FINANCIAL REVIEW
Wainoco incurred net losses during 1995 and 1994 of $19.1 million and $12.6
million, respectively. The 1995 loss reflected severely depressed refining
margins and weak Canadian gas prices. In 1994, the loss was the result of a
$17.3 million charge associated with the termination of exploration activities
in the United States and sale of certain oil and gas properties as well as the
write-down of unsold United States properties.
Wainoco's operating income, excluding the restructuring charges and
associated write-downs in 1994, was $2.7 million in 1995 compared to $24.7
million in 1994. Refining operations contributed $1.5 million of operating
income in 1995 compared to $23 million in 1994. Canadian oil and gas operations
contributed $2.7 million of operating income in 1995 compared to $6.1 million
in 1994.
Refined products revenues and refining operating costs are impacted by the
change in the price of crude oil. Generally, the price of crude oil decreased
in 1994 and increased in 1995 and these changes had a corresponding impact on
refined product revenues and refining operating costs.
Oil and gas revenues and operating costs decreased in 1995 because the
Company ceased its United States oil and gas producing activities.
Selling and general expenses decreased 4% in 1995 in response to the
termination of United States oil and gas activities in late 1995. The Company
anticipates a further $2.5 million reduction in 1996 reflecting a full year
without United States oil and gas activities ($1.5 million of selling and
general expenses in 1995) and the downsizing of the Houston office, including
the transfer of corporate accounting and tax responsibilities to the Calgary
office.
Interest expense declined 4% in 1995 after increasing 3% in 1994. During
1995, the Company reduced long-term debt by $25.4 million with the major
portion of the reduction occurring in late December with proceeds from the sale
of the last major United States oil and gas property.
Beginning in 1995, the provision for income taxes increased due to the
reclassification of the Alberta Royalty Tax Credit (ARTC) as oil and gas
revenues whereas it had been classified as a tax benefit in prior years. The
ARTC was $.5 million, $1.1 million and $.6 million in 1995, 1994 and 1993,
respectively.
CANADIAN OIL & GAS OPERATIONS
INFORMATION AND ANALYSIS
(In thousands)
1995 1994 1993
-------- -------- --------
Operating margin $ 14,809 $ 18,461 $ 16,975
Selling and general expenses 2,431 2,189 2,067
Depreciation, depletion and amortization 9,641 10,127 8,793
-------- -------- --------
Operating Income $ 2,737 $ 6,145 $ 6,115
======== ======== ========
The following table presents Canadian production information. Gross volumes
represent Wainoco's working interest plus associated freehold, provincial and
other royalties. This is presented herein because it is equivalent to the
reporting used by other Canadian oil and gas companies.
(Dollars in thousands) 1995 1994 1993
-------- -------- --------
Gross Volume - Oil (bbls) 315,669 266,079 281,583
Natural Gas (mmcf) 17,303 18,120 18,504
Royalty (mmcfe) (2,137) (3,045) (2,863)
Net Volume - Oil (bbls) 283,523 224,450 232,115
Natural Gas (mmcf) 15,359 15,325 15,938
Gross Revenue - Oil $ 4,554 $ 3,381 $ 3,595
Natural Gas 15,532 23,725 21,264
Royalty (2,122) (4,205) (3,609)
Net Revenue - Oil $ 4,099 $ 2,873 $ 2,982
Natural Gas 13,865 20,028 18,268
In 1994, oil and gas revenues increased due to rising gas prices.
During the first nine months of 1994 compared to 1993, gas prices rose 19% to
$1.37 per mcf. However, in late 1994, natural gas prices declined to an
average of $1.10 per mcf in December 1994 versus $1.52 per mcf in December
1993, a decrease of 28%. The gas price deterioration which began in late 1994
continued into 1995, resulting in a decrease in the average price of gas from
$1.31 per mcf in 1994 to $.90 per mcf in 1995. Primarily in response to the
weak gas prices, oil and gas revenues declined 22%.
- 9 -
During 1995, gas production from 1994 discoveries placed on production in
late 1994 or early 1995 offset the loss of approximately 713 mmcf of gas
production from the sale late in 1994 of the Chin Lake property and
productivity declines experienced at most mature fields. During 1994, gas
production from new wells helped offset production declines at various
locations. The decrease in sales volumes during 1994 from the prior year was
mainly attributable to curtailments during the installation or modification of
compression facilities, unscheduled equipment repairs and productivity
declines in some areas.
Other income in 1995 includes a gain of $1.8 million from the sale of a 10%
interest in a Canadian gas marketing company.
Declining gas prices during 1995 and the 1994 fourth quarter adversely
impacted operating income growth by increasing depreciation and depletion
expense as a percentage of revenues. This resulted from lower period end gas
prices being used in computing the quarterly depreciation and depletion
provision than those received during the quarter. Additionally, in 1994
increases in the estimated costs of future site restoration added to the
depletable base.
Operating costs increased $615,000 and $346,000 in 1995 and 1994,
respectively. The increases are attributable to successful drilling of wells in
new areas, costs associated with operating additional compressors to maintain
production levels at maturing areas and, in 1994, unscheduled well workovers
and equipment repairs.
The Canadian oil and gas operations are conducted in Canadian currency. The
financial statements of the Canadian oil and gas operations activities are
translated and reported in United States dollars. This conversion lowered
reported results between 1994 and 1993 due to the decline in the Canadian
dollar. The average Canadian/United States dollar exchange rate dropped 6% in
1994 to U.S. $.73, while remaining relatively flat in 1995.
<Caption
REFINING OPERATIONS
INFORMATION AND ANALYSIS
(In thousands)
1995 1994 1993
-------- -------- --------
Operating margin $ 14,642 $ 35,335 $ 29,823
Selling and general expenses 4,629 4,614 4,785
Depreciation, depletion and amortization 8,471 7,702 6,262
-------- -------- --------
Operating Income $ 1,542 $ 23,019 $ 18,776
======== ======== ========
Refining operating income decreased 93% in 1995 compared to a 23% increase
in 1994. The decline in 1995 was due to extremely poor margins for light
refined products, primarily gasoline and diesel. The increase in 1994 was due
to the improved operating reliability of the refinery and the improved
utilization of all the refinery processing units. The refined product spread
was $4.03 per barrel in 1995 as compared to $5.88 per barrel in 1994 and $5.51
per barrel in 1993.
Despite growth in demand in our market, continued high refinery output
nationwide coupled with high nationwide product inventories at the beginning
of 1995 and increased product pipeline deliveries into our marketing area have
kept margins throughout 1995 significantly lower than in 1994 and 1993. In
1995, Frontier experienced its lowest margins for both gasoline and diesel
since its acquisition by the Company in 1991.
Despite the decline in operating income, Frontier has continued to increase
its sales volumes and improve its operating reliability. The increase in sales
of light refined products was achieved by increasing crude oil input 6% during
1995 with yields of gasoline and distillate up by 7% and 5%, respectively.
Crude oil input increased 2% during 1994 with yields of gasoline and distillate
up 6% and 11%, respectively. The ability in future years to increase the
refinery's crude oil charge and yields of gasoline and distillate is dependent
upon its ability to market its products and its continued operating
reliability.
- 10 -
Refined product revenues increased 6% in 1995 primarily from increased sales
volumes as the average price per barrel increased less than 1%. Refined
product revenues declined 4% in 1994 as sales volumes decreased 1% and the
average price per barrel decreased 2%. The decrease in sales volumes in 1994 is
due to the decrease in the resale of finished products which more than offset
the increased refinery yields. Other income included a settlement of a contract
dispute for a gain of $856,000 in 1995 and insurance settlement proceeds of $1
million in 1993.
Refinery operating costs increased 14% in 1995 and decreased 6% in 1994.
