FINANCIAL REVIEW
MANAGEMENT'S DISCUSSION AND ANALYSIS
GENERAL
The Company experiences stronger demand for its refined products, particularly
gasoline and asphalt, during the summer months due to seasonal increases in
highway traffic and road construction work. As a result, the Company's
operating results for the first and fourth calendar quarters are generally lower
than those for the second and third quarters. Demand for diesel is more stable,
but reduced road construction and agricultural work during the winter months
does have an impact on demand for diesel. Consistent with the seasonality of its
business, the Company invests in working capital during the first half of the
year and recovers working capital investment in the second half of the year.
RESULT OF OPERATIONS
1998 Compared with 1997. The Company had net income for the year ended
December 31, 1998 of $15.8 million, or $.55 per diluted share, compared to net
income of $19.1 million, or $.69 per diluted share for 1997. The 1998 results
include a $3.0 million extraordinary loss on early retirement of debt. The 1997
results included a $23.3 million gain on the sale of the Canadian oil and gas
operations which closed on June 16, 1997, a $9.9 million reduction to income in
recognition of the cumulative translation adjustment, a $3.9 million
extraordinary loss on retirement of debt and $1.7 million of income from the
discontinued Canadian oil and gas operations. Income from continuing operations
for the year ended December 31, 1998 was $18.8 million compared to $7.8 million
for 1997. The 1997 and prior operating results for the Company's oil and gas
exploration and production segment have been presented as discontinued
operations in the accompanying financial statements. Frontier's primary
continuing operation is its refining operation in the Rocky Mountain region of
the United States.
Operating income increased $4.0 million in 1998 as compared to 1997 due to an
increase in the refined product spread (revenues less material costs) of $9.5
million offset by a decrease in other income of $621,000 and increases in
refining operating expenses of $3.1 million, selling and general expenses of
$175,000 and depreciation of $1.5 million.
Refined product revenues and refining operating costs are impacted by changes
in the price of crude oil. The price of crude oil was significantly lower in
1998 than in 1997. The refined product spread was $6.09 per bbl compared to
$5.78 per bbl in 1997. The 1998 refined product spread increased due to an
improved light/heavy crude oil spread and better by-product margins from lower
crude oil prices. Light product margins were approximately 14% lower than in
1997 which reduced the refined product spread. Both periods' refined product
spreads were negatively impacted by declines in crude oil prices totaling
approximately $3.7 million in the first quarter and $1.1 million in the fourth
quarter of 1998 and approximately $4.0 million in the first quarter of 1997.
Inventories are recorded at the lower of cost on a first in, first out (FIFO)
basis or market. Refined product revenues decreased $76.4 million or 20%. The
decrease in refined product revenues resulted from a $7.31 per bbl decrease in
average gasoline sales prices and
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a $7.32 per bbl decrease in average diesel sales prices. Refined product sales
volumes increased 5% in 1998 over 1997 levels. Yields of gasoline decreased by
8% while yields of diesel increased 2% in 1998 compared to 1997. The decrease in
gasoline yields was due to the major turnaround, which commenced April 19, 1998
and was completed May 15, 1998, on the fluid catalytic cracking unit and
alkylation and related units.
Other income, which consists primarily of processing fees, decreased $621,000
to $1.7 million in 1998 as compared to 1997. Other income for 1997 included a
gain on foreign currency swaps of $522,000 related to the Canadian sale proceeds
while other income for 1998 includes sulfur credit sales of $360,000.
Refining operating costs decreased $82.8 million or 25% in the year ended
December 31, 1998 from 1997 levels due to a decrease in material costs offset by
an increase in operating expenses. Material costs per bbl decreased 33% or
$6.48 per bbl in 1998 due to lower oil prices, increased percentage use of heavy
crude oil, an increase in the light/heavy spread and a 2% decrease in refinery
charge rates. During 1998, the Refinery heavy crude oil utilization rate
expressed as a percentage of total crude oil increased to 94% from 91% in 1997.
The light/heavy spread increased 17% to average $4.15 per bbl in 1998. Refinery
operating expenses increased $3.1 million in 1998 as compared to 1997, and
refining operating expense per bbl increased $.04 per bbl to $3.34 per bbl in
1998. The increase in refining operating expenses during 1998 was due to higher
natural gas usage during the turnaround, increased chemical usage due to unit
operating problems which were corrected during the turnaround and increased
transportation costs for asphalt and other product sales. Although focus to
reduce refining operating expenses will continue, maintenance problems may arise
in the future, resulting in downtime of certain processing units and reduced
yields which may increase operating expenses and negatively impact
profitability. A turnaround is scheduled in the spring of 1999 on the crude
unit. This unit is scheduled to be down for 14 days, which will decrease
average yields during that time. Other turnaround work is scheduled for several
Refinery units during 1999, but this work should not materially impact yields.
Selling and general expenses increased $175,000 or 2% for the year ended
December 31, 1998 reflecting increases in salaries and benefits.
Depreciation increased $1.5 million or 17% for the year ended December 31,
1998 as compared to 1997, attributable to increases in capital investment and
the write-off of certain equipment replaced in connection with the turnaround
work.
The interest expense decrease of $7.2 million or 52% in 1998 was attributable
to utilizing Canadian sale proceeds to retire debt during the third and fourth
quarters of 1997. Average debt decreased from $138 million in 1997 to $79
million in 1998.
During 1998, the price of light crude oil declined by approximately $6.00 per
bbl to $12.05 per bbl at December 31, 1998. The price of heavy crude oil
likewise declined. The low price of crude oil has caused the production of some
heavy crude oil in both Wyoming and Canada to become uneconomical. The reduced
supply of heavy crude oil and the high demand for heavy crude oil due to
attractive asphalt margins are major factors contributing to the current decline
in the light/heavy spread. During the third and fourth quarters of 1998, the
Company experienced a shortfall in contracted heavy crude oil deliveries from
Wyoming of approximately 5,100 bpd which required the Company to buy additional
heavy Canadian crude oil at spot prices. The price of heavy crude oil purchased
at spot prices was substantially higher than contracted Wyoming and Canadian
crude oil resulting in the decline of the light/heavy spread from $4.81 per bbl
in the second quarter of 1998 to $3.66 per bbl in the third quarter of 1998, and
to $3.40 per bbl in the fourth quarter of 1998.
The Company is dependent upon regional and Canadian crude oil for its
refinery. Should low crude oil prices continue into 1999, the Company expects
the supply of heavy crude oil to continue to decline which should cause the
price of such heavy crude oil to increase. Consequently, the light/heavy spread
will decline. The Company plans to increase its use of lighter crude oil,
should prices stay at current levels, to offset declining heavy crude oil
supply. Since the Company is dependent upon regional and Canadian crude oil, it
is possible at current prices the Company may not be able to obtain
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the quantity of crude oil it desires which will result in reduce refinery crude
oil charge rates and negatively impact profitability. Based on contracts for
1999 heavy crude oil averaging approximately 14,000 bpd, the light/heavy spread
will average $1.50 to $2.00 per bbl less than 1998. Because of the higher cost
of heavy crude oil, fewer bbls have been contracted for at a fixed price above
postings than in prior years and the length of the 1999 contracts shortened to
mainly average three to six months. Consequently, any sustained improvement in
crude oil prices may enable the Company to benefit from an improvement in the
light/heavy spread.
1997 Compared with 1996. The Company had net income for the year ended
December 31, 1997 of $19.1 million or $.69 per share, compared to a loss of $6.9
million or ($.25) per share for 1996. The 1997 results include a $23.3 million
gain resulting from the Canadian disposition which closed on June 16, 1997, a
$9.9 million reduction to income in recognition of the cumulative translation
adjustment and a $3.9 million extraordinary loss on early retirement of debt.
