financial review
10 management's discussion and analysis
17 consolidated statements of operations
18 consolidated balance sheets
19 consolidated statements of cash flows
20 consolidated statements of shareholders' equity
21 notes to consolidated financial statements
28 report of independent public accountants
29 supplemental financial information (unaudited)
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Page 10
management's discussion and analysis
The following information is provided to assist understanding of the 1996, 1995
and 1994 consolidated financial statements and accompanying notes of Wainoco Oil
Corporation and its wholly-owned subsidiaries.
operating results
summary
In 1996, operating income increased $9.7 million to $10.7 million from $1.0
million in 1995. The improvement in operating results was primarily due to a
$6.2 million increase in refining operations, a $1.4 million increase in
Canadian oil and gas operations and $2.1 million in selling and general expense
savings associated with termination of the United States oil and gas operations
and associated corporate restructuring. In 1996, no operating results are
reflected for the United States oil and gas operations other than $1.0 million
included in other income related to the reduction of certain accruals
established previously, versus an operating loss of $.6 million reported in
1995.
Operating income as reported decreased $6.4 million to $1.0 million in 1995
from $7.4 million in 1994. Excluding restructuring charges and write-downs
related to termination of the United States oil and gas operations of $1.7
million in 1995 and $17.3 million in 1994, operating income decreased $22.0
million to $2.7 million in 1995 from $24.7 million in 1994. Refining operating
income dropped $21.5 million from 1994 as a result of extremely poor margins for
light refined products, primarily gasoline and diesel. Canadian oil and gas
operating income decreased $3.4 million from 1994 levels as a result of weaker
gas prices resulting in lower gas revenues and a higher average effective
depreciation and depletion rate.
Wainoco's reported net loss of $6.9 million in 1996 reflected an improvement
of $12.2 million from the $19.1 million loss reported in 1995. Other income in
1996 includes $1.0 million due to the reduction of certain accruals associated
with the disposition of United States oil and gas operations. In 1995, other
income included $4.9 million of nonrecurring items. These included $.9 million
received in the settlement of a contract dispute included in refining operating
income, the sale by the Canadian oil and gas operations of its interest in a
Canadian gas marketing company for a net gain of $1.8 million and settlement by
the United States oil and gas operations of a breach of contract claim against a
former gas purchaser in amount of $2.2 million.
The net loss of $19.1 million in 1995 was $6.5 million higher than the $12.6
million net loss reported in 1994. Excluding the restructuring charges and
write-downs related to termination of the United States oil and gas operations
of $1.7 million in 1995 and $17.3 million in 1994, the net loss was $22.1
million higher in 1995 than 1994.
canadian oil and gas operations
The following table summarizes oil and gas production activities:
Increase Increase
(dollars in millions) 1996 (Decrease) 1995 (Decrease) 1994
-------- ---------- -------- ---------- --------
Operating margin $ 14.6 (1%) $ 14.8 (20%) $ 18.4
Selling and general expenses 2.4 0% 2.4 9% 2.2
Depreciation, depletion and
amortization 8.1 (16%) 9.7 (4%) 10.1
-------- ---------- -------- ---------- --------
Operating income $ 4.1 52% $ 2.7 (56%) $ 6.1
-------- ---------- -------- ---------- --------
Natural gas:
Net revenue $ 12.9 (7%) $ 13.9 (31%) $ 20.0
Net sales volume (bcf) 12.5 (19%) 15.4 1% 15.3
Average sales price:
US$/mcf $ 1.03 14% $ 0.90 (31%) $ 1.31
C$/mcf $ 1.40 13% $ 1.24 (31%) $ 1.79
Oil and liquids:
Net revenue $ 5.9 44% $ 4.1 41% $ 2.9
Net sales volume (mbbls) 329 16% 284 27% 224
Average sales price:
US$/bbl $ 17.83 23% $ 14.46 13% $ 12.80
Canadian operating income increased $1.4 million or 52% in 1996 versus 1995
due to improved oil and gas revenues of $.8 million, reduced operating costs of
$1.3 million and reduced depreciation and depletion expense of $1.6 million,
offset by a nonrecurring gain on sale of its interest in a gas marketing company
of $1.8 million in 1995 and a general reduction of joint venture overhead and
other fees of $.5 million from 1995 associated with a lower level of capital
expenditures. Oil and gas revenues increased $.8 million or 4% to $18.7 million
in 1996 versus 1995 as a result of higher oil and gas prices and oil volumes,
partially offset by a decrease in gas volumes. Oil revenue increased 44% due to
a 23% improvement in oil price reflective of the strong market for oil sustained
throughout 1996 and the 16% improvement in oil volumes resulting from production
throughout the entire year from prospects primarily developed throughout 1995.
The 7% decrease in gas revenue in 1996 is attributable to a 19% decline in sales
volumes, partially offset by a 14% increase in average gas price in 1996. The
1996 decline in gas volumes resulted from the Company's decision to sell
non-core high operating cost producing properties, from numerous lengthy
unanticipated production interruptions as a result of various operating problems
encountered by a major third party gas processing and transmission company and
as a result of normal production declines.
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Page 11
Although the average gas price increase reflected in 1996 increased 14% to
$1.03/mcf, the entire increase is attributable to price escalations experienced
during the fourth quarter of 1996. By comparison, the average gas price for the
first nine months of 1996 was $.89/mcf versus $.90/mcf in 1995. The average gas
price for the fourth quarter of 1996 was $1.43/mcf, an increase of 59% over
$.90/mcf in 1995. The average gas price for December of 1996 was $2.05/mcf
versus $1.01/mcf in 1995, a 103% increase. Operating expenses decreased 21% to
$5.0 million in 1996 primarily as a result of continued focus on cost reduction,
including the disposition of various non-core high operating cost properties for
proceeds approximating $1.0 in 1996. Depreciation and depletion expense
decreased 16% in 1996 of which $2.0 million was attributable to a rate decrease
in 1996, offset by $.4 million related to the higher sales revenues in 1996. The
aforementioned significant gas price increase in the fourth quarter of 1996
yielded $1.1 million of the $2.0 million depreciation and depletion rate savings
realized over the entire year. The average depreciation and depletion rate for
the year decreased to 43% in 1996 from 53% in 1995, while the fourth quarter
rate decreased to 31% in 1996 from 49% in 1995.
Canadian operating income decreased $3.4 million or 56% in 1995 versus 1994
due to decreased oil and gas revenues of $4.9 million, increased operating costs
of $.6 million and reduced depreciation and depletion expenses of $.4 million.
In 1995, the Company realized a gain on the sale of its interest in a gas
marketing company of $1.8 million. Oil and gas revenues decreased $4.9 million
or 21% to $18.0 million in 1995 versus 1994 as a result of a major decline in
gas prices, partially offset by an increase in oil volumes and prices. In 1995,
gas prices continued the decline that commenced during the fourth quarter of
1994, and the 31% decline in average gas price resulted in a 31% revenue decline
of $6.1 million from 1994. Gas production from 1994 discoveries placed on stream
in late 1994 or early 1995 offset production loss from a property sale in late
1994 and normal production declines experienced at most mature fields. An oil
volume increase of 27% in 1995 due to oil prospects discovered in 1994
commencing production in late 1994 and throughout 1995, together with a 13% oil
price increase in 1995, resulted in increased oil revenue of $1.2 million or 41%
in 1995 versus 1994. Operating costs increased $.6 million or 11% in 1995 over
1994 due to production costs of new wells on stream and costs associated with
newly installed compressors to maintain gas production at maturing fields.
