Management's Discussion and Analysis
General
In 1997 the Company decided to focus entirely on its refining business and to
divest its remaining exploration and production operations. The Company had
previously completed the sale of its domestic oil and gas properties (the "U.S.
Disposition") in 1995, and in June 1997, it closed the sale of all of its
Canadian oil and gas properties (the "Canadian Disposition"). After such
dispositions, the Company's primary continuing operation is the Frontier
Refinery. Accordingly, the Company's operating results for its oil and gas
operations segment, comprising the oil and gas properties divested in the U.S.
Disposition and the Canadian Disposition, are presented as discontinued
operations in the consolidated financial statements.
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.
Results of Operations
1997 Compared with 1996. The Company had net income for the year ended
December 31, 1997 of $19.1 million or $0.69 per share, compared to a loss of
$6.9 million or ($0.25) 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 material costs) 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 which
more than offset inventory losses in the first quarter of 1997 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 $0.05 per bbl increase in
average gasoline sales prices. Refined product sales volumes were nearly the
same for the 1997 and 1996 periods.
Other income increased $1.1 million to $2.3 million for the year ended
December 31, 1997 as compared to 1996 mostly due to foreign currency transaction
gains 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 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
- 10 -
spread increased 38% to average $3.54 per bbl for the year ended December 31,
1997 because the Company contracted for 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 has
contracted for an average of 29,000 bpd of Wyoming and Canadian heavy crudes at
a light/heavy spread ranging from $4.80 to $5.25 per bbl. Refining operating
expenses increased by $0.15 per bbl to $3.30 due to higher maintenance and
turnaround costs and leased equipment costs offset by decreased natural gas and
utility costs. Prior year operating expenses were reduced by a $1.3 million
settlement of repair costs rela ted to a 1995 pipeline gas explosion. Although
efforts 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 major turnaround is scheduled in the spring of 1998 on
the fluid catalytic cracking unit and alkylation and related units. These units
are scheduled to be down for 28 days, which will decrease average yields during
that time. Other turnaround work is scheduled for several Refinery units during
1998, but this work should not materially impact yields.
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 $0.2 million of salary and salary-related expenses of certain
employees who were not retained after March 31, 1996, in connection with the
U.S. Disposition in late 1995 and a corporate reorganization 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 $2.0 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.
1996 Compared with 1995. Operating income increased $6.7 million, or 605%, in
1996 compared to 1995. Such increase was attributable to improved refined
product spread of $5.9 million, reduced operating costs of $1.2 million and
reduced selling and general costs of $0.9 million, offset by a decrease in other
income of $0.8 million and an increased depreciation expense of $0.5 million.
The 1995 other income was related to a settlement of a contract dispute.
Refined products revenues and refining operating costs are impacted by
changes in the price of crude oil. Generally, the price of crude oil remained
strong throughout 1996 compared to a lower average price in 1995. The refined
product spread increased 11%, to $4.48 per bbl, in 1996. Lower national
distillate inventory levels in 1996 contributed to the improved diesel margins;
however, a continued decline in the light/heavy spread in 1996 compared to 1995
increased material costs. The adverse impact of higher crude oil prices
significantly reduced margins for by-products, such as asphalt, in 1996 compared
to 1995 levels. In 1996, refined product revenues increased 16% from 1995 due to
a $3.84 per bbl increase in average sales price, offset by a 2% decrease in
sales volumes.
- 11 -
Refining operating costs increased $45.2 million, or 14%, in 1996 compared to
1995 due to a 17% increase in material costs associated with the strong
worldwide crude oil market, offset by a reduction in the refining operating
expenses of $1.2 million. During 1996, Frontier increased its use of heavy crude
oil by 17% which favorably impacted material costs. The heavy crude oil
utilization rate expressed as a percent of total crude oil increased to 88% in
1996 from 77% in 1995. The favorable impact of the increased use of heavy crude
oil in 1996 was offset somewhat by the continued decline in the light/heavy
spread during 1996. In 1996, the light/heavy spread declined 13% from 1995 to
average $2.56 per bbl as a result of increased competition for Wyoming heavy
crude oil and other sources of heavy crude oil in the Company's market area.
However, in the fourth quarter of 1996, the Frontier Refinery experienced an
increase in the light/heavy spread when it contracted for delivery in 1997 of
approximately 25,000 bpd of Wyoming heavy crude oil at a light/heavy spread of
$3.25 to $3.75 per bbl. The $1.2 million decrease in refinery operating expenses
in 1996 was primarily attributable to recovery in the first quarter of 1996 of
approximately $1.3 million of repair costs related to a pipeline gas explosion
in 1995. The repair costs approximating $1.3 million in 1995, and related
recovery in 1996, were both included in refinery operating expense. During 1996,
refinery operating expenses were reduced in various categories including
insurance and turnaround expense; however, these savings were offset by cost
increases associated with higher natural gas prices and general maintenance
costs. The strike by approximately 150 union employees which commenced May 8,
1996 and settled July 29, 1996 did not adversely impact operating costs or
throughput. The increase in depreciation expense reflected in 1996 of $500,000,
or 6%, from 1995 was primarily attributable to ongoing capital investment in the
Frontier Refinery.