Operating income increased by $16.1 million in the year ended December 31,
1997 as compared to 1996 due to an increase in the refined product spread
(revenues less materials cost) of $19.5 million and an increase in other income
of $1.1 million, offset by an increase in refining operating expenses of $2.6
million and selling and general costs of $1.8 million.
Refined product revenues and refining operating costs are impacted by changes
in the price of crude oil. The price of crude oil was lower in 1997 than in
1996. The refined product spread for 1997 was $5.78 per bbl compared to $4.48
per bbl for 1996. The refined product spread increased due to better light
product margins, primarily gasoline, and an improved light/heavy spread despite
the first quarter 1997 inventory losses of approximately $4.0 million from a
decline in crude oil prices of more than $6.00 per bbl. Inventories are
recorded at the lower of cost on a FIFO basis or market. Refined product
revenues decreased $8.0 million or 2% in 1997 as compared to 1996. The decrease
in refined product revenues resulted primarily from $1.67 per bbl decrease in
average diesel sales prices offset by a $.05 per bbl increase in average
gasoline sales prices. Refined product sales volumes were nearly the same for
the 1997 and 1996 periods.
Other income, which consists primarily of processing fees, increased $1.1
million to $2.3 million for the year ended December 31, 1997 as compared to 1996
mostly due to gains on foreign currency swaps of $522,000 related to the
Canadian sales proceeds and higher processing fees.
Refining operating costs decreased $25.0 million or 7% in the year ended
December 31, 1997 from 1996 due to a $27.6 million decrease in material costs
partially offset by an increase in refining operating expenses of $2.6 million.
Material costs per bbl decreased 9%, or $2.01 per bbl in 1997 due to lower oil
prices, lower crude oil charges, increased use of heavy crude oil and an
increase in the light/heavy spread. The crude oil charge rate, (or the volume
of crude oil processed by the crude unit), declined by 870 bpd in 1997 due to
turnaround work conducted on the crude unit in the fourth quarter of 1997.
During 1997, Frontier increased its use of heavy crude oil by 1% and the heavy
crude oil utilization rate expressed as a percent of total crude oil increased
to 91% in 1997 from 88% in 1996. In addition the light/heavy spread increased
38%, to average $3.54 per bbl for the year ended December 31, 1997 because the
Company contracted approximately 30,000 bpd of Wyoming and Canadian heavy crude
oil for much of 1997 at a light/heavy spread substantially better than it
obtained for the same period in 1996. For 1998 the Company contracted an
average of 29,000 bpd of Wyoming and Canadian heavy crude at a light/heavy
spread ranging from $4.80 to $5.25 per bbl. Refining operating expenses per bbl
increased by $.15, to $3.30 per bbl due to higher maintenance and turnaround
costs and lease equipment costs offset by decreased natural gas and utility
costs compared to operating expenses for the prior year, which were reduced by a
$1.3 million settlement of repair costs related to a 1995 pipeline gas
explosion.
Selling and general expenses increased $1.8 million or 28% for the year ended
December 31, 1997 reflecting increases in salaries and benefits. Included in
1996 is $.2 million of salary and salary-related expenses of certain employees
who were not retained after March 31, 1996, in connection with the
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U.S. disposition in late 1995 and a corporate reorganization to reduce the
number of corporate employees and to transfer some job functions to other
locations in early 1996.
Depreciation increased $152,000 or 2% for the year ended December 31, 1997 as
compared to 1996. Such increase was attributable to ongoing capital investment
in the Refinery.
Net interest expense decreased by $3.3 million, or 19% in the year ended
December 31, 1997 as compared to 1996. Such decrease was attributable to
interest income of $2 million earned primarily on the sale proceeds of the
Canadian disposition and reduced interest expense of $1.3 million due to early
retirement of debt. On October 1, 1997, the Company retired $7.5 million of its
10-3/4% Subordinated Debentures, and by the end of 1997, $72.4 million principal
amount of its 12% Senior Notes was retired. Average debt decreased from $154
million for the year ended December 31, 1996 to $138 million in 1997.
Income from discontinued oil and gas operations includes the Company's
Canadian oil and gas operation through May 5, 1997. Income from discontinued
operations was $1.7 million for the year ended December 31, 1997 as compared to
$4.8 million for 1996.
LIQUIDITY AND CAPITAL RESOURCES
On February 9, 1998, the Company issued $70 million of 9-1/8% Senior Notes due
2006 and received net proceeds of approximately $67.9 million. On February 10,
1998, the Company called for redemption the remaining $24.8 million of its 12%
Senior Notes and $46 million of its 7-3/4% Convertible Subordinated Debentures.
This redemption was completed on March 12, 1998 resulting in the payment of
$71.4 million, including redemption premiums and the issuance of 83,535 shares
of common stock. Under a stock repurchase plan, approved by the board of
directors to purchase the approximate number of shares issued upon conversion of
the Convertible Debentures, 83,500 shares of common stock have been repurchased
by the Company for $651,000.
On September 1, 1998, the Company announced that the Board of Directors had
approved a stock repurchase program of up to three million shares of common
stock. Through December 31, 1998, an additional 469,700 shares of common stock
have been purchased by the Company for $2.3 million.
Net cash provided by operating activities was $31.3 million, $12.5 million and
$8.5 million for 1998, 1997 and 1996, respectively. Working capital changes
provided $1.7 million of cash flows in 1998 while requiring $9.9 million and
$2.6 million of cash flows for 1997 and 1996, respectively. During 1998,
significant declines occurred in receivables, inventory and payables due to
declining crude oil prices. The Company was able to increase cash flows from
working capital changes by reducing inventory quantities of unfinished products
and timing of receivable collections. The major use of cash for working capital
changes was the reduction in accrued liabilities for the 1998 turnaround work.
Consistent with the seasonality of its business, the Company invests in working
capital during the first half of the year and recovers working capital
investment in the second half of the year.
At December 31, 1998, the Company had $33.6 million of cash and $6.8 million
available under the Refinery line of credit. The Company had working capital of
$30.1 million at December 31, 1998.
Additions to property and equipment during 1998 of $16.8 million, increased
$7.8 million from 1997 attributable to an increase of $11.1 million in Refinery
capital expenditures in 1998 offset by the 1997 discontinued Canadian oil and
gas operations capital expenditures of $3.3 million. Refinery capital
expenditures of $9.1 million are planned in 1999. It is anticipated that cash
generated from operating activities will be sufficient to meet its 1999
investment requirements.
Under certain conditions, the Refinery's revolving credit facility restricts
the transfer of cash in the form of dividends, loans or advances to the Company
from the Refinery. The Company does not believe these restrictions limit its
current operating plans.
MARKET RISKS
Impact of Changing Prices. The Company's revenues and cash flows, as well as
estimates of future cash flows are very sensitive to changes in energy prices.
Major shifts in the cost of crude oil and the price of refined products can
result in large changes in the operating margin from refining operations. Energy
prices also determine the carrying value of the Refinery's inventory.
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Hedging Activities. The Company, at times, engages in futures transactions in
its refining operations for the purpose of hedging its refining position. To
date, the use of futures transactions has been limited to protect against price
declines for excess inventory volumes. No futures transactions were entered into
during 1998 to hedge excess inventories. In addition, the Company, at times,
engages in futures transactions for the purchase of natural gas at fixed prices.
Natural gas is consumed by the refinery for energy purposes. Gains and losses
on futures contracts designated as hedges are recognized in refinery operating
costs when the associated hedge transaction is consummated. In 1998, the
Company recognized a net loss from forward purchases of natural gas of $644,000.
