sale of assets......................... 232 (41) (830) (40)
Foreign currency transaction loss, Argentina.......... 1,844 -- 1,844 --
Extraordinary (gain) loss, net of tax................. (2,091) (68) (2,271) (1,265)
CHANGE IN ASSETS AND LIABILITIES:
(Increase) decrease in accounts receivable............ 31,047 (7,062) 22,903 (22,513)
(Increase) decrease in other current assets........ (2,327) (2,548) (2,497) 1,838
Increase (decrease) in accounts payable, accrued
accrued expenses................................... (17,478) 4,870 (19,466) (3,316)
Other assets and liabilities....................... (1,017) (38) (6,722) (572)
------------ ----------- ----------- -------------
Net cash provided by (used in) operating activities....... 57,586 33,107 102,817 45,465
------------ ----------- ----------- -------------
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures - well servicing................. (16,418) (9,093) (28,312) (17,095)
Capital expenditures - contract drilling.............. (2,923) (4,041) (11,077) (7,174)
Capital expenditures - other.......................... (2,412) (3,942) (5,539) (6,092)
Proceeds from sale of fixed assets.................... 239 850 3,655 952
Acquisitions - well servicing......................... (6,002) (1,700) (8,675) (1,700)
Acquisitions - contract drilling...................... -- (800) -- (800)
------------ ----------- ----------- -------------
Net cash provided by (used in) investing activities... (27,516) (18,726) (49,948) (31,909)
------------ ----------- ----------- -------------
CASH FLOWS FROM FINANCING ACTIVITIES
Repayment of long-term debt........................... (118,441) (13,812) (184,931) (122,597)
Repayment of capital lease obligations................ (2,544) (2,559) (4,999) (4,349)
Borrowings under line-of-credit....................... 53,000 -- 99,000 4,000
Proceeds from equity offering, net of expense......... 42,590 -- 42,590 --
Proceeds from exercise of warrants.................... -- 265 -- 265
Proceeds from exercise of stock options............... 1,079 1,024 1,620 1,357
Other................................................. (89) (15) (89) (186)
------------ ----------- ----------- -------------
Net cash provided by (used in) financing activities... (24,405) (15,097) (46,809) (121,510)
------------ ----------- ----------- -------------
Effect of exchange rate changes on cash............... (192) -- (192) --
------------ ----------- ----------- -------------
Net increase (decrease) in cash and cash equivalents.. 5,473 (716) 5,868 (107,954)
Cash and cash equivalents at beginning of period...... 2,493 2,635 2,098 109,873
------------ ----------- ----------- -----------
Cash and cash equivalents at end of period............ $ 7,966 $ 1,919 $ 7,966 $ 1,919
============ =========== =========== =============
SEE THE ACCOMPANYING NOTES WHICH ARE AN INTEGRAL PART OF THESE
CONSOLIDATED FINANCIAL STATEMENTS.
F-41
KEY ENERGY SERVICES, INC.
UNAUDITED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
THREE MONTHS ENDED THREE MONTHS ENDED
DECEMBER 31, SEPTEMBER 30,
----------------------------- ----------------------------
2001 2000 2001 2000
------------- ------------ ------------- -----------
(IN THOUSANDS)
NET INCOME (LOSS) $ 19,459 $ 11,162 $ 48,635 $ 19,869
OTHER COMPREHENSIVE INCOME (LOSS):
Derivative transition adjustment (see Note 7)..... -- -- -- (778)
Oil and natural gas derivatives adjustment,
net of tax (see Note 7)........................ 180 (52) 357 (52)
Amortization of oil and natural gas derivative,
net of tax (see Note 7)........................ (154) 146 (188) 292
Foreign currency translation gain (loss), net of
tax Note 10)................................... (24,202) -- (24,224) 4
------------- ------------ ------------- -----------
COMPREHENSIVE INCOME (LOSS)......................... $ (4,717) $ 11,256 $ 24,580 $ 19,335
============= ============ ============= ===========
SEE THE ACCOMPANYING NOTES WHICH ARE AN INTEGRAL PART OF THESE
CONSOLIDATED FINANCIAL STATEMENTS.
F-42
KEY ENERGY SERVICES, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2001 AND 2000
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
BASIS OF PRESENTATION
The consolidated financial statements of Key Energy Services, Inc. (the
"Company" or "Key") and its wholly-owned subsidiaries as of December 31, 2001
and for the three and six month periods ended December 31, 2001 and 2000 are
unaudited. Certain information and footnote disclosures normally included in
financial statements prepared in accordance with generally accepted accounting
principles have been condensed or omitted in this Form 10-Q pursuant to the
rules and regulations of the Securities and Exchange Commission. However, in the
opinion of management, these interim financial statements include all the
necessary adjustments to fairly present the results of the interim periods
presented. These unaudited interim consolidated financial statements should be
read in conjunction with the audited financial statements included in the
Company's Annual Report on Form 10-K for the fiscal year ended June 30, 2001.