Depreciation and depletion decreased 4% in 1995 versus 1994 due to lower oil and
gas revenues subject to depletion in 1995 versus 1994, partially offset by an
increased depletion rate in 1995 caused by the decline in gas prices during
1995. The average depreciation and depletion rate for the year increased to 53%
in 1995 from 44% in 1994.
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. The average Canadian/United
States dollar exchange rate remained relatively flat approximating US $.73 in
1996, 1995 and 1994.
The following table is provided to allow comparability with the operating
results of Canadian based oil and gas companies that report sales on a gross
before royalty basis:
Increase Increase
(dollars in millions) 1996 (Decrease) 1995 (Decrease) 1994
-------- ---------- -------- ---------- --------
Natural gas
- gross before royalty:
Revenue $ 14.4 (7%) $ 15.5 (35%) $ 23.7
Sales volume (bcf) 14.0 (19%) 17.3 (4%) 18.1
Average sales price:
US$/mcf $ 1.03 14% $ 0.90 (31%) $ 1.31
C$/mcf $ 1.40 13% $ 1.24 (31%) $ 1.79
Oil and liquids
- gross before royalty:
Revenue $ 6.6 43% $ 4.6 35% $ 3.4
Sales volume (mbbls) 371 17% 316 19% 266
Average sales price:
US$/bbl $ 17.83 23% $ 14.46 13% $ 12.80
refining operations
The following table summarizes refining activities:
Increase Increase
(dollars in millions) 1996 (Decrease) 1995 (Decrease) 1994
-------- ---------- -------- ---------- --------
Operating margin $ 20.9 43% $ 14.6 (59%) $ 35.3
Selling and general expenses 4.2 (9%) 4.6 0% 4.6
Depreciation, depletion and
amortization 8.9 5% 8.5 10% 7.7
-------- ---------- -------- ---------- --------
Operating income $ 7.8 420% $ 1.5 (93%) $ 23.0
-------- ---------- -------- ---------- --------
Refining information:
Total charges (bpd) 41,191 2% 40,344 8% 37,295
Sour crude charge rate (%) 88% 14% 77% (5%) 81%
Gasoline yields (bpd) 16,825 (3%) 17,263 7% 16,106
Distillate yields (bpd) 13,712 0% 13,744 5% 13,094
Total product yields (bpd) 39,752 2% 38,958 9% 35,775
Total product sales (bpd) 40,178 (2%) 40,813 5% 38,789
Refined product spread ($/bbl) $ 4.48 11% $ 4.03 (31%) $ 5.88
Sweet/sour spread ($/bbl) $ 2.56 (13%) $ 2.94 (19%) $ 3.61
Operating expense ($/bbl) $ 3.15 (1%) $ 3.19 (8%) $ 3.45
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Refining operating income increased $6.3 million or 420% in 1996 versus 1995.
This was due to improved refined product margins of $5.9 million, reduced
operating costs of $1.2 million and reduced selling and general costs of $.4
million, offset by a decrease in other income of $.9 million and increased
depreciation and depletion expense of $.4 million. The 1995 other income was
related to 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 versus a lower
average price in 1995, resulting in a $52.3 million or 16% increase in refined
products revenues and corresponding $46.4 million or 17% increase in material
costs in 1996 versus 1995. The refined product spread increased 11% to $4.48/bbl
in 1996. Lower national distillate inventory levels in 1996 contributed to the
improved diesel margins, however a continued erosion in the sweet/sour spread in
1996 from 1995, increased material costs and the adverse impact of higher crude
prices significantly reduced margins for by-products such as asphalt in 1996
from 1995 levels. The Refinery has continued to increase its crude charge and
product yield rates over the last four year period, with both rates increasing
2% in 1996 over 1995 levels. Gasoline yields decreased 3% in 1996 due to
increased sour crude rates and reduced purchases of gasoline blend stocks.
Diesel yields in 1996 remained flat with 1995 levels. The ability in future
years to increase the Refinery's crude oil charge and yields is dependent upon
market conditions and its continued operating reliability.
In 1996, refined product revenues increased 16% due to a $3.84/bbl increase
in average sales price, offset by a 2% decrease in sales volumes. Refinery
operating costs increased $45.2 million or 14% in 1996 due to a 17% increase in
material costs associated with the strong worldwide crude market, offset by a
reduction in refinery operating expenses in 1996 of $1.2 million. During 1996,
the Refinery increased its use of sour crude oil by 17% which favorably impacted
material costs. The sour crude utilization rate expressed as a percent of total
crude increased to 88% in 1996 from 77% in 1995. The favorable impact of the
increased use of sour crude in 1996 was offset somewhat by the continued decline
in the sweet/sour spread during 1996. The sweet/sour spread declined 13% to
average $2.56/bbl in 1996, as a result of increased competition for Wyoming sour
crude oil and alternate sour crudes. However, in the fourth quarter of 1996, the
Refinery experienced an increase in the sweet/sour spread when they contracted
for delivery in 1997 of approximately 25,000 bpd of Wyoming sour crude oil at a
sweet/sour spread of $3.25 to $3.75/bbl. Further, the completion of the 172,000
bpd Express Pipeline, expected in the second quarter of 1997, will allow
additional supplies of Canadian heavy crude into the Refinery's market, which
may further influence the sweet/sour spread to the Refinery's benefit. The
Refinery has contracted for 13,800 bpd of pipeline capacity on Express Pipeline.
The $1.2 million decrease in refinery operating expenses in 1996 is 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. Although focus
to reduce operating costs will continue, maintenance problems may arise in the
future, resulting in downtime of certain processing units and reduced yields
which may increase operating costs and negatively impact profitability. A major
turnaround is scheduled in the fourth quarter of 1997 on the crude unit and
reformer unit. These units are scheduled to be down for 10 and 14 days,
respectively, which will decrease average yields during that time. Other
turnaround work is scheduled for several Refinery units during 1997, but this
work should not materially impact yields. The increase in depreciation expense
reflected in 1996 of $.4 million or 5% is primarily attributable to ongoing
capital investment in the Refinery.
In 1995, refining operating income decreased $21.5 million or 93% versus 1994
due to a collapse in margins for both gasoline and distillate of $23.3 million,
offset by reduced operating costs of $1.3 million and an increase in other
income of $1.3 million (of which $.9 million related to settlement of a contract
dispute reflected in 1995) and increased depreciation and depletion expense of
$.8 million. Refined products revenues increased $17.4 million or 6%, offset by
$40.7 million or 18% increase in material costs in 1995 versus 1994. As a
result, the refined product spread plunged 31% to $4.03/bbl in 1995 versus $5.88
in 1994. High nationwide refining output and inventory levels, together with
increased product pipeline deliveries into our marketing area depressed 1995
margins to the lowest levels since acquisition of the Refinery in 1991. The
price of crude oil increased throughout 1995 versus a lower average price in
1994 which adversely impacted material costs in 1995 versus 1994. In addition,
the sweet/sour spread declined 19% to $2.94/bbl in 1995. In 1995, the Refinery
increased its crude charge rate by 6% and product yield rates by 9% over 1994
levels, including increased yields of gasoline and distillate up by 7% and 5%,
respectively. The improvement in yield rate in 1995 was reflective of the
improved reliability in 1995 versus the adverse impact downtime associated with
a crude unit fire and maintenance turnaround work performed on two of the
Refinery's major operating units had on yields in 1994.
