SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2004
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934.
For the transition period from _______ to _______.
Commission File Number: 1-10398
GIANT INDUSTRIES, INC.
(Exact name of registrant as specified in its charter)
Delaware 86-0642718
(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
23733 North Scottsdale Road, Scottsdale, Arizona 85255
(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code:
(480) 585-8888
Indicate by check mark whether the registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act
of 1934 during the preceding 12 months (or for such shorter period that
the registrant was required to file such reports) and (2) has been subject
to such filing requirements for the past 90 days.
Yes [X] No [ ]
Indicate by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act).
Yes [ ] No [X]
Number of Common Shares outstanding at November 1, 2004: 12,328,901
shares.
GIANT INDUSTRIES, INC. AND SUBSIDIARIES
INDEX
PART I - FINANCIAL INFORMATION....................................... 1
Item 1 - Financial Statements........................................ 1
Condensed Consolidated Balance Sheets September 30,
2004 and December 31, 2003 (Unaudited)...................... 1
Condensed Consolidated Statements of Earnings
for the Three and Nine Months Ended September 30, 2004
and 2003 (Unaudited)........................................ 2
Condensed Consolidated Statements of Cash Flows
for the Nine Months Ended September 30, 2004
and 2003 (Unaudited)........................................ 3
Notes to Condensed Consolidated Financial Statements
(Unaudited).................................................. 4-41
Item 2 - Management's Discussion and Analysis of
Financial Condition and Results of Operations............... 42-62
Item 3 - Quantitative and Qualitative Disclosures
About Market Risk........................................... 62
Item 4 - Controls and Procedures..................................... 63
PART II - OTHER INFORMATION........................................... 64
Item 1 - Legal Proceedings........................................... 64
Item 6 - Exhibits and Reports on Form 8-K............................ 64
SIGNATURE............................................................. 65
PART I
FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS.
GIANT INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In thousands, except shares and per share data)
September 30, December 31,
2004 2003
------------- ------------
ASSETS
Current assets:
Cash and cash equivalents............................. $ 34,287 $ 27,263
Receivables, net...................................... 99,690 82,788
Inventories........................................... 109,194 133,621
Prepaid expenses and other............................ 9,327 8,030
--------- ---------
Total current assets................................ 252,498 251,702
--------- ---------
Property, plant and equipment........................... 654,608 628,718
Less accumulated depreciation and amortization.......... (256,932) (235,539)
--------- ---------
397,676 393,179
--------- ---------
Goodwill................................................ 40,314 24,578
Assets held for sale.................................... 533 5,190
Other assets............................................ 23,963 25,005
--------- ---------
$ 714,984 $ 699,654
========= =========
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Current portion of long-term debt..................... $ - $ 11,128
Accounts payable...................................... 95,081 86,651
Accrued expenses...................................... 57,139 56,629
--------- ---------
Total current liabilities........................... 152,220 154,408
--------- ---------
Long-term debt, net of current portion.................. 292,638 355,601
Deferred income taxes................................... 31,500 28,039
Other liabilities and deferred income................... 23,286 22,170
Commitments and contingencies (notes 11 and 12)
Stockholders' equity:
Common stock, par value $.01 per share,
50,000,000 shares authorized, 16,078,381 and
12,537,535 shares issued............................ 161 126
Additional paid-in capital............................ 135,036 74,660
Retained earnings..................................... 116,597 101,104
--------- ---------
251,794 175,890
Less common stock in treasury - at cost,
3,751,980 shares.................................... (36,454) (36,454)
--------- ---------
Total stockholders' equity.......................... 215,340 139,436
--------- ---------
$ 714,984 $ 699,654
========= =========
See accompanying notes to our Condensed Consolidated Financial Statements.
1
GIANT INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF EARNINGS
(Unaudited)
(In thousands, except per share data)
Three Months Ended Nine Months Ended
September 30, September 30,
--------------------- -----------------------
2004 2003 2004 2003
--------- --------- ---------- ----------
Net revenues...................................... $ 642,370 $ 472,275 $1,837,084 $1,359,708
Cost of products sold (excluding depreciation
amortization)................................... 564,506 388,831 1,582,515 1,135,511
--------- --------- ---------- ----------
Gross margin...................................... 77,864 83,444 254,569 224,197
Operating expenses................................ 42,119 42,046 129,749 122,088
Depreciation and amortization..................... 9,016 9,314 27,318 27,731
Selling, general and administrative expenses...... 10,110 8,124 28,361 22,419
Net (gain) loss on disposal/write-down of assets,
including assets held for sale.................. (907) 151 (327) 369
Gain from insurance settlement of fire incident... (958) - (958) -
--------- --------- ---------- ----------
Operating income.................................. 18,484 23,809 70,426 51,590
Interest expense.................................. (7,173) (9,657) (25,222) (29,679)
Costs associated with early debt extinguishment... - - (10,875) -
Amortization/write-off of financing costs......... (1,013) (1,202) (7,827) (3,591)
Interest and investment income.................... 57 - 138 81
--------- --------- ---------- ----------
Earnings from continuing operations
before income taxes............................. 10,355 12,950 26,640 18,401
Provision for income taxes........................ 4,347 5,257 10,978 7,499
--------- --------- ---------- ----------
Earnings from continuing operations
before discontinued operations and
cumulative effect of change
in accounting principle....................... 6,008 7,693 15,662 10,902
Loss from discontinued operations, net of income
tax benefit of $13, $102, $105 and $370......... (21) (164) (169) (596)
Cumulative effect of change in accounting
principle, net of income tax benefit of $468.... - - - (704)
--------- --------- ---------- ----------
Net earnings...................................... $ 5,987 $ 7,529 $ 15,493 $ 9,602
========= ========= ========== ==========
Earnings (loss) per common share:
Basic
Continuing operations......................... $ 0.49 $ 0.88 $ 1.46 $ 1.25
Discontinued operations....................... - (0.02) (0.02) (0.07)
Cumulative effect of change
in accounting principle..................... - - - (0.08)
--------- --------- ---------- ----------
$ 0.49 $ 0.86 $ 1.44 $ 1.10
========= ========= ========== ==========
Assuming dilution
Continuing operations......................... $ 0.48 $ 0.87 $ 1.43 $ 1.24
Discontinued operations....................... - (0.02) (0.02) (0.07)
Cumulative effect of change
in accounting principle..................... - - - (0.08)
--------- --------- ---------- ----------
$ 0.48 $ 0.85 $ 1.41 $ 1.09
========= ========= ========== ==========
See accompanying notes to our Condensed Consolidated Financial Statements.
2
GIANT INDUSTRIES, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
(In thousands)
Nine Months Ended
September 30,
-------------------------
2004 2003
--------- ---------
Cash flows from operating activities:
Net earnings.............................................. $ 15,493 $ 9,602
Loss from discontinued operations, net.................... 169 596
Cumulative effect of change in accounting principle, net.. - 704
--------- ---------
Net earnings from continuing operations................... 15,662 10,902
Adjustments to reconcile net earnings from continuing:
operations to net cash provided by operating activities:
Depreciation and amortization........................... 27,317 27,731
Amortization/write-off of financing costs............... 7,827 6,108
Deferred income taxes................................... 4,037 3,591
Deferred crude oil purchase discounts................... 2,051 -
Net (gain) loss on the disposal/write-down of assets,
including assets held for sale........................ (327) 369
(Gain) from insurance settlement of fire incident........ (958) -
Income tax benefit from exercise of stock options....... 718 -
Changes in operating assets and liabilities
(Increase) decrease in receivables.................... (16,829) 909
Decrease (increase) in inventories.................... 24,422 (4,911)
Decrease in prepaid expenses.......................... 1,367 4,138
(Increase) in other assets............................ (2,904) (699)
Increase (decrease) in accounts payable............... 8,431 (1,268)
Increase in accrued expenses.......................... 292 4,849
Increase in other liabilities......................... 765 234
--------- ---------
Net cash provided by operating activities................... 71,871 51,953
--------- ---------
Cash flows from investing activities:
Purchase of property, plant and equipment................. (39,842) (11,590)
Proceeds from assets held for sale and
discontinued operations................................. 8,055 1,360
Yorktown refinery acquisition contingent payment.......... (15,300) (8,120)
Net proceeds from insurance settlement of fire incident... 3,032 -
Proceeds from sale of property, plant and equipment
and other assets........................................ 2,972 9,900
--------- ---------
Net cash used in investing activities....................... (41,083) (8,450)
--------- ---------
Cash flows from financing activities:
Payments of long-term debt................................ (205,616) (12,947)
Payments on line of credit................................ (17,573) (121,000)
Proceeds from line of credit.............................. - 96,000
Proceeds from issuance of long-term debt.................. 147,467 -
Net proceeds from issuance of common stock................ 57,374 -
Proceeds from exercise of stock options................... 1,418 -
Deferred financing costs.................................. (6,834) (50)
--------- ---------
Net cash used in financing activities....................... (23,764) (37,997)
--------- ---------
Net increase in cash and cash equivalents................... 7,024 5,506
Cash and cash equivalents:
Beginning of period..................................... 27,263 10,168
--------- ---------
End of period........................................... $ 34,287 $ 15,674
========= =========
Significant Noncash Investing and Financing Activities: On February 25, 2004, we contributed 49,046 newly
issued shares of our common stock, valued at $900,000, to our 401(k) plan as a discretionary contribution for
the year 2003. On January 1, 2003, in accordance with Statement of Financial Accounting Standards No. 143,
"Accounting for Asset Retirement Obligations," we recorded an asset retirement obligation of $2,198,000, asset
retirement assets of $1,580,000 and related accumulated depreciation of $674,000. We also reversed a previously
recorded asset retirement obligation for $120,000, and recorded a cumulative effect adjustment of $1,172,000
($704,000 net of taxes). See Note 4 for further information.
See accompanying notes to our Condensed Consolidated Financial Statements.
3
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)
NOTE 1 - ORGANIZATION AND BASIS OF PRESENTATION:
ORGANIZATION
Giant Industries, Inc., through our subsidiary Giant Industries
Arizona, Inc. and its subsidiaries, refines and sells petroleum products.
Our operations are located:
- on the East Coast - primarily in Virginia, Maryland, and North
Carolina; and
- in the Southwest - primarily in New Mexico, Arizona, and Colorado,
with a concentration in the Four Corners area where these states
meet.
In addition, our Phoenix Fuel Co., Inc. subsidiary distributes
commercial wholesale petroleum products primarily in Arizona.
We have three business units:
- our refining group;
- our retail group; and
- Phoenix Fuel.
See Note 3 for a further discussion of our business segments.
Basis of Presentation:
The accompanying unaudited condensed consolidated financial
statements have been prepared in accordance with accounting principles
generally accepted in the United States of America, hereafter referred to
as generally accepted accounting principles, for interim financial
information and with the instructions to Form 10-Q and Rule 10-01 of
Regulation S-X. Accordingly, they do not include all of the information
and notes required by generally accepted accounting principles for
complete financial statements. In the opinion of management, all
adjustments and reclassifications considered necessary for a fair and
comparable presentation have been included. These adjustments and
reclassifications are of a normal recurring nature, with the exception of
the cumulative effect of a change in accounting for asset retirement
obligations (see Note 4), discontinued operations (see Note 6), and costs
and write-offs related to early debt extinguishment (see Note 11).
Operating results for the three and nine months ended September 30, 2004
are not necessarily indicative of the results that may be expected for the
year ending December 31, 2004. The accompanying financial statements
should be read in conjunction with the consolidated financial statements
and notes thereto included in our Annual Report on Form 10-K for the year
ended December 31, 2003.
We have made certain reclassifications to our 2003 financial
statements and notes to conform to the financial statement classifications
used in the current year. These reclassifications relate primarily to
discontinued operations reporting. These reclassifications had no effect
on reported earnings or stockholders' equity.
4
NOTE 2 - STOCK-BASED EMPLOYEE COMPENSATION:
We have a stock-based employee compensation plan that is more fully
described in Note 18 to our financial statements included in our Annual
Report on Form 10-K for the year ended December 31, 2003. We account for
this plan under the recognition and measurement principles of Accounting
Principles Board Opinion ("APB") No. 25, "Accounting for Stock Issued to
Employees", and related interpretations. We use the intrinsic value method
to account for stock-based employee compensation. The following table
illustrates the effect on net earnings and earnings per share as if we had
applied the fair value recognition provisions of Statement of Financial
Accounting Standards ("SFAS") No. 123, "Accounting for Stock-Based
Compensation", to stock-based employee compensation.
Three Months Ended Nine Months Ended
September 30, September 30,
------------------ ------------------
2004 2003 2004 2003
------- ------- ------- -------
(In thousands, except per share data)
Net earnings, as reported....... $ 5,987 $ 7,529 $15,493 $ 9,602
Add: Stock-based employee
compensation expense included
in reported net income, net
of related tax effect......... - - - -
Deduct: Total stock-based
employee compensation
expense determined under the
fair value based method for
all awards, net of related
tax effect.................... (24) (74) (123) (167)
------- ------- ------- -------
Pro forma net earnings.......... $ 5,963 $ 7,455 $15,370 $ 9,435
======= ======= ======= =======
Earnings per share:
Basic - as reported........... $ 0.49 $ 0.86 $ 1.44 $ 1.10
======= ======= ======= =======
Basic - pro forma............. $ 0.49 $ 0.85 $ 1.44 $ 1.08
======= ======= ======= =======
Diluted - as reported......... $ 0.48 $ 0.85 $ 1.41 $ 1.09
======= ======= ======= =======
Diluted - pro forma........... $ 0.48 $ 0.84 $ 1.40 $ 1.07
======= ======= ======= =======
5
NOTE 3 - BUSINESS SEGMENTS:
We are organized into three business segments based on manufacturing
and marketing criteria. These segments are the refining group, the retail
group and Phoenix Fuel. Our operations that are not included in any of the
three segments are included in the category "Other" and are then allocated
to the business segments. These operations consist primarily of corporate
staff operations.