As of December 31, 1998, the Company had entered
SELECTED QUARTERLY FINANCIAL AND OPERATING DATA
(Dollars in thousands except per share)
1998 1997
------------------------------------------ ------------------------------------------
Unaudited Fourth Third Second First Fourth Third Second First
--------- --------- --------- --------- --------- --------- --------- ---------
Revenues $ 64,555 $ 80,863 $ 84,259 $ 69,691 $ 82,410 $ 108,108 $ 96,330 $ 89,570
Operating income (loss) 2,581 11,015 10,973 1,131 3,489 14,743 9,045 (5,574)
Income (loss) from continuing operations 1,004 9,448 9,205 (839) 1,505 11,806 4,534 (10,033)
Income from discontinued operations,
net of taxes (1) - - - - - - 13,606 1,554
Income (loss) before extraordinary item 1,004 9,448 9,205 (839) 1,505 11,806 18,140 (8,479)
Extraordinary loss, net of taxes - - - 3,013 1,295 2,622 - -
Net income (loss) 1,004 9,448 9,205 (3,852) 210 9,184 18,140 (8,479)
Basic earnings (loss) per share:
Continuing operations .04 .34 .33 (.03) .05 .42 .17 (.37)
Net income (loss) .04 .34 .33 (.14) .01 .33 .66 (.31)
Diluted earnings (loss) per share:
Continuing operations .04 .33 .32 (.03) .05 .42 .17 (.37)
Net income (loss) .04 .33 .32 (.14) .01 .33 .66 (.31)
EBITDA (2) 5,365 13,743 13,795 3,507 5,826 17,037 11,311 (3,301)
Net cash provided by (used in) operating
activities 8,009 17,241 11,975 (5,962) 5,698 11,620 9,245 (14,065)
Refining operations
Total charges (bpd) 40,450 41,782 37,953 41,355 39,215 44,907 42,341 38,623
Heavy crude charge rate (%) 94 94 93 93 92 91 92 90
Gasoline yields (bpd) 16,092 16,233 13,368 17,268 15,834 18,679 16,456 17,268
Diesel yields (bpd) 13,975 11,951 12,248 14,228 11,393 12,936 13,676 13,441
Total product sales (bpd) 40,993 45,010 44,479 40,293 36,036 46,205 41,848 38,105
Average light/heavy spread based on
delivered crude costs (per bbl) $ 3.40 $ 3.66 $ 4.81 $ 4.72 $ 3.82 $ 3.54 $ 3.32 $ 3.48
(1) Discontinued operations reflected in the above periods represent the
Company's Canadian oil and gas operating segment. On June 16, 1997 the
Company completed the Canadian disposition.
(2) EBITDA represents income from continuing operations before interest expense,
income tax and depreciation and amortization. EBITDA is not a calculation
based upon generally accepted accounting principles; however, the amounts
included in the EBITDA calculation are derived from amounts included in the
consolidated financial statements of the Company. In addition, EBITDA
should not be considered as an alternative to net income or operating
income, as an indication of operating performance of the Company or as an
alternative to operating cash flow as a measure of liquidity.
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into futures contracts to purchase through April 1999 an average of 6,000 mcf
per day of natural gas at an average futures price of $2.47 per mcf per the New
York Mercantile Exchange. The estimated fair value of the Company's open natural
gas contracts at December 31, 1998 was $(371,000). Futures contracts and options
may also, in the future, be used to fix margins in its refining and marketing
operations.
Interest Rate Risk. Borrowings under the Refinery credit facility are
generally repaid monthly and bear a current market rate of interest. The
average effective interest rate was 8% during 1998. The Company's $70.0 million
of 9-1/8% Senior Notes, Due 2006, have a fixed interest rate and the Company has
no current plans to redeem these notes. Thus the Company's long-term debt is
not exposed to cash flow or fair value risk from interest rate changes. The
estimated fair value of the 9-1/8% Senior Notes at December 31, 1998 was $65.1
million.
ENVIRONMENTAL
Numerous local, state and federal laws, rules and regulations relating to the
environment are applicable to the Company's operations. As a result, the
Company falls under the jurisdiction of numerous state and federal agencies for
administration and is exposed to the possibility of judicial or administrative
actions for remediation and/or penalties brought by those agencies. Among these
requirements are regulations recently promulgated by the EPA under the authority
of Title III of the Clean Air Act Amendments. The Company expended
approximately $600,000 by the regulatory compliance deadline of August 1, 1998
to improve the Frontier Refinery's control of emissions of hazardous air
pollutants. Subsequent rule making authorized by this or other titles of the
Clean Air Act Amendments or similar laws may necessitate additional expenditures
in future years.
FIVE YEAR FINANCIAL DATA
(In thousands except per share)
1998 1997 1996 1995 1994
--------- --------- --------- --------- ---------
Revenues $299,368 $376,418 $383,373 $331,832 $313,187
Operating income (loss) 25,700 21,703 5,585 (1,106) 20,416
Income (loss) from continuing operations 18,818 7,812 (11,644) (19,336) 1,693
Income (loss) from discontinued operation,
net of taxes (1) - 15,160 4,752 211 (14,300)
Income (loss) before extraordinary item 18,818 22,972 (6,892) (19,125) (12,607)
Extraordinary loss, net of taxes 3,013 3,917 - - -
Net income (loss) 15,805 19,055 (6,892) (19,125) (12,607)
Basic earnings (loss) per share:
Continuing operations .67 .28 (.43) (.71) .06
Net income (loss) .56 .69 (.25) (.70) (.46)
Diluted earnings (loss) per share:
Continuing operations .65 .28 (.43) (.71) .06
Net income (loss) .55 .69 (.25) (.70) (.46)
EBITDA (2) 36,410 30,873 14,603 7,365 28,118
Net cash provided by operating activities 31,263 12,498 8,465 9,878 32,108
Working capital (deficit) 30,125 20,928 (3,752) (2,485) 1,532
Total assets 182,026 177,915 239,865 238,382 277,536
Long-term debt 70,000 70,572 145,928 145,377 170,797
Shareholders' equity 70,353 55,934 25,269 32,464 49,449
Capital expenditures from continuing operations 16,763 5,675 4,760 5,217 7,979
Dividends declared - - - - -
(1) Discontinued operations reflected in the above periods represent the
Company's oil and gas operating segment, comprising the Canadian and Unite
States oil and gas properties. On June 16, 1997, the Company completed th
Canadian disposition. The Company completed the U.S. dispositon during
1995.
(2) EBITDA represents income from continuing operations before interest expense,
income tax and depreciation and amortization. EBITDA is not a calculaton
based upon generally accepted accounting principles; however, the amounts
included in the EBITDA calculation are derived from amounts included in the
consolidated financial statements of the Company. In addition, EBITDA
should not be considered as an alternative to net income or operating
income, as an indication of operating performance of the Company or as an
alternative to operating cash flow as a measure of liquidity.
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Because other refineries will be required to make similar expenditures, the
Company does not expect such expenditures to materially adversely impact its
competitive position. Frontier is party to one consent decree requiring the
investigation and, in certain instances, mitigation of environmental impacts
resulting from past operational activities. The Company has been and will be
responsible for costs related to compliance with or remediations resulting from
environmental regulations. There are currently no identified environmental
remediation projects of which the costs can be reasonably estimated. However,
the continuation of the present investigative process, other more extensive
investigations over time or changes in regulatory requirements could result in
future liabilities. The effects to the future consolidated financial position,
results of operations or capital expenditures is unknown.
YEAR 2000 ISSUES
Many of the computer systems used by the Company today were designed and
developed using two digits, rather than four, to specify the year. As a result,
such systems will recognize the year 2000 as "00". This could cause many
computer applications to fail completely or to create erroneous results unless
corrective measures are taken. The Company utilizes software and related
information technology ("IT") essential to its operations that may be affected
by the Year 2000 issue. The company also relies on non-IT systems in its daily
operations, such as fax machines, radios, voice mail systems, alarms, monitors
and other miscellaneous systems. Additionally the company is dependent upon
third party relationships with both suppliers and customers.