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In 1995, refined product revenues increased $17.4 million or 6% primarily due
to a 5% increase in sales volumes, while average prices increased less than 1%.
Increased sales volumes are primarily associated with the improved reliability
of the Refinery in 1995 and lack of major maintenance turnarounds performed in
1995 versus 1994. Refinery operating costs increased $39.5 million or 14% in
1995 due to an 18% increase in material costs associated with the increased cost
of crude and increased crude rate in 1995, offset by a decrease in refinery
operating expense in 1995 of $1.3 million. The Refinery's utilization of sour
crude remained unchanged from 1994 to 1995, but with the 8% increase in total
charge rate in 1995, the sour crude utilization rate expressed as a percent of
total crude decreased to 77% in 1995 from 81% in 1994. The $.67/bbl decline in
the sweet/sour spread in 1995 adversely impacted our material costs in 1995
compared with 1994, and was the result of increased competition for Wyoming sour
crude and alternate sour crudes in our market. In 1995, refinery operating
expense decreased $1.3 million or 3% from 1994 levels, related to decreased
salaries and benefits of $1.1 million, and related to reductions in many cost
categories such as natural gas offset by increases in others such as increased
maintenance. Maintenance costs of $1.0 million associated with the crude unit
fire are included in 1994, while repair costs of $1.3 million associated with a
pipeline gas explosion are reflected in refinery operating expense in 1995. The
increase in depreciation expense reflected in 1995 of $.8 million or 10% is
primarily attributable to increases in capital investment.
united states oil and gas operations
The following table summarizes activities related to the United States oil
and gas operations which were discontinued and all related assets sold during
1995:
Increase Increase
(dollars in millions) 1996 (Decrease) 1995 (Decrease) 1994
-------- ---------- -------- ---------- --------
Operating margin $ 1.0 (83%) $ 5.9 (36%) $ 9.2
Selling and general expenses - - 1.5 (32%) 2.2
Depreciation, depletion and
amortization - - 3.3 (63%) 8.9
Restructuring charges, primarily
property write-downs in 1994 - - 1.7 (90%) 17.3
-------- ---------- -------- ---------- --------
Operating income $ 1.0 267% $ (0.6) 97% $ (19.2)
-------- ---------- -------- ---------- --------
Natural gas:
Net revenue - - $ 1.0 (84%) $ 6.2
Net sales volume (bcf) - - 0.6 (80%) 3.0
Average sales price ($/mcf) - - $ 1.62 (22%) $ 2.08
Oil and liquids:
Net revenue - - $ 6.5 (38%) $ 10.4
Net sales volume (mbbls) - - 409 (41%) 696
Average sales price ($/bbl) - - $ 15.94 6% $ 14.99
In the third quarter of 1994, the Company 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 are net of a $.7 million property gain. The 1994 loss
was comprised of an accrued $10.9 million loss on sales of properties, a $5.4
million charge for additional depreciation and depletion and the recognition of
$1.0 million in restructuring charges. Other income in 1996 includes $1.0
million due to the reduction of certain accruals associated with the disposition
of United States oil and gas operations as these issues were resolved.
other expenses
Total selling and general expenses decreased $2.5 million or 23% to $8.6
million in 1996, of which $2.0 million is associated with the termination of
United States oil and gas operations in 1995 and transfer of corporate
accounting and tax responsibilities to the Calgary office in 1996. Additionally,
1996 includes approximately $.2 million related to United States employees who
were retained until March 31, 1996, when disposition of the United States oil
and gas operations was completed.
Interest expense declined $2.6 million or 13% in 1996 as a result of the
lower average debt balance outstanding throughout 1996 with proceeds from the
United States property sales applied to reduce debt primarily in December 1995.
Interest expense declined $.8 million or 4% in 1995 from 1994 primarily as a
result of such United States oil and gas property sale proceeds received
throughout 1995. Bank interest rates declined significantly during 1996, however
the majority of the Company's debt is at fixed rates, and accordingly the
Company did not benefit significantly from such interest rate declines during
1996. Average outstanding long term debt was $154 million, $167 million and $180
million for the years 1996, 1995 and 1994, respectively.
Beginning in 1995, the provision for income taxes increased due to the
reclassification of Alberta Royalty Tax Credit (ARTC) as oil and gas revenues
whereas it had previously been classified as a tax benefit. The ARTC was $.6
million, $.5 million and $1.1 million in 1996, 1995 and 1994, respectively.
- ------------
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liquidity and
capital resources
The Company is highly leveraged as reflected by the debt to total
capitalization ratio of 85% 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) the
Company's ability to obtain additional financing to the extent the Company
requires additional financing for working capital, capital expenditures, debt
refinancing or other purposes. At December 31, 1996, the Company had $5.2
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 $5 million
of Senior Notes held by Wainoco that were available for resale. Throughout 1996,
Frontier borrowed funds under its working capital facility to finance primarily
the increase in inventory caused by the crude oil price increase throughout
1996. As of December 31, 1996, the Company had no debt outstanding on either the
reserve-based line of credit or the Frontier line of credit. During 1996 the
Company amended both the Frontier line of credit and Canadian reserve-based line
of credit agreements.
Cash provided by operating activities decreased $1.4 million or 14% to $8.5
million in 1996, even though 1996 operating income increased $6.2 million and
$1.4 million for the refining and Canadian oil and gas operations, respectively.
Working capital required for operations in 1996 versus 1995 increased $9.4
million primarily due to the increased value of refining inventory attributable
to significantly higher crude oil pricing in 1996 and utilization of
approximately $3.3 million in cash during 1996 to reduce current liabilities
associated with disposition of the United States oil and gas operations. The
working capital deficit increased to $3.8 million in 1996 versus $2.5 million in
1995, due to an increase in current portion of long-term debt due in 1997 of
$2.5 million. Working capital in 1994 was $1.5 million.
Investing activities in 1996 included capital expenditures of $12.7 million,
a decrease of $3.4 million from 1995, primarily due to a $3.1 million decrease
in Canadian oil and gas operations investment. Capital expenditures of
approximately $10.2 million are planned for 1997, however, this expenditure
level will be adjusted downward if anticipated cash flows are not expected to be
achieved due to weak product prices or other negative cash flow impacts. These
expenditures are allocated $5.1 million for the Refinery and $5.1 million for
Canadian exploration and development. The Refinery's projected capital
expenditures for 1997 are flat with the prior two years. The Company believes
sustaining capital expenditures of $5-10 million annually will be required at
Frontier. During 1996, the Company received proceeds of $1.0 million for the
disposal of Canadian non-core high operating cost areas, a significant decrease
from $34.1 million received in 1995, of which $2.7 million was related to
Canadian properties including proceeds of $1.8 million for the sale of its
interest in a Canadian gas marketing company, and the balance related to the
disposition of the United States oil and gas operations.
During 1996, cash provided by operations together with a decrease in cash of
$.9 million and proceeds of $3.0 million received on the resale of 12% Senior
Notes were utilized to fund 1996 net investing activities. It is anticipated
that cash generated by operating activities and available borrowing capacity
will be sufficient to meet 1997 investing requirements and debt retirement
obligations.