Selling and general expenses decreased $0.9 million, or 12%, to $6.3 million
in 1996 compared to 1995 due to a reduction in corporate staff after the U.S.
Disposition. Additionally, 1996 included approximately $0.2 million in expenses
for corporate staff who were retained until March 31, 1996.
Net interest expense decreased $1.0 million, or 5%, in 1996 compared to 1995
as a result of lower average debt balance outstanding throughout 1996 with
proceeds from the U.S. Disposition applied to reduce debt primarily in December
1995.
Discontinued oil and gas operations includes both Canadian and United States
oil and gas operations. Income from discontinued operations was $4.8 million in
1996 compared to $211,000 in 1995.
Liquidity and Capital Resources
On June 16, 1997, the Company completed the Canadian Disposition. Net
proceeds after purchase price adjustments, transaction expenses and severance
costs were approximately $91.3 million (C$126.7 million). With proceeds from the
sale, the Company redeemed $49.2 million of its 12% Senior Notes, including
redemption premium, during the third quarter of 1997, and on October 1, 1997,
redeemed the remaining $7.5 million outstanding of 10-3/4% Subordinated
Debentures at par. In addition, on December 30, 1997, the Company redeemed $25.6
million of its 12% Senior Notes, including redemption premium. In total, $79.9
million principal amount of debt was retired with sales proceeds. As of December
31, 1997, the Company had a debt to capitalization ratio of 56% compared to the
highly leveraged percentage of 85% as of year-end 1996.
On February 9, 1998, the Company issued $70 million of 9-1/8% Senior Notes
(the "New Senior Notes") due 2006. On February 10, 1998, the Company called for
redemption the remaining $24.6 million of its Senior Notes and $46 million of
its Convertible Subordinated Debentures outstanding at December 31, 1997
(together, the "Redemptions"). The Company will use the net proceeds from the
issuance of the New Senior Notes and available cash to fund the Redemptions. To
the extent the holders of the Convertible Subordinated Debentures elect to
convert their Convertible Subordinated Debentures into shares of the Company's
common stock prior to redemption, a portion of the net proceeds will not be
needed to effect such redemption. Depending on market conditions, the Company
may use any such excess proceeds to repurchase shares of its common stock in the
open market. Any remaining unused proceeds will be used for general corporate
purposes.
- 12 -
At December 31, 1997, the Company had $21.7 million available in cash, $20
million available under the Frontier Credit Facility and $250,000 of 12% Senior
Notes held by Wainoco. The Company had working capital of $20.9 million at
December 31, 1997, including the portion of the sales proceeds from the Canadian
Disposition remaining after debt retirement.
Net cash provided by operating activities was $12.5 million, $8.5 million and
$9.9 million for 1997, 1996 and 1995, respectively. Working capital changes
required $9.9 million and $2.6 million of cash flows for 1997 and 1996,
respectively. 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.
Investing activities in 1997 included capital expenditures of $9.0 million, a
decrease of $4.4 million from 1996, primarily due to a $5.4 million decrease in
oil and gas operations investment. Investing activities include proceeds from
the Canadian Disposition of $91.3 million for the year ended December 31, 1997.
Capital expenditures were $13.4 for the year ended December 31, 1996 compared to
$17.2 million in 1995. Refinery capital expenditures of $13 million are planned
in 1998. It is anticipated that cash generated from operating activities will
be sufficient to meet its 1998 investing requirements.
The Company's 12% Senior Notes currently restrict it from the payment of
dividends. Additionally, under certain conditions, the Frontier credit facility
restricts the transfer of cash in the form of dividends, loans or advances to
the Company from Frontier. Wainoco does not believe these restrictions limit its
current operating plans.
Other Matters
IMPACT OF CHANGING PRICES/HEDGING
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 and the price of refined products can result in large changes in
operating margin from refining operations. Energy prices also determine the
carrying value of the Refinery's inventory.
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
future transactions has been limited to protect against price declines for
excess inventory volumes. Futures contracts and options may also, in the future,
be used to fix margins in its refining and marketing operations. 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.
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 estimates that the
Title III regulations will require the Company to expend 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. 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.
- 13 -
YEAR 2000
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
computer technology essential to its operations that may be affected by the Year
2000 issue. A review of the Company's primary computer accounting system
indicated only minor modifications will be required to make it Year 2000
compliant. Reviews are being done to determine what actions will be necessary to
make its remaining computer systems Year 2000 compliant. The Company expects to
complete its remaining reviews and prepare cost estimates by mid-1998.