Beginning in the second quarter of 2004, operating income for our
segments includes an allocation of corporate overhead. We have
reclassified prior period segment information for comparative purposes.
Operating income before corporate allocation for each segment
consists of net revenues less cost of products sold, operating expenses,
depreciation and amortization, and the segment's selling, general and
administrative expenses. Cost of products sold reflects current costs
adjusted, where appropriate, for the last-in, first-out ("LIFO") inventory
method and lower of cost or market inventory adjustments.
The total assets of each segment consist primarily of net property,
plant and equipment, inventories, accounts receivable and other assets
directly associated with the segment's operations. Included in the total
assets of the corporate staff operations are a majority of our cash and
cash equivalents, and various accounts receivable, net property, plant and
equipment, and other long-term assets.
A description of each segment and its principal products follows:
REFINING GROUP
Our refining group operates our Ciniza and Bloomfield refineries in
the Four Corners area of New Mexico and the Yorktown refinery in Virginia.
It also operates a crude oil gathering pipeline system in New Mexico, two
finished products distribution terminals, and a fleet of crude oil and
finished product trucks. Our three refineries make various grades of
gasoline, diesel fuel, and other products from crude oil, other
feedstocks, and blending components. We also acquire finished products
through exchange agreements and purchase agreements with various
suppliers. We sell these products through our service stations,
independent wholesalers and retailers, commercial accounts, and sales and
exchanges with major oil companies. We purchase crude oil, other
feedstocks, and blending components from various suppliers.
RETAIL GROUP
Our retail group operates service stations, which include convenience
stores or kiosks. Our service stations sell various grades of gasoline,
diesel fuel, general merchandise, including tobacco and alcoholic and
nonalcoholic beverages, and food products to the general public. Our
refining group or Phoenix Fuel supplies the gasoline and diesel fuel our
retail group sells. We purchase general merchandise and food products from
various suppliers. At September 30, 2004, we operated 125 service stations
with convenience stores or kiosks.
6
PHOENIX FUEL
Phoenix Fuel distributes commercial wholesale petroleum products. It
includes several lubricant and bulk petroleum distribution plants, an
unmanned fleet fueling operation, a bulk lubricant terminal facility, and
a fleet of finished product and lubricant delivery trucks. Phoenix Fuel
purchases petroleum fuels and lubricants from suppliers and to a lesser
extent from our refining group.
Disclosures regarding our reportable segments with reconciliations to
consolidated totals for the three months ended September 30, 2004 and
2003, are presented below.
7
As of and for the Three Months Ended September 30, 2004
----------------------------------------------------------------
Refining Retail Phoenix Reconciling
Group Group Fuel Other Items Consolidated
----------------------------------------------------------------
(In thousands)
Customer net revenues:
Finished products:
Four Corners operations.............. $116,983
Yorktown operations.................. 234,744
--------
Total................................ $351,727 $ 63,121 $149,543 $ - $ - $ 564,391
Merchandise and lubricants............. - 36,276 8,393 - - 44,669
Other.................................. 29,170 3,539 506 154 - 33,369
-------- -------- -------- -------- --------- ----------
Total................................ 380,897 102,936 158,442 154 - 642,429
-------- -------- -------- -------- --------- ----------
Intersegment net revenues:
Finished products...................... 50,653 - 14,883 - (65,536) -
Other.................................. 3,887 - - - (3,887) -
-------- -------- -------- -------- --------- ----------
Total................................ 54,540 - 14,883 - (69,423) -
-------- -------- -------- -------- --------- ----------
Total net revenues....................... 435,437 102,936 173,325 154 (69,423) 642,429
Less net revenues of discontinued
operations............................. - (59) - - - (59)
-------- -------- -------- -------- --------- ----------
Net revenues of continuing operations.... $435,437 $102,877 $173,325 $ 154 $ (69,423) $ 642,370
======== ======== ======== ======== ========= ==========
Operating income (loss):
Four Corners operations................ $ 8,150
Yorktown operations.................... 11,652
--------
Total operating income (loss) before
corporate allocation................... $ 19,802 $ 1,428 $ 2,216 $ (6,879) $ 1,883 $ 18,450
Corporate allocation..................... (3,273) (1,895) (574) 5,742 - -
-------- -------- -------- -------- --------- ----------
Total operating income (loss) after
corporate allocation................... 16,529 (467) 1,642 (1,137) 1,883 18,450
Discontinued operations loss/(gain)...... - 52 - - (18) 34
-------- -------- -------- -------- --------- ----------
Operating income (loss)
from continuing operations............. $ 16,529 $ (415) $ 1,642 $ (1,137) $ 1,865 18,484
======== ======== ======== ======== =========
Interest expense......................... (7,173)
Amortization and write-offs of
financing costs........................ (1,013)
Interest income.......................... 57
----------
Earnings from continuing operations
before income taxes.................... $ 10,355
==========
Depreciation and amortization:
Four Corners operations................ $ 4,045
Yorktown operations.................... 2,275
--------
Total................................ $ 6,320 $ 2,119 $ 380 $ 211 $ - $ 9,030
Less discontinued operations......... - (14) - - - (14)
-------- -------- -------- -------- --------- ----------
Continuing operations................ $ 6,320 $ 2,105 $ 380 $ 211 $ - $ 9,016
======== ======== ======== ======== ========= ==========
Total assets............................. $471,659 $107,278 $ 85,719 $ 50,328 $ - $ 714,984
Capital expenditures..................... $ 16,438 $ 919 $ 500 $ 135 $ - $ 17,992
Yorktown refinery acquisition
contingent payment..................... $ 3,605 $ - $ - $ - $ - $ 3,605
8
As of and for the Three Months Ended September 30, 2003
----------------------------------------------------------------
Refining Retail Phoenix Reconciling
Group Group Fuel Other Items Consolidated
----------------------------------------------------------------
(In thousands)
Customer net revenues:
Finished products:
Four Corners operations.............. $ 72,194
Yorktown operations.................. 201,722
--------
Total................................ $273,916 $ 51,316 $100,718 $ - $ - $ 425,950
Merchandise and lubricants............. - 35,387 6,559 - - 41,946
Other.................................. 3,154 3,916 265 60 - 7,395
-------- -------- -------- -------- --------- ----------
Total................................ 277,070 90,619 107,542 60 - 475,291
-------- -------- -------- -------- --------- ----------
Intersegment net revenues:
Finished products...................... 43,579 - 12,512 - (56,091) -
Other.................................. 7,669 - - - (7,669) -
-------- -------- -------- -------- --------- ----------
Total................................ 51,248 - 12,512 - (63,760) -
-------- -------- -------- -------- --------- ----------
Total net revenues....................... 328,318 90,619 120,054 60 (63,760) 475,291
Less net revenues of discontinued
operations............................. - (3,016) - - - (3,016)
-------- -------- -------- -------- --------- ----------
Net revenues of continuing operations.... $328,318 $ 87,603 $120,054 $ 60 $ (63,760) $ 472,275
======== ======== ======== ======== ========= ==========
Operating income (loss):
Four Corners operations................ $ 13,269
Yorktown operations.................... 10,540
--------
Total operating income (loss) before
corporate allocation................... $ 23,809 $ 4,153 $ 2,101 $ (6,147) $ (373) $ 23,543
Corporate allocation..................... (2,973) (1,721) (522) 5,216 - -
-------- -------- -------- -------- --------- ----------
Total operating income (loss) after
corporate allocation................... 20,836 2,432 1,579 (931) (373) 23,543
Discontinued operations loss/(gain)...... - 44 - - 222 266
-------- -------- -------- -------- --------- ----------
Operating income (loss)
from continuing operations............. $ 20,836 $ 2,476 $ 1,579 $ (931) $ (151) 23,809
======== ======== ======== ======== =========
Interest expense......................... (9,657)
Amortization and write-offs of
financing costs........................
(1,202)
----------
Earnings from continuing operations
before income taxes.................... $ 12,950
==========
Depreciation and amortization:
Four Corners operations................ $ 3,969
Yorktown operations.................... 2,064
--------
Total................................ $ 6,033 $ 2,518 $ 435 $ 405 $ - $ 9,391
Less discontinued operations......... - (77) - - - (77)
-------- -------- -------- -------- --------- ----------
Continuing operations................ $ 6,033 $ 2,441 $ 435 $ 405 $ - $ 9,314
======== ======== ======== ======== ========= ==========
Total assets............................. $439,880 $115,642 $ 67,111 $ 60,853 $ - $ 683,486
Capital expenditures..................... $ 567 $ 490 $ 271 $ 112 $ - $ 1,440
Yorktown refinery acquisition
contingent payment..................... $ 2,645 $ - $ - $ - $ - $ 2,645
9
Disclosures regarding our reportable segments with reconciliations to
consolidated totals for the nine months ended September 30, 2004 and 2003, are
presented below.
As of and for the Nine Months Ended September 30, 2004
------------------------------------------------------------------
Refining Retail Phoenix Reconciling
Group Group Fuel Other Items Consolidated
------------------------------------------------------------------
(In thousands)
Customer net revenues:
Finished products:
Four Corners operations.............. $ 306,735
Yorktown operations.................. 742,013
----------
Total................................ $1,048,748 $172,295 $427,261 $ - $ - $1,648,304
Merchandise and lubricants............. - 101,661 23,989 - - 125,650
Other.................................. 51,508 11,171 1,430 487 - 64,596
---------- -------- -------- -------- --------- ----------
Total................................ 1,100,256 285,127 452,680 487 - 1,838,550
---------- -------- -------- -------- --------- ----------
Intersegment net revenues:
Finished products...................... 154,314 - 45,944 - (200,258) -
Other.................................. 11,653 - - - (11,653) -
---------- -------- -------- -------- --------- ----------
Total................................ 165,967 - 45,944 - (211,911) -
---------- -------- -------- -------- --------- ----------
Total net revenues....................... 1,266,223 285,127 498,624 487 (211,911) 1,838,550
Less net revenues of discontinued
operations............................. - (1,466) - - - (1,466)
---------- -------- -------- -------- --------- ----------
Net revenues of continuing operations.... $1,266,223 $283,661 $498,624 $ 487 $(211,911) $1,837,084
========== ======== ======== ======== ========= ==========
Operating income (loss):
Four Corners operations................ $ 28,014
Yorktown operations.................... 47,899
----------
Total operating income (loss) before
corporate allocation................... $ 75,913 $ 5,030 $ 7,290 $(19,402) $ 1,321 $ 70,152
Corporate allocation..................... (9,359) (5,418) (1,642) 16,419 - -
---------- -------- -------- -------- --------- ----------
Total operating income (loss) after
corporate allocation................... 66,554 (388) 5,648 (2,983) 1,321 70,152
Discontinued operations loss/(gain)...... - 310 - - (36) 274
---------- -------- -------- -------- --------- ----------
Operating income (loss)
from continuing operations............. $ 66,554 $ (78) $ 5,648 $ (2,983) $ 1,285 70,426
========== ======== ======== ======== =========
Interest expense......................... (25,222)
Costs associated with early debt
extinguishment......................... (10,875)
Amortization and write-offs of
financing costs........................ (7,827)
Interest income.......................... 138
----------
Earnings from continuing operations
before income taxes.................... $ 26,640
==========
Depreciation and amortization:
Four Corners operations................ $ 12,120
Yorktown operations.................... 6,667
----------
Total................................ $ 18,787 $ 6,792 $ 1,204 $ 647 $ - $ 27,430
Less discontinued operations......... - (112) - - - (112)
---------- -------- -------- -------- --------- ----------
Continuing operations................ $ 18,787 $ 6,680 $ 1,204 $ 647 $ - $ 27,318
========== ======== ======== ======== ========= ==========
Total assets............................. $ 471,659 $107,278 $ 85,719 $ 50,328 $ - $ 714,984
Capital expenditures..................... $ 36,673 $ 1,616 $ 1,293 $ 260 $ - $ 39,842
Yorktown refinery acquisition
contingent payment..................... $ 15,300 $ - $ - $ - $ - $ 15,300
10
As of and for the Nine Months Ended September 30, 2003
----------------------------------------------------------------
Refining Retail Phoenix Reconciling
Group Group Fuel Other Items Consolidated
----------------------------------------------------------------
(In thousands)
Customer net revenues:
Finished products:
Four Corners operations.............. $218,836
Yorktown operations.................. 564,669
--------
Total................................ $783,505 $155,886 $294,941 $ - $ - $1,234,332
Merchandise and lubricants............. - 100,890 19,277 - - 120,167
Other.................................. 18,242 11,843 1,253 270 - 31,608
-------- -------- -------- -------- --------- ----------
Total................................ 801,747 268,619 315,471 270 - 1,386,107
-------- -------- -------- -------- --------- ----------
Intersegment net revenues:
Finished products...................... 130,483 - 36,564 - (167,047) -
Other.................................. 15,876 - - - (15,876) -
-------- -------- -------- -------- --------- ----------
Total................................ 146,359 - 36,564 - (182,923) -
-------- -------- -------- -------- --------- ----------
Total net revenues....................... 948,106 268,619 352,035 270 (182,923) 1,386,107
Less net revenues of discontinued
operations............................. - (26,399) - - - (26,399)
-------- -------- -------- -------- --------- ----------
Net revenues of continuing operations.... $948,106 $242,220 $352,035 $ 270 $(182,923) $1,359,708
======== ======== ======== ======== ========= ==========
Operating income (loss):
Four Corners operations................ $ 35,488
Yorktown operations.................... 16,050
--------
Total operating income (loss) before
corporate allocation................... $ 51,538 $ 10,025 $ 5,991 $(16,105) $ (825) $ 50,624
Corporate allocation..................... (7,780) (4,504) (1,365) 13,649 - -
-------- -------- -------- -------- --------- ----------
Total operating income (loss) after
corporate allocation................... 43,758 5,521 4,626 (2,456) (825) 50,624
Discontinued operations loss/(gain)...... - 510 - - 456 966
-------- -------- -------- -------- --------- ----------
Operating income (loss)
from continuing operations............. $ 43,758 $ 6,031 $ 4,626 $ (2,456) $ (369) 51,590
======== ======== ======== ======== =========
Interest expense......................... (29,679)
Amortization and write-offs of
financing costs........................ (3,591)
Interest income.......................... 81
----------
Earnings from continuing operations
before income taxes.................... $ 18,401
==========
Depreciation and amortization:
Four Corners operations................ $ 11,927
Yorktown operations.................... 5,878
--------
Total................................ $ 17,805 $ 8,128 $ 1,336 $ 1,093 $ - $ 28,362
Less discontinued operations......... - (631) - - - (631)
-------- -------- -------- -------- --------- ----------
Continuing operations................ $ 17,805 $ 7,497 $ 1,336 $ 1,093 $ - $ 27,731
======== ======== ======== ======== ========= ==========
Total assets............................. $439,880 $115,642 $ 67,111 $ 60,853 $ - $ 683,486
Capital expenditures..................... $ 9,929 $ 864 $ 604 $ 193 $ - $ 11,590
Yorktown refinery acquisition
contingent payment..................... $ 8,120 $ - $ - $ - $ - $ 8,120
11
NOTE 4 - ASSET RETIREMENT OBLIGATIONS:
On January 1, 2003, we adopted SFAS No. 143, "Accounting for Asset
Retirement Obligations." SFAS No. 143 addresses financial accounting and
reporting obligations associated with the retirement of tangible long-
lived assets and the associated asset retirement costs.