FIVE YEAR OPERATING DATA
1998 1997 1996 1995 1994
--------- --------- --------- --------- ---------
Charges (bpd)
Light crude 2,174 3,162 4,322 8,098 6,165
Heavy crude 32,303 31,967 31,677 27,174 27,025
Other feed and blend stocks 5,909 6,154 5,192 5,072 4,105
Total charges 40,386 41,283 41,191 40,344 37,295
Manufactured product yields (bpd)
Gasoline 15,738 17,060 16,825 17,263 16,106
Diesel 13,097 12,856 13,712 13,744 13,094
Asphalt and other 10,236 10,200 9,215 7,951 6,575
Total manufactured product yield 39,071 40,116 39,752 38,958 35,775
Product sales (bpd)
Gasoline 21,421 20,499 20,311 20,767 19,437
Diesel 12,484 12,110 12,561 13,265 12,628
Asphalt and other 8,797 7,949 7,306 6,781 6,724
Total product sales 42,702 40,558 40,178 40,813 38,789
Average sales price (per bbl)
Gasoline $ 21.52 $ 28.83 $ 28.78 $ 24.68 $ 24.57
Diesel 19.90 27.22 28.89 23.48 23.48
Asphalt and other 12.07 13.13 13.21 11.73 12.18
Operating margin information (per sales bbl)
Average sales price $ 19.10 $ 25.27 $ 25.98 $ 22.14 $ 22.06
Material costs 13.01 19.49 21.50 18.11 16.18
Product spread 6.09 5.78 4.48 4.03 5.88
Operating expenses excluding depreciation 3.34 3.30 3.15 3.19 3.45
Depreciation .68 .61 .59 .55 .53
Operating margin 2.07 1.87 .74 .29 1.90
Average light/heavy spread based
on delivered crude costs (per bbl) $ 4.15 $ 3.54 $ 2.56 $ 2.94 $ 3.61
- 15 -
The Company initiated a company wide task force to assess and resolve the
business risks associated with the Year 2000 issues. The process implemented by
the task force included identification of possibly effected systems, assessment
of probability of and implications of noncompliance, alternative modifications
to or replacements of existing systems or technology and cost and timetables for
completion. The analysis is being substantially completed by internal resources
with third party vendor verification when available.
The Company has completed a preliminary review of its' IT, accounting and
operational, systems for Year 2000 compliance. The review of the Company's
primary financial computer systems, including its accounting system, indicated
only minor modifications will be required to make them Year 2000 compliant. The
process control system has been documented as Year 2000 compliant by the vendor
literature but further testing is being pursued to verify this. The Company
believes it will be able to implement the necessary corrections to all of its
critical information technology and non-IT systems by mid 1999. Systems
identified as non-critical noncompliant will be addressed at later dates.
The Company does significant business with and is dependent upon various third
party entities. These relationships include customers, critical suppliers of
products and utilities, financial institutions, transportation companies and
others. The Company is also reviewing the possible impact of Year 2000
noncompliance by its outside providers. Communications with critical third
parties regarding their plans and progress addressing the Year 2000 has been
initiated and continues. The Company is dependent upon the reliability and
completeness of the third parties representations in assessing their Year 2000
readiness.
The estimated costs of the software and hardware modifications and some
consultant support identified to date will be between $125,000 to $350,000 to
implement and will be financed from operating cash flows. Expenditures through
January 31, 1999 totaled approximately $18,000. The Company does not separately
track the internal costs for the Year 2000 project, and such costs are
principally the related payroll costs for its information systems group.
The Company's refinery operations are very dependent upon outside providers
and in certain areas an alternative to the Company is not available. Failure to
correct a material year 2000 issue could result in an interruption in, or a
failure of, certain normal business activities or operations. Although the
Company is taking steps to reduce the likelihood of interruption or failure of
normal operations, there can be no guarantee that other companies' systems, on
which our systems rely, will be timely Year 2000 compliant. To date, the Company
is not aware of any significant Year 2000 problems with these outside providers
that would have a material adverse effect on the Company's business or results
of operations, liquidity and financial operations.
The Company is in the process of developing contingency plans to address
issues associated with the reasonably likely worst case scenarios. The Company
expects to have such contingency plans formulated by the end of August 1999.
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CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands except per share amounts)
For the years ended December 31, 1998 1997 1996
--------- --------- ---------
Revenues:
Refined products $ 297,662 $ 374,091 $ 382,098
Other 1,706 2,327 1,275
--------- --------- ---------
299,368 376,418 383,373
--------- --------- ---------
Costs and Expenses:
Refining operating costs 254,733 337,495 362,485
Selling and general expenses 8,225 8,050 6,285
Depreciation 10,710 9,170 9,018
--------- --------- ---------
273,668 354,715 377,788
--------- --------- ---------
Operating Income 25,700 21,703 5,585
Interest expense, net 6,732 13,891 17,229
--------- --------- ---------
Income (Loss) From Continuing Operations Before Income Taxes 18,968 7,812 (11,644)
Provision for income taxes 150 - -
--------- --------- ---------
Income (Loss) From Continuing Operations 18,818 7,812 (11,644)
Discontinued Operations:
Income from oil and gas operations, net of taxes - 1,721 4,752
Gain on disposal of Canadian oil and gas properties, net of taxes - 23,301 -
Recognition of cumulative translation adjustment - (9,862) -
--------- --------- ---------
Income (Loss) Before Extraordinary Item 18,818 22,972 (6,892)
Extraordinary loss on retirement of debt, net of taxes 3,013 3,917 -
--------- --------- ---------
Net Income (Loss) $ 15,805 $ 19,055 $ (6,892)
========= ========= =========
Basic Earnings (Loss) Per Share of Common Stock:
Continuing operations $ .67 $ .28 $ (.43)
Discontinued operations - .55 .18
Extraordinary loss (.11) (.14) -
--------- --------- ---------
Net income (loss) $ .56 $ .69 $ (.25)
========= ========= =========
Diluted Earnings (Loss) Per Share of Common Stock:
Continuing operations $ .65 $ .28 $ (.43)
Discontinued operations - .55 .18
Extraordinary loss (.10) (.14) -
--------- --------- ---------
Net income (loss) $ .55 $ .69 $ (.25)
========= ========= =========
The accompanying notes are an integral part of these financial statements.
- 17 -
CONSOLIDATED BALANCE SHEETS
(In thousands except shares)
December 31, 1998 1997
--------- ---------
ASSETS
Current Assets:
Cash, including cash equivalents of $31,781 and $19,981
at December 31, 1998 and 1997, respectively $ 33,589 $ 21,735
Trade receivables, less allowance for doubtful accounts
of $500 at December 31, 1998 and 1997 9,986 16,674
Other receivables 1,035 530
Inventory of crude oil, products and other 20,269 27,666
Other current assets 560 1,391
--------- ---------
Total current assets 65,439 67,996
--------- ---------
Property, Plant and Equipment, at cost:
Refinery and pipeline 164,664 149,201
Furniture, fixtures and other equipment 3,426 3,044
--------- ---------
168,090 152,245
Less - Accumulated depreciation 56,217 45,586
--------- ---------
111,873 106,659
Other Assets 4,714 3,260
--------- ---------
Total Assets $ 182,026 $ 177,915
========= =========
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities:
Accounts payable $ 23,492 $ 33,527
Revolving credit facility 3,800 -
Accrued turnaround cost 1,339 6,771
Accrued liabilities and other 4,280 5,240
Accrued interest 2,403 1,530
--------- ---------
Total current liabilities 35,314 47,068
--------- ---------
Long-Term Debt, net of current maturities 70,000 70,572
Deferred Credits and Other 5,238 2,801
Deferred Income Taxes 1,121 1,540
Commitments and Contingencies
Shareholders' Equity:
Preferred stock, $100 par value, 500,000 shares
authorized, no shares issued - -
Common stock, no par, 50,000,000 shares authorized,
28,385,584 shares and 28,111,289 shares
issued in 1998 and 1997, respectively 57,278 57,251
Paid-in capital 86,305 84,785
Retained earnings (deficit) (70,061) (85,866)
Treasury stock, 605,700 shares and 52,500 shares
at December 31, 1998 and 1997, respectively (3,169) (236)
--------- ---------
Total shareholders' equity 70,353 55,934
--------- ---------
Total liabilities and shareholders' equity $ 182,026 $ 177,915
========= =========
The accompanying notes are an integral part of these financial statements.