Material costs per barrel increased 12% in 1995 reflecting the worldwide
increase in crude oil prices. Material costs per barrel declined 5% in 1994
reflecting the worldwide decline in crude oil prices.
The sweet/sour spread declined to $2.94 per barrel in 1995 compared to $3.61
per barrel in 1994 and $4.48 per barrel in 1993. The declining sweet/sour
spread is the result of the increased competition for Wyoming sour crude oil
and the increased use of higher priced Canadian and other types of sour crudes.
Factors increasing demand for Wyoming sour crude oil include more sour refining
capacity inside and outside our region, a decline in the production of Wyoming
sour crude oil and a worldwide increase in demand for sour crude oils.
Refinery operating expenses decreased $.26 per barrel to $3.19 in 1995 and
$.10 per barrel to $3.45 in 1994. Operating expenses for 1995 included repair
costs of $1.3 million necessitated by an explosion of natural gas that had
migrated from a leaking pipeline near our refinery. In 1994, repair costs of
$1 million resulting from a fire at the refinery's crude unit were included in
operating expenses. Frontier's steps to reduce operating costs have continued
in 1995 with salaries and benefits decreasing by $1.1 million in 1995 after
being flat in 1994. Although continued reductions are planned, maintenance
problems may arise in the future, resulting in down time of certain processing
units and reduced yields, which may increase operating costs and negatively
impact profitability. No major turnaround work is scheduled for 1996.
Depreciation expense has increased each year due to increasing investment in
the refinery.
UNITED STATES OIL & GAS OPERATIONS
INFORMATION AND ANALYSIS
(In thousands)
1995 1994 1993
-------- -------- --------
Operating margin $ 5,902 $ 9,184 $ 10,059
Selling and general expenses 1,525 2,180 2,110
Depreciation, depletion and amortization 3,299 8,911 7,629
Restructuring charges, primarily
oil and gas property write-downs in 1994 1,701 17,299 0
-------- -------- --------
Operating Income (Loss) $ (623) $(19,206) $ 320
======== ======== ========
In the third quarter of 1994, Wainoco announced its intention to cease all
exploration in the United States and sell its United States oil and gas assets.
During 1995, Wainoco completed the sales process and ended its production
activities in the United States. Wainoco recorded restructuring losses of $1.7
million and $17.3 million in 1995 and 1994, respectively. The 1995
restructuring costs of $1.7 million were net of a $.7 million property
disposition gain. The 1994 loss was comprised of an accrued $10.9 million loss
on sales of properties, a $5.4 million charge for additional DD&A and the
recognition of $1 million in restructuring charges.
Gas production increased in 1994, the result of a 1993 discovery which began
production in February 1994. Average gas prices declined 22% to $1.62 per mcf
in 1995 and were relatively flat in 1994 compared to 1993. Oil production
declined 7% in 1994 due to the sales of marginal properties and natural
reservoir declines. Average oil prices increased 6% in 1995, reversing an 11%
decline in 1994.
Other income in 1995 includes a gain of $2.2 million resulting from the
settlement of a breach-of-contract claim against a former gas purchaser.
Operating costs decreased 11% in 1994, the result of reduced production
taxes reflecting lower sales, cost controls being stressed in an atmosphere of
weak prices and the sale or abandonment of uneconomic wells.
LIQUIDITY AND CAPITAL COMMITMENTS
INTERNAL AND EXTERNAL FUNDING
Net cash provided by operating activities was $9.9 million, $32.1
million and $32.8 million for 1995, 1994 and 1993, respectively.
The Company
- 11 -
reduced debt by $25.4 million and $6.1 million during 1995 and 1994,
respectively, primarily from United States oil and gas property sales. No
new financing was undertaken in 1995 or 1994 whereas the Company sold
common stock in July 1993 and the net proceeds of $20.8 million were used
to retire $5 million of Subordinated Debentures and pay down the Company's
bank lines.
LIQUIDITY AND FUTURE PLANNING
The Company is highly leveraged as reflected by the debt to total
capitalization ratio of 82% at year-end. The Company's leverage will result in
its business prospects being more vulnerable to (1) downward swings in oil and
gas prices and refining margins or to interruptions at the refinery and (2)
if, and to the extent, the Company requires additional financing for working
capital, capital expenditures, debt refinancing or other purposes, the
Company's ability to obtain additional financing. At December 31, 1995, the
Company had $6 million available in cash, $13.1 million available under its oil
and gas line of credit, $20 million available under the Frontier line of
credit and $8 million of Senior Notes held by Wainoco that are available for
resale.
Capital expenditures of approximately $15.5 million are budgeted for
1996, however, the budgeted expenditure level will be adjusted downward if
anticipated cash flow projections are not achieved due to weak product
prices or other negative cash flow impacts. These expenditures are
allocated $5.1 million for the refinery and $10.4 million for Canadian
exploration and development. The refinery's projected capital expenditures
for 1996 are in line with those of 1995 and down substantially from the
$58.4 million incurred during 1993 and 1992 for the refinery capital
improvement program. The Company believes sustaining capital expenditure
requirements at Frontier will be $5 10 million annually. Additionally, to
improve refinery controls over emissions, approximately $2 million may be
required over three years beginning in 1996.
It is anticipated that cash generated by operating activities and available
borrowing capacity will be sufficient to meet 1996 capital needs and the
additional future anticipated costs for emissions control.
The functional currency for the Company's Canadian operations is the
Canadian dollar which year-end rate increased in 1995 after declining over the
prior two years. Accordingly, the Company's Canadian net assets of C$100.2
million at December 31, 1995 are exposed to a certain level of economic risk
stemming from fluctuations in the Canadian/United States dollar exchange rate.
The translation adjustments included in the Company's consolidated statements
of shareholders' equity arise from consolidating its Canadian operations.
Wainoco's credit agreements and Senior Notes currently restrict it from the
payment of dividends. Additionally, under certain conditions, Frontier is
restricted from the transfer of cash in the form of loans or advances to the
parent. Wainoco does not believe these restrictions limit its current
operating plans.
IMPACT OF CHANGING PRICES
The Company's revenues and cash flows, as well as estimates of future cash
flows from oil and gas reserves, 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. Since
energy prices are also a determining factor in the carrying value of oil and
gas assets, any reductions in the prices of oil and natural gas could require
noncash write-downs of those assets.
ENVIRONMENTAL
Numerous local, state and federal laws, rules and regulations relating to
the environment are applicable to the Company's operations and activities. 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. Frontier is party to two consent decrees 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 for 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.