This statement requires that the fair value of a liability for an
Asset Retirement Obligation ("ARO") be recognized in the period in which
it is incurred if a reasonable estimate of fair value can be made. The
associated Asset Retirement Cost ("ARC") is capitalized as part of the
carrying amount of the long-lived asset. To initially recognize our ARO
liability, we capitalized the fair value, calculated as of the date the
liability would have been recognized were SFAS No. 143 in effect at that
time, of all ARO's that we identified. In accordance with SFAS No. 143, we
also recognized the cumulative accretion and accumulated depreciation from
the date the liability would have been recognized had the provisions of
SFAS No. 143 been in effect, to January 1, 2003, the date we adopted SFAS
No. 143. As a result, on January 1, 2003, we recorded an ARO liability of
$2,198,000, ARC assets of $1,580,000 and related accumulated depreciation
of $674,000. We also reversed a previously recorded asset retirement
obligation of $120,000, and recorded a cumulative effect adjustment of
$1,172,000 ($704,000 net of taxes). Our legally restricted assets that are
set aside for purposes of settling ARO liabilities are less than $810,000.
These assets are set aside to fund costs associated with the closure of
certain solid waste management facilities. These ARO liabilities are
included in "Other liabilities and deferred income" on our Condensed
Consolidated Balance Sheets on page 1.
We identified the following ARO's:
1. Landfills - pursuant to Virginia law, the two solid waste
management facilities at our Yorktown refinery must satisfy closure and
post-closure care and financial responsibility requirements.
2. Crude Pipelines - our right-of-way agreements generally require
that pipeline properties be returned to their original condition when the
agreements are no longer in effect. This means that the pipeline surface
facilities must be dismantled and removed and certain site reclamation
performed. We do not believe these right-of-way agreements will require us
to remove the underground pipe upon taking the pipeline permanently out of
service. Regulatory requirements, however, may mandate that out-of-service
underground pipe be purged.
3. Storage Tanks - we have a legal obligation under applicable law
to remove or close in place all underground and aboveground storage tanks,
both on owned property and leased property, once they are taken out of
service. Under some lease arrangements, we also have committed to restore
the leased property to its original condition.
The following table reconciles the beginning and ending aggregate
carrying amount of our ARO's for the nine month period ended September 30,
2004 and the year ended December 31, 2003, respectively.
12
September 30, December 31,
2004 2003
------------- ------------
(In thousands)
Liability beginning of year........... $2,223 $2,198
Liabilities incurred.................. 9 -
Liabilities settled................... (87) (146)
Accretion expense..................... 153 171
------ ------
Liability end of period............... $2,298 $2,223
====== ======
13
NOTE 5 - Goodwill and Other Intangible Assets:
At September 30, 2004 and December 31, 2003, we had goodwill of
$40,314,000 and $24,578,000, respectively.
The changes in the carrying amount of goodwill for the nine months
ended September 30, 2004 are as follows:
Refining Retail Phoenix
Group Group Fuel Total
-------- ------- ------- -------
(In thousands)
Balance as of January 1, 2004.......... $ 5,379 $ 4,477 $14,722 $24,578
Yorktown refinery acquisition
contingent consideration(a).......... 15,774 - - 15,774
Goodwill written off related to
the sale of certain retail units..... - (38) - (38)
Other.................................. - (14) 14 -
------- ------- ------- -------
Balance as of September 30, 2004....... $21,153 $ 4,425 $14,736 $40,314
======= ======= ======= =======
(a) We paid $15,300,000 in earn-out payments under the earn-out provision of the
Yorktown acquisition agreement in the first nine months of 2004. These earn-
out payments are an additional element of cost that represents an excess of
purchase price over the amounts assigned to the assets acquired and
liabilities assumed. We allocated $14,928,000 of this amount to goodwill and
$372,000 to deferred taxes.
A summary of intangible assets that are included in "Other Assets" in
the Condensed Consolidated Balance Sheets at September 30, 2004 is
presented below:
Gross Net
Carrying Accumulated Carrying
Value Amortization Value
-------- ------------ --------
(In thousands)
Amortized intangible assets:
Rights-of-way.......................... $ 3,564 $ 2,667 $ 897
Contracts.............................. 1,368 1,079 289
Licenses and permits................... 1,075 287 788
------- ------- -------
6,007 4,033 1,974
Unamortized intangible assets:
Liquor licenses........................ 7,286 - 7,286
------- ------- -------
Total intangible assets.................. $13,293 $ 4,033 $ 9,260
======= ======= =======
14
Intangible asset amortization expense for the three and nine months
ended September 30, 2004 was $98,000 and $303,000, respectively.
Intangible asset amortization expense for the three and nine months ended
September 30, 2003 was $94,000 and $330,000, respectively. Estimated
amortization expense for the five succeeding fiscal years is as follows:
(In thousands)
--------------
2004 remainder.................. $ 96
2005............................ 384
2006............................ 381
2007............................ 238
2008............................ 196
2009............................ 196
15
NOTE 6 - DISCONTINUED OPERATIONS, ASSET DISPOSALS, AND ASSETS HELD FOR SALE:
The following table contains information regarding our discontinued
operations, all of which are included in our retail group and include some
service station/convenience stores in both periods and our travel center
in 2003.
Three Months Ended Nine Months Ended
September 30, September 30,
------------------ -----------------
2004 2003 2004 2003
------ ------ ------ -------
(In thousands)
Net revenues......................... $ 59 $3,016 $1,466 $26,399
Net operating loss................... $ (52) $ (44) $ (310) $ (510)
Gain/(loss) on disposal.............. $ 168 $ (45) $ 533 $ (203)
Impairment and other write-downs..... $ (150) $ (177) $ (497) $ (253)
------ ------ ------ -------
Loss before income taxes............. $ (34) $ (266) $ (274) $ (966)
------ ------ ------ -------
Net income/(loss).................... $ (21) $ (164) $ (169) $ (596)
Allocated goodwill included in
gain/(loss) on disposal............ $ - $ 16 $ 38 $ 78
Included in "Assets Held for Sale" in the accompanying Condensed
Consolidated Balance Sheets are the following categories of assets.
September 30, December 31,
2004 2003
------------- ------------
(In thousands)
Closed retail units..................... $ 533 $3,158
Vacant land............................. - 1,596
Property, plant and equipment........... - 330
Inventories............................. - 106
------ ------
$ 533 $5,190
====== ======
All of these assets are or were being marketed for sale at the
direction of management. We expect to dispose of the remaining properties
within the next twelve months.
16
In the first quarter of 2004, we sold one closed retail unit, and in
the first quarter of 2003 we sold two retail units, one of which was
closed.
In the second quarter of 2004, we sold 40 acres of vacant land known
as the Jomax property for approximately $5,302,000, net of expenses. We
also sold two operating service station/convenience stores for
approximately $808,000, net of expenses. Furthermore, we recorded a loss
on impairment of approximately $859,000 on two pieces of vacant land and a
retail unit that was classified as held for sale. These three properties
were sold for approximately $699,000 in the third quarter of 2004.
Additionally, in the third quarter of 2004, we also sold a piece of
land and an operating service station/convenience store for approximately
$1,876,000, net of expenses and recorded a loss on impairment of
approximately $121,000 on a retail unit that was classified as held for
sale. This retail unit was subsequently sold for $575,000 in the fourth
quarter of 2004.
17
NOTE 7 - EARNINGS PER SHARE:
The following table sets forth the computation of basic and diluted
earnings per share:
Three Months Ended Nine Months Ended
September 30, September 30,
--------------------- ---------------------
2004 2003 2004 2003
---------- --------- ---------- ---------
Numerator (In thousands)
Earnings from continuing operations.............. $ 6,008 $ 7,693 $ 15,662 $ 10,902
Loss from discontinued operations................ (21) (164) (169) (596)
Cumulative effect of change in
accounting principle........................... - - - (704)
---------- --------- ---------- ---------
Net earnings..................................... $ 5,987 $ 7,529 $ 15,493 $ 9,602
========== ========= ========== =========
Three Months Ended Nine Months Ended
September 30, September 30,
--------------------- ---------------------
2004 2003 2004 2003
---------- --------- ---------- ---------
Denominator
Basic - weighted average shares outstanding...... 12,242,994 8,785,555 10,693,386 8,713,513
Effect of dilutive stock options................. 253,210 102,269 267,298 75,323
---------- --------- ---------- ---------
Diluted - weighted average shares outstanding.... 12,496,204 8,887,824 10,960,684 8,788,836
========== ========= ========== =========
Three Months Ended Nine Months Ended
September 30, September 30,
--------------------- ---------------------
2004 2003 2004 2003
---------- --------- ---------- ---------
Basic Earnings (Loss) Per Share
Earnings from continuing operations.............. $ 0.49 $ 0.88 $ 1.46 $ 1.25
Loss from discontinued operations................ - (0.02) (0.02) (0.07)
Cumulative effect of change in
accounting principle........................... - - - (0.08)
---------- --------- ---------- ---------
Net earnings..................................... $ 0.49 $ 0.86 $ 1.44 $ 1.10
========== ========= ========== =========
18
Three Months Ended Nine Months Ended
September 30, September 30,
--------------------- ---------------------
2004 2003 2004 2003
---------- --------- ---------- ---------
Diluted Earnings (Loss) Per Share
Earnings from continuing operations.............. $ 0.48 $ 0.87 $ 1.43 $ 1.24
Loss from discontinued operations................ - (0.02) (0.02) (0.07)
Cumulative effect of change in
accounting principle........................... - - - (0.08)
---------- --------- ---------- ---------
Net earnings..................................... $ 0.48 $ 0.85 $ 1.41 $ 1.09
========== ========= ========== =========
On February 25, 2004, we contributed 49,046 newly issued shares of
our common stock to our 401(k) plan as a discretionary contribution for
the year 2003.
On May 3, 2004, we issued 3,000,000 shares of our common stock at a
public offering price of $18.50 per share. On May 7, 2004, the
underwriters purchased an additional 283,300 shares pursuant to their
over-allotment option.
At September 30, 2004, there were 12,326,401 shares of our common
stock outstanding. There were no transactions subsequent to September 30,
2004, that if the transactions had occurred before September 30, 2004,
would materially change the number of common shares or potential common
shares outstanding as of September 30, 2004.
19
NOTE 8 - INVENTORIES:
Our inventories consist of the following:
September 30, December 31,
2004 2003
------------- ------------
(In thousands)
First-in, first-out ("FIFO") method:
Crude oil............................ $ 42,579 $ 54,771
Refined products..................... 98,378 68,622
Refinery and shop supplies........... 12,146 11,306
Merchandise.......................... 2,683 2,946
Retail method:
Merchandise.......................... 9,610 11,474
-------- --------
Subtotal........................... 165,396 149,119
Adjustment for LIFO.................... (56,202) (15,498)
-------- --------
Total.............................. $109,194 $133,621
======== ========
The portion of inventories valued on a LIFO basis totaled $70,796,000
and $97,700,000 at September 30, 2004 and December 31, 2003, respectively.
The data in the following paragraph will facilitate comparison with the
operating results of companies using the FIFO method of inventory
valuation.
If inventories had been determined using the FIFO method at September
30, 2004 and 2003, net earnings and diluted earnings per share would have
been higher as follows:
Three Months Ended Nine Months Ended
September 30, September 30,
------------------ ------------------
2004 2003 2004 2003
------- ------- ------- -------
(In thousands, except per share data)
Net earnings.................... $11,404 $ 651 $23,934 $ 2,439
Diluted earnings per share...... $ 0.91 $ 0.07 $ 2.18 $ 0.28
20
For interim reporting purposes, inventory increments expected to be
liquidated by year-end are valued at the most recent acquisition costs,
and inventory liquidations expected to be reinstated by year end are
excluded for LIFO inventory valuation calculations. The LIFO effects of
inventory increments not expected to be liquidated by year-end, and the
LIFO effects of inventory liquidations not expected to be reinstated by
year-end, are recorded in the period such increments and liquidations
occur.