SELECTED QUARTERLY FINANCIAL AND OPERATING DATA
1997 1996
(Unaudited, dollars in thousands --------------------------------------- ---------------------------------------
except per share) Fourth Third Second First Fourth Third Second First
-------- -------- -------- -------- -------- -------- -------- --------
Revenues $ 82,410 $108,108 $ 96,330 $ 89,570 $100,448 $107,039 $100,320 $ 75,566
Operating income (loss) 3,489 14,743 9,045 (5,574) (513) 3,178 5,921 (3,001)
Income (loss) from
continuing operations 1,505 11,806 4,534 (10,033) (4,716) (1,262) 1,545 (7,211)
Income from discontinued
operations, net of taxes (1) - - 13,606 1,554 2,497 294 192 1,769
Income (loss) before
extraordinary item 1,505 11,806 18,140 (8,479) (2,219) (968) 1,737 (5,442)
Extraordinary loss,
net of taxes 1,295 2,622 - - - - - -
Net income (loss) 210 9,184 18,140 (8,479) (2,219) (968) 1,737 (5,442)
Basic and diluted earnings
(loss) per share:
Continuing operations 0.05 0.42 0.17 (0.37) (0.17) (0.05) 0.06 (0.26)
Net income (loss) 0.01 0.33 0.66 (0.31) (0.08) (0.04) 0.06 (0.20)
EBITDA (2) 5,826 17,037 11,311 (3,301) 1,740 5,467 8,186 (790)
Net cash provided by (used in)
operating activities 5,698 11,620 9,245 (14,065) 14,420 1,358 1,140 (8,453)
Refining operations
Total charges (bpd) 39,215 44,907 42,341 38,623 40,659 43,718 42,296 38,070
Heavy crude
charge rate (%) 92 91 92 90 97 87 84 84
Gasoline yields (bpd) 15,834 18,679 16,456 17,268 14,775 17,900 16,969 17,668
Diesel yields (bpd) 11,393 12,936 13,676 13,441 14,973 13,129 14,169 12,570
Total product sales (bpd) 36,036 46,205 41,848 38,105 38,946 44,248 40,910 36,579
Average light/heavy spread based on
layed-in crude costs (per bbl) $ 3.82 $ 3.54 $ 3.32 $ 3.48 $ 2.63 $ 2.51 $ 2.58 $ 2.53
(1) Discontinued operations reflected in the above periods represent the
Company's oil and gas operating segment, comprising the Canadian and United
States oil and gas properties. On June 16, 1997, the Company completed the
Canadian Disposition. The Company completed the U.S. Disposition during
1995.
(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.
- 14 -
FIVE YEAR FINANCIAL DATA
(In thousands except per share) 1997 1996 1995 1994 1993
-------- -------- -------- -------- --------
Revenues $376,418 $383,373 $331,832 $313,187 $326,138
Operating income (loss) 21,703 5,585 (1,106) 20,416 15,700
Income (loss) from continuing operations 7,812 (11,644) (19,336) 1,693 (2,232)
Income (loss) from discontinued operations,
net of taxes (1) 15,160 4,752 211 (14,300) 4,736
Income (loss) before extraordinary item 22,972 (6,892) (19,125) (12,607) 2,504
Extraordinary loss, net of taxes 3,917 - - - -
Net income (loss) 19,055 (6,892) (19,125) (12,607) 2,504
Basic and diluted earnings (loss) per share:
Continuing operations 0.28 (0.43) (0.71) 0.06 (0.09)
Net income (loss) 0.69 (0.25) (0.70) (0.46) 0.10
EBITDA (2) 30,873 14,603 7,365 28,118 22,566
Net cash provided by operating activities 12,498 8,465 9,878 32,108 32,800
Working capital (deficit) 20,928 (3,752) (2,485) 1,532 (1,905)
Total assets 177,915 239,865 238,382 277,536 296,811
Long-term debt 70,572 145,928 145,377 170,797 176,900
Shareholders' equity 55,934 25,269 32,464 49,449 66,040
Capital expenditures from continuing operations 5,675 4,760 5,217 7,979 28,700
Dividends declared - - - - -
(1) Discontinued operations reflected in the above periods represent the
Company's oil and gas operating segment, comprising the Canadian and United
States oil and gas properties. On June 16, 1997, the Company completed the
Canadian Disposition. The Company completed the U.S. Disposition during
1995.
(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.