- 12 -
SELECTED QUARTERLY FINANCIAL AND OPERATING DATA
(Unaudited, dollars in thousands except per share and average prices)
1995 1994
-------------------------------------- --------------------------------------
Fourth Third Second First Fourth Third Second First
-------- -------- -------- -------- -------- -------- -------- --------
Revenues $ 90,736 $ 94,295 $100,366 $ 77,348 $ 91,421 $ 99,498 $ 90,590 $ 72,206
Restructuring Charges, primarily
United States Oil and Gas
Property Write-downs 1,701 0 0 0 17,299 0 0 0
Operating Income (Loss) (2,127) 1,533 6,081 (4,479) (13,517) 7,543 6,965 6,364
Net Income (Loss) (7,069) (3,519) 1,054 (9,591) (18,695) 2,612 2,001 1,475
Earnings (Loss) Per Share (.26) (.13) (.04) (.35) (.68) .10 .07 .05
Earnings before Interest, Taxes, Depreciation
Depletion and Amortization and Restructuring
Charges, primarily United States Oil and Gas
Property Write-downs (EBITDA)* 4,569 6,565 11,350 1,636 10,650 14,825 13,597 12,322
Net Cash Provided By Operating Activities 9,867 (1,379) 7,580 (6,190) 13,781 8,329 9,163 835
Oil and Gas Operations (including United States)
Production - Oil (mbbls) 164 145 161 223 218 224 246 232
Gas (bcf) 3.6 3.5 4.5 4.4 4.7 4.7 4.5 4.3
Average sales price - Oil (per bbl) $ 15.14 $ 14.36 $ 16.29 $ 15.42 $ 15.09 $ 15.97 $ 14.86 $ 11.96
Gas (per mcf) .92 .93 .89 .98 1.30 1.41 1.49 1.55
Refining Operations
Total charges (bpd) 41,230 41,209 42,402 36,481 39,581 36,993 36,133 36,442
Sour crude charge rate (%) 84 59 83 84 87 80 80 78
Gasoline yields (bpd) 17,903 17,020 18,485 15,620 16,806 15,859 15,723 16,029
Distillate yields (bpd) 15,125 12,817 15,573 11,430 14,906 11,282 13,325 12,860
Total product sales (bpd) 41,960 42,855 42,264 36,086 40,702 38,551 40,066 35,785
FIVE YEAR FINANCIAL DATA
(In thousands except per share)
1995 1994 1993 1992 1991
-------- -------- -------- -------- --------
Revenues $362,745 $353,715 $366,556 $376,842 $130,067
Restructuring Charges and United States
Oil and Gas Property Write-downs 1,701 17,299 0 0 13,000
Operating Income (Loss) 1,008 7,355 22,210 16,079 (8,713)
Income (Loss) Before Taxes (18,992) (13,442) 1,989 (1,393) (18,909)
Provision (Benefit) For Income Taxes 133 (835) (515) (415) (618)
Net Income (Loss) (19,125) (12,607) 2,504 (978) (18,291)
Earnings (Loss) Per Share (.70) (.46) .10 (.04) (.90)
EBITDA* 24,120 51,394 45,448 39,510 27,308
Net Cash Provided By Operating Activities 9,878 32,108 32,800 23,336 17,513
Working Capital (Deficit) (2,485) 1,532 (1,905) 3,344 (9,156)
Total Assets 238,382 277,536 296,811 291,417 286,604
Long-Term Debt 145,377 170,797 176,900 189,273 154,417
Shareholders' Equity 32,464 49,449 66,040 44,956 53,987
Capital Expenditures 16,131 23,822 40,651 41,761 47,561
Dividends Declared 0 0 0 0 0
*EBITDA is provided supplementally because it is a commonly used measure of
performance in the energy industry. EBITDA is not presented in accordance
with generally accepted accounting principles (GAAP) and should not be used
in lieu of GAAP presentations of results of operations and cash flows.
EBITDA and operating income before depreciation are the same as operating
income before DD&A.
- 13 -
CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands except per share)
For the years ended December 31, 1995 1994 1993
-------- -------- --------
REVENUES
Refined products $329,784 $312,376 $324,504
Oil and gas sales 25,447 39,567 39,137
Other 7,514 1,772 2,915
-------- -------- --------
362,745 353,715 366,556
-------- -------- --------
COSTS AND EXPENSES
Refining operating costs 317,311 277,852 296,255
Oil and gas operating costs 10,202 12,883 13,444
Selling and general expenses 11,112 11,586 11,409
Depreciation, depletion and amortization 21,411 26,740 23,238
Restructuring charges, primarily United States oil
and gas property write-downs in 1994 1,701 17,299 0
-------- -------- --------
361,737 346,360 344,346
-------- -------- --------
OPERATING INCOME 1,008 7,355 22,210
Interest expense, net 20,000 20,797 20,221
-------- -------- --------
INCOME (LOSS) BEFORE INCOME TAXES (18,992) (13,442) 1,989
Provision (benefit) for income taxes 133 (835) (515)
-------- -------- --------
NET INCOME (LOSS) $(19,125) $(12,607) $ 2,504
======== ======== ========
INCOME (LOSS) PER SHARE $ (.70) $ (.46) $ .10
======== ======== ========
The accompanying notes are an integral part of these financial statements.
- 15 -
CONSOLIDATED BALANCE SHEETS
(In thousands except shares)
December 31, 1995 1994
-------- --------
ASSETS
Current Assets -
Cash, including cash equivalents of $1,000 and
$467 at December 31, 1995 and 1994, respectively $ 6,045 $ 5,831
Trade receivables 20,022 17,990
Joint operator and other receivables 2,345 3,209
Inventory of crude oil, products and other 19,736 23,618
Other current assets 708 1,129
-------- --------
Total Current Assets 48,856 51,777
Property, Plant and Equipment - at cost, and
oil and gas properties on a full cost basis 306,725 592,936
Less - Accumulated depreciation, depletion and amortization 122,404 372,937
-------- --------
Net Property, Plant and Equipment 184,321 219,999
Other Assets 5,205 5,760
-------- --------
Total Assets $238,382 $277,536
======== ========
LIABILITIES AND SHAREHOLDERS' EQUITY
Current Liabilities -
Accounts payable $ 35,909 $ 32,991
Oil and gas proceeds payable 2,705 3,421
Accrued interest 5,230 5,602
Accrued turnaround cost 882 2,245
Other accrued liabilities 6,615 5,986
-------- --------
Total Current Liabilities 51,341 50,245
-------- --------
Long-Term Debt 145,377 170,797
Deferred Credits and Other 6,782 4,627
Deferred Income Taxes 2,418 2,418
Commitments and Contingencies
Shareholders' Equity -
Preferred stock, $100 par value, 500,000 shares
authorized, no shares issued 0 0
Common stock, no par, 50,000,000 shares authorized,
27,313,502 shares and 27,310,842 shares issued
in 1995 and 1994, respectively 57,172 57,172
Paid-in capital 81,767 81,758
Retained earnings (deficit) (98,029) (78,904)
Cumulative translation adjustment (8,187) (10,307)
Treasury stock, 57,500 shares and 60,000 shares at
December 31, 1995 and 1994, respectively (259) (270)
-------- --------
Total Shareholders' Equity 32,464 49,449
-------- --------
Total Liabilities and Shareholders' Equity $238,382 $277,536
======== ========
The accompanying notes are an integral part of these financial statements.
- 16 -
CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
For the years ended December 31, 1995 1994 1993
-------- -------- --------
OPERATING ACTIVITIES
Net income (loss) $(19,125) $(12,607) $ 2,504
Adjustments to reconcile net income (loss)
to net cash provided by operating activities
Depreciation, depletion and amortization 21,411 26,740 23,238
Other deferred credits (750) (498) (460)
Restructuring charges, primarily United States
oil and gas property write-downs in 1994 1,701 17,299 0
Gain on sale of Canadian marketing company (1,780) 0 0
Other 1,563 882 598
-------- -------- --------
3,020 31,816 25,880
-------- -------- --------
Changes in components of working
capital from operations
(Increase) decrease in receivables (1,283) (1,624) (668)
(Increase) decrease in inventory 3,884 (2,722) 8,659
(Increase) decrease in other current assets 175 949 (1,137)
Increase (decrease) in accounts payable 4,161 4,258 (684)
Increase (decrease) in accrued liabilities (79) (569) 750
-------- -------- --------
6,858 292 6,920
-------- -------- --------
Net cash provided by operating activities 9,878 32,108 32,800
-------- -------- --------
INVESTING ACTIVITIES
Additions to property, plant and equipment (17,177) (23,802) (42,381)
Sales of oil and gas and other properties 34,145 2,215 2,262
Other (606) (2,045) 1,136
-------- -------- --------
Net cash provided by (used in) investing activities 16,362 (23,632) (38,983)
-------- -------- --------
FINANCING ACTIVITIES
Long-term borrowings - Bank debt 32,500 11,964 27,400
Payments of debt - Bank debt (47,500) (15,664) (37,400)
Senior Notes (8,000) 0 0
Subordinated Debentures (2,500) (2,500) (4,999)
Common stock offering and commitments 0 0 21,725
Other (488) (179) (209)
-------- -------- --------
Net cash provided by (used in) financing activities (25,988) (6,379) 6,517
Effect of exchange rate changes on cash (38) (36) (274)
-------- -------- --------
Increase (decrease) in cash and cash equivalents 214 2,061 60
Cash and cash equivalents, beginning of period 5,831 3,770 3,710
-------- -------- --------
Cash and cash equivalents, end of period $ 6,045 $ 5,831 $ 3,770
======== ======== ========
The accompanying notes are an integral part of these financial statements.