In the first and third quarters of 2004, we liquidated certain lower
cost refining crude oil LIFO inventory layers, which resulted in an increase
in our net earnings and related diluted earnings per share as follows:
Three Months Ended Nine Months Ended
September 30, 2004 September 30, 2004
------------------ ------------------
(In thousands, except per share data)
Net earnings.................... $ 2,062 $ 2,617
Diluted earnings per share...... $ 0.16 $ 0.24
The LIFO layers that were liquidated were deemed to be a permanent
liquidation due to the terms of our supply agreement with Statoil
regarding the ownership of crude oil under the agreement. There were no
similar liquidations in 2003.
21
NOTE 9 - DERIVATIVE INSTRUMENTS:
We are exposed to various market risks, including changes in certain
commodity prices and interest rates. To manage these normal business
exposures, from time to time, we use commodity futures and options
contracts to reduce price volatility, to fix margins in our refining and
marketing operations, and to protect against price declines associated
with our crude oil and finished products inventories.
In the first half of 2003, we entered into various crude oil futures
contracts in order to economically hedge crude oil inventories and
purchases for the Yorktown refinery operations. There were no such
transactions in the third quarter of 2003. For the nine months ended
September 30, 2003, we recognized losses on these contracts of
approximately $1,594,000 in cost of products sold. These transactions did
not qualify for hedge accounting in accordance with SFAS No. 133,
"Accounting for Derivative Instruments and Hedging Activities," as
amended, and accordingly were marked to market each month. There were no
similar transactions for the nine months ended September 30, 2004. There
were no open crude oil futures contracts or other commodity derivative
contracts at September 30, 2004.
22
NOTE 10 - PENSION AND POST-RETIREMENT BENEFITS:
In December 2003, FASB revised SFAS No. 132, "Employers' Disclosures
about Pensions and Other Postretirement Benefits," to enhance disclosures
of relevant accounting information by providing additional information on
plan assets, obligations, cash flows, and net cost. The components of the
Net Periodic Benefit Cost are as follows:
Yorktown
Cash Balance Plan
------------------------------------------------
Three Months Ended Nine Months Ended
September 30, September 30,
---------------------- -----------------------
2004 2003 2004 2003
--------- --------- ---------- ----------
Service cost........................... $ 345,005 $ 287,996 $1,035,015 $ 863,988
Interest cost.......................... 134,294 132,739 402,882 398,217
Expected return on plan assets......... (28,624) (5,891) (85,872) (17,673)
Amortization of prior service costs.... - - - -
Amortization of net (gain)/loss........ - - - -
--------- --------- ---------- ----------
Net Periodic Benefit Cost.............. $ 450,675 $ 414,844 $1,352,025 $1,244,532
========= ========= ========== ==========
Yorktown
Retiree Medical Plan
-----------------------------------------------
Three Months Ended Nine Months Ended
September 30, September 30,
---------------------- ----------------------
2004 2003 2004 2003
--------- --------- ---------- ----------
Service cost........................... $ 51,893 $ 48,095 $ 155,679 $ 144,285
Interest cost.......................... 48,673 44,403 146,019 133,209
Expected return on plan assets......... - - - -
Amortization of prior service costs.... - - - -
Amortization of net (gain)/loss........ 4,374 2,537 13,122 7,611
--------- --------- ---------- ----------
Net Periodic Benefit Cost.............. $ 104,940 $ 95,035 $ 314,820 $ 285,105
========= ========= ========== ==========
We previously disclosed in our financial statements for the year
ended December 31, 2003, that we expected to contribute $2,200,000 to our
Yorktown Cash Balance Plan in 2004. Due to recent legislation, which
affected the calculation of our contribution, we contributed $1,828,000 to
the plan on September 15, 2004.
23
On December 8, 2003, the President signed the Medicare Prescription
Drug, Improvement and Modernization Act of 2003 (The "Act"). The Act
provides a federal subsidy to employers whose prescription drug benefits
are actuarially equivalent to certain benefits provided by Medicare. We
have not reflected any expected subsidy in these financial statements and
accompanying notes because, at this time, we have not concluded whether
the benefits provided by our medical plan are actuarially equivalent to
the relevant Medicare benefits.
24
NOTE 11 - LONG-TERM DEBT:
Our long-term debt consisted of the following:
September 30, December 31,
2004 2003
------------- ------------
(In thousands)
11% senior subordinated notes, due 2012, net
of unamortized discount of $3,712 and $5,288,
interest payable semi-annually...................... $145,116 $194,712
9% senior subordinated notes, due 2007,
interest payable semi-annually...................... - 150,000
8% senior subordinated notes, due 2014,
net of unamortized discount of $2,478,
interest payable semi-annually...................... 147,522 -
Senior secured mortgage loan facility, due 2005,
floating interest rate, principal and interest
payable monthly..................................... - 22,000
Other................................................. - 17
-------- --------
Subtotal............................................ 292,638 366,729
Less current portion.................................. - (11,128)
-------- --------
Total............................................... $292,638 $355,601
======== ========
On April 13, 2004, we made an offer to purchase for cash all
$150,000,000 aggregate principal amount outstanding of our 9% senior
subordinated notes due 2007 (the "9% notes") at a price of 103.375% of
their principal amount, plus accrued interest. The offer included a
consent solicitation, which expired on April 26, 2004. The offer was
subject to our successful completion of a new offering of $150,000,000
aggregate principal amount of 8% senior subordinated notes due 2014.
At the expiration of the consent period on April 26, 2004, the
holders of $116,115,000 of our 9% notes had tendered into the tender
offer. The tender offer expired on May 10, 2004. On May 3, 2004, and May
11, 2004, we purchased all of the 9% notes tendered in the consent
solicitation and tender offer. On May 11, 2004, we provided irrevocable
notice to the trustee to redeem the rest of the 9% notes that were not
tendered when the tender offer expired. The redemption of the remaining 9%
notes occurred on June 11, 2004.
On April 28, 2004, we priced our offering of 8% senior subordinated
notes due 2014 at a discount, to yield 8-1/4%. The offering closed on May
3, 2004. At closing, we received net proceeds (before expenses) of
approximately $147,466,500. We used all of the net proceeds of the new
senior subordinated notes offering, together with cash on hand, to settle
the tender offer and consent solicitation and to redeem all 9% notes that
remained outstanding after the expiration of the tender offer.
25
On May 3, 2004, we issued 3,000,000 shares of our common stock at a
public offering price of $18.50 per share. In connection with the
offering, we granted the underwriters an option for a period of 30 days
from the initial offering to purchase up to an additional 450,000 shares
of common stock to cover over-allotments, if any. On May 7, 2004, the
underwriters purchased an additional 283,300 shares pursuant to their
over-allotment option. We received net proceeds from the two sales of
approximately $57,374,000. On June 17, 2004, we used all of the net
proceeds of the common stock offering to redeem a portion of our
outstanding 11% senior subordinated notes due 2012 (including interest to
the date of redemption and the redemption premium) through the exercise of
the provision of the indenture governing the notes that allows us to
repurchase such debt as a result of an equity offering. The redemption
date was June 17, 2004.
Repayment of both the 11% and 8% senior subordinated notes
(collectively, the "Notes") is jointly and severally guaranteed on an
unconditional basis by our subsidiaries, subject to a limitation designed
to ensure that such guarantees do not constitute a fraudulent conveyance.
Except as otherwise specified in the indentures pursuant to which the
Notes were issued, there are no restrictions on the ability of our
subsidiaries to transfer funds to us in the form of cash dividends, loans
or advances. General provisions of applicable state law, however, may
limit the ability of any subsidiary to pay dividends or make distributions
to us in certain circumstances.
The indentures governing the notes contain restrictive covenants
that, among other things, restrict our ability to:
- create liens;
- incur or guarantee debt;
- pay dividends;
- repurchase shares of our common stock;
- sell certain assets or subsidiary stock;
- engage in certain mergers;
- engage in certain transactions with affiliates; or
- alter our current line of business.
In addition, subject to certain conditions, we are obligated to offer
to repurchase a portion of the notes at a price equal to 100% of the
principal amount thereof, plus accrued and unpaid interest, if any, to the
date of repurchase, with the net cash proceeds of certain sales or other
dispositions of assets. Upon a change of control, we would be required to
offer to repurchase all of the notes at 101% of the principal amount
thereof, plus accrued interest, if any, to the date of purchase. At
September 30, 2004, retained earnings available for dividends under the
most restrictive terms of the indentures were approximately $26,148,000.
26
We also have a $100,000,000 three-year senior secured revolving
credit facility (the "Credit Facility") with a group of banks. We entered
into the Credit Facility on July 15, 2004. The Credit Facility amended and
restated a similar $100,000,000 credit facility. At September 30, 2004,
there were no direct borrowings outstanding under the Credit Facility. At
September 30, 2004, there were, however, $20,544,000 of irrevocable
letters of credit outstanding, primarily to crude oil suppliers, insurance
companies, and regulatory agencies. At December 31, 2003, there were no
direct borrowings and $36,961,000 of irrevocable letters of credit
outstanding under the previous credit facility.
The interest rate applicable to the Credit Facility is based on
various short-term indices. At September 30, 2004, this rate was
approximately 4.3% per annum. We are required to pay a quarterly
commitment fee of 0.50% per annum of the unused amount of the facility.
Under the new Credit Facility, our existing borrowing costs are
reduced and certain of the covenants have been relaxed. The Credit
Facility is primarily a working capital and letter of credit facility. The
availability of funds under this facility is the lesser of (i)
$100,000,000, or (ii) the amount determined under a borrowing base
calculation tied to the eligible accounts receivable and inventories. We
have a one-time option to increase the size of the facility to up to
$125,000,000. At October 31, 2004, the availability of funds under the
Credit Facility was $100,000,000. There were no direct borrowings
outstanding under this facility at October 31, 2004, and there were
approximately $29,298,000 of irrevocable letters of credit outstanding,
primarily to crude oil suppliers, insurance companies and regulatory
agencies.
The obligations under the Credit Facility are guaranteed by each of
our principal subsidiaries and secured by a security interest in our
personal property, including:
- accounts receivable;
- inventory;
- contracts;
- chattel paper;
- trademarks;
- copyrights;
- patents;
- license rights;
- deposits; and
- investment accounts and general intangibles.
The Credit Facility contains negative covenants limiting, among other
things, our ability to:
- incur additional indebtedness;
- create liens;
- dispose of assets;
27
- consolidate or merge;
- make loans and investments;
- enter into transactions with affiliates;
- use loan proceeds for certain purposes;
- guarantee obligations and incur contingent obligations;
- enter into agreements restricting the ability of subsidiaries to
pay dividends to us;
- make distributions or stock repurchases;
- make significant changes in accounting practices or change our
fiscal year; and
- prepay or modify subordinated indebtedness, except on terms
acceptable to the senior secured lenders.
The Credit Facility also requires us to meet certain financial
covenants, including maintaining a minimum consolidated net worth, a
minimum fixed charge coverage ratio, and a maximum consolidated funded
indebtedness to total capitalization percentage.
Our failure to satisfy any of the covenants in the Credit facility is
an event of default under the Credit Facility. The Credit Facility also
includes other customary events of default, including, among other things,
a cross-default to our other material indebtedness and certain changes of
control.
We had a $40,000,000 three-year senior secured mortgage loan facility
(the "Loan Facility") with a group of financial institutions. We paid off
the remaining $17,556,000 balance of the Loan Facility on July 14, 2004
from cash on hand.
Separate financial statements of our subsidiaries are not included
herein because the aggregate assets, liabilities, earnings, and equity of
the subsidiaries are substantially equivalent to our assets, liabilities,
earnings, and equity on a consolidated basis; the subsidiaries are jointly
and severally liable for the repayment of the Notes; and the separate
financial statements and other disclosures concerning the subsidiaries are
not deemed by us to be material to investors.
28
NOTE 12 - COMMITMENTS AND CONTINGENCIES
COMMITMENTS
- -----------
AIRPLANE LEASE AGREEMENT
We presently own and operate a 1976 airplane (the "Old Aircraft").
Upgrades to the Old Aircraft's avionics and navigation system required in
2005 and future upgrades beyond 2005 would be significant. In addition,
the costs to operate and maintain the Old Aircraft are expected to
increase significantly over the next few years. In lieu of trying to
upgrade and maintain the Old Aircraft, we have decided to sell it and to
lease an airplane (the "Leased Aircraft"). The base term of the lease will
be 12.5 years with an option to purchase the Leased Aircraft, which is
exercisable at three points during the base term of the lease. The lease
payments will be adjusted based on changes in the one-month London
Interbank Offered rate ("LIBOR"). Annual lease payments before the
adjustment for LIBOR rate changes are as follows:
Years 1 to 6 $729,000
Year 7 $850,000
Years 8 and thereafter $890,000
CONTINGENCIES
- -------------
We have various legal actions, claims, assessments and other
contingencies arising in the normal course of our business pending against
us, including those matters described below. Some of these matters involve
or may involve significant claims for compensatory, punitive or other
damages. These matters are subject to many uncertainties, and it is
possible that some of these matters could be ultimately decided, resolved
or settled adversely. We have recorded accruals for losses related to
those matters that we consider to be probable and that can be reasonably
estimated. We currently believe that any amounts exceeding our recorded
accruals should not materially affect our financial condition or
liquidity. It is possible, however, that the ultimate resolution of these
matters could result in a material adverse effect on our results of
operations for a particular reporting period.