- 18 -
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
For the years ended December 31, 1998 1997 1996
--------- --------- ---------
OPERATING ACTIVITIES
Net Income (loss) $ 15,805 $ 19,055 $ (6,892)
Extraordinary loss on retirement of debt 3,013 3,917 -
Depreciation, depletion and amortization 10,710 13,018 17,141
Gain on disposal of Canadian oil and gas properties - (23,301) -
Recognition of cumulative translation adjustment - 9,862 -
Other 20 (202) 795
Changes in components of working capital from operations
(Increase) decrease in receivables 6,183 905 765
(Increase) decrease in inventory 7,397 1,856 (9,881)
(Increase) decrease in other current assets 831 (642) (35)
Increase (decrease) in accounts payable (9,196) (8,617) 7,659
Increase (decrease) in accrued liabilities and other (3,500) (3,353) (1,087)
--------- --------- ---------
Net cash provided by operating activities 31,263 12,498 8,465
INVESTING ACTIVITIES
Additions to property, plant and equipment:
Continuing operations (16,763) (5,675) (4,760)
Discontinued operations - (3,298) (8,654)
Sales of oil and gas and other properties - 91,307 990
Other - (590) 429
--------- --------- ---------
Net cash provided by (used in) investing activities (16,763) 81,744 (11,995)
FINANCING ACTIVITIES
Borrowings:
9-1/8% Senior notes 70,000 - -
Revolving credit facility 3,800 - -
12% Senior notes - 2,000 3,000
Payments of debt:
12% Senior notes, including redemption premium (25,423) (74,932) -
7-3/4% Convertible subordinated debentures,
including redemption premium (45,971) - -
Subordinated debentures - (7,500) -
Debt issuance costs (2,575) - -
Issuance of common stock 816 3,109 -
Purchase of treasury stock (2,933) - -
Other (360) (357) (345)
--------- --------- ---------
Net cash provided by (used in) financing activities (2,646) (77,680) 2,655
Effect of exchange rate changes on cash - (10) 13
--------- --------- ---------
Increase (decrease) in cash and cash equivalents 11,854 16,552 (862)
Cash and cash equivalents, beginning of period 21,735 5,183 6,045
--------- --------- ---------
Cash and cash equivalents, end of period $ 33,589 $ 21,735 $ 5,183
========= ========= =========
The accompanying notes are an integral part of these financial statements.
- 19 -
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS' EQUITY
(In thousands except shares)
Common Stock
---------------------- Accumulated
Number Other Retained
of Shares Treasury Paid-In Comprehensive Earnings Comprehensive
Issued Amount Stock Capital Income (Deficit) Total Income
----------- --------- --------- --------- ------------- --------- --------- -------------
DECEMBER 31, 1995 27,313,502 $ 57,172 $ (259) $ 81,767 $ (8,187) $ (98,029) $ 32,464
Comprehensive income
Net loss -- -- -- -- -- (6,892) (6,892) $ (6,892)
Foreign currency translation -- -- -- -- (314) -- (314) (314)
---------
Comprehensive income $ (7,206)
=========
Shares issued under:
Directors' stock plan -- -- 11 -- -- -- 11
----------- --------- --------- --------- ------------- --------- ---------
DECEMBER 31, 1996 27,313,502 57,172 (248) 81,767 (8,501) (104,921) 25,269
Comprehensive income
Net income -- -- -- -- -- 19,055 19,055 $ 19,055
Foreign currency translation -- -- -- -- (1,361) -- (1,361) (1,361)
Disposition of Canadian
assets -- -- -- -- 9,862 -- 9,862 9,862
---------
Comprehensive income $ 27,556
=========
Shares issued under:
Stock option plan 797,787 79 -- 3,018 -- -- 3,097
Directors' stock plan -- -- 12 -- -- -- 12
----------- --------- --------- --------- ------------- --------- ---------
DECEMBER 31, 1997 28,111,289 57,251 (236) 84,785 -- (85,866) 55,934
Comprehensive income
Net income 15,805 15,805 $ 15,805
---------
Comprehensive income $ 15,805
=========
Shares issued under:
Stock option plan 190,760 19 -- 797 -- -- 816
Debentures converted 83,535 8 -- 723 -- -- 731
Shares purchased under stock
repurchase plans (1) -- -- (2,933) -- -- -- (2,933)
----------- --------- --------- --------- ------------- --------- ---------
DECEMBER 31, 1998 28,385,584 $ 57,278 $ (3,169) $ 86,305 $ -- $ (70,061) $ 70,353
========== ========= ========= ========= ============= ========= =========
(1) Consists of 553,200 shares repurchased during 1998 that are held in
treasury.
The accompanying notes are an integral part of these financial statements.
- 20 -
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. NATURE OF OPERATIONS
The financial statements include the accounts of Frontier Oil Corporation
(formerly known as Wainoco Oil Corporation), a Wyoming corporation, and its
wholly-owned subsidiaries, including Frontier Holdings Inc. (the "Refinery"),
collectively referred to as Frontier or the Company. At the Annual Meeting held
on April 27, 1998, the shareholders of the Company approved the change in the
Company's corporate name from "Wainoco Oil Corporation" to "Frontier Oil
Corporation." The Company is engaged in the crude oil refining and wholesale
marketing of refined petroleum products business (the "refining operations").
The Company conducts its refining operations in the Rocky Mountain region of
the United States. The Company's Cheyenne, Wyoming Refinery purchases the crude
oil to be refined and markets the refined petroleum products produced, including
various grades of gasoline, diesel fuel, asphalt and petroleum coke.
Prior to the third quarter of 1997, the Company also explored for and produced
oil and gas in Canada and prior to the first quarter of 1996 in the United
States (together, the "oil and gas operations"). Operating results for the
Company's oil and gas operations segment are presented as discontinued
operations in the accompanying statements of operations and all previously
reported results are restated to this presentation.
2. SIGNIFICANT ACCOUNTING POLICIES
PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment are depreciated based on the straight-line
method over their estimated useful lives. The estimated useful lives are:
Refinery plant and equipment . . 5 to 20 years
Pipeline and pumps . . . . . . . 10 to 20 years
Furniture, fixtures and other. . 3 to 10 years
Maintenance and repairs are expensed as incurred except for major scheduled
repairs and maintenance ("turnaround") of the Refinery operating units. The
costs for turnarounds are ratably accrued over the period from the prior
turnaround to the next scheduled turnaround. Major improvements are
capitalized, and the assets replaced are retired.
INVENTORIES
Inventories of crude oil, other unfinished oils and all finished products are
recorded at the lower of cost on a first-in, first-out (FIFO) basis or market.
Refined product exchange transactions are considered asset exchanges with
deliveries offset against receipts. The net exchange balance is included in
inventory. Inventories of materials and supplies are recorded at the lower of
average cost or market.
SCHEDULE OF COMPONENTS OF INVENTORY
(In thousands)
December 31, 1998 1997
--------- ---------
Crude oil $ 1,407 $ 3,904
Unfinished products 2,644 6,338
Finished products 8,602 9,929
Chemicals 1,333 1,534
Repairs and maintenance supplies and other 6,283 5,961
--------- ---------
$ 20,269 $ 27,666
========= =========
ENVIRONMENTAL EXPENDITURES
Environmental expenditures are expensed or capitalized based upon their future
economic benefit. Costs which improve a property's pre-existing condition and
costs which prevent future environmental contamination are capitalized. Costs
related to environmental damage resulting from operating activities subsequent
to acquisition are expensed. Liabilities for these expenditures are recorded
when it is probable that obligations have been incurred and the amounts can be
reasonably estimated.