- 17 -
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY
(In thousands except shares)
Common Stock Other
------------------- -------------------------------------
Number of Retained Cumulative Commitment Deferred
Shares Paid-In Earnings Translation To Issue Treasury Employee
Issued Amount Capital (Deficit) Adjustment Common Stock Stock Compensation
---------- ------- ------- -------- ----------- ------------ -------- ------------
DECEMBER 31, 1992 22,122,177 $56,653 $60,513 $(68,801) $ (2,993) $ 0 $ (270) $ (146)
Shares issued in equity offering 5,000,000 500 20,342 0 0 0 0 0
Commitment to issue shares 0 0 0 0 0 883 0 0
Deferred compensation amortization 0 0 0 0 0 0 0 95
Translation adjustment 0 0 0 0 (3,240) 0 0 0
Net income 0 0 0 2,504 0 0 0 0
---------- ------- ------- -------- ----------- ------------ -------- ------------
DECEMBER 31, 1993 27,122,177 57,153 80,855 (66,297) (6,233) 883 (270) (51)
Shares issued under:
Common stock commitment 175,275 18 865 0 0 (883) 0 0
Stock option plan 13,390 1 38 0 0 0 0 0
Deferred compensation amortization 0 0 0 0 0 0 0 51
Translation adjustment 0 0 0 0 (4,074) 0 0 0
Net loss 0 0 0 (12,607) 0 0 0 0
---------- ------- ------- -------- ----------- ------------ -------- ------------
DECEMBER 31, 1994 27,310,842 57,172 81,758 (78,904) (10,307) 0 (270) 0
Shares issued under:
Stock option plan 2,660 0 9 0 0 0 0 0
Directors' stock plan 0 0 0 0 0 0 11 0
Translation adjustment 0 0 0 0 2,120 0 0 0
Net loss 0 0 0 (19,125) 0 0 0 0
---------- ------- ------- -------- ----------- ------------ -------- ------------
DECEMBER 31, 1995 27,313,502 $57,172 $81,767 $(98,029) $ (8,187) $ 0 $ (259) $ 0
The accompanying notes are an integral part of these financial statements.
-18 -
NOTES TO 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 both the crude oil (oil) and natural gas (gas)
exploration, development and production business (oil and gas operations) and
the crude oil refining and wholesale marketing of refined petroleum products
business (refining operations). Based on current levels of capital
expenditures, Wainoco places greatest emphasis on its oil and gas operations.
Wainoco's oil and gas operations efforts are undertaken in western
Canada and the refining operations conducts business 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 fourth quarter of 1994, Wainoco also explored for and
produced oil and gas in the United States. 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.
2
SIGNIFICANT ACCOUNTING POLICIES
PROPERTY, PLANT AND EQUIPMENT
Refining Operations. 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.
Oil and Gas Operations. Wainoco follows the accounting policy (commonly
referred to as full-cost accounting) of capitalizing costs incurred in the
acquisition, exploration and development of oil and gas reserves. The estimated
costs of dismantlement, restoration and abandonment, net of salvage value,
along with other future development costs are added to the costs being
amortized and, when subsequently incurred, are capitalized as part of the
full-cost pool.
Proceeds from sales of oil and gas properties are credited to the
full-cost pool unless the sale is significant, in which case a gain or loss on
the sale is recognized.
Wainoco computes the provision for depreciation, depletion and
amortization (DD&A) of oil and gas properties on a quarterly basis using the
composite unit-of-production method based on future gross revenue attributable
to proved reserves.
Capitalized oil and gas property costs, by country, are limited to the
present value of future net income from estimated production of proved oil and
gas reserves discounted at 10%, plus the value of unproved properties.
Largely as a result of price declines for gas at December 31, 1995,
capitalized oil and gas property costs are approaching the limitation on such
costs, as described above. Further price deterioration during 1996 could result
in a downward revision in the present value of future net income from estimated
production of oil and gas reserves. A downward revision might require Wainoco
to provide an additional provision for depreciation, depletion and amortization
in future periods.
New Accounting Statement. The Company adopted the Financial Accounting
Standards Board's Statement of Financial Accounting Standards No. 121,
Accounting For the Impairment of Long-Lived Assets, in 1995. The oil and gas
properties accounted for under the full-cost method are not affected by this
satement. There was no impairment in the refinery properties.
- 19 -
SCHEDULE OF PROPERTY, PLANT AND EQUIPMENT
(In thousands)
December 31, 1995 1994
-------- --------
Oil and gas properties
Canada $164,711 $151,184
United States 0 303,375
Refinery and pipeline 137,598 132,872
Furniture, fixtures and other 4,416 5,505
-------- --------
$306,725 $592,936
======== ========
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, 1995 1994
-------- --------
Crude oil $ 2,517 $ 6,135
Unfinished products 4,016 3,489
Finished products 6,629 7,737
Chemicals 1,060 1,277
Repairs and maintenance supplies and other 5,514 4,980
-------- --------
$ 19,736 $ 23,618
======== ========
ENVIRONMENTAL EXPENDITURES
Environmental expenditures are expensed or capitalized based upon their
future economic benefit. Costs which improve a property, as compared with the
condition of the property when originally constructed or acquired, 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.
HEDGING
The Company, at times, engages in futures transactions in its refining
operations and oil and gas operations for the purpose of hedging its inventory
position and product prices. Changes in the market value of futures contracts
for the purpose of hedging are included in the measurement of the related
transaction.
INTEREST
Interest is reported net of interest capitalized and interest income.
Interest income of $248,000, $216,000 and $93,000 was recorded in the years
ended December 31, 1995, 1994 and 1993, respectively. During 1993 the Company
capitalized interest of $728,000. 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.
CURRENCY TRANSLATION
The Canadian dollar financial statements of the Canadian division 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.
INTERCOMPANY TRANSACTIONS
Significant intercompany transactions are eliminated in consolidation.
- 20 -
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 debt instruments with a maturity, when purchased, of three
months or less are considered to be cash equivalents. Cash payments for
interest during 1995, 1994 and 1993 were $18.8 million, $19.4 million and $19.7
million, respectively, and cash payments for income taxes during 1995, 1994 and
1993 were $133,000, $116,000 and $124,000, respectively.
3
LONG-TERM DEBT
SCHEDULE OF LONG-TERM DEBT
(In thousands)
December 31, 1995 1994
-------- --------
Credit facilities
Canadian oil and gas $ 0 $ 0
Refining 0 0
United States oil and gas 0 15,000
Senior Notes 92,000 100,000
Convertible Subordinated Debentures 46,000 46,000
Subordinated Debentures 7,377 9,797
-------- --------
$145,377 $170,797
======== ========
OIL AND GAS CREDIT FACILITIES
Wainoco has a long-term credit facility with two banks for its Canadian
oil and gas operations. Interest rates are based, at the Company's option, on
1) the bank's prime rate plus three-quarters of one percent, or 2) LIBOR, at
its prevailing rate, plus one and three-quarters percent. The agreement
provides for a commitment fee of one-half of 1%.
The facility converts to a two-year term loan on December 31, 1997 with
payments commencing on March 31, 1998. The credit agreements can be extended
annually at the option of the lenders. The loan covenants include net worth,
fixed charge coverage ratio and interest coverage ratio requirements.