The fundamental currency for the Company's Canadian operations is the
Canadian dollar which year-end rate decreased to $.7297 in 1996 compared with
$.7329 and $.7129 in 1995 and 1994, respectively. Accordingly, the Company's
Canadian net assets of C$100.0 million at December 31, 1996 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 form
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, provincial, state and federal laws, rules and regulations
relating to the environment are applicable to the Company's operations and
activities in both Canada and the United States. As a result, the Company falls
under the jurisdiction of numerous provincial, 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.
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Page 15
selected quarterly financial and operating data
(unaudited, dollars in thousands except per share and average prices)
1996 1995
------------------------------------------ ------------------------------------------
Fourth Third Second First Fourth Third Second First
--------- --------- --------- --------- --------- --------- --------- ---------
Revenues $ 106,881 $ 111,301 $ 104,207 $ 81,563 $ 90,736 $ 94,295 $ 100,366 $ 77,348
Restructuring charges, primarily United
States oil and gas property write-downs - - - - 1,701 - - -
Operating income (loss) 2,089 3,577 6,165 (1,130) (2,127) 1,533 6,081 (4,479)
Net income (loss) (2,219) (968) 1,737 (5,442) (7,069) (3,519) 1,054 (9,591)
Net income (loss) per share (.08) (.04) .06 (.20) (.26) (.13) .04 (.35)
Earnings before interest, taxes,
depreciation, depletion and amortization
and restructuring charges, primarily
United States oil and gas property
write-downs (EBITDA)* 6,239 7,902 10,302 3,399 4,569 6,565 11,350 1,636
Net cash provided by (used in) operating
activities 14,420 1,358 1,140 (8,453) 9,867 (1,379) 7,580 (6,190)
Oil and gas operations
(including United States)
Production:
Oil (mmbbls) 78 78 77 96 164 145 161 223
Gas (bcf) 3.2 2.9 2.9 3.5 3.6 3.5 4.5 4.4
Average sales price:
Oil (per bbl) $ 21.67 $ 18.75 $ 15.88 $ 15.56 $ 15.14 $ 14.36 $ 16.29 $ 15.42
Gas (per mcf) 1.43 .86 .81 .98 .92 .93 .89 .98
Refining operations
Total charges (bpd) 40,659 43,718 42,296 38,070 41,230 41,209 42,402 36,481
Sour crude charge rate (%) 97 87 84 84 84 59 83 84
Gasoline yields (bpd) 14,775 17,900 16,969 17,668 17,903 17,020 18,485 15,620
Distillate yields (bpd) 14,973 13,129 14,169 12,570 15,125 12,817 15,573 11,430
Total product sales 38,946 44,248 40,910 36,579 41,960 42,855 42,264 36,086
five year financial data
(in thousands except per share)
1996 1995 1994 1993 1992
---------- ---------- ---------- ---------- ----------
Revenues $ 403,952 $ 362,745 $ 353,715 $ 366,556 $ 376,842
Restructuring charges and United States
oil and gas property write-downs - 1,701 17,299 - -
Operating income 10,701 1,008 7,355 22,210 16,079
Income (loss) before taxes (6,705) (18,992) (13,442) 1,989 (1,393)
Provision (benefit) for income taxes 187 133 (835) (515) (415)
Net income (loss) (6,892) (19,125) (12,607) 2,504 (978)
Net income (loss) per share (.25) (.70) (.46) .10 (.04)
EBITDA* 27,842 24,120 51,394 45,448 39,510
Net cash provided by operating activities 8,465 9,878 32,108 32,800 23,336
Working capital (deficit) (3,752) (2,485) 1,532 (1,905) 3,344
Total assets 239,865 238,382 277,536 296,811 291,417
Long-term debt 145,928 145,377 170,797 176,900 189,273
Shareholders' equity 25,269 32,464 49,449 66,040 44,956
Capital expenditures 12,679 16,131 23,822 40,651 41,761
Dividends declared - - - - -
* 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.
- ------------
Page 16
five year operating data
(dollars in thousands except per barrel and average prices)
1996 1995 1994 1993 1992
---------- ---------- ---------- ---------- ----------
Canadian oil and gas operations
Annual production
Oil (mbbls) 329 284 224 232 267
Gas (bcf) 12.5 15.4 15.3 15.9 16.0
Daily average production
Oil (bopd) 899 778 614 636 730
Gas (mmcfd) 34.2 42.1 42.0 43.7 43.7
Average sales price
Oil (per bbl) $ 17.83 $ 14.46 $ 12.80 $ 12.85 $ 14.13
Gas (per mcf) 1.03 .90 1.31 1.15 1.00
Proved reserves
Oil (mbbls) 1,718 2,352 1,308 1,524 1,792
Gas (bcf) 93.6 112.7 120.9 118.7 151.0
Pretax future net income at constant
prices, discounted at 10% $ 121,523 $ 63,852 $ 68,865 $ 88,577 $ 76,816
Proved developed reserves as a
percentage of total reserves 98 99 99 98 91
Refining operations
Charges (bpd)
Sweet crude 4,322 8,098 6,165 6,581 8,766
Sour crude 31,677 27,174 27,025 25,909 21,015
Other feed and blend stocks 5,192 5,072 4,105 2,957 3,079
Total charges 41,191 40,344 37,295 35,447 32,860
Manufactured product yields (bpd)
Gasoline 16,825 17,263 16,106 15,129 13,131
Distillate 13,712 13,744 13,094 11,777 10,877
Asphalt and other 9,215 7,951 6,575 7,128 7,485
Total manufactured product yields 39,752 38,958 35,775 34,034 31,493
Product sales (bpd)
Gasoline 20,311 20,767 19,437 19,837 19,499
Distillate 12,561 13,265 12,628 11,819 11,330
Asphalt and other 7,306 6,781 6,724 7,682 6,500
Total product sales 40,178 40,813 38,789 39,338 37,329
Average sales price (per bbl)
Gasoline $ 28.78 $ 24.68 $ 24.57 $ 25.24 $ 27.78
Distillate 28.89 23.48 23.48 25.06 25.57
Asphalt and other 13.21 11.73 12.18 12.00 12.16
Operating margin information
(per sales bbl)
Average sales price 25.98 22.14 22.06 22.60 24.39
Material costs 21.50 18.11 16.18 17.09 19.56
Product spread 4.48 4.03 5.88 5.51 4.83
Operating expenses excluding
depreciation 3.15 3.19 3.45 3.55 3.18
Depreciation .59 .55 .53 .42 .28
Operating margin .74 .29 1.90 1.54 1.37
Average sweet/sour spread based on
layed-in crude costs (per bbl) 2.56 2.94 3.61 4.48 5.53
- -----------
Page 17
consolidated statements of operations
(in thousands except per share)
for the years ended December 31, 1996 1995 1994
---------- ---------- ----------
Revenues
Refined products $ 382,098 $ 329,784 $ 312,376
Oil and gas sales 18,738 25,447 39,567
Other 3,116 7,514 1,772
---------- ---------- ----------
403,952 362,745 353,715
---------- ---------- ----------
Costs and expenses
Refining operating costs 362,485 317,311 277,852
Oil and gas operating costs 4,986 10,202 12,883
Selling and general expenses 8,639 11,112 11,586
Depreciation, depletion and amortization 17,141 21,411 26,740
Restructuring charges, primarily United
States oil and gas property write-downs
in 1994 - 1,701 17,299
---------- ---------- ----------
393,251 361,737 346,360
---------- ---------- ----------
Operating income 10,701 1,008 7,355
Interest expense, net 17,406 20,000 20,797
---------- ---------- ----------
Income (loss) before income taxes (6,705) (18,992) (13,442)
Provision (benefit) for income taxes 187 133 (835)
---------- ---------- ----------
Net income (loss) $ (6,892) $ (19,125) $ (12,607)
---------- ---------- ----------
Net income (loss) per share $ (.25) $ (.70) $ (.46)
---------- ---------- ----------
(the accompanying notes are an integral part of these financial statements)
- -----------
Page 18
consolidated balance sheets
(in thousands except shares)
December 31, 1996 1995