REFINED PRODUCT REVENUES
Revenues are recognized when product ownership is transferred to the customer.
Excise and other taxes on products sold are netted against revenues.
- 21 -
HEDGING
The Company, at times, engages in futures transactions in its refining
operations for the purpose of hedging its inventory position and natural gas
prices. Gains and losses on futures contracts designated as hedges are
recognized in refining operating costs when the associated hedge transaction is
consummated. The Company does not enter into derivative contracts for
speculative purposes.
INTEREST
Interest is reported net of interest capitalized and interest income. Interest
income of $1.5 million, $2.0 million and $109,000 was recorded in the years
ended December 31, 1998, 1997 and 1996, respectively. During 1998 and 1996 the
Company capitalized interest of $101,000 and $24,000, respectively. The Company
capitalizes interest on debt incurred to fund the construction or acquisition of
a significant asset.
STOCK BASED COMPENSATION
Compensation cost is measured using the intrinsic value method. Under this
method, compensation cost is the excess, if any, of the quoted market value of
the Company's common stock at the grant date over the amount the employee must
pay to acquire the stock. No compensation cost was recognized for the years
ended December 31, 1998, 1997 and 1996.
CURRENCY TRANSLATION
The Canadian dollar financial statements of the Canadian oil and gas
operations have been translated to United States dollars. Gains and losses on
currency transactions were included in the consolidated statements of operations
currently, and translation adjustments were included in the consolidated
statements of changes in shareholders' equity. See Note 8 for information
relating to the recognition of the cumulative translation adjustment in 1997.
INTERCOMPANY TRANSACTIONS
Significant intercompany transactions are eliminated in consolidation.
USE OF ESTIMATES
The preparation of financial statements in conformity with generally accepted
accounting principles requires management to make estimates and assumptions that
affect the reported amounts of assets and liabilities and disclosures of
contingent assets and liabilities at the date of the financial statements and
the reported amounts of revenues and expenses during the reporting period.
Actual results could differ from those estimates.
NEW ACCOUNTING STATEMENT
In June 1998, the Financial Accounting Standards Board issued Statement of
Financial Accounting Standards No. 133, "Accounting for Derivative Instruments
and Hedging Activities". The Statement established accounting and reporting
standards requiring that every derivative instrument (including certain
derivative instruments embedded in other contracts) be recorded in the balance
sheet as either an asset or liability measured at its fair value. The Statement
requires that changes in the derivative's fair value be recognized currently in
earnings unless specific hedge accounting criteria are met. Special accounting
for qualifying hedges allows a derivative's gains and losses to offset related
results on the hedged item in the income statement, and requires that a company
must formally document, designate, and assess the effectiveness of transactions
that receive hedge accounting.
Statement 133 is effective for fiscal years beginning after June 15, 1999. A
company may also implement the Statement as of the beginning of any fiscal
quarter after issuance (that is fiscal quarters beginning June 16, 1998 and
thereafter). Statement 133 cannot be applied retroactively. Statement 133 must
be applied to (a) derivative instruments and (b) certain derivative instruments
embedded in hybrid contracts that were issued, acquired, or substantively
modified after December 31, 1997 (and, at the company's election, before January
1, 1998).
The Company has not yet quantified the impacts of adopting Statement 133 on
the financial statements. However, the Statement could increase volatility in
earnings and other comprehensive income.
CASH FLOW REPORTING
Highly liquid investments with a maturity, when purchased, of three months or
less are considered to be cash equivalents. Cash payments for interest during
1998, 1997 and 1996 were $6.3 million, $18.4 million and $16.3 million,
respectively. Cash payments for income taxes during 1998, 1997 and 1996 were
$582,000, $930,000 and $187,000, respectively.
- 22 -
3. DEBT
SCHEDULE OF LONG-TERM DEBT
(In thousands)
December 31, 1998 1997
--------- ---------
9-1/8% Senior Notes $ 70,000 $ --
12% Senior Notes -- 24,572
7-3/4% Convertible Subordinated Debentures -- 46,000
--------- ---------
$ 70,000 $ 70,572
========= =========
SENIOR NOTES
On February 9, 1998, the Company issued $70 million of 9-1/8% Senior Notes due
2006. The Notes are redeemable, at the option of the Company, at a premium of
104.563% after February 15, 2002, declining to 100% in 2005. Prior to February
15, 2002, the Company at its option may redeem the Notes at a defined make-whole
amount. Interest is paid semiannually. The net proceeds were utilized to fund
redemptions of the Company's 12% Senior Notes and 7-3/4% Convertible
Subordinated Debentures.
EARLY RETIREMENT OF DEBT
On February 10, 1998, the Company called for redemption the remaining $24.8
million of its 12% Senior Notes and the $46 million 7-3/4% Convertible
Subordinated Debentures. The redemptions were completed on March 12, 1998.
Holders of $731,000 of 7-3/4% Convertible Subordinated Debentures elected to
convert into 83,535 shares of the Company's common stock. Based on the
redemptions, the Company has recognized a 1998 extraordinary loss of
approximately $3.0 million, net of taxes, due to the redemption premiums on the
Senior Notes and Convertible Debentures and the write-off of the related
remaining debt issuance costs. The redemptions and retirement of these debt
obligations were funded with proceeds from the issuance of the 9-1/8% Senior
Notes.
Based on early debt redemptions during 1997, the Company recognized an
extraordinary loss of approximately $3.9 million, net of taxes, due to the
redemption premium on the 12% Senior notes and reduction of debt issuance costs.
The debt redemptions were funded with proceeds from the sale of the Canadian oil
and gas operations.
REVOLVING CREDIT FACILITY
The refining operations has a working capital credit facility with a group of
three banks which expires on June 30, 2000. The facility is a collateral-based
facility with total capacity of up to $50 million, of which maximum cash
borrowings are $20 million. Any unutilized capacity after cash borrowings is
available for letters-of-credit. Short-term debt outstanding was $3.8 million
at December 31, 1998. Standby letters of credit outstanding were $7.7 million
and $4.5 million at December 31, 1998 and 1997, respectively.
The facility provides working capital financing for operations, generally the
financing of crude and product supply. It is generally secured by the
Refinery's current assets. The agreement provides for a quarterly commitment
fee of .375 of 1% per annum. Interest rates are based, at the Company's option,
on the agent bank's prime rate plus 1/2%, the prevailing Federal Funds Rate plus
2-1/4% or the reserve-adjusted LIBOR plus 1-3/4%. Standby letters-of-credit
issued bear a fee of 1-1/4% annually, plus standard issuance and renewal fees.
The agreement includes certain financial covenant requirements relating to the
Refinery's working capital, cash earnings, tangible net worth and fixed charge
coverage.
RESTRICTIONS ON LOANS, TRANSFER OF FUNDS AND PAYMENT OF DIVIDENDS
The Refinery credit facility restricts the Refinery as to the distribution of
capital assets and the transfer of cash in the form of dividends, loans or
advances when there are any outstanding borrowings under the facility or when a
default exists or would occur.
FIVE-YEAR MATURITIES
The 9-1/8% Senior Notes are due 2006; until then there are no maturities of
long-term debt.
- 23 -
4. INCOME TAXES
The following is the provision (benefit) for income taxes for the three years
ended December 31, 1998, 1997 and 1996.