Federal, state and local laws relating to the environment, health and
safety affect nearly all of our operations. As is the case with all
companies engaged in the refining and related businesses, we face
significant exposure from actual or potential claims and lawsuits
involving environmental matters. These matters include soil and water
contamination, air pollution and personal injuries or property damage
allegedly caused by substances made, handled, used, released or disposed
of by us or by our predecessors.
29
Future expenditures related to environmental, health and safety
matters cannot be reasonably quantified in many circumstances for various
reasons. These reasons include the speculative nature of remediation and
clean-up cost estimates and methods, imprecise and conflicting data
regarding the hazardous nature of various types of substances, the number
of other potentially responsible parties involved, various defenses that
may be available to us, and changing environmental, health and safety
laws, including changing interpretations of those laws.
ENVIRONMENTAL AND LITIGATION ACCRUALS
As of September 30, 2004 and December 31, 2003, we had environmental
liability accruals of approximately $6,843,000 and $7,592,000,
respectively, which are summarized below, and litigation accruals in the
aggregate of $1,109,000 at September 30, 2004 and $573,000 at December 31,
2003. The environmental accruals are recorded in the current and long-term
sections of our consolidated balance sheets and the litigation accruals
are all recorded as current liabilities.
SUMMARY OF ACCRUED ENVIRONMENTAL CONTINGENCIES
(In thousands)
December 31, Increase September 30,
2003 (Decrease) Payments 2004
------------ ---------- -------- -------------
Yorktown 1991 Order....................... $ 5,916 $ - $ (780) $ 5,136
Farmington Refinery....................... 570 - - 570
Bloomfield Refinery....................... 267 - (15) 252
Ciniza - Solid Waste Management Units..... 275 - - 275
Ciniza - Land Treatment Facility.......... 186 - - 186
Ciniza Well Closures...................... 140 - (31) 109
Retail Service Stations - Various......... 146 13 (11) 148
East Outfall - Bloomfield................. 25 - (12) 13
Western Outfall - Bloomfield.............. - 150 (51) 99
Bloomfield Tank Farm (Old Terminal)....... 67 - (12) 55
------- ----- ------ -------
Totals................................. $ 7,592 $ 163 $ (912) $ 6,843
======= ===== ====== =======
Approximately $6,419,000 of our environmental accruals are for the
following projects:
- certain environmental obligations assumed in connection with our
acquisitions of the Yorktown refinery and the Bloomfield refinery;
30
- the remediation of the hydrocarbon plume that appears to extend no
more than 1,800 feet south of our inactive Farmington refinery;
- the closure of certain solid waste management units at the Ciniza
refinery in accordance with the refinery's Resource Conservation
and Recovery Act permit; and
- closure of the Ciniza refinery land treatment facility, including
post-closure expenses.
The remaining amount of the accruals relate to smaller remediation
and monitoring projects.
YORKTOWN ENVIRONMENTAL LIABILITIES
We assumed certain liabilities and obligations in connection with our
purchase of the Yorktown refinery from BP Corporation North America Inc.
and BP Products North America Inc. (collectively "BP"). BP agreed to
reimburse us in specified amounts for some matters. Among other things,
and subject to certain exceptions, we assumed responsibility for all
costs, expenses, liabilities, and obligations under environmental, health
and safety laws caused by, arising from, incurred in connection with or
relating to the ownership of the refinery or its operation. We agreed to
reimburse BP for losses incurred in connection with or related to
liabilities and obligations assumed by us. Certain environmental matters
relating to the Yorktown refinery are discussed below.
YORKTOWN CONSENT DECREE
We assumed environmental obligations that include BP's
responsibilities relating to the Yorktown refinery under a consent decree
among various parties covering many locations (the "Consent Decree").
Parties to the Consent Decree include the United States, BP Exploration
and Oil Co., Amoco Oil Company, and Atlantic Richfield Company. We assumed
BP's responsibilities as of January 18, 2001, the date the Consent Decree
was lodged with the court. As applicable to the Yorktown refinery, the
Consent Decree requires, among other things, reduction of NOx, SO2 and
particulate matter emissions and upgrades to the refinery's leak detection
and repair program. We estimate that we will incur capital expenditures of
between $20,000,000 and $27,000,000 to comply with the Consent Decree
through 2006, and have expended approximately $300,000 of this amount
through the end of the third quarter. We believe we will incur most of the
remaining expenditures in 2005 and 2006. In addition, we estimate that we
will incur operating expenses associated with the requirements of the
Consent Decree of between $1,600,000 and $2,600,000 per year.
YORKTOWN 1991 ORDER
In connection with the Yorktown acquisition, we also assumed BP's
obligations under an administrative order issued by EPA in 1991 under the
Resource Conservation and Recovery Act. The order requires an
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investigation of certain areas of the refinery and the development of
measures to correct any releases of contaminants or hazardous substances
found in these areas. A Resource Conservation and Recovery Act Facility
Investigation was conducted and approved conditionally by EPA in 2002.
Following the investigation, a Risk Assessment/Corrective Measures Study
("RA/CMS") was finalized in 2003, which summarized the remediation
measures agreed upon by us, EPA, and the Virginia Department of
Environmental Quality ("VDEQ"). The RA/CMS include certain investigation,
sampling, monitoring, and cleanup measures, including the construction of
an on-site corrective action management unit that would be used to
consolidate hazardous solid materials associated with these measures.
These proposed actions relate to soil, sludge, and remediation wastes
relating to solid waste management units. Groundwater in the aquifers
underlying the refinery, and surface water and sediment in a small pond
and tidal salt marsh on the refinery property also are addressed in the
RA/CMS.
Based upon the RA/CMS, EPA issued a proposed cleanup plan for public
comment in December 2003 setting forth preferred corrective measures for
remediating soil, groundwater, sediment, and surface water contamination
at the refinery. Following the public comment period, EPA issued its final
remedy decision and response to comments in April 2004. EPA currently is
developing the administrative consent order pursuant to which we will
implement the corrective measures.
Our most current estimate of expenses associated with the actions
described in the cleanup plan is between $24,000,000 and $26,000,000. We
anticipate that these expenses will be incurred over a period of
approximately 35 years after the consent order is issued. We believe that
about $7,500,000 of this amount will be incurred over an initial 3-year
period, and additional expenditures of about $6,000,000 will be incurred
over the following 3-year period. As more fully described below, we may
not, however, be responsible for all of these expenditures due to the
environmental reimbursement provisions included in our purchase agreement
with BP. Additionally, the facility's underground sewer system will be
cleaned, inspected and repaired as needed as part of the RA/CMS process.
We anticipate that this work, the cost of which is included in the above
cost estimate, will begin near the start of construction of the corrective
action management unit and will progress in phases over the following four
to five years.
CLAIMS FOR REIMBURSEMENT FROM BP
BP has agreed to reimburse us for all losses that are caused by or
relate to property damage caused by, or any environmental remediation
required due to, a violation of environmental, health, and safety laws
during BP's operation of the refinery. In order to have a claim against
BP, however, the total of all our losses must exceed $5,000,000, in which
event our claim only relates to the amount exceeding $5,000,000. After
32
$5,000,000 is reached, our claim is limited to 50% of the amount by which
our losses exceed $5,000,000 until the total of all our losses exceeds
$10,000,000. After $10,000,000 is reached, our claim would be for 100% of
the amount by which our losses exceed $10,000,000. In applying these
provisions, losses amounting to a total of less than $250,000 arising out
of the same event are not added to any other losses for purposes of
determining whether and when the $5,000,000 or $10,000,000 thresholds have
been reached. After the $5,000,000 or $10,000,000 thresholds have been
reached, BP has no obligation to reimburse us for any losses amounting to
a total of less than $250,000 arising out of the same event. Except as
specified in the refinery purchase agreement, in order to seek
reimbursement from BP, we were required to notify BP of a claim within two
years following the closing date. Further, BP's total liability for
reimbursement under the refinery purchase agreement, including liability
for environmental claims, is limited to $35,000,000.
FARMINGTON REFINERY
In 1973, we constructed the Farmington refinery that we operated
until 1982. In 1985, we became aware of soil and shallow groundwater
contamination at this facility. Our environmental consulting firms
identified several areas of contamination in the soils and shallow
groundwater underlying the Farmington property. One of our consultants
indicated that contamination attributable to past operations at the
Farmington property has migrated off the refinery property, including a
hydrocarbon plume that appears to extend no more than 1,800 feet south of
the refinery property. Our remediation activities are ongoing under the
supervision of the New Mexico Oil Conservation Division ("OCD"), although
OCD has not issued a cleanup order.
LEE ACRES LANDFILL
The Farmington refinery property is located next to the Lee Acres
Landfill, a closed landfill formerly operated by San Juan County. The
landfill is situated on lands owned by the United States Bureau of Land
Management (the "BLM"). Industrial and municipal wastes from numerous
sources were disposed of in the landfill. While the landfill was
operational, we used it to dispose of office trash, maintenance shop
trash, used tires, and water from the Farmington refinery's evaporation
pond.
The landfill was added to the National Priorities List as a
Comprehensive Environmental Response, Compensation and Liability Act
("CERCLA") Superfund site in 1990. In connection with this listing, EPA
defined the site as the landfill and the landfill's associated groundwater
plume. EPA excluded any releases from the Farmington refinery itself from
the definition of the site. In May 1991, EPA notified us that we may be a
potentially responsible party under CERCLA for the release or threatened
release of hazardous substances, pollutants or contaminants at the
landfill.
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BLM made a proposed cleanup plan for the landfill available to the
public in 1996. In September 2004, EPA and BLM issued a Record of
Decision, which presents the cleanup plan selected for the landfill. The
selected remedy consists of placing a cap over a portion of the old
landfill, together with a barrier to prevent contaminants from moving off
the site, groundwater monitoring, and site usage limitations. The Record
of Decision states that the total estimated cost of these actions is
$2,200,000 in the near term, with the total future cost for remediation of
the landfill not expected to exceed $3,500,000 over 30 years. If
monitoring data indicated a long-term trend of significantly increasing
pollution concentrations, then the selected remedy would be reevaluated,
and appropriate corrective action would be taken, if needed.
In 1989, one of our consultants estimated, based on various
assumptions, that our share of potential landfill liability could be
approximately $1,200,000. This figure was based upon estimated landfill
remediation costs significantly higher than the estimated costs reflected
in the Record of Decision. The figure also was based on the consultant's
evaluation of such factors as available clean-up technology, BLM's
involvement at the site and the number of other entities that may have had
involvement at the site, but did not include an analysis of all of our
potential legal defenses and arguments, including possible setoff rights.
Potentially responsible party liability is joint and several, which
means that a responsible party may be liable for all of the clean-up costs
at a site even though the party was responsible for only a small part of
the contamination. Although it is possible that we may ultimately incur
liability for clean-up costs associated with the landfill, a reasonable
estimate of the amount of this liability, if any, cannot be made at this
time for various reasons. These reasons include:
- a number of entities had involvement at the site;
- allocation of responsibility among potentially responsible parties
has not yet been proposed or made; and
- potentially applicable factual and legal issues have not been
resolved.
Accordingly, we have not recorded a liability in relation to BLM's
selected plan, as the amount of any potential liability is currently not
determinable.
BLM or others may assert claims against others and us for
reimbursement of investigative, cleanup and other costs incurred in
connection with the landfill and surrounding areas. We may assert claims
against BLM or others in connection with contamination that may be
originating from the landfill. Private parties and governmental entities
also may assert claims against us, BLM, and others for property damage,
personal injury and other damages allegedly arising out of any
contamination originating from the landfill and the Farmington property.
Parties also may request judicial determination of their rights and
responsibilities, and the rights and responsibilities of others, in
connection with the landfill and the Farmington property. Currently,
however, there is no outstanding litigation against us by BLM or any other
party.
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BLOOMFIELD REFINERY
In connection with the acquisition of the Bloomfield refinery, we
assumed certain environmental obligations including Bloomfield Refining
Company's ("BRC") obligations under an administrative order issued by EPA
in 1992 pursuant to the Resource Conservation and Recovery Act. The order
required BRC to investigate and propose measures for correcting any
releases of hazardous waste or hazardous constituents at or from the
Bloomfield refinery. EPA has delegated its oversight authority over the
order to the New Mexico Environment Department's ("NMED's") Hazardous
Waste Bureau ("HWB"). In December 2002, HWB and OCD approved a cleanup
plan for the refinery, subject to various actions to be taken by us to
implement the plan. We estimate that remaining remediation expenses
associated with the cleanup plan will be approximately $252,000, and that
these expenses will be incurred through approximately 2018.
WESTERN OUTFALL - BLOOMFIELD REFINERY
In August 2004, hydrocarbon discharges were discovered seeping into
two small gullies, or draws, on the north side of the Bloomfield refinery
site. We took immediate containment and other corrective actions,
including removal of contaminated soils, construction of lined collection
sumps, and further investigation and monitoring. We are engaged in
discussions with OCD on the design and scope of a permanent remediation
plan. OCD has indicated that it will be issuing a compliance order,
including a possible penalty, in connection with these discharges, but we
have not received any order to date. OCD also indicated that its preferred
remedy is an underground barrier with a pollutant extraction and
collection system. We currently estimate that the cost of such a remedy
could range from $500,000 to $1,000,000. The barrier could be constructed
as early as the first quarter of 2005, with the extraction and collection
system to be designed and completed later in 2005. These costs will
involve construction of permanent facilities, which will be accounted for
as capital expenditures and therefore are not included in our
environmental accrual for this matter. As of September 30, 2004, $99,000
has been accrued for non-capital expenditures associated with our
remediation efforts.