---------- ----------
Assets
Current assets:
Cash, including cash equivalents of $609 and $1,000
at December 31, 1996 and 1995, respectively $ 5,183 $ 6,045
Trade receivables 19,422 20,022
Joint operator and other receivables 1,357 2,345
Inventory of crude oil, products and other 29,617 19,736
Other current assets 730 708
---------- ----------
Total current assets 56,309 48,856
---------- ----------
Property, plant and equipment - at cost, and oil and
gas properties on a full cost basis 317,697 306,725
Less - accumulated depreciation, depletion and
amortization 139,091 122,404
---------- ----------
Net property, plant and equipment 178,606 184,321
Other assets 4,950 5,205
---------- ----------
Total assets $ 239,865 $ 238,382
---------- ----------
Liabilities and shareholders' equity
Current liabilities:
Accounts payable $ 43,789 $ 35,909
Oil and gas proceeds payable 1,207 2,705
Accrued interest 5,249 5,230
Accrued turnaround cost 3,490 882
Other accrued liabilities 3,826 6,615
Current maturities of long-term debt 2,500 -
---------- ----------
Total current liabilities 60,061 51,341
---------- ----------
Long-term debt 145,928 145,377
Deferred credits and other 6,189 6,782
Deferred income taxes 2,418 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, 27,313,502 shares issued
in 1996 and 1995, respectively 57,172 57,172
Paid-in capital 81,767 81,767
Accumulated deficit (104,921) (98,029)
Cumulative translation adjustment (8,501) (8,187)
Treasury stock, 55,000 shares and 57,500 shares
at December 31, 1996 and 1995, respectively (248) (259)
---------- ----------
Total shareholders' equity 25,269 32,464
---------- ----------
Total liabilities and shareholders' equity $ 239,865 $ 238,382
---------- ----------
(the accompanying notes are an integral part of these financial statements)
- ------------
Page 19
consolidated statements of cash flows
(in thousands)
for the years ended December 31, 1996 1995 1994
---------- ---------- ----------
Operating activities
Net income (loss) $ (6,892) $ (19,125) $ (12,607)
Adjustments to reconcile net loss to net
cash provided by operating activities:
Depreciation, depletion and amortization 17,141 21,411 26,740
Other deferred credits 529 (750) (498)
Restructuring charges, primarily United
States oil and gas property write-downs
in 1994 - 1,701 17,299
Gain on sale of a Canadian marketing company - (1,780) -
Other 266 1,563 882
---------- ---------- ----------
11,044 3,020 31,816
---------- ---------- ----------
Changes in components of working capital
from operations
(Increase) decrease in receivables 765 (1,283) (1,624)
(Increase) decrease in inventory (9,881) 3,884 (2,722)
(Increase) decrease in other current assets (35) 175 949
Increase (decrease) in accounts payable 7,659 4,161 4,258
Increase (decrease) in accrued liabilities (1,087) (79) (569)
---------- ---------- ----------
(2,579) 6,858 292
---------- ---------- ----------
Net cash provided by operating activities 8,465 9,878 32,108
---------- ---------- ----------
Investing activities
Additions to property, plant and equipment (13,414) (17,177) (23,802)
Sales of oil and gas and other properties 990 34,145 2,215
Other 429 (606) (2,045)
---------- ---------- ----------
Net cash provided by (used in) investing
activities (11,995) 16,362 (23,632)
---------- ---------- ----------
Financing activities
Long-term borrowings:
Bank debt 9,143 32,500 11,964
Senior notes 3,000 - -
Payments of debt:
Bank debt (9,143) (47,500) (15,664)
Senior notes - (8,000) -
Subordinated debentures - (2,500) (2,500)
Other (345) (488) (179)
---------- ---------- ----------
Net cash provided by (used in) financing
activities 2,655 (25,988) (6,379)
Effect of exchange rate changes on cash 13 (38) (36)
---------- ---------- ----------
Increase (decrease) in cash and cash equivalents (862) 214 2,061
Cash and cash equivalents, beginning of period 6,045 5,831 3,770
---------- ---------- ----------
Cash and cash equivalents, end of period $ 5,183 $ 6,045 $ 5,831
---------- ---------- ----------
(the accompanying notes are an integral part of these financial statements)
- ------------
Page 20
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, 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 - - (883) - -
Stock option plan 13,390 1 38 - - - - -
Deferred compensation
amortization - - - - - - - 51
Translation adjustment - - - - (4,074) - - -
Net income (loss) - - - (12,607) - - - -
---------- ---------- ---------- ---------- ------------ ------------ ---------- ------------
December 31, 1994 27,310,842 57,172 81,758 (78,904) (10,307) - (270) -
Shares issued under:
Stock option plan 2,660 - 9 - - - - -
Directors' stock plan - - - - - - 11 -
Translation adjustment - - - - 2,120 - - -
Net income (loss) - - - (19,125) - - - -
---------- ---------- ---------- ---------- ------------ ------------ ---------- ------------
December 31, 1995 27,313,502 57,172 81,767 (98,029) (8,187) - (259) -
Shares issued under:
Stock option plan - - - - - - - -
Directors' stock plan - - - - - - 11 -
Translation adjustment - - - - (314) - - -
Net income (loss) - - - (6,892) - - - -
---------- ---------- ---------- ---------- ------------ ------------ ---------- ------------
December 31, 1996 27,313,502 $ 57,172 $ 81,767 $ (104,921) $ (8,501) $ - $ (248) $ -
---------- ---------- ---------- ---------- ------------ ------------ ---------- ------------
(the accompanying notes are an integral part of these financial statements)
- ------------
Page 21
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 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).
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 full cost method of accounting for the capitalization of
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.
New Accounting Statement
The Company adopted the Financial Accounting Standards Board's Statement of
Financial Accounting Standards No. 123, Accounting for Stock-Based Compensation,
in 1996. As permitted by SFAS No. 123, the Company elected to continue to
account for employee stock-based compensation using the intrinsic value method
prescribed by Accounting Principles Board (APB) Opinion No. 25, "Accounting for
Stock Issued to Employees". Accordingly, the adoption of SFAS No. 123,
"Accounting for Stock-Based Compensation" in 1996 had no effect on the Company's
results of operations.
schedule of property, plant and equipment
(in thousands)
December 31, 1996 1995
---------- ----------
Oil and gas properties $ 170,879 $ 164,711
Refinery and pipeline 142,169 137,598
Furniture, fixtures and other 4,649 4,416
---------- ----------
$ 317,697 $ 306,725
---------- ----------
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, 1996 1995
---------- ----------
Crude oil $ 2,863 $ 2,517
Unfinished products 7,024 4,016
Finished products 12,816 6,629
Chemicals 851 1,060
Repairs and maintenance supplies and other 6,063 5,514
---------- ----------
$ 29,617 $ 19,736
---------- ----------
- ------------
Page 22
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.