The results of operations for the three and six month periods ended December 31,
2001 are not necessarily indicative of the results of operations for the full
fiscal year ending June 30, 2002.
RECLASSIFICATIONS
Certain reclassifications have been made to the consolidated financial
statements for the three and six month periods ended December 31, 2000 to
conform to the presentation for the three and six month periods ended December
31, 2001. The reclassifications consist primarily of reclassifying oil and
natural gas production revenues and expenses. Oil and natural gas production
revenues and related expenses have been reclassified to other revenues and other
expenses because the Company does not believe this business segment is material
to the Company's consolidated financial statements.
2. EARNINGS PER SHARE
The Company accounts for earnings per share based upon Statement of
Financial Accounting Standards No. 128, "Earnings per Share" ("SFAS 128"). Under
SFAS 128, basic earnings per common share are determined by dividing net
earnings applicable to common stock by the weighted average number of common
shares actually outstanding during the period. Diluted earnings per common share
is based on the increased number of shares that would be outstanding assuming
exercise of dilutive stock options and warrants and conversion of dilutive
outstanding convertible securities using the "as if converted" method.
F-43
THREE MONTHS ENDED SIX MONTHS ENDED
DECEMBER 31, DECEMBER 31,
2001 2000 2001 2000
--------------------------- ----------------------------
(IN THOUSANDS, EXCEPT (IN THOUSANDS, EXCEPT
PER SHARE DATA) PER SHARE DATA)
BASIC EPS COMPUTATION:
NUMERATOR
Net income (loss) before extraordinary
gain (loss)............................... $ 17,368 $ 11,094 $ 46,364 $ 18,604
Extraordinary gain (loss), net of tax....... 2,091 68 2,271 1,265
------------ ----------- ----------- ------------
Net income (loss)........................... $ 19,459 $ 11,162 $ 48,635 $ 19,869
============ =========== =========== ============
DENOMINATOR
Weighted average common shares outstanding.. 103,115 97,534 102,421 97,207
------------ ----------- ----------- ------------
BASIC EPS:
Before extraordinary gain (loss)............ $ 0.17 $ 0.11 $ 0.45 $ 0.19
Extraordinary gain (loss), net of tax....... 0.02 - 0.02 0.01
------------ ----------- ----------- ------------
After extraordinary gain (loss)............. $ 0.19 $ 0.11 $ 0.47 $ 0.20
============ =========== =========== ============
DILUTED EPS COMPUTATION:
NUMERATOR
Net income (loss) before extraordinary
gain (loss)............................... $ 17,368 $ 11,094 $ 46,364 $ 18,604
Effect of dilutive convertible securities,
tax effected.............................. - 4 - 26
Extraordinary gain (loss), net of tax....... 2,091 68 2,271 1,265
------------ ----------- ----------- ------------
Net income (loss)........................... $ 19,459 $ 11,166 $ 48,635 $ 19,895
============ =========== =========== ============
DENOMINATOR
Weighted average common shares outstanding.. 103,115 97,534 102,421 97,207
Warrants.................................... 526 80 552 91
Stock options............................... 1,170 2,882 1,384 3,003
7% Convertible Debentures................... - - - 35
------------ ----------- ----------- ------------
104,811 100,496 104,357 100,336
============ =========== =========== ============
DILUTED EPS:
Before extraordinary gain (loss)............ $ 0.17 $ 0.11 $ 0.44 $ 0.19
Extraordinary gain (loss), net of tax....... 0.02 - 0.02 0.01
------------ ----------- ----------- ------------
After extraordinary gain (loss)............. $ 0.19 $ 0.11 $ 0.46 $ 0.20
============ =========== =========== ============
The diluted earnings per share calculation (i) for the three month period
ended December 31, 2001 excludes the effects of 3,588,000 stock options and (ii)
for the six month period ended December 31, 2000 excludes the effects of
1,463,000 stock options. Both calculations exclude the effects of the conversion
of the Company's 5% Convertible Subordinated Notes. The effects of such options
and convertible notes on earnings per share would be anti-dilutive.
The diluted earnings per share calculation for the three and six month
periods ended December 31, 2000 excludes the effects of 1,175,000 stock options
and the effects of the conversion of the Company's 5% Convertible Subordinated
Notes because the effects of such options and convertible notes on earnings per
share would be anti-dilutive.