PROVISION (BENEFIT) FOR INCOME TAXES
(In thousands)
1998 1997 1996
--------- --------- ---------
Current $ 569 $ 194 $ --
Deferred (419) (194) --
--------- --------- ---------
$ 150 $ -- $ --
========= ========= =========
The following is a reconciliation of the provision (benefit) for income taxes
computed at the statutory United States income tax rates on pretax income (loss)
and the provision (benefit) for income taxes as reported for the three years
ended December 31, 1998, 1997 and 1996.
RECONCILIATION OF TAX PROVISION
(In thousands)
1998 1997 1996
--------- --------- ---------
Provision (benefit) based on statutory rates $ 6,639 $ 2,656 $ (4,242)
Increase (decrease) resulting from:
Net operating loss carryforwards (6,639) (2,656) 4,242
State income taxes 150 -- --
--------- --------- ---------
Provision as reported $ 150 $ -- $ --
========= ========= =========
The following are the significant components, by type of temporary differences
or carryforwards, of deferred tax liabilities and tax assets, computed at the
federal statutory rate, as of December 31, 1998 and 1997.
COMPONENTS OF DEFERRED TAXES
(In thousands)
December 31, 1998 1997
--------- ---------
DEFERRED TAX LIABILITIES
Property, plant and equipment due
to differences in depreciation $ 17,731 $ 19,624
Other 697 918
--------- ---------
DEFERRED TAX LIABILITIES 18,428 20,542
--------- ---------
DEFERRED TAX ASSETS
Tax loss carryforwards 43,820 50,960
Depletion carryforwards 3,045 3,045
Other 1,828 3,069
--------- ---------
48,693 57,074
--------- ---------
LESS-VALUATION ALLOWANCE 31,386 38,072
--------- ---------
NET DEFERRED TAX ASSETS 17,307 19,002
--------- ---------
NET DEFERRED TAX LIABILITIES $ 1,121 $ 1,540
========= =========
Realization of deferred tax assets is dependent on the Company's ability to
generate taxable income within the life of the tax loss carryforwards. As a
result of the Company's history of operating losses, a valuation allowance has
been provided for deferred tax assets that are not offset by scheduled future
reversals of deferred tax liabilities.
At December 31, 1998, the Company had regular net operating loss ("NOL")
carryforwards for United States tax reporting purposes of $125.2 million
available to reduce future federal taxable income. The regular NOL
carryforwards will expire as follows: $11.8 million in 2002, $7.7 million in
2003, $11.3 million in 2004, $29.5 million in 2005, $17.2 million in 2006, $13.7
million in 2007, $11.3 million in 2008, $2.2 million in 2009, $16.1 million in
2010 and $4.4 million in 2011.
Also, at December 31, 1998, the Company had alternative minimum tax net
operating loss ("AMT NOL") carryforwards for United States tax reporting of
$79.6 million to reduce future taxable income. The AMT NOL carryforwards will
expire as follows: $25.4 million in 2005, $13.1 million in 2006, $11.6 million
in 2007, $8.6 million in 2008, $1.4 million in 2009, $16.8 million in 2010 and
$2.7 million in 2011.
The Company has alternative minimum tax carryforwards of $1.3 million and tax
depletion carryforwards of $8.7 million which are indefinitely available to
reduce future United States income taxes payable.
- 24 -
5. COMMON STOCK
EARNINGS PER SHARE
The following is a reconciliation of the numerators and denominators used in
the calculation of basic and diluted earnings per share ("EPS") for income
(loss) from continuing operations for the years ended December 31, 1998, 1997,
and 1996.
1998 1997 1996
----------------------------------- ----------------------------------- -----------------------------------
Income Shares Per Share Income Shares Per Share Income Shares Per Share
(Numerator) (Denominator) Amount (Numerator) (Denominator) Amount (Numerator) (Denominator) Amount
----------- ------------- --------- ----------- ------------- --------- ----------- ------------- ---------
(In thousands except per share amounts)
BASIC EPS:
Income (loss) from
continuing operations $ 18,818 28,124 $ .67 $ 7,812 27,457 $ .28 $ (11,644) 27,257 $ (.43)
======== ======== ========
DILUTIVE SECURITIES:
Stock options -- 622 -- 494 -- --
----------- ------------- ----------- ------------- ----------- -------------
DILUTED EPS:
Income (loss) from
continuing operations $ 18,818 28,746 $ .65 $ 7,812 27,951 $ .28 $ (11,644) 27,257 $ (.43)
=========== ============= ======== =========== ============= ======== =========== ============= =========
Certain of the Company's stock options that could potentially dilute basic EPS
in the future were not included in the computation of diluted EPS because to do
so would have been antidilutive for the periods presented.
NON-EMPLOYEE DIRECTORS STOCK GRANT PLAN
During 1995, the Company established a stock grant plan for non-employee
directors. The purpose of the plan is to provide a part of non-employee
directors compensation in Company stock. The plan will be beneficial to the
Company and its stockholders by allowing non-employee directors to have a
personal financial stake in the Company through an ownership interest in the
Company's common stock. The plan may grant an aggregate of 60,000 shares of the
Company's common stock held in treasury. The Company made grants to directors
under this plan of 2,500 shares in 1997 and 1996.
STOCK OPTION PLANS
The Company has three stock option plans which authorize the granting of
restricted stock and options to purchase shares. The plans through December 31,
1998 have reserved for issuance a total of 3,959,355 shares of common stock of
which 2,555,435 shares were granted and exercised, 1,318,250 shares were granted
and were outstanding and 85,670 shares were available to be granted. Options
under the plans are granted at not less than fair market value on the date of
grant. No entries are made in the accounts until the options are exercised, at
which time the proceeds are credited to common stock and paid-in capital.
Generally, the options vest ratably throughout their one- to five-year terms.
A summary of the status of the Company's plans as of December 31, 1998, 1997
and 1996, and changes during the years ended on those dates is presented below:
1998 1997 - Restated 1996
-------------------- -------------------- --------------------
Weighted- Weighted- Weighted-
Average Average Average
Number of Exercise Number of Exercise Number of Exercise
Options Price Options Price Options Price
--------- --------- --------- --------- --------- ---------
Outstanding at beginning of year 1,526,340 $ 4.06 2,331,904 $ 3.81 2,332,842 $ 4.32
Granted -- -- 612,800 4.09 981,229 3.31
Exercised (190,760) 3.81 (797,787) 3.89 -- --
Reissued -- -- -- -- (669,229) 4.30
Expired (17,330) 5.18 (620,577) 3.48 (312,938) 4.53
--------- --------- --------- --------- --------- ---------
Outstanding at end of year 1,318,250 3.95 1,526,340 4.06 2,331,904 3.81
========= ========= =========
Exercisable at end of year 1,060,320 4.45 914,850 4.03 1,526,561 4.04
========= ========= =========
Available for grant at end of year 85,670 69,390 68,208
========= ========= =========
Weighted-average fair value of
options granted during the year -- 1.51 .65
- 25 -
The following table summarizes information about stock options outstanding at
December 31, 1998:
Options Outstanding Options Exercisable
--------------------------------------- -------------------------
Weighted-
Average Weighted- Weighted-
Number Remaining Average Average
Range of Outstanding Contractual Exercise Exerciseable Exercise
Exercise Prices at 12/31/98 Life Price at 12/31/98 Price
- --------------- ----------- ----------- --------- ------------ ---------
$2.88 to $7.82 1,318,250 2.26 $ 3.95 1,060,320 $ 4.45
Had compensation costs been determined based on the fair value at the
grant dates for awards made in 1997 and 1996 (no awards were made in 1998), the
Company's net income (loss) and EPS would have been the pro forma amounts
indicated below for the years ended December 31, 1998, 1997 and 1996:
(In thousands except per share amounts)
1998 1997 1996
--------- --------- ---------
Net income (loss):
As reported $ 15,805 $ 19,055 $ (6,892)
Pro forma 15,281 18,578 (7,263)
Basic EPS:
As reported $ .56 $ .69 $ (.25)
Pro forma .54 .67 (.27)
Diluted EPS:
As reported $ .55 $ .69 $ (.25)
Pro forma .53 .67 (.27)
The fair value of grants was estimated on the date of grant using the
Black-Scholes option pricing model with the following weighted-average
assumptions used: risk-free interest rates of 5.91% and 5.33%, expected
volatilities of 41.07%, and 32.95%, expected lives of 2.32 and 1.59 years and
no dividend yield in 1997 and 1996, respectively.