The bank reviews the oil and gas properties at least annually and make a
determination of the credit to be made available (the borrowing base). If the
bank determines that the unpaid balance on the line is in excess of the
borrowing base, then the Company must either 1) provide additional security to
increase the borrowing base by an amount at least equal to such excess, 2)
repay any such excess, or 3) convert the outstanding balance to a term loan.
The C$18 million (the United States dollar equivalent of approximately
$13.1 million at December 31, 1995) Canadian revolving line of credit is
secured by substantially all of the Canadian oil and gas properties. The
Company may issue up to $1 million in letters-of-credit under the credit
facility of which an $86,000 letter-of-credit was outstanding at December 31,
1995.
The long-term credit facility for the United States oil and gas operations
was terminated in 1995 in conjunction with the sales of the United States oil
and gas properties.
REFINING CREDIT FACILITY
The refining operations credit facility with a group of three banks
expires April 2, 1997, and 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.
At December 31, 1995, there were $12.7 million in standby letters-of-credit
outstanding.
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 .4 of 1%. Interest rates are based, at the Company's option, on the
agent bank's prime rate plus seven-eighths percent or the reserve-adjusted
LIBOR plus two percent. Standby letters-of-credit issued bear a fee of one and
one-quarter percent annually, plus standard issuance and
- 21 -
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 $92 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. In December 1995, the Company utilized proceeds from the sale of
the Conroe property to acquire $8 million of Senior Notes and holds them as
treasury notes.
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 103.875% 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. Based on the effective yield at the time of issuance, the debentures
are not considered common stock equivalents.
SUBORDINATED DEBENTURES
The $7.4 million of 10 3/4% Subordinated Debentures (Subordinated
Debentures), which represent a discount to the $7.5 million face value, are due
in 1998, and are redeemable at 100% of their principal amount at the option of
the Company. Interest is payable semiannually, and sinking fund payments of
$2.5 million for 1997 and $5 million in 1998 are required.
RESTRICTIONS ON LOANS, TRANSFER OF FUNDS
AND PAYMENT OF DEVIDENDS
Under its credit agreements, Wainoco is required to maintain a minimum
consolidated shareholders' equity (as defined) equal to $30 million at December
31, 1995. Additionally, the Frontier credit facility restricts Frontier as to
the distribution of capital assets and the transfer of cash in the form of
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 $2.5 million in
1997, $5 million in 1998 and $2.3 million in 2000.
4
INCOME TAXES
Wainoco files a consolidated United States federal income tax return and a
separate Canadian income tax return. During 1995, the Canadian/United States
income tax convention was amended (the amended tax convention) and will be
implemented beginning January 1, 1996. Under the amended tax convention,
Wainoco will be deemed a resident of the United States and no longer a dual
resident. Wainoco undertook a Canadian tax strategy whereby certain Canadian
net operating losses and oil and gas deductions arising from foreign
exploration and development expenditures were recharacterized as tax asset
basis. The tax asset basis will result in future oil and gas tax deductions
over approximately the next seven years. The strategy will generally allow
Wainoco to have the same available deductions before and after the enactment of
the amended tax convention.
The amended tax convention will have no current impact on Wainoco's tax
provision. However, the Company will no longer be able to deduct corporate
general and administrative overhead and interest expense against Canadian
income for Canadian income tax purposes. The amended tax convention does not
change the existing method of avoiding double taxation through the use of
foreign tax credits.
The following is the pretax income (loss) and the provision (benefit) for
income taxes for the three years ended December 31, 1995, 1994 and 1993.
- 22 -
PRETAX INCOME (LOSS)
(In thousands)
1995 1994 1993
-------- -------- --------
Canada $ 2,052 $ 5,743 $ 5,552
United States (21,044) (19,185) (3,563)
-------- -------- --------
$(18,992) $(13,442) $ 1,989
======== ======== ========
PROVISION (BENEFIT) FOR INCOME TAXES
(In thousands)
1995 1994 1993
-------- -------- --------
Canada - Current $ 133 $ (955) $ (515)
United States - Deferred 0 120 0
-------- -------- --------
$ 133 $ (835) $ (515)
======== ======== ========
The following is a reconciliation of the provision (benefit) for income
taxes computed at the statutory Canadian and 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, 1995, 1994 and 1993.
RECONCILIATION OF TAX PROVISION
(In thousands)
1995 1994 1993
-------- -------- --------
Provision (benefit) based
on statutory rates $ (6,446) $ (3,722) $ 1,241
Increase (decrease) resulting from -
Unutilized net operating loss 6,446 3,722 (1,241)
Canada
Alberta Royalty Tax Credits (ARTC)* 0 (1,075) (621)
Large corporation tax and other 133 120 106
-------- -------- --------
133 (955) (515)
United States 0 120 0
-------- -------- --------
Provision (benefit) as reported $ 133 $ (835) $ (515)
======== ======== ========
*Beginning in 1995, the ARTC is recorded as oil and gas revenues.
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 rates, as of December 31, 1995 and 1994.
COMPONENTS OF DEFERRED TAXES
(In thousands)
December 31, 1995 December 31, 1994
------------------ ------------------
United United
Canada States Canada States
-------- -------- -------- --------
DEFERRED TAX LIABILITIES
Property, plant and equipment
due to differences in DD&A $ 4,646 $ 12,963 $ 6,989 $ 21,022
Installment sale 0 5,435 0 5,435
Other 0 1,910 0 1,509
-------- -------- -------- --------
DEFERRED TAX LIABILITIES 4,646 20,308 6,989 27,966
-------- -------- -------- --------
DEFERRED TAX ASSETS
Tax loss carryforwards 601 41,321 4,798 38,417
Depletion carryforwards 3,851 3,045 3,745 3,045
Tax credit carryforwards 0 1,915 0 2,509
Foreign exploration and
development expenditures 0 0 16,337 0
Tax asset basis with no book basis 25,525 0 0 0
Other 0 3,246 0 2,005
-------- -------- -------- --------
29,977 49,527 24,880 45,976
LESS - VALUATION ALLOWANCE 25,331 31,637 17,891 20,428
-------- -------- -------- --------
NET DEFERRED TAX ASSETS 4,646 17,890 6,989 25,548
======== ======== ======== ========
NET DEFERRED TAX LIABILITIES $ 0 $ 2,418 $ 0 $ 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.
- 23 -
The Company has net operating loss carryforwards for Canadian tax
reporting purposes of $1.3 million which expire in 2002. The Company also has
oil and gas deductions of $117.4 million and earned depletion of $8.6 million
which are available indefinitely to reduce future taxable income.
The Company has net operating loss carryforwards for United States tax
reporting purposes of $117.9 million available to reduce future federal taxable
income. The net operating loss carryforwards will expire as follows: $24.2
million in 1996, $22.7 million in 1997, $4.7 million in 1998, $1.7 million in
2000, $7.6 million in 2001, $3 million in 2003, $15.5 million in 2004, $4.2
million in 2005, $12 million in 2006, $8.7 million in 2007, $3.6 million in
2008 and $10 million in 2010. The Company also has tax depletion carryforwards
of $8.7 million which are indefinitely available to reduce future United States
income taxes payable and $.7 million in investment tax credit carryforwards
available to reduce future United States income taxes payable. The investment
tax credit carryforwards expire in various amounts through 2000.
5
COMMON STOCK
EARNINGS PER SHARE
In 1995 and 1994, the primary and fully diluted earnings per share were
computed based on the average number of shares outstanding and did not assume
the exercise of stock option shares, as losses were incurred. In 1993, the
primary and fully diluted earnings per share were computed based on the average
number of shares outstanding and assumed the exercise of stock option and other
equivalent shares. The primary and fully diluted weighted average shares
outstanding were 27,253,881, 27,335,360 and 24,454,262 in 1995, 1994 and 1993,
respectively. The primary and fully diluted earnings per share for the year
1993 were five cents more than the sum of the 1993 quarters due to the issuance
of five million shares of common stock in July, which had a more significant
impact on the higher earnings of the third and fourth quarters than on the year
taken as a whole.