F-44
3. STOCKHOLDERS' EQUITY
EQUITY OFFERING
On December 19, 2001, the Company closed an "at-the-market" public
offering of 5,400,000 shares of common stock, yielding net proceeds to the
Company of approximately $43.2 million or $8.00 per share (the "Equity
Offering"). Net proceeds from the Equity Offering of approximately $42.6 million
were used to temporarily reduce amounts outstanding under the Company's
revolving line of credit. The net proceeds of the Equity Offering were
ultimiately used in January, 2002 to redeem a portion of the Company's 14%
Senior Subordinated Notes fully utilizing the Company's equity "claw-back"
rights for up to 35% of the original $150 million in issue.
4. COMMITMENTS AND CONTINGENCIES
Various suits and claims arising in the ordinary course of business are
pending against the Company. Management does not believe that the disposition of
any of these items will result in a material adverse impact to the consolidated
financial position, results of operations or cash flows of the Company.
5. INDUSTRY SEGMENT INFORMATION
The Company's reportable business segments are well servicing and
contract drilling. Oil and natural gas production operations were previously
separately presented as a reportable business segment and are now included in
"corporate/other".
WELL SERVICING: The Company's operations provide well servicing (ongoing
maintenance of existing oil and natural gas wells), completions, workover (major
repairs or modifications necessary to optimize the level of production from
existing oil and natural gas wells) and production services (fluid hauling and
fluid storage tank rental).
CONTRACT DRILLING: The Company provides contract drilling services for
major and independent oil companies onshore the continental United States,
Argentina and Ontario, Canada.
WELL CONTRACT CORPORATE
SERVICING DRILLING /OTHER TOTAL
------------ -------------- ------------ -------------
(IN THOUSANDS)
THREE MONTHS ENDED DECEMBER 31, 2001
Operating revenues.................................... $186,338 $25,654 $ 1,345 $ 213,337
Operating profit ..................................... 69,246 8,314 195 77,755
Depreciation, depletion and amortization.............. 16,470 2,204 1,050 19,724
Interest expense...................................... 405 - 10,692 11,097
Net income (loss) before extraordinary gain (loss)*... 26,546 2,555 (11,733) 17,368
Identifiable assets................................... 673,162 94,693 255,281 1,023,136
Capital expenditures ................................. 16,418 2,923 2,412 21,753
THREE MONTHS ENDED DECEMBER 31, 2000
Operating revenues.................................... $178,650 $24,178 $ 1,083 203,911
Operating profit...................................... 60,527 5,818 418 66,763
Depreciation, depletion and amortization.............. 15,261 1,890 995 18,146
Interest expense...................................... 446 - 14,135 14,581
Net income (loss) before extraordinary gain (loss)*... 24,720 1,208 (14,834) 11,094
Identifiable assets................................... 639,979 91,066 233,019 964,064
Capital expenditures (excluding acquisitions)......... 9,093 4,041 3,942 17,076
* Net income (loss) includes general and administrative expenses allocated on a
percentage of revenue basis.
Operating revenues for the Company's foreign operations for the three
months ended December 31, 2001 and 2000 were $11.9 million and $13.3 million,
respectively. Operating profits for the Company's foreign operations for the
three months ended December 31, 2001 and 2000 were $2.1 million and $3.2
million, respectively. The
F-45
Company had $56.1 million and $75.3 million of identifiable assets as of
December 31, 2001 and 2000, respectively, related to foreign operations.
WELL CONTRACT CORPORATE
SERVICING DRILLING /OTHER TOTAL
------------ -------------- ---------------------------
(IN THOUSANDS)
SIX MONTHS ENDED DECEMBER 31, 2001
Operating revenues.................................... $398,839 $59,290 $ 4,445 $ 462,574
Operating profit ..................................... 148,967 20,762 2,110 171,839
Depreciation, depletion and amortization.............. 31,027 4,584 1,982 37,593
Interest expense...................................... 953 - 22,093 23,046
Net income (loss) before extraordinary gain (loss)*... 61,091 7,863 (22,590) 46,364
Identifiable assets................................... 673,162 94,693 255,281 1,023,136
Capital expenditures (excluding acquisitions)......... 28,312 11,077 5,539 44,928
SIX MONTHS ENDED DECEMBER 31, 2000
Operating revenues.................................... 345,215 $46,323 $ 4,052 $ 395,590
Operating profit...................................... 115,406 10,505 2,064 127,975
Depreciation, depletion and amortization.............. 30,950 3,696 1,811 36,457
Interest expense...................................... 1,103 - 29,589 30,692
Net income (loss) before extraordinary gain (loss)*... 46,499 1,861 (29,756) 18,604
Identifiable assets................................... 639,979 91,066 233,019 964,064
Capital expenditures (excluding acquisitions)......... 17,095 7,174 6,092 30,361
* Net income (loss) includes general and administrative expenses allocated on a
percentage of revenue basis.