NOTICES OF VIOLATION AT FOUR CORNERS REFINERIES
In June 2002, we received a draft compliance order from the NMED
alleging violations of air quality regulations at the Ciniza refinery.
These alleged violations relate to an inspection completed in April 2001.
In August 2002, we received a compliance order from NMED alleging
violations of air quality regulations at the Bloomfield refinery. These
alleged violations relate to an inspection completed in September 2001.
35
In the second quarter of 2003, EPA informally told us that it also
intended to allege air quality violations in connection with the 2001
inspections at both refineries. We have since participated in joint
meetings with NMED and EPA. These discussions have addressed alleged
violations through December 31, 2003, in addition to matters relating to
the 2001 inspections. If no settlement is reached, we currently estimate
that potential penalties could amount to between $4,000,000 and
$6,000,000. We have accrued significantly less than these amounts because
settlement discussions with NMED and EPA are ongoing. These discussions
may result in reductions in the amount of potential penalties. In lieu of
fines and as part of an administrative settlement, we expect that EPA and
NMED may require us to undertake certain environmentally beneficial
projects known as supplemental environmental projects.
In the first quarter of 2004, EPA told us that any administrative
settlement also must be consistent with the consent decrees EPA has
entered with other refiners as part of its national refinery enforcement
program. In these other settlements, EPA generally has required that the
refiner:
- implement controls to reduce emissions of nitrogen oxide, sulfur
dioxide, carbon monoxide, and particulate matter from the largest
emitting process units;
- upgrade leak-detection and repair practices;
- minimize the number and severity of flaring events; and
- adopt strategies to ensure compliance with benzene waste
requirements.
We currently believe that we could satisfy the requirements of the
national refinery initiative by making modifications to our Four Corners
refineries that would cost between approximately $14,000,000 and
$20,000,000, and that it might be possible to spread these costs over a
period of five to eight years following the date of any settlement. In
addition, on-going annual operating costs associated with these
modifications are currently estimated to be as much as $1,500,000 per
year. We currently anticipate that the majority of the capital and
operating costs would be incurred in the later portion of the projected
five to eight year phase-in period. These costs could be subject to
reduction in the event of the temporary, partial or permanent
discontinuance of operations at one or both facilities, as more fully
discussed in the section titled "Other" in Part I, Item 2, Management's
Discussion and Analysis of Financial Condition and Results of Operations.
There is no assurance, however, that EPA will agree with our assessment of
the national refinery initiative requirements. Accordingly, EPA might
require us to incur additional national refinery initiative compliance
costs as a part of any settlement.
As of September 30, 2004, we were continuing joint settlement
discussions with NMED and EPA.
36
JET FUEL CLAIM
In February 2003, we filed a complaint against the United States in
the United States Court of Federal Claims related to military jet fuel
that we sold to the Department of Defense from 1983 through 1994. We
asserted that the federal government underpaid for the jet fuel by about
$17,000,000. We requested that we be made whole in connection with
payments that were less than the fair market value of the fuel, that we be
reimbursed for the value of transporting the fuel in some contracts, and
that we be reimbursed for certain additional costs of complying with the
government's special requirements. The U.S. has said that it may
counterclaim and assert, based on its interpretation of the contracts,
that we owe additional amounts of between $2,100,000 and $4,900,000. In
the first quarter of 2004, the United States Court of Appeals for the
Federal Circuit agreed to hear appeals in other jet fuel cases. The issues
before the Court of Appeals in these cases are almost identical to the
issues in our case. The judge in our case has halted any further action
pending a guiding decision by the Court of Appeals. As of September 30,
2004, we are continuing to await further action by the appellate court.
Due to the preliminary nature of this matter, there can be no assurance
that we will ultimately prevail on our claims or the U.S.'s potential
counterclaim, nor is it possible to predict when any payment will be
received if we are successful. Accordingly, we have not recorded a
receivable for these claims or a liability for any potential counterclaim.
MTBE LITIGATION
Lawsuits have been filed in numerous states alleging that MTBE, a
blendstock used by many refiners in producing specially formulated
gasoline, has contaminated or threatens to contaminate water supplies.
MTBE contamination primarily results from leaking underground or
aboveground storage tanks. We are a defendant in three MTBE lawsuits filed
in Virginia in the fourth quarter of 2003. Since then, we have been added
as a defendant in over thirty additional MTBE lawsuits, including suits
pending in the States of Connecticut, Illinois, Indiana, Massachusetts,
New Hampshire, New York, Pennsylvania, Vermont, and West Virginia. All of
these cases have been consolidated and transferred to a federal district
court in New York City. The majority of the plaintiffs in these suits are
cities, counties, or other public entities that own or operate water
supplies. The plaintiffs assert that numerous refiners, distributors, or
sellers of MTBE and/or gasoline containing MTBE are responsible for MTBE
contamination. The plaintiffs also claim that the defendants are jointly
and severally liable for compensatory and punitive damages, costs, and
interest. Joint and several liability means that each defendant may be
liable for all of the damages even though that party was responsible for
only a small part of the damages. We are vigorously defending these
lawsuits. It is possible that we could be named as a defendant in
additional lawsuits, which we also would plan to vigorously defend. Due to
the preliminary nature of these lawsuits, we cannot predict their outcome
and, accordingly, have not recorded a liability in connection with this
matter.
37
YORKTOWN POWER OUTAGE CLAIM
On April 28, 2003, a breaker failure disrupted operations at the
electric generation plant that supplies our Yorktown refinery with power.
As a result of the failure, the refinery suffered a complete loss of power
and shutdown all processing units. By the middle of May 2003, the refinery
was operating at full capacity. We incurred costs of approximately
$1,254,000 as a result of the loss of power, all of which we expensed in
the second quarter of 2003. Reduced production also resulted in a loss of
earnings. We are pursuing reimbursement from the power station owner as
well as other forms of relief. As of September 30, 2004, settlement
discussions with the power station owner were continuing and, accordingly,
we have not recorded any receivables related to this claim.
CINIZA REFINERY INCIDENT
On April 8, 2004, a fire occurred at our Ciniza refinery in the
alkylation unit which produces high octane blending stock for gasoline.
Emergency personnel responded immediately and contained the fire to the
alkylation unit, although there also was some damage to ancillary
equipment and to two adjacent units. Four of our employees were injured
and transported to an Albuquerque hospital. Presently, three have been
released and one remains hospitalized.
In October 2004, the Occupational Health and Safety Board of the New
Mexico Environment Department ("OHSB") completed an investigation of
matters relating to the fire. We are vigorously contesting violations
alleged by OHSB in connection with its investigation and related proposed
fines. We are currently in settlement discussions with OHSB. We anticipate
that any fines ultimately imposed by OHSB will be less than $65,000.
An investigation by the U.S. Chemical Safety and Hazard Investigation
Board ("CSB") of matters relating to the fire is ongoing. CSB, however,
does not have authority to issue any monetary fines.
Based upon a very preliminary investigation, we had estimated that
the cost to repair the damage caused by the fire would be in the range of
$2,500,000 to $10,000,000 and that repairs would be completed before the
end of June. As the investigation proceeded, and we began to make repairs,
additional damage was discovered. The repairs have been completed at a
cost of approximately $13,800,000 and the unit was restarted in the third
quarter of 2004. The repairs took longer than initially anticipated as we
experienced delays in receiving a vessel, instrumentation, and valves
necessary to complete the repairs. We have property insurance coverage
that should reimburse us for a significant portion of the repair costs,
and approximately $3,600,000 has been received through the end of the
third quarter. We hope to resolve all matters relating to potential
insurance reimbursements by the end of this year. We also have worker's
compensation insurance to cover the physical injuries sustained by
personnel.
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NEW MEXICO CONVENIENCE STORE SAFETY REGULATIONS
In May 2004, OHSB proposed regulations that require additional
security measures in the convenience store industry in New Mexico. These
requirements relate to, among other things, exterior lighting, late night
security, employee training, door and window signage, and security
surveillance systems and alarms. In June 2004, the New Mexico
Environmental Improvement Board (the "EIB") agreed to stay some of these
regulations, including late night security requirements, for further
study. The EIB subsequently decided to proceed with the regulations, which
we anticipate will become enforceable in December 2004. The legality of
these regulations, however, is the subject of a court challenge by, among
others, the New Mexico Petroleum Marketers Association.
We will need to modify our current operations to comply with the
convenience store safety regulations. For example, we could comply with
the late night security requirements by having two employees on duty
between the hours of 11:00 p.m. and 5:00 a.m. We estimate that having two
employees at all of our New Mexico stores during these late night hours
could increase our payroll costs between $700,000 and $1,000,000 annually.
Alternately, we could add security enclosures to our stores at an
estimated one-time cost of approximately $2,200,000. In either case, we
also could incur additional one-time costs of approximately $300,000 for
enhanced security surveillance systems and alarms, safes, and security
signs. These are preliminary cost estimates with many variables that could
affect the actual costs. We are evaluating our options for complying with
these regulations.
FORMER CEO MATTERS
The board of directors terminated James E. Acridge as our President
and Chief Executive Officer on March 29, 2002, and replaced him as our
Chairman of the Board. Mr. Acridge's term of office as a director
subsequently expired on April 29, 2004.
On July 22, 2002, Mr. Acridge filed a lawsuit in the Superior Court
of Arizona for Maricopa County against a number of our officers and
directors. The lawsuit was also filed against unidentified accountants,
auditors, appraisers, attorneys, bankers and professional advisors. Mr.
Acridge alleged that the defendants wrongfully interfered with his
employment agreement and caused the board to fire him. The complaint
sought unspecified damages to compensate Mr. Acridge for the defendants'
alleged wrongdoing, as well as punitive damages, and costs and attorneys'
fees. The complaint also stated that Mr. Acridge intended to initiate a
separate arbitration proceeding against us, alleging that we breached his
employment agreement and violated an implied covenant of good faith and
fair dealing. The court subsequently ruled that the claims raised in Mr.
Acridge's lawsuit were subject to arbitration and the lawsuit was
dismissed. Arbitration proceedings were never initiated. Subsequent to the
filing of the claims, Mr. Acridge filed for bankruptcy.
39
In addition to Mr. Acridge's personal bankruptcy filing, Pinnacle
Rodeo LLC, Pinnacle Rawhide LLC, and Prime Pinnacle Peak Properties, Inc.,
three entities originally controlled by Mr. Acridge, also commenced
Chapter 11 bankruptcy proceedings. A Chapter 11 trustee was appointed in
these cases. The four bankruptcy cases have been administered together.
We had an outstanding loan to Mr. Acridge in the principal amount of
$5,000,000. In the fourth quarter of 2001, we established a reserve for
the entire amount of the loan plus interest accrued through December 31,
2001. The loan was subsequently written off, at which time the reserve was
removed. We filed proofs of claim in the bankruptcy proceedings seeking
to recover amounts we believe are owed to us by Mr. Acridge, and the other
entities, including amounts relating to the outstanding $5,000,000 loan.
We also filed a complaint in the Acridge bankruptcy proceeding on July 31,
2003, in which we sought a determination that certain of the amounts we
believe are owed to us by Mr. Acridge are not dischargeable in bankruptcy.
The court has entered a default against Mr. Acridge in connection with our
complaint. The court, however, has not yet ruled on whether we are
entitled to receive any of the damages that we have requested. Even if the
court decides that we can receive damages, we do not know whether we would
be able to recover any of these damages from Mr. Acridge.
The court-appointed trustee in Mr. Acridge's personal bankruptcy
retained counsel to investigate the claims that Mr. Acridge asserted in
his state court lawsuit, along with other pre-bankruptcy claims that Mr.
Acridge might have had against us, our officers or directors, or our
third-party advisors. The trustee's counsel ultimately informed us that he
believed that such potential claims might exist. We believe that, as a
result of Mr. Acridge's bankruptcy filing, any such claims now belong to
Mr. Acridge's bankruptcy estate rather than to Mr. Acridge personally, and
the trustee has indicated that he shares this belief.
We have evaluated the trustee's contentions and do not believe that
the potential claims have any merit. Nonetheless, in an effort to avoid
the considerable expense associated with litigation, we recently entered
into a settlement agreement with the trustee in Mr. Acridge's personal
bankruptcy, the official committee of unsecured creditors, and the trustee
in the Prime Pinnacle proceeding. The bankruptcy court has approved this
settlement agreement.
Pursuant to the settlement, we have made a payment for the benefit of
the Acridge estate. Additionally, we have given up all of our rights to
receive distributions from the estates, with the exception of a claim for
our share of any assets of the Acridge estate that we do not know about
and that have not yet been identified in the Acridge bankruptcy
proceeding. In return, the four estates have released us from all of their
claims, if any, against us, our officers or directors, or our third party
advisors. Neither the plan, nor our settlement agreement, preclude us from
pursuing our non-dischargeability complaint against Mr. Acridge.
40
In addition to our settlement, the bankruptcy court has approved
plans of reorganization for the Acridge and Prime Pinnacle Peak Properties
bankruptcy cases. The plans describe a process for the liquidation of the
estates and the payment of liquidation proceeds to creditors. The Pinnacle
Rodeo and Pinnacle Rawhide bankruptcy cases have been converted to Chapter
7 liquidation proceedings.