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,
1995 have reserved for issuance a total of 4,019,000 shares of common stock of
which 1,566,888 shares were granted and exercised, 2,332,842 shares were
granted and were outstanding and 119,270 shares were available to be granted.
As of December 31, 1994, the plans had 596,325 shares available to be granted.
A summary of the plans' activity is set forth in the Stock Option Activity
table. 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.
RESTRICTED STOCK GRANTS
The Company issued 63,900 restricted shares of common stock during 1989.
The value of these shares and related deferred compensation was recorded in
equity. The deferred compensation, based on the market value of the shares
issued, was amortized ratably over a five-year vesting period.
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.
- 24 -
STOCK OPTION ACTIVITY
Option Price
Shares Range
--------- ------------
OUTSTANDING
December 31, 1992 1,608,067 3.50 to 8.50
Granted 428,600 4.13 to 5.00
Exchanged (118,000) 6.88 to 6.88
Lapsed (23,300) 3.50 to 6.71
--------- ------------
December 31, 1993 1,895,367 3.37 to 7.75
Granted 457,400 4.62 to 5.00
Exercised (13,390) 3.50 to 4.21
Exchanged (394,400) 6.33 to 7.20
Lapsed (86,530) 3.50 to 8.50
--------- ------------
December 31, 1994 1,858,447 3.27 to 7.75
Granted 760,500 2.87 to 4.50
Exercised (2,660) 3.50 to 3.50
Exchanged (129,400) 6.43 to 7.75
Lapsed (154,045) 3.50 to 7.75
--------- ------------
December 31, 1995 2,332,842 2.84 to 5.13
--------- ------------
EXERCISABLE
December 31, 1993 1,441,114 3.37 to 7.75
December 31, 1994 1,582,702 3.27 to 7.75
December 31, 1995 1,707,312 2.84 to 5.13
========= ============
ACCOUNTING FOR STOCK-BASED COMPENSATION
The Financial Accounting Standards Board's Statement of Financial
Accounting Standards No. 123, Accounting for Stock-Based Compensation, is
applicable to Wainoco beginning in 1996. Wainoco will disclose such information
under the alternate reporting method in a footnote to the financial statements.
COMMON STOCK OFFERING
The Company sold five million shares of common stock in July 1993 through
a public offering. The net proceeds of $20.8 million were used to pay down
borrowings under its revolving credit facilities and to retire $5 million
principal amount of its Subordinated Debentures which were applied to its 1993
and 1994 sinking fund requirements.
COMMON STOCK ISSUANCE
The Company's Canadian oil and gas division entered into a drilling program in
1993 with a third party and received $883,000 in exchange for 175,275 shares of
its common stock and the distribution of Canadian tax deductions attributable
to certain of the Company's exploration and development activities in Canada.
6
SEGMENT INFORMATION
Wainoco's two business segments are oil and gas operations and refining
operations. Geographically, the oil and gas operations were located in the
United States and Canada. However, Wainoco at December 31, 1995 no longer owns
oil and gas properties in the United States. Income taxes, interest and certain
amounts included in other revenues, selling and general expenses, and
depreciation, depletion and amortization are not allocated to the operating
segments.
The following schedule presents certain operating income (loss) items and
capital expenditures for the three years ended December 31, 1995, and
identifiable assets as of December 31, 1995, 1994 and 1993, by segment by
country.
- 25 -
SEGMENT INFORMATION
(In thousands)
1995 1994 1993
-------- -------- --------
REVENUES
Refining $331,953 $313,187 $326,078
Oil and Gas - Canada 21,096 24,133 22,301
United States and Other 9,696 16,395 18,177
-------- -------- --------
362,745 353,715 366,556
-------- -------- --------
DEPRECIATION, DEPLETION AND AMORTIZATION*
Refining 8,471 7,702 6,262
Oil and Gas - Canada 9,641 10,127 8,793
United States and Other 3,299 14,311 8,183
-------- -------- --------
21,411 32,140 23,238
-------- -------- --------
OPERATING INCOME
Refining 1,542 23,019 18,776
Oil and Gas - Canada 2,737 6,145 6,115
United States and Other (623) (19,206) 320
Unallocated Expenses (2,648) (2,603) (3,001)
-------- -------- --------
1,008 7,355 22,210
-------- -------- --------
CAPITAL EXPENDITURES
Refining 4,989 8,245 26,932
Oil and Gas - Canada 10,865 11,171 6,828
United States and Other 277 4,406 6,891
-------- -------- --------
16,131 23,822 40,651
-------- -------- --------
IDENTIFIABLE ASSETS
Refining 155,515 158,654 156,265
Oil and Gas - Canada 75,229 74,037 76,294
United States and Other 0 40,351 60,207
Unallocated 7,638 4,494 4,045
-------- -------- --------
$238,382 $277,536 $296,811
======== ======== ========
*Includes the United States oil and gas property write-down in 1994.
7
COMMITMENTS AND CONTINGENCIES
LEASE AND OTHER COMMITMENTS
Wainoco has noncapitalized building, equipment and vehicle lease
agreements which expire from 1996 through 2002 having minimum annual payments
as of December 31, 1995 of $2.1 million for 1996, $1.5 million for 1997, $1.3
million for 1998, $.8 million for 1999, $.4 million for 2000 and $.6 million
thereafter. The foregoing includes commitments of $228,000 in 1996, $304,000 in
1997, and $228,000 in 1998 which were recognized as restructuring costs in 1995
as a result of the closing of United States oil and gas operations and the
relocation of the corporate headquarters to a smaller location. Operating lease
rental expense (exclusive of oil and gas lease rentals) was $2.2 million, $1.8
million and $1.2 million for the three years ended December 31, 1995, 1994 and
1993, respectively.
The Company has entered into firm pipeline capacity contracts in Canada to
meet contracted gas supply requirements. The Company's commitment under these
contracts is approximately $3.7 million in 1996, $2.5 million in 1997, $2
million in 1998 to 1999, $1.2 million in 2000, $.6 million in 2001 and $.5
million a year from 2002 to 2009.
CONCENTRATION OF CREDIT RISK
The Company's two operations have 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, jobbers and major oil
companies located primarily in the Denver, western Nebraska and eastern
Wyoming regions, with 11% of its customers accounting for approximately 69%
of total refined product sales. Canadian oil and gas operations sell
primarily to gas aggregators and marketers located in Alberta and British
Columbia, who in turn supply natural gas to a diversified western United
States and Canadian market. 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 1995, the Company made sales to
CITGO Petroleum Corporation of $53.4 million, which accounted for 15% of
consolidated revenues.
- 26 -
CONTRIBUTION PLANS
Wainoco sponsors separate defined contribution plans for Canadian division
employees, United States employees covered by a collective bargaining agreement
and United States 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, 1995, 1994 and 1993 was $1.7 million, $1.9 million and $1.7
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 and activities. 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 two consent decrees 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 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
Wainoco's refining unit hourly employees are covered by two collective
bargaining agreements which expire May 7, 1996. The union employees represent
61% of the refining unit's work force.
8
RESTRUCTURING OF OPERATIONS
In the fourth quarter of 1995, Wainoco culminated the restructuring of
operations announced in the third quarter of 1994. Wainoco has ceased
exploration activities in the United States and sold its domestic oil and gas
assets. The revenues, lease operating expense and DD&A related to these assets
were recorded until the sales closed, which occurred at various times
throughout 1995.
Properties in the process of being sold at December 31, 1994 were recorded
at net realizable value, which was the estimated sales price less cost to sell
and resulted in a loss of $10.9 million. The cost of the remaining United
States oil and gas producing properties at December 31, 1994 was recorded at
the present value of their estimated future net income discounted at 10%, which
resulted in an additional write-down of $5.4 million.