Operating revenues for the Company's foreign operations for the six
months ended December 31, 2001 and 2000 were $23.9 million and $26.5 million,
respectively. Operating profits for the Company's foreign operations for the six
months ended December 31, 2001 and 2000 were $4.7 million and $6.2 million,
respectively. The Company had $56.1 million and $75.3 million of identifiable
assets as of December 31, 2001 and 2000, respectively, related to foreign
operations.
6. VOLUMETRIC PRODUCTION PAYMENT
In March 2000, Key sold a portion of its future oil and natural gas
production from Odessa Exploration Incorporated, its wholly owned subsidiary,
for gross proceeds of $20 million pursuant to an agreement under which the
purchaser is entitled to receive a portion of the production from certain oil
and natural gas properties over the six year period ending February 28, 2006 in
amounts starting at 10,000 barrels of oil per month and declining to 3,500
barrels of oil per month and starting at 122,100 Mmbtu of natural gas per month
and declining to 58,800 Mmbtu of natural gas per month. The total volume of the
forward sale is approximately 486,000 barrels of oil and 6,135,000 Mmbtu of
natural gas.
7. DERIVATIVE INSTRUMENTS
The Company utilizes derivative financial instruments to manage
well-defined commodity price risks. The Company is exposed to credit losses in
the event of nonperformance by the counter-parties to its commodity hedges. The
Company only deals with reputable financial institutions as counter-parties and
anticipates that such counter-parties will be able to fully satisfy their
obligations under the contracts. The Company does not obtain collateral or other
security to support financial instruments subject to credit risk but monitors
the credit standing of the counter-parties.
The Company periodically hedges a portion of its oil and natural gas
production through collar and option agreements. The purpose of the hedges is to
provide a measure of stability in the volatile environment of oil and natural
gas prices and to manage exposure to commodity price risk under existing sales
commitments. The Company's risk management objective is to lock in a range of
pricing for expected production volumes. This allows the Company to forecast
future earnings within a predictable range. The Company meets this objective by
entering into collar and option arrangements which allow for acceptable cap and
floor prices.
F-46
The Company does not enter into derivative instruments for any purpose
other than for economic hedging. The Company does not speculate using derivative
instruments. The Company has identified the following derivative instruments:
FREESTANDING DERIVATIVES: On March 30, 2000 the Company entered into a
collar arrangement for a 22-month period whereby the Company will pay if the
specified price is above the cap index and the counter-party will pay if the
price should fall below the floor index. The hedge defines a range of cash flows
bounded by the cap and floor prices. On May 25, 2001 the Company entered into an
option arrangement for a 12-month period beginning March 2002 whereby the
counter-party will pay should the price fall below the floor index. The Company
desires a measure of stability to ensure that cash flows do not fall below a
certain level.
Prior to the adoption of Statement of Financial Accounting Standards No.
133, Accounting for Derivative Instruments and Hedging Activities, ("SFAS No.
133"), as amended by SFAS No. 137 and 138, these collars were accounted for as
cash flow type hedges. Accordingly, the July 1, 2000 transition adjustment
resulted in recording a $778,000 liability for the fair value of the collars to
accumulated other comprehensive income. Approximately $97,000 of the transition
adjustment was recognized in earnings during the three months ended December 31,
2001. The unamortized balance of the transition adjustment, approximately
$64,000, will be recognized in earnings over the next three months. As of July
1, 2001, the Company has documented the May 25, 2001 options as cash flow
hedges. During the quarter ended December 31, 2001, the Company recorded a net
decrease in net derivative assets of approximately $105,000, which included an
earnings charge of approximately $392,000 from ineffectiveness.
EMBEDDED DERIVATIVES. The Company is party to a volumetric production
payment of which certain terms meet the definition of an embedded derivative
under SFAS No. 133. Effective July 1, 2000, the Company has determined and
documented that the production payment is excluded from the scope of SFAS No.
133 under the normal purchases/sales exclusion as set forth in SFAS 138.
8. CONDENSED CONSOLIDATING FINANCIAL INFORMATION
The Company's senior notes are guaranteed by all of the Company's
subsidiaries (except for the foreign subsidiaries), all of which are
wholly-owned. The guarantees are joint and several, full, complete and
unconditional. There are currently no restrictions on the ability of the
subsidiary guarantors to transfer funds to the parent company.
The accompanying condensed consolidating financial information has been
prepared and presented pursuant to SEC Regulation S-X Rule 3-10, Financial
Statements of Guarantors and Issuers of Guaranteed Securities Registered or
Being Registered. The information is not intended to present the financial
position, results of operations and cash flows of the individual companies or
groups of companies in accordance with generally accepted accounting principles.