- 15 -
FIVE YEAR OPERATING DATA
1997 1996 1995 1994 1993
-------- -------- -------- -------- --------
Charges (bpd)
Light crude 3,162 4,322 8,098 6,165 6,581
Heavy crude 31,967 31,677 27,174 27,025 25,909
Other feed and blend stocks 6,154 5,192 5,072 4,105 2,957
Total charges 41,283 41,191 40,344 37,295 35,447
Manufactured product yields (bpd)
Gasoline 17,060 16,825 17,263 16,106 15,129
Diesel 12,856 13,712 13,744 13,094 11,777
Asphalt and other 10,200 9,215 7,951 6,575 7,128
Total manufactured product yields 40,116 39,752 38,958 35,775 34,034
Product sales (bpd)
Gasoline 20,499 20,311 20,767 19,437 19,837
Diesel 12,110 12,561 13,265 12,628 11,819
Asphalt and other 7,949 7,306 6,781 6,724 7,682
Total product sales 40,558 40,178 40,813 38,789 39,338
Average sales price (per sales bbl)
Gasoline $ 28.83 $ 28.78 $ 24.68 $ 24.57 $ 25.24
Diesel 27.22 28.89 23.48 23.48 25.06
Asphalt and other 13.13 13.21 11.73 12.18 12.00
Operating margin information (per sales bbl)
Average sales price $ 25.27 $ 25.98 $ 22.14 $ 22.06 $ 22.60
Material costs 19.49 21.50 18.11 16.18 17.09
Product spread 5.78 4.48 4.03 5.88 5.51
Operating expenses excluding depreciation 3.30 3.15 3.19 3.45 3.55
Depreciation 0.61 0.59 0.55 0.53 0.42
Operating margin 1.87 0.74 0.29 1.90 1.54
Average light/heavy spread based on layed-in
crude costs (per bbl) $ 3.54 $ 2.56 $ 2.94 $ 3.61 $ 4.48
- 16 -
Consolidated Statements of Operations
(In thousands except per share amounts)
For the years ended December 31, 1997 1996 1995
--------- --------- ---------
Revenues:
Refined products $ 374,091 $ 382,098 $ 329,784
Other 2,327 1,275 2,048
--------- --------- ---------
376,418 383,373 331,832
--------- --------- ---------
Costs and Expenses:
Refining operating costs 337,495 362,485 317,311
Selling and general expenses 8,050 6,285 7,156
Depreciation 9,170 9,018 8,471
--------- --------- ---------
354,715 377,788 332,938
--------- --------- ---------
Operating Income (loss) 21,703 5,585 (1,106)
Interest expense, net 13,891 17,229 18,230
--------- --------- ---------
Income (loss) from continuing operations
before income taxes 7,812 (11,644) (19,336)
Provision for Income Taxes - - -
--------- --------- ---------
Income (loss) from continuing operations 7,812 (11,644) (19,336)
Discontinued operations
Income from oil and gas operations, net of taxes 1,721 4,752 211
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 22,972 (6,892) (19,125)
Extraordinary loss on retirement of debt, net of taxes 3,917 - -
--------- --------- ---------
Net income (loss) $ 19,055 $ (6,892) $ (19,125)
========= ========= =========
Basic and diluted earnings (loss) per share
of common stock:
Continuing operations $ .28 $ (.43) $ (.71)
Discontinued operations .55 .18 .01
Extraordinary loss (.14) - -
--------- --------- ---------
Net Income (Loss) $ .69 $ (.25) $ (.70)
========= ========= =========
The accompanying notes are an integral part of these financial statements.
- 17 -
Consolidated Balance Sheets
(In thousands except shares)
December 31, 1997 1996
--------- ---------
Assets
Current assets:
Cash, including cash equivalents of $19,981 and $609 at
December 31, 1997 and 1996, respectively $ 21,735 $ 5,183
Trade receivables 16,674 19,422
Other receivables 530 1,357
Inventory of crude oil, products and other 27,666 29,617
Other current assets 1,391 730
--------- ---------
Total current assets 67,996 56,309
--------- ---------
Property, plant and equipment, at cost:
Refinery and pipeline 149,201 143,172
Furniture, fixtures and other equipment 3,044 3,646
Oil and gas properties, on a full-cost basis - 170,879
--------- ---------
152,245 317,697
Less - accumulated depreciation, depletion and amortization 45,586 139,091
--------- ---------
106,659 178,606
Other assets 3,260 4,950
--------- ---------
Total assets $ 177,915 $ 239,865
========= =========
Liabilities and Shareholders' Equity
Current Liabilities:
Accounts payable $ 33,527 $ 43,789
Accrued turnaround cost 6,771 3,490
Accrued liabilities and other 5,240 5,033
Accrued interest 1,530 5,249
Current maturities of long-term debt - 2,500
--------- ---------
Total current liabilities 47,068 60,061
--------- ---------
Long-Term Debt, net of current maturities 70,572 145,928
Deferred Credits and Other 2,801 6,189
Deferred Income Taxes 1,540 2,418
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,
28,111,289 shares and 27,313,502 shares
issued in 1997 and 1996, respectively 57,251 57,172
Paid-in capital 84,785 81,767
Retained earnings (deficit) (85,866) (104,921)
Cumulative translation adjustment - (8,501)
Treasury stock, 52,500 shares and 55,000 shares
at December 31, 1997 and 1996, respectively (236) (248)
--------- ---------
Total shareholders' equity 55,934 25,269
--------- ---------
Total liabilities and shareholders' equity $ 177,915 $ 239,865
========= =========
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, 1997 1996 1995
--------- --------- ---------
Operating activities
Net income (loss) $ 19,055 $ (6,892) $ (19,125)
Gain on disposal of Canadian oil and gas properties (23,301) - -
Recognition of cumulative translation adjustment 9,862 - -
Extraordinary loss on retirement of debt 3,917 - -
Depreciation, depletion and amortization 13,018 17,141 21,411
Other (202) 795 734
--------- --------- ---------
22,349 11,044 3,020
--------- --------- ---------
Changes in components of working capital from operations
(Increase) decrease in receivables 905 765 (1,283)
(Increase) decrease in inventory 1,856 (9,881) 3,884
(Increase) decrease in other current assets (642) (35) 175
Increase (decrease) in accounts payable (8,617) 7,659 4,161
Increase (decrease) in accrued liabilities (3,353) (1,087) (79)
--------- --------- ---------
(9,851) (2,579) 6,858
--------- --------- ---------
Net cash provided by operating activities 12,498 8,465 9,878
--------- --------- ---------
Investing activities
Additions to property, plant and equipment:
Continuing operations (5,675) (4,760) (5,217)
Discontinued operations (3,298) (8,654) (11,960)
Sales of oil and gas and other properties 91,307 990 34,145
Other (590) 429 (606)
--------- --------- ---------
Net cash provided by (used in) investing activities 81,744 (11,995) 16,362
--------- --------- ---------
Financing activities
Borrowings:
Senior notes 2,000 3,000 -
Payments of debt:
Bank debt, net - - (15,000)
Senior notes, including redemption premium (74,932) - (8,000)
Subordinated debentures (7,500) - (2,500)
Issuance of common stock 3,109 - -
Other (357) (345) (488)
--------- --------- ---------
Net cash provided by (used in) financing activities (77,680) 2,655 (25,988)
Effect of exchange rate changes on cash (10) 13 (38)
--------- --------- ---------
Increase (decrease) in cash and cash equivalents 16,552 (862) 214
Cash and cash equivalents, beginning of period 5,183 6,045 5,831
--------- --------- ---------
Cash and cash equivalents, end of period $ 21,735 $ 5,183 $ 6,045
========= ========= =========
The accompanying notes are an integral part of these financial statements.