In December 1995, the Company sold all remaining United States oil and gas
properties, primarily the Conroe field, for proceeds of $18.7 million and
recorded a gain of $.7 million.
In connection with the restructuring, Wainoco communicated termination
arrangements with certain of its United States oil and gas operations and
corporate employees. The Company accrued severance and related costs in the
amount of $2.5 million (including $.8 million for office lease abandonment) in
1995 and $1 million in 1994.
Wainoco recorded restructuring losses in 1995 and 1994 (the gain in 1995
and loss in 1994 on the sales of assets, the 1994 additional write-down of
remaining properties and the severance and related costs) in the income
statement under the caption "Restructuring charges, primarily United States oil
and gas properties write-downs in 1994."
- 27 -
9
FAIR VALUE OF FINANCIAL INSTRUMENTS
The fair value of the Company's Senior Notes, Convertible Subordinated
Debentures and 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,
1995 and 1994, the carrying amounts of long-term debt instruments were $145.4
million and $170.8 million, respectively, and the estimated fair values were
$130.8 million and $170.7 million.
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,
1995 and 1994, and the related consolidated statements of operations,
shareholders' equity and cash flows for each of the three years in the period
ended December 31, 1995. 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 Wainoco Oil Corporation and
subsidiaries as of December 31, 1995 and 1994, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1995, in conformity with generally accepted accounting principles.
ARTHUR ANDERSEN LLP
Houston, Texas
February 12, 1996
- 28 -
SUPPLEMENTAL FINANCIAL INFORMATION (UNAUDITED)
The schedules presented in Supplemental Financial Information summarize the
Company's oil and gas exploration and production activities. During 1994, all
United States exploration ceased and certain producing properties were sold,
and during 1995, the remaining oil and gas assets were sold.
The results of operations from oil and gas producing activities are similar
to the segment information disclosure in Note 6 to the financial statements,
but differ as to the level of detail, classification of depreciation on
furniture and fixtures and the inclusion of income taxes. The following
schedule excludes interest expense, net. The income tax expenses were
determined by applying statutory rates to pretax income with adjustments for
tax credits, net operating loss carryforwards and permanent differences. During
1994 and 1993, the Alberta Royalty Tax Credits of $1.1 million and $.6 million,
respectively, were included as credits to income tax expense, whereas in 1995,
the credit of $.5 million was included in revenues from operations.
RESULTS OF OPERATIONS FROM OIL AND GAS PRODUCING ACTIVITIES
(In thousands)
1995 1994 1993
---------------------------- ---------------------------- ----------------------------
United United United
Canada States Total Canada States Total Canada States Total
-------- -------- -------- -------- -------- -------- -------- -------- --------
Revenues from operations $ 21,096 $ 9,817 $ 30,913 $ 24,133 $ 16,595 $ 40,728 $ 22,301 $ 18,177 $ 40,478
Production costs 6,287 3,480 9,767 5,672 6,407 12,079 5,326 7,089 12,415
Production taxes 0 435 435 0 804 804 0 1,029 1,029
Technical support and other 2,500 1,617 4,117 2,238 2,306 4,544 2,111 2,276 4,387
Provision for DD&A 9,572 3,207 12,779 10,080 8,785 18,865 8,759 7,463 16,222
Restructuring charges, primarily
oil and gas property
write-downs in 1994 0 1,701 1,701 0 17,299 17,299 0 0 0
-------- -------- -------- -------- -------- -------- -------- -------- --------
Operating income (loss) 2,737 (623) 2,114 6,143 (19,006) (12,863) 6,105 320 6,425
Income tax expense (benefit) 133 0 133 (835) 0 (835) (515) 0 (515)
-------- -------- -------- -------- -------- -------- -------- -------- --------
Income (loss) from
producing activities $ 2,604 $ (623) $ 1,981 $ 6,978 $(19,006) $(12,028) $ 6,620 320 6,940
Normal DD&A per dollar of
oil and gas sales $ .53 $ .43 $ .50 $ .44 $ .53 $ .48 $ .41 $ .42 $ .41
======== ======== ======== ======== ======== ======== ======== ======== ========
The table on the following page summarizes Wainoco's proved oil and gas
reserves. Oil includes condensate and natural gas liquids, and is stated in
thousands of barrels. Natural gas is stated in millions of cubic feet. For the
years ended December 31, 1995, 1994, 1993 and 1992, Ryder Scott Company
Petroleum Engineers prepared reserve studies comprising 93%, 87%, 93% and 93%,
respectively, of the Company's total discounted reserve value. The Company
prepared reserve studies on the remaining properties. MBOE is defined as a
thousand barrels of oil equivalent and is based on British Thermal Units at a
ratio of six mcf of natural gas to one barrel of oil.
- 29 -
CHANGES IN PROVED OIL AND GAS RESERVE QUANTIITES
Canada United States Total
---------------------------- ---------------------------- ----------------------------
Oil Gas MBOE Oil Gas MBOE Oil Gas MBOE
-------- -------- -------- -------- -------- -------- -------- -------- --------
DEVELOPED AND UNDEVELOPED
December 31, 1992 1,792 150,969 26,954 4,500 43,511 11,753 6,292 194,480 38,707
Revision to previous estimates (172) (18,026) (3,176) (974) 1,332 (752) (1,146) (16,694) (3,928)
Extensions, discoveries and
other additions 171 4,262 881 545 3,622 1,149 716 7,884 2,030
Purchases of reserves-in-place 1 607 102 8 218 44 9 825 146
Production (232) (15,938) (2,888) (747) (2,504) (1,164) (979) (18,442) (4,052)
Sales of reserves-in-place (36) (3,164) (563) (193) (914) (345) (229) (4,078) (908)
-------- -------- -------- -------- -------- -------- -------- -------- --------
December 31, 1993 1,524 118,710 21,310 3,139 45,265 10,685 4,663 163,975 31,995
Revisions to previous estimates (124) 3,025 380 683 (7,319) (537) 559 (4,294) (157)
Extensions, discoveries and
other additions 135 15,857 2,777 226 371 288 361 16,228 3,065
Purchases of reserves-in-place 0 27 4 3 85 17 3 112 21
Production (224) (15,325) (2,777) (696) (2,993) (1,197) (920) (18,318) (3,974)
Sales of reserves-in-place (3) (1,407) (238) (71) (128) (92) (74) (1,535) (330)
-------- -------- -------- -------- -------- -------- -------- -------- --------
December 31, 1994 1,308 120,887 21,456 3,284 35,281 9,164 4,592 156,168 30,620
Revisions to previous estimates 73 385 137 0 0 0 73 385 137
Extensions, discoveries and
other additions 1,255 6,773 2,384 0 0 0 1,255 6,773 2,384
Purchases of reserves-in-place 0 338 56 0 0 0 0 338 56
Production (284) (15,359) (2,844) (409) (593) (508) (693) (15,952) (3,352)
Sales of reserves-in-place 0 (276) (46) (2,875) (34,688) (8,656) (2,875) (34,964) (8,702)
-------- -------- -------- -------- -------- -------- -------- -------- --------
December 31, 1995 2,352 112,748 21,143 0 0 0 2,352 112,748 21,143
-------- -------- -------- -------- -------- -------- -------- -------- --------
DEVELOPED
December 31, 1992 1,726 137,163 24,587 4,486 42,083 11,500 6,212 179,246 36,087
December 31, 1993 1,524 115,628 20,795 3,124 43,837 10,430 4,648 159,465 31,225
December 31, 1994 1,301 119,195 21,167 3,014 35,173 8,876 4,315 154,368 30,043
December 31, 1995 2,343 111,016 20,846 0 0 0 2,343 111,016 20,846
-------- -------- -------- -------- -------- -------- -------- -------- --------
DEVELOPED AS A PERCENTAGE OF TOTAL
December 31, 1992 96% 91% 91% 100% 97% 98% 99% 92% 93%
December 31, 1993 100 97 98 100 97 98 100 97 98
December 31, 1994 99 99 99 92 100 97 94 99 98
December 31, 1995 100 98 99 0 0 0 100 98 99
-------- -------- -------- -------- -------- -------- -------- -------- --------
- 30 -
CAPITALIZED COSTS AND RELATED ACCUMULATED DD&A
(In thousands)
1995 1994
-------- ----------------------------
United
Canada Canada States Total
-------- -------- -------- --------
CAPITALIZED COSTS
Unproved properties $ 6,037 $ 5,940 $ 1,264 $ 7,204
Proved properties 158,674 145,244 302,111 447,355
-------- -------- -------- --------
164,711 151,184 303,375 454,559
ACCUMULATED DD&A 94,265 82,884 269,169 352,053
-------- -------- -------- --------
NET CAPITALIZED COSTS $ 70,446 $ 68,300 $ 34,206 $102,506
======== ======== ======== ========
CAPITALIZED COSTS INCURRED FOR OIL AND GAS ACTIVITITIES
(In thousands)
Unproved Proved
Property Property Exploration Development Total
---------- ---------- ---------- ---------- ----------
1995
Canada $ 3,172 $ 3 $ 4,913 $ 2,670 $ 10,758
United States 0 0 0 253 253
---------- ---------- ---------- ---------- ----------
3,172 3 4,913 2,923 11,011
1994
Canada 2,457 146 5,475 3,020 11,098
United States and Other 163 58 2,781 1,302 4,304
---------- ---------- ---------- ---------- ----------
2,620 204 8,256 4,322 15,402
1993
Canada 1,399 429 3,138 1,841 6,807
United States and Other 980 69 4,294 1,221 6,564
---------- ---------- ---------- ---------- ----------
$ 2,379 $ 498 $ 7,432 $ 3,062 $ 13,371
========== ========== ========== ========== ==========
The preceding tables set forth the capitalized costs and related accumulated
depreciation, depletion and amortization and capitalized costs incurred for oil
and gas activities.