CONDENSED CONSOLIDATING BALANCE SHEETS
DECEMBER 31, 2001
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Assets:
Current assets................. $ 13,689 $ 145,963 $ 20,422 $ -- $ 180,074
Net property and equipment..... 25,716 739,181 35,605 -- 800,502
Goodwill, net ................. 3,502 188,389 1,326 -- 193,217
Deferred costs, net............ 14,257 -- -- -- 14,257
Intercompany receivables....... 578,459 -- -- (578,459) --
Other assets................... 21,470 6,772 61 -- 28,303
------------ ---------------- -------------------- ----------------- ---------------
Total assets....................... $ 657,093 $ 1,080,305 $ 57,414 $ (578,459) $ 1,216,353
============ ================ ==================== ================= ===============
Liabilities and equity:
F-47
Current liabilities............ $ 31,603 52,910 $ 7,592 $ -- $ 92,105
Long-term debt................. 379,269 -- -- -- 379,269
Capital lease obligations...... 352 15,875 -- -- 16,227
Intercompany payables.......... -- 538,818 39,641 (578,459) --
Deferred tax liability......... 151,305 -- -- -- 151,305
Other long-term liabilities.... 9,716 11,641 -- -- 21,357
Stockholders' equity........... 84,848 461,061 10,181 -- 556,090
------------ ---------------- -------------------- ----------------- ---------------
Total liabilities and
stockholders' equity............ $ 657,093 $ 1,080,305 $ 57,414 $ (578,459) $ 1,216,353
============ ================ ==================== ================= ===============
JUNE 30, 2001
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Assets:
Current assets................. $ 10,680 165,653 29,817 - 206,150
Net property and equipment..... 21,418 717,989 54,309 - 793,716
Goodwill, net ................. 3,374 184,379 2,122 - 189,875
Deferred costs, net............ 17,624 - - 17,624
Intercompany receivables....... 664,592 - - (664,592) -
Other assets................... 15,303 5,616 - - 20,919
------------ ---------------- -------------------- ----------------- ---------------
Total assets....................... $ 732,991 $ 1,073,637 $ 86,248 $ (664,592) $ 1,228,284
============ ================ ==================== ================= ===============
Liabilities and equity:
Current liabilities............ 35,671 64,679 15,203 $ $ 115,553
Long-term debt................. 470,578 15,331 (38) 470,578
Capital lease obligations......
Intercompany payables.......... - 608,764 55,828 (664,592) -
Deferred tax liability......... 127,400 - - - 127,400
Other long-term liabilities.... 8,240 14,252 - - 22,492
Stockholders' equity........... 91,012 370,611 15,255 - 476,878
============ ================ ==================== ================= ===============
Total liabilities and
stockholders' equity............. $ 732,991 1,073,637 $86,248 $ (664,592) $ 1,228,284
============ ================ ==================== ================= ===============
F-48
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
THREE MONTHS ENDED DECEMBER 31, 2001
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Revenues........................... $ 329 $ 201,119 $ 11,889 $ -- $ 213,337
Costs and expenses:
Direct expenses................ -- 125,799 9,783 -- 135,582
Depreciation, depletion
and amortization............. 429 18,283 1,012 -- 19,724
General and administrative..... 5,137 10,854 764 -- 16,755
Interest....................... 10,692 136 269 -- 11,097
Argentine foreign currency
transaction loss............. -- -- 1,844 -- 1,844
Other expenses................. -- 64 -- -- 64
------------ ---------------- -------------------- ----------------- ---------------
Total costs and expenses........... 16,258 155,136 13,672 -- 185,066
============ ================ ==================== ================= ===============
Income (loss) before
income taxes................... (15,929) 45,983 (1,783) -- 28,271
Income tax (expense) benefit....... 6,145 (17,736) 688 -- (10,903)
------------ ---------------- -------------------- ----------------- ---------------
Income (loss) before
extraordinary items............ (9,784) 28,247 (1,095) -- 17,368
Extraordinary items, net of tax.... 2,091 -- -- -- 2,091
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss).................. $ (7,693) $ 28,247 $ (1,095) $ -- $ 19,459
============ ================ ==================== ================= ===============
THREE MONTHS ENDED DECEMBER 31, 2000
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Revenues........................... $ 195 $ 190,404 $ 13,312 $ -- $ 203,911
Costs and expenses:
Direct expenses................ -- 127,013 10,135 -- 137,148
Depreciation, depletion
and amortization............. 474 16,653 1,019 -- 18,146
General and administrative..... 3,230 11,152 882 -- 15,264
Interest....................... 14,135 389 57 -- 14,581
Other expenses................. 311 398 -- -- 709
------------ ---------------- -------------------- ----------------- ---------------
Total costs and expenses........... 18,150 155,605 12,093 -- 185,848
============ ================ ==================== ================= ===============
Income (loss) before