- 19 -
Consolidated Statements of Shareholders' Equity
Common Stock
-----------------------
Number Retained Cumulative
of Shares Paid-In Earnings Translation Treasury
(In thousands except shares) Issued Amount Capital (Deficit) Adjustment Stock Total
----------- --------- --------- ---------- ----------- --------- ---------
December 31, 1994 27,310,842 $ 57,172 $ 81,758 $ (78,904) $ (10,307) $ (270) $ 49,449
Shares issued under:
Stock option plan 2,660 - 9 - - - 9
Directors' stock plan - - - - - 11 11
Translation adjustment - - - - 2,120 - 2,120
Net loss - - - (19,125) - - (19,125)
----------- --------- --------- ---------- ----------- --------- ---------
December 31, 1995 27,313,502 57,172 81,767 (98,029) (8,187) (259) 32,464
Shares issued under:
Directors' stock plan - - - - - 11 11
Translation adjustment - - - - (314) - (314)
Net loss - - - (6,892) - - (6,892)
----------- --------- --------- ---------- ----------- --------- ---------
December 31, 1996 27,313,502 57,172 81,767 (104,921) (8,501) (248) 25,269
Shares issued under:
Stock option plan 797,787 79 3,018 - - - 3,097
Directors' stock plan - - - - - 12 12
Translation adjustment - - - - (1,361) - (1,361)
Net income - - - 19,055 - - 19,055
Disposition of Canadian assets - - - - 9,862 - 9,862
----------- --------- --------- ---------- ----------- --------- ---------
December 31, 1997 28,111,289 $ 57,251 $ 84,785 $ (85,866) $ - $ (236) $ 55,934
=========== ========= ========= ========== =========== ========= =========
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 Wainoco Oil Corporation, a
Wyoming corporation, and its wholly-owned subsidiaries, including Frontier
Holdings Inc. ("Frontier"), collectively referred to as Wainoco or the Company.
Wainoco is engaged in the crude oil refining and wholesale marketing of refined
petroleum products business (the "refining operations").
Wainoco 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, Wainoco 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"). On June 16, 1997, Wainoco
completed the sale of all its Canadian oil and gas properties. During the third
quarter of 1994, the Company announced that it intended to cease all exploration
activities in the United States and during 1995 completed the sale of its United
States oil and gas assets. Operating results for Wainoco'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
Refinery plant and equipment is depreciated based on the straight-line method
over estimated useful lives of three to twenty 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.
NEW ACCOUNTING STATEMENTS
The Company adopted the Financial Accounting Standards Board's ("FASB")
Statement of Financial Accounting Standard ("SFAS") No. 128, "Earnings Per
Share" in 1997 which establishes new standards for computing and presenting
earnings per share. SFAS No. 128 requires the presentation of basic and diluted
earnings per share for each period presented. Earnings (loss) per share has been
restated for periods presented to give effect for the adoption of SFAS No. 128.
In June 1997, the FASB issued SFAS No. 130 "Reporting Comprehensive Income"
which establishes standards for reporting and displaying comprehensive income
and its components in the financial statements. SFAS No. 130 is effective for
fiscal years beginning after December 15, 1997. The adoption of this statement
requires incremental financial statement disclosures and thus will have no
effect on the Company's financial position or results of operations.
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 cost.
SCHEDULE OF COMPONENTS OF INVENTORY
(In thousands)
December 31, 1997 1996
--------- ---------
Crude oil $ 3,904 $ 2,863
Unfinished products 6,338 7,024
Finished products 9,929 12,816
Chemicals 1,534 851
Repairs and maintenance supplies and other 5,961 6,063
--------- ---------
$ 27,666 $ 29,617
========= =========
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.
- 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 $2.0 million, $109,000 and $140,000 was recorded in the years
ended December 31, 1997, 1996 and 1995, respectively. During 1996, the Company
capitalized interest of $24,000. Wainoco capitalizes interest on debt incurred
to fund the construction or acquisition of a significant asset.
Additionally, to manage its interest cost and exposure to interest rate
movements, the Company, at times, enters into interest rate swaps. Such
agreements effectively change the Company's interest rate exposure. At December
31, 1997, the Company was not subject to any such agreements.