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 deferred and recognized when the hedged
transaction is consummated.
interest
Interest is reported net of interest capitalized and interest income.
Interest income of $181,000, $248,000 and $216,000 was recorded in the years
ended December 31, 1996, 1995 and 1994, 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, 1996, the Company was not subject to any such agreements.
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.
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 1996, 1995 and 1994 were $16.9 million, $18.8 million and $19.4 million,
respectively, and cash payments for income taxes during 1996, 1995 and 1994 were
$187,000, $133,000 and $116,000, respectively.
3
long-term debt
schedule of long-term debt
(in thousands)
December 31, 1996 1995
---------- ----------
Credit facilities
Canadian oil and gas $ - $ -
Refining - -
Senior notes 95,000 92,000
Convertible subordinated debentures 46,000 46,000
Subordinated debentures 7,428 7,377
---------- ----------
148,428 145,377
Less - current maturities 2,500 -
---------- ----------
$ 145,928 $ 145,377
---------- ----------
oil and gas credit facility
Wainoco has a long-term credit facility with two banks for its Canadian oil
and gas operations. Effective September 30, 1996, the Company amended its
Canadian reserve-based credit facility to reduce its tangible net worth, fixed
charge coverage and interest coverage covenants, and to extend its revolving
period thereunder from December 31, 1997 to December 31, 1998. The loan
previously converted to a two-year term loan on December 31, 1998 with payments
commencing on March 31, 1999, whereas the September 30, 1996 amendment now
requires payment in full of all outstanding principal on the maturity date
December 31, 1998. Effective September 30, 1996, interest rates on the prime
loan increased one-quarter of one percent to the bank's prime rate plus one
percent. Also, the interest rate on Euro-Dollar loans increased from LIBOR, at
its prevailing rate, plus one and three-quarters percent to LIBOR plus two
percent providing the outstanding principal under the credit facility is equal
to or less than C$5 million, or LIBOR plus two and one-quarter percent in the
event the outstanding principal under the credit facility exceeds C$5 million.
Finally, issuance fees for letters of credit increased from one and
three-quarters percent to two percent if on the issue date the outstanding
principal under the credit facility is equal to or less than C$5 million, or two
and one-quarter percent if on the issue date the outstanding principal under the
credit facility exceeds C$5 million. The credit agreement can be extended
annually at the option of the lenders.
- ------------
Page 23
The bank reviews the oil and gas properties at least annually and makes 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 or (2)
repay any such excess.
The C$18 million (the United States dollar equivalent of approximately $13.1
million at December 31, 1996) 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 $.7
million and $.1 million were outstanding at December 31, 1996 and 1995,
respectively. No debt was outstanding under this credit line at December 31,
1996 and 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 has a working capital credit facility with a group of
three banks. This facility was amended during 1996, which amendment extended the
maturity from April 2, 1997 to April 2, 1998. 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, 1996 and 1995. Standby letters-of-credit outstanding were $19.5 and
$12.7 million at December 31, 1996 and 1995.
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%, reduced from .4 of 1% in the recent amendment. Interest rates are based, at
the Company's option, on the agent bank's prime rate plus one-half percent
(reduced from seven-eighths percent) or the reserve-adjusted LIBOR plus 1.75%
(reduced from two percent). Standby letters-of-credit issued bear a fee of one
and one-quarter percent 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 $95 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 held as treasury
notes $5 million and $8 million at December 31, 1996 and 1995, respectively.
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. 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 dividends
Under its credit agreements, Wainoco is required to maintain a minimum
consolidated shareholders' equity (as defined) equal to $19.5 million at
December 31, 1996. 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, $2.3 million in 2000 and 2001.
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 implemented
beginning January 1, 1996. Under the amended tax convention, Wainoco is 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.
- ------------
Page 24
The amended tax convention will have no current impact on Wainoco's tax
provision. However, the Company is no longer 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, 1996, 1995 and 1994.
pretax income (loss)
(in thousands) 1996 1995 1994
---------- ---------- ----------
Canada $ 3,952 $ 2,052 $ 5,743
United States (10,657) (21,044) (19,185)
---------- ---------- ----------
$ (6,705) $ (18,992) $ (13,442)
---------- ---------- ----------
provision (benefit) for income taxes
(in thousands) 1996 1995 1994
---------- ---------- ----------
Canada - current $ 187 $ 133 $ (955)
United States - deferred - - 120
---------- ---------- ----------
$ 187 $ 133 $ (835)
---------- ---------- ----------
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, 1996, 1995 and 1994.
reconciliation of tax provision
(in thousands) 1996 1995 1994
---------- ---------- ----------
Provision (benefit) based on statutory rates $ (2,443) $ (6,446) $ (3,722)
---------- ---------- ----------
Increase (decrease) resulting from -
Unutilized net operating loss 2,443 6,446 3,722
Canada
Alberta Royalty Tax Credits (ARTC)* - - (1,075)
Large corporation tax and other 187 133 120
---------- ---------- ----------
187 133 (955)
---------- ---------- ----------
United States - - 120
---------- ---------- ----------
Provision (benefit) as reported $ 187 $ 133 $ (835)
---------- ---------- ----------
*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, 1996 and 1995.
components of deferred taxes
December 31, 1996 December 31, 1995
------------------ ------------------
United United
(in thousands) Canada States Canada States
-------- -------- -------- --------
Deferred tax liabilities
Property, plant and equipment
due to differences in DD&A $ 233 $ 14,874 $ 4,646 $ 12,963
Installment sale - 5,435 - 5,435
Other - 1,415 - 1,910
-------- -------- -------- --------
Deferred tax liabilities 233 21,724 4,646 20,308
-------- -------- -------- --------
Deferred tax assets
Tax loss carryforwards 920 34,944 601 41,321
Depletion carryforwards 3,862 3,045 3,851 3,045
Tax credit carryforwards - 1,209 - 1,915
Foreign exploration and
development expenditures - - - -
Tax asset basis with no book basis 21,788 - 25,525 -
Other - 3,151 - 3,246
-------- -------- -------- --------
26,570 42,349 29,977 49,527
-------- -------- -------- --------
Less - valuation allowance 26,337 23,043 25,331 31,637
-------- -------- -------- --------
Net deferred tax assets 233 19,306 4,646 17,890
-------- -------- -------- --------
Net deferred tax liabilities $ - $ 2,418 $ - $ 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.
The Company has net operating loss carryforwards for Canadian tax reporting
purposes of $2.1 million which expire in 2003. The Company also has oil and gas
deductions of $116.7 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 $99.8 million available to reduce future federal taxable
income. The net operating loss carryforwards will expire as follows: $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, $12.7 million in
2010 and $3.4 million in 2011. 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.
- ------------
Page 25
5
common stock
earnings per share
In 1996, 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. The primary and
fully diluted weighted average shares outstanding were 27,257,252, 27,253,881
and 27,335,360 in 1996, 1995 and 1994, respectively.