income taxes................... (17,955) 34,799 1,219 -- 18,063
Income tax (expense) benefit....... 6,927 (13,426) (470) -- (6,969)
------------ ---------------- -------------------- ----------------- ---------------
Income (loss) before
extraordinary items............ (11,028) 21,373 749 -- 11,094
Extraordinary items, net of tax.... 68 -- -- -- 68
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss).................. $ (10,960) $ 21,373 $ 749 $ -- $ 11,162
============ ================ ==================== ================= ===============
F-49
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
SIX MONTHS ENDED DECEMBER 31, 2001
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Revenues........................... $ 822 $ 437,760 $ 23,992 $ -- $ 462,574
Costs and expenses:
Direct expenses................ -- 271,449 19,286 -- 290,735
Depreciation, depletion
and amortization............. 740 34,791 2,062 -- 37,593
General and administrative..... 10,465 22,606 1,568 -- 34,639
Interest....................... 22,093 341 612 -- 23,046
Argentine foreign currency
transaction loss............. -- -- 1,844 -- 1,844
Other expenses................. -- 308 -- -- 308
------------ ---------------- -------------------- ----------------- ---------------
Total costs and expenses........... 33,298 329,495 25,372 -- 388,165
============ ================ ==================== ================= ===============
Income (loss) before
income taxes.................... (32,476) 108,265 (1,380) -- 74,409
Income tax (expense) benefit....... 12,292 (40,784) 537 -- (28,045)
------------ ---------------- ------------------ ----------------- -----------------
Income (loss) before
extraordinary items............ (20,184) 67,391 (843) -- 46,364
Extraordinary items, net of tax.... 2,271 -- -- -- 2,271
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss).................. $ (17,913) $ 67,391 $ (843) $ -- $ 48,635
============ ================ ==================== ================= ===============
SIX MONTHS ENDED DECEMBER 31, 2000
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Revenues........................... $ 1,574 $ 367,477 $ 26,539 $ -- $ 395,590
Costs and expenses:
Direct expenses................ -- 247,299 20,316 -- 267,615
Depreciation, depletion
and amortization............ 778 33,695 1,984 -- 36,457
General and administrative..... 6,985 20,932 1,714 -- 29,631
Interest....................... 29,589 793 310 -- 30,692
Other expenses................. 311 592 -- -- 903
------------ ---------------- -------------------- ----------------- ---------------
Total costs and expenses........... 37,663 303,311 24,324 -- 365,298
============ ================ ==================== ================= ===============
Income (loss) before
income taxes................... (36,089) 64,166 2,215 -- 30,292
Income tax (expense) benefit....... 13,925 (24,795) (854) -- (11,688)
------------ ---------------- -------------------- ----------------- ---------------
Income (loss) before
extraordinary items............ (22,164) 39,407 1,361 -- 18,604
Extraordinary items, net of tax.... 1,265 -- -- -- 1,265
------------ ---------------- -------------------- ----------------- ---------------
Net income (loss).................. $ (20,899) $ 39,407 $ 1,361 $ -- $ 19,869
============ ================ ==================== ================= ===============
F-50
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
THREE MONTHS ENDED DECEMBER 31, 2001
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Net cash provided by (used in)
operating activities........... $ 34,549 $ 21,084 $ 1,953 $ -- $ 57,586
Net cash provided by (used in)
investing activities........... (7,431) (18,862) (1,223) -- (27,516)
Net cash provided by (used in)
financing activities........... (21,963) (2,442) -- -- (24,405)
Effect of exchange rate changes
on cash........................ -- -- (192) -- (192)
------------ ---------------- -------------------- ----------------- ---------------
Net increase (decrease) in
cash........................... 5,155 (220) 538 -- 5,473
Cash at beginning of period........ (2,648) 3,996 1,145 -- 2,493
------------ ---------------- -------------------- ----------------- ---------------
Cash at end of period.............. $ 2,507 $ 3,776 $ 1,683 $ -- $ 7,966
============ ================ ==================== ================= ===============
THREE MONTHS ENDED DECEMBER 31, 2000
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Net cash provided by (used in)
operating activities........... $ 20,880 $ 10,175 $ 2,052 $ -- $ 33,107
Net cash provided by (used in)
investing activities........... (5,933) (10,658) (2,135) -- (18,726)
Net cash provided by (used in)
financing activities........... (12,544) (2,540) (13) -- (15,097)
------------ ---------------- -------------------- ----------------- ---------------
Net increase (decrease) in
cash........................... 2,403 (3,023) (96) -- (716)
Cash at beginning of period........ 5,074 (3,364) 925 -- 2,635
------------ ---------------- -------------------- ----------------- ---------------
Cash at end of period.............. $ 7,477 $ (6,387) 829 -- $ 1,919