41
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
COMPANY OVERVIEW
We refine and sell petroleum products and operate service stations
and convenience stores. Our operations are divided into three strategic
business units, the refining group, the retail group and Phoenix Fuel. The
refining group operates two refineries in the Four Corners area of New
Mexico and one refinery in Yorktown, Virginia. The refining group sells
its products to wholesale distributors and retail chains. Our retail group
operated 125 service stations at September 30, 2004. The retail group
sells its petroleum products and merchandise to consumers in New Mexico,
Arizona and southern Colorado. Phoenix Fuel distributes commercial
wholesale petroleum products primarily in Arizona.
Our strategy is to maintain and improve our financial performance. To
this end, we are focused on several critical and challenging objectives.
We will be addressing these objectives in the short-term as well as over
the next three to five years. In our view, the most important of these
objectives are:
- increasing margins (through management of inventories and taking
advantage of sales and purchasing opportunities;
- minimizing or reducing operating expenses and capital
expenditures;
- increasing the available crude oil supply for our Four Corners
refineries;
- cost effectively complying with current environmental regulations
as they apply to our refineries, including future clean air
standards;
- improving our overall financial health and flexibility by, among
other things, reducing our debt and overall cost of capital,
including our interest and financing costs, and maximizing our
return on capital employed; and
- evaluating opportunities for internal growth and growth by
acquisition.
CRITICAL ACCOUNTING POLICIES
A critical step in the preparation of our financial statements is the
selection and application of accounting principles, policies, and
procedures that affect the amounts that we report. In order to apply these
principles, policies, and procedures, we must make judgments, assumptions,
and estimates based on the best available information at the time. Actual
results may differ based on the accuracy of the information utilized and
subsequent events, some of which we may have little or no control over. In
addition, the methods used in applying the above may result in amounts
that differ considerably from those that would result from the application
of other acceptable methods. The development and selection of these
critical accounting policies, and the related disclosure below, have been
reviewed with the audit committee of our board of directors.
42
Our significant accounting policies, including revenue recognition,
inventory valuation, and maintenance costs, are described in Note 1 to our
Consolidated Financial Statements included in our Annual Report on Form
10-K for the year ended December 31, 2003. The following accounting
policies are considered critical due to the uncertainties, judgments,
assumptions and estimates involved:
- accounting for contingencies, including environmental remediation
and litigation liabilities;
- assessing the possible impairment of long-lived assets;
- accounting for asset retirement obligations; and
- accounting for our pension and post-retirement benefit plans.
There have been no changes to these policies in 2004.
RESULTS OF OPERATIONS
The following discussion of our Results of Operations should be read
in conjunction with the Consolidated Financial Statements and related
notes thereto included in Part I, Item 1, and Part I, Item 8 in our Annual
Report on Form 10-K for the year ended December 31, 2003.
43
Below is operating data for our operations:
Three Months Ended Nine Months Ended
September 30, September 30,
--------------------- ---------------------
2004 2003 2004 2003
--------- --------- --------- ---------
Refining Group Operating Data:
Four Corners Operations:
Crude Oil/NGL Throughput (BPD)................ 29,271 29,244 28,010 30,741
Refinery Sourced Sales Barrels (BPD).......... 28,412 30,147 27,072 30,713
Average Crude Oil Costs ($/Bbl)............... $ 40.99 $ 28.90 $ 36.60 $ 29.34
Refining Margins ($/Bbl)...................... $ 8.14 $ 9.51 $ 9.54 $ 9.03
Yorktown Operations:
Crude Oil/NGL Throughput (BPD)................ 53,991 60,485 60,918 56,368
Refinery Sourced Sales Barrels (BPD).......... 53,585 62,937 62,391 58,804
Average Crude Oil Costs ($/Bbl)............... $ 38.43 $ 28.54 $ 35.27 $ 29.91
Refining Margins ($/Bbl)...................... $ 6.01 $ 4.61 $ 5.93 $ 3.93
Retail Group Operating Data:
(Continuing operations only)
Fuel Gallons Sold (000's)....................... 41,244 39,524 116,664 110,700
Fuel Margins ($/gal)............................ $ 0.179 $ 0.205 $ 0.184 $ 0.198
Merchandise Sales ($ in 000's).................. $ 36,214 $ 34,664 $101,194 $ 95,020
Merchandise Margins............................. 20% 29% 23% 29%
Operating Retail Outlets at Period End:
Continuing Operations......................... 125 125 125 125
Discontinued Operations....................... - 4 - 4
Phoenix Fuel Operating Data:
Fuel Gallons Sold (000's)....................... 119,253 109,903 356,439 318,088
Fuel Margins ($/gal)............................ $ 0.051 $ 0.052 $ 0.053 $ 0.051
Lubricant Sales ($ in 000's).................... $ 7,933 $ 6,140 $ 22,635 $ 17,967
Lubricant Margins............................... 13.0% 15.8% 13.0% 15.7%
We believe the comparability of our continuing results of operations
for the three and nine months ended September 30, 2004 with the same
periods in 2003 was affected by, among others, the following factors:
- stronger combined net refining margins for our refineries in 2004,
due to, among other things:
- increased finished product demand;
- increased sales in our Tier 1 markets;
44
- reduced imports of foreign gasoline, due to a reduction in
gasoline sulfur limits;
- elimination of MTBE in Connecticut, New York, and California; and
- tight finished product supply in certain of our market areas.
- the processing of lower priced acidic crude oils at our Yorktown
refinery, including crude oil purchased under our supply agreement
with Statoil that began deliveries in late February 2004;
- a processing unit turnaround at our Yorktown refinery in 2003,
which resulted in the refinery being out of operation from March
21, 2003 to April 16, 2003;
- an unplanned shutdown of all processing units at the Yorktown
refinery from the end of April 2003 to the middle of May 2003 as a
result of a breaker failure at the electric generation plant that
supplies the refinery;
- continued reduced production at our Four Corners refineries
because of lower crude oil receipts due to supplier production
problems and reduced supply availability;
- stronger finished product sales volumes and margins for our
Phoenix Fuel operations, due to, among other things:
- increased finished product demand;
- an expanded customer base; and
- tight finished product supplies in our Phoenix market;
- lower merchandise margins for our retail group;
- the shutdown of the alkylation unit at our Ciniza refinery as a
result of the fire that occurred on April 8, 2004, which resulted
in the alkylation unit being out of operation from April 8, 2004
to September 1, 2004;
- a scheduled turnaround, which started early as a result of the
fire discussed above, at the Ciniza refinery, which resulted in
the refinery being out of operation from April 8, 2004 to May 9,
2004 (except the alkylation unit, which was not repaired and
restarted until September 1, 2004); and
- a partial shutdown of our Yorktown refinery to perform upgrades
related to processing higher acid crude oil, which resulted in
portions of the refinery being out of operation from September 3,
2004 to October 11, 2004.
45
EARNINGS FROM CONTINUING OPERATIONS BEFORE INCOME TAXES
Our earnings from continuing operations before income taxes decreased
$2,595,000 for the three months ended September 30, 2004, compared to the
same period in 2003. This decrease was primarily due to the following:
- A decrease in operating earnings before corporate allocation from
our refinery operations of $4,007,000 due to lower volumes sold
as a result of a scheduled partial shutdown at our Yorktown
refinery in the third quarter of 2004;
- A 31% decline in our Retail Group's merchandise margins due to,
among other things, an inventory reduction related to rebate
accounting and lower rebates; and
- A 24% increase in selling, general and administrative expenses
due to an increase in accrued management incentive bonuses.
This decrease was partially offset by the following:
- a 26% decrease in interest expense due to the refinancing activity
(see Footnote 11) during the second quarter of 2004;
- a 9% increase in fuel volumes sold by Phoenix Fuel while
maintaining approximately the same margins; and
- a $958,000 gain from insurance settlement due to the Ciniza fire
incident on April 8, 2004.
Our earnings from continuing operations before income taxes increased
$8,239,000 for the nine months ended September 30, 2004, compared to the
same period in 2003. This increase was primarily due to the following:
- an increase in operating earnings before corporate allocation from
our refinery operations of $24,375,000 due to higher margins and
volumes sold;
- a 12% increase in fuel volumes sold by Phoenix Fuel while
maintaining approximately the same margins; and
- a 15% decrease in interest expense.
- a $958,000 gain from insurance settlement due to the Ciniza fire
incident on April 8, 2004.
This increase was partially offset by the following:
- a 6% increase in operating expenses;
- a 12% decline in our Four Corners refineries' fuel volumes sold;
- $10,875,000 of costs incurred and write-offs of $4,885,000 of
previously deferred financing costs and original issue discount
that were related to early extinguishment of part of our long-term
debt as a result of the refinancing during the second quarter; and
- a 21% decline in our retail group's merchandise margin due to,
among other things, an inventory reduction related to rebate
accounting and lower rebates.
46
YORKTOWN REFINERY
Our Yorktown refinery operated at an average throughput rate of
approximately 53,900 barrels per day in the third quarter of 2004,
compared to 60,400 barrels per day in the third quarter of 2003. In the
month of September, we reduced the throughput at our Yorktown refinery to
approximately 29,300 barrels per day as we performed various upgrades
throughout the refinery. These upgrades will allow us to substantially
increase the amount of acidic crude oil that can be processed under the
crude supply agreement that we entered into with Statoil earlier this
year.
For the nine months ended September 30, 2004 and 2003, the average
throughput rate was 60,900 and 56,300 barrels per day, respectively. This
increase was due primarily to the shutdowns that occurred in 2003 which
reduced our throughput rates in 2003.
Refining margins for the third quarter of 2004 were $6.01 per barrel
as compared to $4.61 per barrel for the same period in 2003. Refining
margins for the nine months ended September 30, 2004 and 2003 were $5.93
and $3.93 per barrel, respectively. This increase was primarily due to
increased demand, lower imports into the East coast of finished products,
lower nationwide production due to turnarounds being done, and limited
refining capacity in the United States.
Revenues for our Yorktown refinery increased for the three and nine
months ended September 30, 2004, respectively, as compared to the same
periods in 2003. The increase for the three months ended September 30,
2004 was primarily due to an increase in price per barrel sold, partially
offset by a reduction in volume sold due to the scheduled partial shutdown
that took place in the third quarter of 2004. The increase for the nine
months ended September 2004 was primarily due to increases in volume and
price per barrel sold.
Cost of products sold for our Yorktown refinery increased for the
three and nine months ended September 30, 2004, respectively, as compared
to the same periods in 2003. The increase for the three months ended
September 30, 2004 was primarily due to the increase in the average cost
per barrel of crude oil. The increase for the nine months ended September
30, 2004 was primarily due to the increase in finished product volumes
sold and an increase in the average cost per barrel of crude oil. In late
February 2004, we began receiving supplies of acidic crude oil under a
long-term supply agreement with Statoil. This contract enabled us to
reduce our cost of crude oil as compared to other supply alternatives.
Operating expenses increased for the three and nine months ended
September 30, 2004 primarily due to the following:
- higher maintenance costs primarily related to tank inspections and
repairs and coker unit repairs;
47
- higher operating costs due to higher volumes, higher electrical
costs and higher purchased costs of natural gas;
- higher chemical and catalyst costs, primarily related to higher
cost catalyst required to meet more stringent sulfur reduction
requirements; and
- higher payroll and related costs, due in part to the
capitalization of certain wages in the first half of 2003
(primarily due to turnaround activity) and increased group medical
insurance premiums and workers compensation costs.
Depreciation and amortization expense increased for the three and
nine months ended September 30, 2004 as compared with the same periods in
2003, primarily due to the amortization of certain refinery turnaround
costs incurred in 2003.
FOUR CORNERS REFINERIES
Our Four Corners refineries operated at an average throughput rate of
approximately 29,200 barrels per day in the third quarter of 2004 and
2003. For the nine months ended September 30, 2004 and 2003, the average
throughput rate was 28,000 and 30,700 barrels per day, respectively. This
decrease was primarily due to a decrease in crude oil supply.
Refining margins for the third quarter of 2004 were $8.14 per barrel
as compared to $9.51 per barrel for the same period in 2003. Refining
margins for the nine months ended September 30, 2004 and 2003 were $9.54
and $9.03 per barrel, respectively. The higher per barrel margin in the
third quarter of 2003 resulted in part from a temporary reduction in crude
oil supply due to a damaged pipeline that effectively raised prices
temporarily. The increase for the nine months ended September 30, 2004 was
primarily due to increased demand, lower imports into the West coast of
finished products, lower nationwide production due to turnarounds being
done, and limited refining capacity in the United States.
Revenues increased for the three and nine months ended September 30,
2004 as compared with the same period in 2003, primarily due to
significantly higher prices, partially offset by lower volume. Sales
volumes were reduced for the three months ended September 30, 2004 because
of lower crude oil supplies. Sales volumes were reduced for the nine
months ended September 30, 2004 because of the Ciniza fire, turnarounds at
both refineries, and lower crude oil supplies.
Cost of products sold increased for the three and nine months ended
September 30, 2004, as compared with the same periods in 2003, primarily
due to the increase in average crude oil prices, partially offset by the
decrease in finished product volumes sold.
Operating expenses increased for the three and nine months ended
September 30, 2004 compared with the same periods in 2003. This was
primarily due to increased maintenance required for the Bloomfield
refinery.
48
Depreciation and amortization expense for our Four Corners refineries
increased slightly for the three and nine months ended September 30, 2004,
as compared to the same periods in 2003, respectively.
RETAIL GROUP
Average fuel margin was $0.179 per gallon for the three months ended
September 30, 2004 as compared to $0.205 per gallon for the same period in
2003 due to market conditions and higher cost of finished product. Fuel
volumes sold for the three months ended September 30, 2004 increased by 4%
as compared to the same period a year ago due to market conditions.
Average fuel margin was $0.184 per gallon for the nine months ended
September 30, 2004 as compared to $0.198 per gallon for the same period in
2003. Fuel volumes sold for the nine months ended September 30, 2004
increased by 5% as compared to the same period a year ago due to market
conditions.