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 initially held in treasury. The Company made grants to
directors under this plan of 2,500 shares in 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,
1996 have reserved for issuance a total of 3,967,000 shares of common stock of
which 1,566,888 shares were granted and exercised, 2,331,904 shares were granted
and were outstanding and 68,208 shares were available to be granted. As of
December 31, 1995, the plans had 119,270 shares 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, 1996, 1995
and 1994, and changes during the years ended on those dates is presented below:
1996 1995 1994
--------------------------- --------------------------- ---------------------------
Weighted- Weighted- Weighted-
Number of Average Number of Average Number of Average
Options Exercise Price Options Exercise Price Options Exercise Price
----------- -------------- ----------- -------------- ----------- --------------
Outstanding at beginning of year 2,332,842 $ 4.08 1,858,447 $ 4.84 1,895,367 $ 5.38
Granted 981,229 3.31 760,500 4.34 457,400 4.87
Exercised 0 - (2,660) 3.50 (13,390) 3.93
Reissued (669,229) 4.30 (129,400) 7.39 (394,400) 7.07
Expired (312,938) 4.53 (154,045) 5.55 (86,530) 5.79
Outstanding at end of year 2,331,904 3.81 2,332,842 4.32 1,858,447 4.84
Exercisable at end of year 1,526,561 4.04 1,707,312 4.41 1,582,702 4.94
Available for grant at end of year 68,208 119,720 596,325
Weighted-average fair value of
options granted during the year .65 1.04
The following table summarizes information about stock options outstanding at
December 31, 1996:
Options Outstanding Options Exercisable
----------------------------- ----------------------------
Weighted-
Number Average Weighted- Weighted- Weighted-
Outstanding Remaining Average Exercisable Average
Range of Exercise Prices at 12/31/96 Contractual Life Exercise Price at 12/31/96 Exercise Price
- ------------------------ ----------- ---------------- -------------- ------------ --------------
$2.83 to $4.88 2,331,904 3.04 $ 3.81 1,526,561 $ 4.04
- -----------
Page 26
As permitted by SFAS No. 123, the Company applies APB Opinion No. 25 and
related Interpretations in accounting for its stock option plans. Accordingly,
no compensation cost has been recognized for its stock option plans. Had
compensation costs been determined based on the fair value at the grant dates
for awards made in 1996 and 1995 consistent with the method of SFAS No. 123, the
Company's net income and earnings per share would have been reduced to the pro
forma amounts indicated below:
(in thousands, except per share amounts) 1996 1995
---------- ----------
Net income (loss)
As reported $ (6,892) $ (19,125)
Pro forma (7,263) (19,316)
Net income (loss) per share
As reported (.25) (.70)
Pro forma (.26) (.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 5.33 and 6.54%, expected
volatilities of 32.95 and 38.11%, expected lives of 1.59 and 1.93 years and no
dividend yield in 1996 and 1995, respectively.
6
segment information
Wainoco's two business segments are oil and gas and refining. Geographically,
the oil and gas operations were located in the United States and Canada. Effec-
tive December 31, 1995, Wainoco completed disposition of all assets related to
its United States oil and gas operations. During 1996, Wainoco included in other
income $1.0 million due to the reduction of certain accruals associated with the
disposition of United States oil and gas operations. 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, 1996, and
identifiable assets as of December 31, 1996, 1995 and 1994, by segment by
country.
segment information
(in thousands) 1996 1995 1994
---------- ---------- ----------
Revenues
Refining $ 383,373 $ 331,953 $ 313,187
Oil and gas:
Canada 19,592 21,096 24,133
United States 987 9,696 16,395
---------- ---------- ----------
403,952 362,745 353,715
---------- ---------- ----------
Depreciation, depletion and amortization*
Refining 8,941 8,471 7,702
Oil and Gas:
Canada 8,123 9,641 10,127
United States - 3,299 14,311
Unallocated 77 - -
---------- ---------- ----------
17,141 21,411 32,140
---------- ---------- ----------
Operating income
Refining 7,761 1,542 23,019
Oil and Gas:
Canada 4,129 2,737 6,145
United States 987 (623) (19,206)
Unallocated Expenses (2,176) (2,648) (2,603)
---------- ---------- ----------
10,701 1,008 7,355
---------- ---------- ----------
Capital expenditures
Refining 4,638 4,989 8,245
Oil and Gas:
Canada 7,917 10,865 11,171
United States - 277 4,406
Unallocated 124 - -
---------- ---------- ----------
12,679 16,131 23,822
---------- ---------- ----------
Identifiable assets
Refining 160,338 155,515 158,654
Oil and Gas:
Canada 74,001 75,229 74,037
United States - - 40,351
Unallocated 5,526 7,638 4,494
---------- ---------- ----------
$ 239,865 $ 238,382 $ 277,536
---------- ---------- ----------
*Includes the United States oil and gas property write-down in 1994.
- ------------
Page 27
7
commitments and
contingencies
lease and other commitments
Wainoco has noncapitalized building, equipment and vehicle lease agreements
which expire from 1997 through 2002 having minimum annual payments as of
December 31, 1996 of $3.0 million for 1997, $2.8 million for 1998, $4.0 million
for 1999, $.6 million for 2000, $.4 million for 2001 and $.2 million thereafter.
The foregoing includes commitments of $304,000 in 1997, $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, $2.2 million and $1.8 million for
the three years ended December 31, 1996, 1995 and 1994, respectively.
The Company has entered into firm pipeline capacity contracts in Canada to
meet contracted gas supply requirements. The Company's annual commitment under
these contracts is approximately $3 million from 1997 to 2001 decreasing to
approximately $2 million from 2002 to 2007. The 1997 commitment represents
approximately 58% of gross productive capacity.
The Company has contracted for pipeline capacity of 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 Company also has commitments to
purchase crude oil from various suppliers to meet its Refinery throughput
requirements.
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 12%
of its customers accounting for approximately 63% 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 1996, the Company made
sales to CITGO Petroleum Products of $61.3 million, which accounted for 15% of
consolidated revenues.
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, 1996,
1995 and 1994 was $1.5 million, $1.7 million and $1.9 million, respectively.
environmental
Wainoco accrues for environmental costs as indicated in Note 1. Numerous
local, provincial, state and federal laws, rules and regulations relating to the
environment are applicable to the Company's operations and activities in both
Canada and the United States. As a result, the Company falls under the
jurisdiction of numerous provincial, 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 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 61% of the
refining unit's work force.
- ------------
Page 28
8
restructuring of operations
In the fourth quarter of 1995, Wainoco culminated the restructuring of
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 $2.4 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 property
write-downs in 1994."
During 1996, Wainoco included in other income $1.0 million due to the
reduction of certain accruals associated with disposition of the United States
oil and gas operations.
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, 1996
and 1995, the carrying amounts of long-term debt instruments (including current
maturities) were $148.4 million and $145.4 million, respectively, and the
estimated fair values were $145.0 million and $130.8 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, 1996 and
1995, and the related consolidated statements of operations, shareholders'
equity and cash flows for each of the three years in the period ended December
31, 1996. 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, 1996 and 1995, and the results of their
operations and their cash flows for each of the three years in the period ended
December 31, 1996, in conformity with generally accepted accounting principles.
Arthur Andersen LLP
Houston, Texas
February 12, 1997
- ------------
Page 29
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. During 1996, Wainoco
included in other income $1.0 million due to the reduction of certain accruals
associated with the disposition of United States oil and gas operations.