============ ================ ==================== ================= ===============
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
SIX MONTHS ENDED DECEMBER 31, 2001
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Net cash provided by (used in)
operating activities........... $ 55,161 $ 46,885 $ 771 $ -- $ 102,817
Net cash provided by (used in)
investing activities........... (12,381) (36,228) (1,339) -- (49,948)
Net cash provided by (used in)
financing activities........... (41,920) (4,876) (13) -- (46,809)
Effect of exchange rate
changes on cash................ -- -- (192) -- (192)
------------ ---------------- -------------------- ----------------- ---------------
Net increase (decrease) in
cash........................... 860 5,781 (773) -- 5,868
Cash at beginning of period........ 1,647 (2,005) 2,456 -- 2,098
------------ ---------------- -------------------- ----------------- ---------------
Cash at end of period.............. $ 2,507 $ 3,776 $ 1,683 $ -- $ 7,966
============ ================ ==================== ================= ===============
F-51
SIX MONTHS ENDED DECEMBER 31, 2000
------------------------------------------------------------------------------------------------
PARENT GUARANTOR NON-GUARANTOR ELIMINATIONS CONSOLIDATED
COMPANY SUBSIDIARIES SUBSIDIARIES
------------ ---------------- -------------------- ----------------- ---------------
(IN THOUSANDS)
Net cash provided by (used in)
operating activities........... $ 21,389 $ 19,924 $ 4,152 $ -- $ 45,465
Net cash provided by (used in)
investing activities........... (7,906) (20,754) (3,249) -- (31,909)
Net cash provided by (used in)
financing activities........... (117,172) (4,311) (27) -- (121,510)
------------ ---------------- -------------------- ----------------- ---------------
--
Net increase (decrease) in
cash........................... (103,689) (5,141) 876 (107,954)
Cash at beginning of period........ 111,166 (1,246) (47) -- 109,873
------------ ---------------- -------------------- ----------------- ---------------
Cash at end of period.............. $ 7,477 $ (6,387) $ 829 $ -- $ 1,919
============ ================ ==================== ================= ===============
9. GOODWILL AND OTHER INTANGIBLE ASSETS - ADOPTION OF SFAS 142
The Company has adopted Statement of Financial Accounting Standards No.
142, Goodwill and Other Intangible Assets ("SFAS 142") on July 1, 2001. SFAS 142
eliminates the amortization for goodwill and other intangible assets with
indefinite lives. Intangible assets with lives restricted by contractual, legal,
or other means will continue to be amortized over their useful lives. Goodwill
and other intangible assets not subject to amortization are tested for
impairment annually or more frequently if events or changes in circumstances
indicate that the asset might be impaired. SFAS 142 requires a two-step process
for testing impairment. First, the fair value of each reporting unit is compared
to its carrying value to determine whether an indication of impairment exists.
If impairment is indicated, then the fair value of the reporting unit's goodwill
is determined by allocating the unit's fair value to its assets and liabilities
(including any unrecognized intangible assets) as if the reporting unit had been
acquired in a business combination. The amount of impairment for goodwill and
other intangible assets is measured as the excess of its carrying value over its
fair value.
The Company completed its assessment of goodwill impairment during the
three months ended December 31, 2001, as allowed by SFAS 142. The assessment did
not result in an indication of goodwill impairment.
Intangible assets subject to amortization under SFAS 142 consist of
noncompete agreements. Amortization expense is calculated using the
straight-line method over the period of the agreement, ranging from 3 to 5
years.
The gross carrying amount of noncompete agreements subject to
amortization totaled approximately $8,863,000 and $8,099,000 at December 31,
2001 and June 30, 2001, respectively. Accumulated amortization related to these
intangible assets totaled approximately $4,986,000 and $4,953,000 at December
31, 2001 and June 30, 2001, respectively. Amortization expense for the three
months ended December 31, 2001 and 2000 was approximately $370,000 and $244,000,
respectively. Amortization expense for the six months ended December 31, 2001
and 2000 was approximately $770,000 and $729,000. Amortization expense for the
next five fiscal years is estimated to be $1,783,000, $1,054,000, $400,000,
$373,000 and $267,000.
The Company has identified its reporting segments to be well servicing
and contract drilling. Goodwill allocated to such reporting segments at December
31, 2001 is $178,952,000 and $14,265,000, respectively. The change in the
carrying amount of goodwill for the three and six months ended December 31, 2001
of $2,238,000 and $3,144,000, respectively, relates principally to goodwill from
well servicing assets acquired during the period and the translation adjustment
for Argentina at December 31, 2001.