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, 1997, 1996 and 1995.
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 are included in the consolidated statements of operations
currently, and translation adjustments are included in the consolidated
statements of shareholders' equity. See Note 3 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.
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
1997, 1996 and 1995 were $18.4 million, $16.3 million and $18.8 million,
respectively. Cash payments for income taxes during 1997, 1996 and 1995 were
$930,000, $187,000 and $133,000, respectively.
3 Sale of Oil and Gas Operations
On June 16, 1997, Wainoco 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, available net operating loss carryforwards will be
utilized to offset the gain; however, alternative minimum taxes of approximately
$800,000 are estimated and have been paid.
- 22 -
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, Wainoco 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. As of December 31,
1997, the assets and liabilities of the Canadian operations retained by Wainoco
were not material.
In the fourth quarter of 1995, Wainoco culminated the restructuring of
exploration activities in the United States and sold its last domestic oil and
gas assets.
The following schedule presents certain discontinued oil and gas operating
income (loss) information and capital expenditures for the three years ended
December 31, 1997, 1996 and 1995 and identifiable assets as of December 31,
1997, 1996 and 1995:
(in thousands)
December 31, 1997 1996 1995
--------- --------- ---------
Oil and gas sales
Canada $ 7,280 $ 19,592 $ 21,096
United States - 987 9,696
Depreciation, depletion and amortization
Canada 3,002 8,123 9,641
United States - - 3,299
Operating income (loss)
Canada 1,954 4,129 2,737
United States - 987 (623)
Capital expenditures
Canada 2,815 7,917 10,865
United States - - 277
Identifiable assets
Canada - 74,001 75,229
United States - - -
4 Long-term Debt
SCHEDULE OF LONG-TERM DEBT
(in thousands)
December 31, 1997 1996
--------- ---------
Refining credit facility $ - $ -
12% Senior Notes 24,572 95,000
7-3/4% Convertible Subordinated Debentures 46,000 46,000
10-3/4% Subordinated Debentures - 7,428
--------- ---------
70,572 148,428
Less current maturities - 2,500
--------- ---------
$ 70,572 $ 145,928
========= =========
REFINING CREDIT FACILITY
The refining operations has a working capital credit facility with a group of
three banks which expires on April 2, 1999. 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. No debt was outstanding on this facility at
December 31, 1997 and 1996. Standby letters of credit outstanding were $4.5
million and $19.5 million at December 31, 1997 and 1996, respectively.
The facility provides working capital financing for operations, generally the
financing of crude and product supply. It is generally secured by Frontier'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% 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 facility agreement includes certain financial covenant
requirements relating to Frontier's working capital, cash earnings, tangible net
worth and fixed charge coverage.
SENIOR NOTES
The $24.6 million of unsecured 12% Senior Notes ("Senior Notes") are due
2002. The notes are redeemable, at the option of the Company, at a premium of
103.43% after July 31, 1997, declining to 100% in 1999. Interest is payable
semiannually. See Note 9 for information related to the December 31, 1997 debt
balance and activity subsequent thereto.
- 23 -
CONVERTIBLE SUBORDINATED DEBENTURES
The $46 million of 7-3/4% Convertible Subordinated Debentures ("Convertible
Subordinated Debentures") are due in 2014. The debentures are convertible into
the Company's common stock at $8.75 per share. Interest is payable semiannually.
The debentures are redeemable at a premium of 102.325% declining to 100% in
1999. Sinking fund payments of 5% of the principal amount commence in 2000, and
are calculated to retire 70% of the principal amount prior to maturity. See Note
9 for information related to the December 31, 1997 debt balance and activity
subsequent thereto.
EARLY RETIREMENT OF DEBT
On July 21, 1997, the Company initiated a tender offer for $91.4 million of
its Senior Notes at a price of par as required by the Senior Notes Indenture
after a material sale of assets. The par tender offer expired on August 20, 1997
with approximately $2.2 million being acquired by the Company. On August 21,
1997, the Company called $48.0 million principal amount of its Senior Notes
(including approximately $2.5 million held by the Company) at a price of 103.43%
and redeemed them on September 23, 1997. The Company called all $7.5 million
principal amount of 10-3/4% Subordinated Debentures and redeemed them on October
1, 1997. In addition, on November 25, 1997 the Company called $25.0 million
principal amount of its Senior Notes (including approximately $.3 million held
by the Company) at a price of 103.43% and redeemed them on December 30, 1997.
The debt redemptions were funded with proceeds from the sale of the Canadian oil
and gas operations as disclosed in Note 3. Based on the redemptions, the Company
has recognized an extraordinary loss, net of taxes, of approximately $3.9
million due to the redemption premium of 103.43% on the Senior Notes and
reduction in debt issuance costs.
RESTRICTIONS ON LOANS, TRANSFER OF FUNDS AND PAYMENT OF DIVIDENDS
The Frontier credit facility restricts Frontier 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 estimated five-year maturities of long-term debt are none in 1998 and
1999, $2.3 million in 2000 and 2001, and $26.9 million in 2002.
5 Income Taxes
The following is the provision (benefit) for income taxes for the three years
ended December 31, 1997, 1996 and 1995.