The following tables set forth standardized measure information for proved
reserve quantities. This information is based on the respective prices in
effect as of year-end. Future income taxes are estimated by applying statutory
rates to the excess of future pretax cash flows over the tax basis (including
carryforwards) in the properties involved. Future changes in tax rates are
considered only if legislated by year-end. Tax credits (including
carryforwards) and statutory depletion in excess of cost basis are considered
in determining future income taxes.
- 31 -
STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS RELATING TO PROVED OIL AND GAS RESERVES
1995 1994
-------- ----------------------------
United
Canada Canada States Total
-------- -------- -------- --------
Future cash inflows $152,412 $156,529 $101,061 $257,590
Future production costs 48,126 46,782 42,805 89,587
Future development costs 3,272 3,420 5,849 9,269
-------- -------- -------- --------
Future net inflows before income taxes 101,014 106,327 52,407 158,734
Future income taxes 1,107 1,915 561 2,476
-------- -------- -------- --------
Future net cash flows 99,907 104,412 51,846 156,258
10% discount factor 36,765 36,606 16,189 52,795
-------- -------- -------- --------
Discounted future net cash flows 63,142 67,806 35,657 103,463
-------- -------- -------- --------
Discounted future net cash flows before income taxes $ 63,852 $ 68,865 $ 36,020 $104,885
======== ======== ======== ========
CHANGES IN STANDARDIZED MEASURE OF DISCOUNTED FUTURE NET CASH FLOWS
(In thousands)
Canada United States Total
---------------------------- ---------------------------- ----------------------------
1995 1994 1993 1995 1994 1993 1995 1994 1993
-------- -------- -------- -------- -------- -------- -------- -------- --------
Sales, net of production costs $(11,677) $(17,229) $(15,924) $ (3,568) $ (9,455) $ (9,769) $(15,245) $(26,684) $(25,693)
Net change in sales price and
production costs (10,817) (21,479) 22,807 (450) (11,302) (3,132) (11,267) (32,781) 19,675
Extention, discoveries and other
additions, net of future production
and development costs 14,226 11,417 5,329 0 2,331 9,760 14,226 13,748 15,089
Changes in estimated future
development costs 515 481 3,166 21 (1,079) (709) 536 (598) 2,457
Development costs incurred
during the period that reduced
future development costs 264 409 166 0 22 0 264 431 166
Revisions of quantity estimates 384 1,244 (12,473) 0 (2,421) (3,622) 384 (1,177) (16,095)
Accretion of discount 6,887 8,858 7,681 0 5,644 5,428 6,887 14,502 13,109
Net change in income taxes 349 4,704 (2,098) 363 286 (159) 712 4,990 (2,257)
Purchases of reserves-in-place 65 12 403 0 92 267 65 104 670
Sales of reserves-in-place (313) (356) (629) (32,083) (363) (451) (32,396) (719) (1,080)
Changes in production rates
(timing) and other (4,547) (3,069) 1,235 60 (3,890) 4,391 (4,487) (6,959) 5,626
-------- -------- -------- -------- -------- -------- -------- -------- --------
Net increase (decrease) from
beginning of year $ (4,664) $(15,008) $ 9,663 $(35,657) $(20,135) $ 2,004 $(40,321) $(35,143) $ 11,667
======== ======== ======== ======== ======== ======== ======== ======== ========
- 32 -
CORPORATE INFORMATION
COMMON STOCK
Wainoco's common stock is listed on the New York Stock Exchange and the
Alberta Stock Exchange under the symbol WOL. The quarterly high and low
closing prices as reported on the New York Stock Exchange, rounded to the
nearest one-eighth, are shown in the following table:
High Low
-------- --------
1995
Fourth Quarter $ 3 3/4 $ 2 5/8
Third Quarter 4 3 1/8
Second Quarter 4 3/8 3 5/8
First Quarter 5 3 5/8
1994
Fourth Quarter $ 5 1/2 $ 3 1/2
Third Quarter 5 1/2 3 7/8
Second Quarter 5 7/8 4 1/4
First Quarter 5 1/4 3 5/8
Wainoco has not paid dividends since 1982 and intends to continue following
a policy of retaining funds for other purposes. The number of hodlers of
record for Wainoco Oil Corporation common stock as of February 1, 1996 was
2,386.
REGISTRARS AND TRANSFER AGENTS
Common Stock
Harris Trust and Savings Bank
Chicago, Illinois
12% Senior Notes
Bank One, Texas, N.A.
Houston, Texas
10 3/4% Subordinated Debentures
7 3/4% Convertible Subordinated Debentures
Texas Commerce Bank
Houston, Texas
AUDITORS
Arthur Andersen LLP
Houston, Texas
OFFICERS
James R. Gibbs
President and Chief Executive Officer
Julie H. Edwards
Senior Vice President - Finance and Chief Financial Officer
S. Clark Johnson
Senior Vice President - Refining Operations
Robert D. Jones
Senior Vice President - Canadian Oil and Gas Operations
George E. Aldrich
Vice President - Controller
Gerald B. Faudel
Vice President - Safety and Environmental Affairs
BOARD OF DIRECTORS
Douglas Y. Bech
James R. Gibbs
Paul B. Loyd, Jr.
James S. Palmer
Derek A. Price
Carl W. Schafer
William Scheerer, II (Emeritus)
AVAILABILITY OF FORM 10-K
The Company's annual report on Form 10-K, which is filed with the Securities
and Exchange Commission, is available upon request and may be obtained by
writing:
Mr. Larry E. Bell
Wainoco Oil Corporation
10000 Memorial, Suite 600
Houston, Texas 77024-3411