F-52
The effect of the adoption of SFAS 142 on net income and earnings per share is
as follows:
THREE MONTHS ENDED SIX MONTHS ENDED
DECEMBER 31, DECEMBER 31,
2001 2000 2001 2000
------------ -- ----------- ----------- -- ------------
(IN THOUSANDS, EXCEPT (IN THOUSANDS, EXCEPT
PER SHARE DATA) PER SHARE DATA)
Reported net income (loss) before extraordinary
gain (loss)...................................... $ 17,368 $11,094 $46,364 $ 18,604
Add back: goodwill amortization..................... - 2,204 - 4,655
------------ ----------- ----------- ------------
Adjusted net income (loss) before extraordinary
gain (loss)...................................... 17,368 13,298 46,364 23,259
Extraordinary gain (loss), net of tax................ 2,091 68 2,271 1,265
------------ ----------- ----------- ------------
Adjusted net income (loss)........................... $ 19,459 $13,366 $48,635 $24,524
============ =========== =========== ============
BASIC EARNINGS (LOSS) PER SHARE:
Reported net income (loss) before extraordinary
gain (loss)...................................... $ 0.17 $ 0.11 $ 0.45 $ 0.19
Add back: goodwill amortization..................... - 0.02 - 0.05
------------ ----------- ----------- ------------
Adjusted net income (loss) before extraordinary
gain (loss)...................................... $ 0.17 $ 0.13 $ 0.45 $ 0.24
Extraordinary gain (loss), net of tax................ 0.02 - 0.02 0.01
------------ ----------- ----------- ------------
Adjusted net income (loss)........................... $ 0.19 $ 0.13 $ 0.47 $ 0.25
============ =========== =========== ============
DILUTED EARNINGS (LOSS) PER SHARE:
Reported net income (loss) before extraordinary
gain (loss)...................................... $ 0.17 $ 0.11 $ 0.45 $ 0.19
Add back: goodwill amortization..................... - 0.02 - 0.05
------------ ----------- ----------- ------------
Adjusted net income (loss) before extraordinary
gain (loss)...................................... $ 0.17 $ 0.13 $ 0.45 $ 0.24
Extraordinary gain (loss), net of tax................ 0.02 - 0.02 0.01
------------ ----------- ----------- ------------
Adjusted net income (loss)........................... $ 0.19 $ 0.13 $ 0.47 $ 0.25
============ =========== =========== ============
F-53
10. ARGENTINA FOREIGN CURRENCY TRANSACTION LOSS
The local currency is the functional currency for all of the Company's
foreign operations (Argentina and Canada). The cumulative translation gains and
losses, resulting from translating each foreign subsidiary's financial
statements from the functional currency to U.S. dollars are included in other
comprehensive income and accumulated in stockholders' equity until a partial or
complete sale or liquidation of the Company's net investment in the foreign
entity.
Since 1991, the Argentine peso has been tied to the U.S. dollar at a
conversion ratio of 1:1. However, in December 2001, the Government of Argentina
announced an exchange holiday and, as a result, Argentine pesos could not be
exchanged into other currencies at December 31, 2001. On January 5 and 6, 2002,
the Argentine Congress and Senate gave the President of Argentina emergency
powers and the ability to suspend the law that created the fixed conversion
ratio of 1:1. The Government subsequently announced the creation of a dual
currency system in which certain qualifying transactions will be settled at an
expected fixed conversion ratio of 1.4:1 while all other transactions will be
settled using a free floating market conversion ratio. Under existing guidance,
dividends would not receive the fixed conversion ratio. On January 11, 2002, the
exchange holiday was lifted, making it possible again to buy and sell Argentine
pesos. Banks were legally allowed to exchange currencies, but transactions were
limited and generally took place at exchange houses. These transactions were
conducted primarily by individuals as opposed to commercial transactions, and
occurred at free conversion ratios ranging between 1.6:1 and 1.7:1.
Due to the events described above, which resulted in the temporary lack
of exchangeability of the two currencies at December 31, 2001, the Company has
translated the assets and liabilities of its Argentine subsidiary at December
31, 2001 using a conversion ratio of 1.6:1, which management believes is
indicative of the free floating conversion ratio when the currency market
re-opened on January 11, 2002. As a result, a foreign currency translation loss
of approximately $24.2 million is included in other comprehensive income, a
component of stockholders' equity, in the accompanying December 31, 2001
consolidated balance sheet. Since the 1:1 conversion ratio was in existence
prior to December 2001, income statement and cash flows information has been
translated using the historical 1:1 conversion ratio.
Additionally, the Argentine government has indicated that as part of its
monetary policy changes, it will re-denominate certain consumer loans from U.S.
dollar-denominated to Argentine peso-denominated. As a result, the Company
recorded a foreign currency transaction loss of $1.8 million in the three months
ended December 31, 2001 related to accounts receivable subject to certain U.S.
dollar-denominated contracts held by its Argentine subsidiary which are subject
to re-denomination. These receivables are subject to additional negotiation with
the Company's customers which may result in recovery of a portion of this loss.
F-54