PROVISION (BENEFIT) FOR INCOME TAXES
(In thousands) 1997 1996 1995
--------- --------- ---------
Current $ 194 $ - $ -
Deferred (194) - -
--------- --------- ---------
$ - $ - $ -
========= ========= =========
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, 1997, 1996 and 1995.
RECONCILIATION OF TAX PROVISION
(In thousands) 1997 1996 1995
--------- --------- ---------
Provision (benefit)
based on
statutory rates $ 2,656 $ (4,242) $ (6,563)
--------- --------- ---------
Increase (decrease)
resulting from:
Net operating
loss carryforward (2,656) 4,242 6,563
--------- --------- ---------
Provision
as reported $ - $ - $ -
========= ========= =========
- 24 -
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, 1997 and 1996.
COMPONENTS OF DEFERRED TAXES
(In thousands)
December 31, 1997 1996
--------- ---------
Deferred tax liabilities
Property, plant and equipment due to
differences in depreciation $ 14,189 $ 14,874
Installment sale 5,435 5,435
Other 918 1,415
--------- ---------
Deferred tax liabilities 20,542 21,724
--------- ---------
Deferred tax assets
Tax loss carryforwards 50,960 34,944
Depletion carryforwards 3,045 3,045
Tax credit carryforwards - 1,209
Other 3,069 3,151
--------- ---------
57,074 42,349
--------- ---------
Less - valuation allowance 38,072 23,043
--------- ---------
Net deferred tax assets 19,002 19,306
--------- ---------
Net deferred tax liabilities $ 1,540 $ 2,418
--------- ---------
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, 1997, the Company had regular net operating loss ("NOL")
carryforwards for United States tax reporting purposes of $145.6 million
available to reduce future federal taxable income. The regular NOL carryforwards
will expire as follows: $32.2 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, 1997, the Company had alternative minimum tax net
operating loss ("AMT NOL") carryforwards for United States tax reporting of
$98.4 million to reduce future taxable income. The AMT NOL carryforwards will
expire as follows: $2.8 million in 2002, $5.4 million in 2003, $9.0 million in
2004, $27.0 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 tax depletion carryforwards of $8.7 million which are
indefinitely available to reduce future United States income taxes payable.
As of December 31, 1996, the Company had net operating loss carryforwards for
Canadian tax reporting purposes of $2.1 million which expire in 2003. The
Company also had oil and gas deductions of $116.7 million and earned depletion
of $8.6 million which are available indefinitely to reduce future taxable
income. In June 1997, these tax benefits were acquired by the purchaser of the
Canadian oil and gas properties.
6 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, 1997, 1996
and 1995.
1997 1996 1995
----------------------------------- ----------------------------------- -----------------------------------
(In thousands,
except per share Income Shares Per Share Income Shares Per Share Income Shares Per Share
amounts) (Numerator) (Denominator) Amount (Numerator) (Denominator) Amount (Numerator) (Denominator) Amount
----------- ------------- --------- ----------- ------------- --------- ----------- ------------- ---------
Basic EPS
Income (loss) from
continuing operations $ 7,812 27,457 $ .28 $ (11,644) 27,257 $ (.43) $ (19,336) 27,256 $ (.71)
Dilutive securities
Stock options - 494 - - - -
Dilutive EPS
Income (loss) from
continuing operations $ 7,812 27,951 $ .28 $ (11,644) 27,257 $ (.43) $ (19,336) 27,256 $ (.71)
- 25 -
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 portion 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 initially held in treasury. The Company made grants to
directors under this plan of 2,500 shares in 1997, 1996 and 1995.
STOCK OPTION PLANS
Wainoco has three stock option plans which authorize the granting of
restricted stock and options to purchase shares. The plans through December 31,
1997 have reserved for issuance a total of 4,282,700 shares of common stock of
which 2,364,675 shares were granted and exercised, 1,656,340 shares were granted
and were outstanding and 261,685 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 five-year terms.
A summary of the status of the Company's plans as of December 31, 1997, 1996
and 1995, and changes during the years ended on those dates is presented below.
1997 1996 1995
---------------------- ---------------------- ----------------------
Weighted- Weighted- Weighted-
Average Average Average
Number Exercise Number Exercise Number Exercise
of Options Price of Options Price of Options Price
---------- --------- ---------- --------- ---------- ---------
Outstanding at beginning of year 2,331,904 $ 3.81 2,332,842 $ 4.32 1,858,447 $ 4.84
Granted 742,800 4.74 981,229 3.31 760,500 4.34
Exercised (797,787) 3.89 - - (2,660) 3.50
Reissued - - (669,229) 4.30 (129,400) 7.39
Expired (620,577) 3.48 (312,938) 4.53 (154,045) 5.55
---------- --------- ---------- --------- ---------- ---------
Outstanding at end of year 1,656,340 4.31 2,331,904 3.81 2,332,842 4.32
---------- --------- ---------- --------- ---------- ---------
Exercisable at end of year 940,850 4.14 1,526,561 4.04 1,707,312 4.41
---------- --------- ---------- --------- ---------- ---------
Available for grant at end of year 261,685 68,208 119,720
---------- ---------- ----------
Weighted-average fair value of
options granted during the year 1.51 .65 1.04
The following table summarizes information about stock options outstanding at
December 31, 1997:
Options Outstanding Options Exercisable
------------------------------------------------- ------------------------------
Number Weighted-Average Weighted-
Outstanding Remaining Weighted-Average Exercisable Weighted-Average
Range of exercise prices at 12/31/97 Contractual Life Exercise Price at 12/31/97 Exercise Price
----------- ---------------- ---------------- ----------- ----------------
$2.88 to $7.82 1,656,340 3.23 $ 4.31 940,850 $ 4.14
Had compensation costs been determined based on the fair value at the grant
dates for awards made in 1997, 1996 and 1995, the Company's net income (loss)
and income (loss) per share would have been the pro forma amounts indicated on
the following page for the years ended December 31, 1997, 1996 and 1995.