6. COMMITMENTS AND CONTINGENCIES
LEASE AND OTHER COMMITMENTS
The Company has noncapitalized building, equipment and vehicle lease
agreements which expire from 1999 through 2005 having minimum annual payments as
of December 31, 1998 of $4.1 million for 1999, $719,000 for 2000, $591,000 for
2001, $368,000 for 2002, $174,000 for 2003, $132,000 for 2004 and $25,000 in
2005. Operating lease rental expense was $2.6 million, $2.6 million and $1.7
million for the three years ended December 31, 1998, 1997and 1996, respectively.
The Company contracted for pipeline capacity of approximately 13,800 bpd on
the Express Pipeline from Hardisty, Alberta to Guernsey, Wyoming in 1997 for a
period of 15 years. The Company's commitment for pipeline capacity is
approximately $5.8 million per year. The agreement allows the Company to assign
a portion of its capacity in early years for additional capacity in later years.
The Company owns a 25,000 bpd interest in a crude oil pipeline from Guernsey,
Wyoming to the refinery. The Company's share of operating costs for the crude
oil pipeline are recorded as refining operating costs. The Company also has
commitments to purchase crude oil from various suppliers on a one month to one
year basis at daily market posted prices to meet its Refinery throughput
requirements.
CONCENTRATION OF CREDIT RISK
The Company has concentrations of credit risk with respect to sales within the
same or related industry and within limited geographic areas. The Refining
operation sells its products exclusively at wholesale, principally to
independent retailers and major oil companies located primarily in the Denver,
western Nebraska and eastern Wyoming regions, with 14% of its customers
accounting for approximately 69% of total refined product sales in 1998. The
Company extends credit to its customers based on ongoing credit evaluations. An
allowance for doubtful accounts is provided based on the current evaluation of
each customer's credit risk, past experience and other factors. During 1998,
the Company made sales to CITGO Petroleum Products of approximately $56 million,
which accounted for 19% of consolidated revenues.
CONTRIBUTION PLANS
The Company sponsors separate defined contribution plans for employees covered
by a collective bargaining agreement and employees not covered by such an
agreement. All employees may participate by contributing a portion
- 26 -
of their annual earnings to the plans. The Company makes basic and/or matching
contributions on behalf of participating employees. The cost of the plans for
the three years ended December 31, 1998, 1997 and 1996 was $1.4 million, $1.3
million and $1.2 million, respectively.
ENVIRONMENTAL
The Company accrues for environmental costs as indicated in Note 2. Numerous
local, state and federal laws, rules and regulations relating to the environment
are applicable to the Company's operations. As a result, the Company falls
under the jurisdiction of numerous state and federal agencies and is exposed to
the possibility of judicial or administrative actions for remediation and/or
penalties brought by those agencies. The Refinery is party to one consent
decree requiring the investigation and, in certain instances, mitigation of
environmental impacts resulting from past operational activities. The Company
has been and will be responsible for costs related to compliance with or
remediations resulting from environmental regulations. There are currently no
identified environmental remediation projects of which the costs can be
reasonably estimated. However, the continuation of the present investigative
process, other more extensive investigations over time or changes in regulatory
requirements could result in future liabilities.
LITIGATION
The Company is involved in various lawsuits which are incidental to its
business. In management's opinion, the adverse determination of such lawsuits
would not have a material adverse effect on the Company's financial position or
results of operations.
COLLECTIVE BARGAINING AGREEMENT EXPIRATION
The Company's refining unit hourly employees are represented by seven
bargaining units, the largest being the Paper, Allied-Industrial, Chemical and
Energy Workers International Union ("PACE"). Six AFL-CIO affiliated unions
represent the craft workers. In December 1998, the Company concluded new
bargaining agreements, with the three-year PACE agreement due to expire in July
1999 extended to July 2002, while the six-year AFL-CIO contract due to expire in
June 2002 extended to June 2005. The union employees represent approximately
57% of the Company's work force at December 31, 1998.
7. FAIR VALUE OF FINANCIAL INSTRUMENTS
The fair value of the Company's Senior Notes and Convertible Subordinated
Debentures was estimated based on quotations obtained from broker-dealers who
make markets in these and similar securities. The bank revolving credit
facility is based on floating interest rates and, as such, the carrying amount
is a reasonable estimate of fair value. At December 31, 1998 and 1997, the
carrying amounts of long-term debt instruments (including current maturities)
were $70.0 million and $70.6 million, respectively, and the estimated fair
values were $65.1 million and $72.0 million.
As of December 31, 1998, the Company had entered into futures contracts to
hedge a portion of its natural gas consumption requirements. The futures
contracts are placed with a major financial institution the Company believes is
a minimum credit risk. The futures contracts mature each month through April
1999. The estimated fair value of the Company's open natural gas futures
contract at December 31, 1998 was $(371,000).
8. SALE OF OIL AND GAS OPERATIONS
On June 16, 1997, the Company completed the sale of all its Canadian oil and
gas properties. The transaction was initiated by the Company through a
negotiated bid process in order to maximize shareholder value. The oil and gas
assets were located in British Columbia and Alberta and included approximately
94 billion cubic feet of natural gas, 1.7 million barrels of oil, condensate and
natural gas liquids, 121,500 net undeveloped leasehold acres and a significant
amount of seismic data. Additionally, value was received for certain Canadian
income tax pools of the Company.
The contract purchase price of C$133.6 million was adjusted from the January
1, 1997 effective date of the sale to June 16, 1997. Net proceeds after these
adjustments, transaction expenses and severance costs were approximately C$126.7
million (US$91.3 million) as of June 16, 1997. A net gain of $23.3 million was
realized on the transaction. No Canadian taxes are estimated to be payable due
to available oil and gas deductions and net operating loss carryforwards. For
U.S. federal income taxes,
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available net operating loss carryforwards will be utilized to offset the gain;
however, alternative minimum taxes of approximately $800,000 have been paid.
The cumulative translation adjustment as of May 5, 1997 (the measurement date
of the sale) of $9.9 million was realized against income as a result of the
sale. In prior periods, the Company had recognized the currency translation
impact of its Canadian operations as a direct reduction to shareholders' equity.
Consequently, the recognition of the cumulative translation adjustment in the
accompanying statements of operations has no effect on shareholders' equity. A
net loss of $54,000 from Canadian operations from the measurement date until
June 16, 1997 was included in the gain calculation.
REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS
To the Shareholders of Frontier Oil Corporation:
We have audited the accompanying consolidated balance sheets of Frontier Oil
Corporation (formerly known as Wainoco Oil Corporation) (a Wyoming Corporation)
and subsidiaries as of December 31, 1998 and 1997, and the related consolidated
statements of operations, changes in shareholders' equity and cash flows for
each of the three years in the period ended December 31, 1998. These financial
statements are the responsibility of the Company's management. Our
responsibility is to express an opinion on these financial statements based on
our audits.
We conducted our audits in accordance with generally accepted auditing
standards. Those standards require that we plan and perform the 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 financial statements referred to above present fairly, in
all material respects, the financial position of Frontier Oil Corporation and
subsidiaries as of December 31, 1998 and 1997, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1998, in conformity with generally accepted accounting principles.
ARTHUR ANDERSEN LLP
Houston, Texas
February 5, 1999
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