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, the Alberta Royalty
Tax Credits of $1.1 million were included as credits to income tax expense,
whereas in 1996 and 1995, the credits of $.6 million and $.5 million,
respectively, were included in revenues from operations.
results of operations from oil and gas producing activities
1996 1995 1994
---------- ---------------------------------- ----------------------------------
United United
(in thousands) Canada Canada States Total Canada States Total
---------- ---------- ---------- ---------- ---------- ---------- ----------
Revenues from operations $ 19,592 $ 21,096 $ 9,817 $ 30,913 $ 24,133 $ 16,595 $ 40,728
Production costs 4,986 6,287 3,480 9,767 5,672 6,407 12,079
Production taxes - - 435 435 - 804 804
Technical support and other 2,422 2,500 1,617 4,117 2,238 2,306 4,544
Provision for DD&A 8,055 9,572 3,207 12,779 10,080 8,785 18,865
Restructuring charges, primarily oil
and gas property write-downs in 1994 - - 1,701 1,701 - 17,299 17,299
---------- ---------- ---------- ---------- ---------- ---------- ----------
Operating income (loss) 4,129 2,737 (623) 2,114 6,143 (19,006) (12,863)
Income tax expense (benefit) 187 133 - 133 (835) - (835)
---------- ---------- ---------- ---------- ---------- ---------- ----------
Income (loss) from producing activities $ 3,942 $ 2,604 $ (623) $ 1,981 $ 6,978 $ (19,006) $ (12,028)
---------- ---------- ---------- ---------- ---------- ---------- ----------
Normal DD&A per dollar of oil and
gas sales $ .43 $ .53 $ .43 $ .50 $ .44 $ .53 $ .48
---------- ---------- ---------- ---------- ---------- ---------- ----------
- ------------
Page 30
The table below 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. Subsequent to
disposition of the Company's United States oil and gas operations, the Company
engaged a Canadian consultant, Paddock Lindstrom & Associates Petroleum
Engineers, to evaluate the Company's Canadian-based reserves. For the year ended
December 31, 1996, Paddock Lindstrom & Associates prepared reserve studies
comprising 88% of the Company's total discounted reserve value. For the years
ended December 31, 1995, 1994 and 1993, Ryder Scott Company Petroleum Engineers
prepared reserve studies comprising 93%, 87%, 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.
changes in proved oil and gas reserve quantities
Canada United States Total
------------------------------- ------------------------------- -------------------------------
Oil Gas MBOE Oil Gas MBOE Oil Gas MBOE
--------- --------- --------- --------- --------- --------- --------- --------- ---------
Developed and undeveloped
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 - 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 - - - 73 385 137
Extensions, discoveries and
other additions 1,255 6,773 2,384 - - - 1,255 6,773 2,384
Purchases of reserves-in-place - 338 56 - - - - 338 56
Production (284) (15,359) (2,844) (409) (593) (508) (693) (15,952) (3,352)
Sales of reserves-in-place - (276) (46) (2,875) (34,688) (8,656) (2,875) (34,964) (8,702)
--------- --------- --------- --------- --------- --------- --------- --------- ---------
December 31, 1995 2,352 112,748 21,143 - - - 2,352 112,748 21,143
Revisions to previous estimates (362) (8,840) (1,835) - - - (362) (8,840) (1,835)
Extensions, discoveries and
other additions 93 4,172 788 - - - 93 4,172 788
Purchases of reserves-in-place - 21 4 - - - - 21 4
Production (329) (12,518) (2,415) - - - (329) (12,518) (2,415)
Sales of reserves-in-place (35) (1,995) (368) - - - (35) (1,995) (368)
--------- --------- --------- --------- --------- --------- --------- --------- ---------
December 31, 1996 1,719 93,588 17,317 - - - 1,719 93,588 17,317
--------- --------- --------- --------- --------- --------- --------- --------- ---------
Developed
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 - - - 2,343 111,016 20,846
December 31, 1996 1,707 91,920 17,027 - - - 1,707 91,920 17,027
Developed as a percentage
of total
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 - - - 100 98 99
December 31, 1996 99 98 98 - - - 99 98 98
- ------------
Page 31
capitalized costs and related accumulated DD&A
(in thousands) 1996 1995
---------- ----------
Capitalized costs
Unproved properties $ 7,457 $ 6,037
Proved properties 163,422 158,674
---------- ----------
170,879 164,711
Accumulated DD&A 101,869 94,265
---------- ----------
Net capitalized costs $ 69,010 $ 70,446
---------- ----------
capitalized costs incurred for oil and gas activities
Unproved Proved
(in thousands) Property Property Exploration Development Total
-------- -------- ----------- ----------- ---------
1996
Canada $ 2,915 $ 145 $ 3,598 $ 1,214 $ 7,872
United States - - - - -
-------- -------- ----------- ----------- ---------
2,915 145 3,598 1,214 7,872
-------- -------- ----------- ----------- ---------
1995
Canada 3,172 3 4,913 2,670 10,758
United States - - - 253 253
-------- -------- ----------- ----------- ---------
$ 3,172 $ 3 $ 4,913 $ 2,923 $ 11,011
-------- -------- ----------- ----------- ---------
The preceding tables set forth the capitalized costs and related accumulated
depreciation, depletion and amortization and capitalized costs incurred for oil
and gas activities.
- -----------
Page 32
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.
standardized measure of discounted future net cash flows relating to proved oil
and gas reserves
(in thousands) 1996 1995
---------- ----------
Future cash inflows $ 247,190 $ 152,412
Future production costs 47,089 48,126
Future development costs 4,067 3,272
---------- ----------
Future net inflows before income taxes 196,034 101,014
Future income taxes 27,817 1,107
---------- ----------
Future net cash flows 168,217 99,907
10% discount factor 59,640 36,765
---------- ----------
Discounted future net cash flows 108,577 63,142
---------- ----------
Discounted future net cash flows before income taxes $ 121,523 $ 63,852
---------- ----------
changes in standardized measure of discounted future net cash flows
Canada United States Total
---------------------------- ---------------------------- ----------------------------
(in thousands) 1996 1995 1994 1996 1995 1994 1996 1995 1994
-------- -------- -------- -------- -------- -------- -------- -------- --------
Sales, net of production costs $(13,752) $(11,677) $(17,229) $ - $ (3,568) $ (9,455) $(13,752) $(15,245) $(26,684)
Net change in sales price and
production costs 75,308 (10,817) (21,479) - (450) (11,302) 75,308 (11,267) (32,781)
Extension, discoveries and other
additions, net of future production
and development costs 5,776 14,226 11,417 - - 2,331 5,776 14,226 13,748
Changes in estimated future
development costs (520) 515 481 - 21 (1,079) (520) 536 (598)
Development costs incurred during
the period that reduced future
development costs 260 264 409 - - 22 260 264 431
Revisions of quantity estimates (12,446) 384 1,244 - - (2,421) (12,446) 384 (1,177)
Accretion of discount 6,385 6,887 8,858 - - 5,644 6,385 6,887 14,502
Net change in income taxes (12,236) 349 4,704 - 363 286 (12,236) 712 4,990
Purchases of reserves-in-place 23 65 12 - - 92 23 65 104
Sales of reserves-in-place (553) (313) (356) - (32,083) (363) (553) (32,396) (719)
Changes in production rates
(timing) and other (2,810) (4,547) (3,069) - 60 (3,890) (2,810) (4,487) (6,959)
-------- -------- -------- -------- -------- -------- -------- -------- --------
Net increase (decrease) from
beginning of year $ 45,435 $ (4,664) $(15,008) $ - $(35,657) $(20,135) $ 45,435 $(40,321) $(35,143)
-------- -------- -------- -------- -------- -------- -------- -------- --------
Wainoco Oil Corporation
10000 Memorial Drive
Suite 600
Houston, Texas 77024-3411
713-688-9600