- 26 -
(In thousands,
except per share amounts) 1997 1996 1995
--------- --------- ---------
Net income (loss):
As reported $ 19,055 $ (6,892) $ (19,125)
Pro forma 18,578 (7,263) (19,316)
Basic and diluted income (loss)
per share:
As reported $ .69 $ (.25) $ (.70)
Pro forma .67 (.27) (.71)
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%, 5.33% and 6.54%, expected
volatilities of 41.07%, 32.95% and 38.11%, expected lives of 2.32, 1.59 and 1.93
years and no dividend yield in 1997, 1996 and 1995, respectively.
7 Commitments and Contingencies
LEASE AND OTHER COMMITMENTS
Wainoco has noncapitalized building, equipment and vehicle lease agreements
which expire from 1998 through 2005 having minimum annual payments as of
December 31, 1997 of $2.5 million for 1998, $3.9 million for 1999, $489,000 for
2000, $396,000 for 2001, $202,000 for 2002, $42,000 each for 2003 and 2004 and
$25,000 in 2005. Operating lease rental expense was $2.6 million, $1.7 million
and $1.7 million for the three years ended December 31, 1997, 1996 and 1995,
respectively.
The Company has contracted for pipeline capacity of approximately 13,800 bpd
on the Express Pipeline from Hardisty, Alberta to Guernsey, Wyoming commencing
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 also has commitments to purchase crude oil from various
suppliers 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 13% of its customers
accounting for approximately 66% of total refined product sales in 1997. Wainoco
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 1997, the
Company made sales to CITGO Petroleum Products of approximately $72 million,
which accounted for 19% of consolidated revenues.
CONTRIBUTION PLANS
Wainoco 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 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, 1997, 1996 and 1995 was $1.3 million, $1.2
million and $1.4 million, respectively.
ENVIRONMENTAL
Wainoco accrues for environmental costs as indicated in Note 1. 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. 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.
LITIGATION
The Company is involved in various lawsuits which are incidental to its
business. In management's opinion, the adverse determination of
- 27 -
such lawsuits would not have a material adverse effect on the Company's
financial position or results of operations.
COLLECTIVE BARGAINING AGREEMENT EXPIRATION
Wainoco's refining unit hourly employees are represented by seven bargaining
units, the largest being the Oil, Chemical and Atomic Workers International
Union ("OCAW"). Six AFL-CIO affiliated unions represent the craft workers. In
July 1996, the Company concluded new bargaining agreements, with the three-year
OCAW agreement to expire in July 1999, while the six-year AFL-CIO contract
expires in June 2002. The union employees represent approximately 58% of the
Company's work force at December 31, 1997.
8 Fair Value of Financial Instruments
The fair value of the Company's Senior Notes, Convertible Subordinated
Debentures and 10-3/4% Subordinated Debentures was estimated based on quotations
obtained from broker-dealers who make markets in these and similar securities.
The bank credit facilities are based on floating interest rates and, as such,
the carrying amount is a reasonable estimate of fair value. At December 31, 1997
and 1996, the carrying amounts of long-term debt instruments (including current
maturities) were $70.6 million and $148.4 million, respectively, and the
estimated fair values were $72.0 million and $145.0 million.
As of December 31, 1997, 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
1998. The fair value of the Company's open natural gas futures contract at
December 31, 1997 was $(281,000).
9 Subsequent Event
DEBT REFINANCING
February 9, 1998, the Company issued $70 million of 9-1/8% Senior Notes (the
"New Senior Notes") due 2006. On February 10, 1998, the Company called for
redemption the remaining $24.6 million of its Senior Notes and $46 million of
its Convertible Subordinated Debentures outstanding at December 31, 1997
(together, the "Redemptions"). The Company will use the net proceeds from the
issuance of the New Senior Notes and available cash to fund the Redemptions.
Report of Independent Public Accountants
TO THE SHAREHOLDERS OF WAINOCO OIL CORPORATION:
We have audited the accompanying consolidated balance sheets of Wainoco Oil
Corporation (a Wyoming corporation) and subsidiaries as of December 31, 1997 and
1996, and the related consolidated statements of operations, shareholders'
equity and cash flows for each of the three years in the period ended December
31, 1997. 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 over 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 Wainoco Oil Corporation and
subsidiaries as of December 31, 1997 and 1996, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1997, in conformity with generally accepted accounting principles.
ARTHUR ANDERSEN LLP
Houston, Texas
February 10, 1998
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