Average merchandise margin was 20% for the three months ended
September 30, 2004 as compared to 29% for the same period in 2003.
Average merchandise margin was 23% for the nine months ended September 30,
2004 as compared to 29% for the same period in 2003. The three and nine
month decrease were primarily due to the reduction in merchandise
inventory related to rebate accounting, and a reduction in rebates from
suppliers for 2004 as compared to 2003.
Operating expenses decreased for the three and nine months ended
September 30, 2004 as compared with the same periods in 2003, primarily
due to a reduction in payroll costs for the periods in 2004 as compared to
2003.
Depreciation expense declined for the three and nine months ended
September 30, 2004, as compared to the same periods in 2003, primarily due
to some retail assets becoming fully depreciated.
PHOENIX FUEL
Primarily as a result of the favorable market conditions previously
discussed, fuel volumes sold by Phoenix Fuel increased by 9% and 12% for
the three and nine months ended September 30, 2004, as compared with the
same periods in 2003.
Average fuel margins for Phoenix Fuel were $0.051 per gallon and
$0.053 per gallon for the three and nine months ended September 30, 2004,
as compared with $0.052 per gallon and $0.051 per gallon for three and
nine months ended September 30, 2003.
49
Revenues for Phoenix Fuel increased for the three and nine months
ended September 30, 2004 as compared to the same periods in 2003,
primarily due to an increase in finished product volumes sold, and an
increase in finished product selling prices.
Cost of products sold for Phoenix Fuel increased during the three and
nine months ended September 30, 2004 as compared to the same periods in
2003, primarily due to the increase in finished product volumes sold and
an increase in finished product purchase prices.
Operating expenses for Phoenix Fuel increased during the three and
nine months ended September 30, 2004 as compared to the same periods a
year ago, primarily due to higher payroll and related costs due to higher
sales volumes, and higher fuel and repair and maintenance costs due to
expanded fleet operations resulting from the higher sales volumes.
SELLING, GENERAL AND ADMINISTRATIVE EXPENSES FROM CONTINUING OPERATIONS
For the three and nine months ended September 30, 2004, selling,
general and administrative expenses increased by approximately $1,986,000
and $5,942,000, respectively, primarily due to:
- higher accruals for management incentive bonuses associated with
increased company financial performance;
- higher accruals related to litigation reserves; and
- increased costs associated with complying with the Sarbanes-Oxley
Act.
These increases were partially offset by a reduction in costs related
to our self-insured health plan due to improved claims experience.
INTEREST EXPENSE FROM CONTINUING OPERATIONS
For the three and nine months ended September 30, 2004, interest
expense decreased by approximately $2,484,000 and $4,457,000,
respectively. The decrease was primarily due to interest incurred on
borrowings under our revolving credit facility in the first nine months of
2003. We had no borrowings under this facility in the first nine months of
2004. In addition, interest expense was reduced due to the payoff in 2003
of certain capital lease obligations and our mortgage loan facility
principal balance in July 2004, and the refinancing activity in the second
quarter of 2004. For a further discussion of the refinancing activity, see
Note 11 to our Condensed Consolidated Financial Statements, captioned
"Long-Term Debt".
INCOME TAXES FROM CONTINUING OPERATIONS
The effective tax rates for the three months ended September 30, 2004
and 2003 were approximately 42.0% and 40.6%, respectively. The effective
tax rates for the nine months ended September 30, 2004 and 2003 were
approximately 41.2% and 40.8%, respectively. The difference in the
effective rates are primarily due to higher state taxes.
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DISCONTINUED OPERATIONS
Discontinued operations include the operations of some of our retail
service station/convenience stores and our travel center, which was sold
on June 19, 2003. See Note 6 to our Condensed Consolidated Financial
Statements included in Part I, Item 1 for additional information relating
to these operations.
OUTLOOK
Overall, we believe that our current refining fundamentals are more
positive now than the same time last year. Domestic distillate inventories
continue to be very tight as we head into what is typically the peak
distillate demand season, and gasoline inventories are running below
historical levels for this time of year. Same store fuel gross margin is
above the prior year's level. Same store merchandise gross margin is,
however, lower than it was at this time last year, although we do not
expect this trend to continue. Phoenix Fuel currently continues to see
growth, with increased gross margin as compared to the same time last
year. Our businesses are, however, very volatile and there can be no
assurance that currently existing conditions will continue for any of our
business segments.
LIQUIDITY AND CAPITAL RESOURCES
CAPITAL STRUCTURE
At September 30, 2004, we had long-term debt of $292,638,000. At
December 31, 2003 we had long-term debt of $355,601,000, net of the
current portion of $11,128,000.
The amount at September 30, 2004 includes:
- $150,000,000 of 8% Senior Subordinated Notes due 2014; and
- $148,828,000 of 11% Senior Subordinated Notes due 2012.
The amount at December 31, 2003 includes:
- $150,000,000 of 9% Senior Subordinated Notes due 2007; and
- $200,000,000 of 11% Senior Subordinated Notes due 2012.
As discussed below, in the second quarter of 2004 we completed
offerings of $150,000,000 of 8% Senior Subordinated Notes due 2014 and
3,283,300 shares of common stock. We used the proceeds from the note
offering and cash on hand to repurchase or redeem our 9% Notes, and the
proceeds from the common stock offering to redeem a portion of the 11%
Notes.
51
At September 30, 2004, we also had a $100,000,000 revolving credit
facility that we entered into on July 15, 2004. The credit facility
amended and restated a similar $100,000,000 credit facility. This
amendment, among other things, extends the maturity of the facility for an
additional three years. This amendment substantially reduces our existing
borrowing and letter of credit costs and relaxes some of the covenants in
the credit facility. We also expanded the size of our bank group to
accommodate a much larger credit facility should it become useful. For a
further discussion of this matter, see Note 11 to our Condensed
Consolidated Financial Statements, captioned "Long-Term Debt".
The credit facility is primarily a working capital and letter of
credit facility. At September 30, 2004, we had no direct borrowings
outstanding under the facility and $20,544,000 of letters of credit
outstanding. At December 31, 2003, we had no direct borrowings outstanding
under the previous facility and $36,961,000 of letters of credit
outstanding.
On July 14, 2004, we prepaid our mortgage loan facility in full from
cash on hand. This facility had a balance of $22,000,000 on December 31,
2003.
At September 30, 2004, our long-term debt, net of current portion,
was 57.6% of total capital (long-term debt, net of current portion, plus
total stockholders' equity). At December 31, 2003, it was 71.8%. Our net
debt (long-term debt, net of current portion, less cash and cash
equivalents) to total capitalization percentage at September 30, 2004, was
54.5%. At December 31, 2003, this percentage was 70.2%.
Our credit facility and the indentures governing our notes contain
restrictive covenants and other terms and conditions that if not
maintained, if violated, or if certain conditions are met, could result in
default, affect our ability to borrow funds, make certain payments, or
engage in certain activities. A default under any of the notes or the
credit facility could cause such debt, and by reason of cross-default
provisions, our other debt to become immediately due and payable. If we
are unable to repay such amounts, the lenders under our credit facility,
could proceed against the collateral granted to them to secure that debt.
If those lenders accelerate the payment of the credit facility, we cannot
provide assurance that our assets would be sufficient to pay that debt and
other debt or that we would be able to refinance such debt or borrow more
money on terms acceptable to us, if at all. Our ability to comply with the
covenants, and other terms and conditions, of the indentures and the
credit facility may be affected by many events beyond our control, and we
cannot provide assurance that our operating results will be sufficient to
allow us to comply with the covenants.
52
We expect to be in compliance with the covenants going forward, and
we do not believe that any presently contemplated activities will be
constrained. Higher than anticipated capital expenditures or a prolonged
period of low refining margins, however, would have a negative impact on
our ability to borrow funds and to make expenditures and would have an
adverse impact on compliance with our debt covenants.
We presently have senior subordinated ratings of "B3" from Moody's
Investor Services and "B-" from Standard & Poor's. Moody's Investor
Services recently confirmed its "B3" rating. Standard and Poor's also
reaffirmed its ratings but revised the outlook to positive from negative.
As is discussed in more detail in Note 11 to our Condensed
Consolidated Financial Statements included in Part I, Item 1, we completed
a refinancing of a portion of our long-term debt in the second quarter of
2004. As part of the refinancing, we completed the following:
- a tender offer and consent solicitation of our 9% senior
subordinated notes due 2007;
- a redemption of the 9% notes not tendered in the tender offer;
- the sale of $150,000,000 of 8% senior subordinated notes due 2014;
- the sale of 3,283,300 shares of our common stock;
- the prepayment of the outstanding balance on our mortgage loan
facility; and
- the renegotiation of our revolving credit facility.
This refinancing should reduce our annual pre-tax interest expense
by approximately $10,600,000 in comparison to the 2003 level, assuming no
future borrowings on our revolving credit facility.
In connection with these transactions, we incurred and expensed
$10,875,000 of costs associated with early debt extinguishment, and we
wrote-off $4,885,000 of previously deferred financing costs and original
issue discount. We also incurred additional costs that have been deferred
and are being amortized over the term of the 8% notes.
We also incurred financing costs in connection with our credit
facility that have been deferred and are being amortized over the term of
the facility.
CASH FLOW FROM OPERATIONS
Our operating cash flows increased by $19,918,000 for the nine months
ended September 30, 2004 compared to the nine months ended September 30,
2003. This resulted primarily from decreases in the first nine months of
2004 in cash used by working capital items and an increase in net earnings
from continuing operations.
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WORKING CAPITAL
We anticipate that working capital, including that necessary for
capital expenditures and debt service, will be funded through existing
cash balances, cash generated from operating activities, existing credit
facilities, and, if necessary, future financing arrangements. Future
liquidity, both short and long-term, will continue to be primarily
dependent on producing or purchasing, and selling, sufficient quantities
of refined products at margins sufficient to cover fixed and variable
expenses. Based on the current operating environment for all of our
operations, we believe that we will have sufficient working capital to
meet our needs over the next 12-month period.
Working capital at September 30, 2004 consisted of current assets of
$252,498,000 and current liabilities of $152,220,000, or a current ratio
of 1.66:1. At December 31, 2003, the current ratio was 1.63:1, with
current assets of $251,702,000 and current liabilities of $154,408,000.
Current assets increased in the first nine months of 2004 by
$796,000, primarily due to increases in accounts receivable and cash and
cash equivalents. These increases were offset, in part, by a decrease in
inventories. Cash and cash equivalents at November 1, 2004 were
approximately $33,100,000.
Accounts receivable increased in the first nine months of 2004
primarily due to higher trade receivables, due in part to higher finished
product selling prices and volumes sold.
Inventories decreased in the first nine months of 2004 primarily due
to:
- decreases in onsite crude oil volumes at our Yorktown refinery;
and
- decreases in Four Corners, Phoenix Fuel and terminal refined
product volumes.
These decreases were offset, in part, by:
- increases in crude oil and refined product prices; and
- increases in crude oil volumes at the Four Corners refineries.
Current liabilities decreased in the first nine months of 2004 by
$2,188,000, primarily due to a decrease in our current portion of long-
term debt, partially offset by an increase in accounts payable.
CAPITAL EXPENDITURES AND RESOURCES
Net cash used in investing activities totaled approximately
$41,083,000 and $8,450,000 for the nine months ended September 30, 2004
54
and 2003, respectively. Expenditures for the nine months ended September
30, 2004 include $13,800,000 of costs that were capitalized as
construction-in-progress due to the Ciniza fire incident, and $8,084,000
of "turnaround" costs that were capitalized. The remainder of these
expenditures primarily were for operational and environmental projects for
the refineries, Phoenix Fuel and retail operations. Expenditures for 2003
primarily were for turnaround expenditures at the Yorktown refinery and
operational and environmental projects for the refineries and retail
operations.
We received proceeds of approximately $2,972,000 from the sale of
property, plant and equipment and other assets in the first nine months of
2004 and $9,900,000 in the first nine months of 2003. In addition, we also
received approximately $6,924,000 from the sale of 40 acres of vacant land
known as the Jomax property and three other pieces of land. We also
received approximately $2,064,000 from the sale of five other service
station/convenience stores that were classified in discontinued
operations. Proceeds received in the first nine months of 2003 were
primarily from the sale of our Giant Travel Center, including its related
inventories, to Pilot Travel Centers LLC for approximately $6,311,000. The
remaining proceeds for 2003 were from the sale of property, plant and
equipment and other assets.
We continue to monitor and evaluate our assets and may sell
additional non-strategic or underperforming assets that we identify as
circumstances allow. We also continue to evaluate potential acquisitions
in our strategic markets, including lease arrangements.
Under the terms of the earn-out provisions of the Yorktown
acquisition agreement, a payment of $846,000 was owed to BP in October
2004. This amount was the final payment required by the earn-out. As a
result of a dispute with BP relating to certain inventory paid for by us
at the closing of the acquisition of the Yorktown refinery, we have offset
$416,000 against the final payment. BP disputes both the amount of the
set-off and our ability to take a set-off against the earn-out payments.
This dispute does not have any effect on net earnings.
On April 8, 2004, we had a fire in the alkylation unit at our Ciniza
refinery, requiring us to temporarily shutdown all of the operating units
at the refinery. As a result of this incident, a major repair and upgrade
shutdown (known as a "turnaround") that was scheduled for April 17, 2004
was accelerated and completed. At September 30, 2004, we had received net
proceeds of approximately $3,600,000 from our insurance carriers in
connection with the fire. See Note 12 to our Condensed Consolidated
Financial Statements included in Part I, Item 1 for a further discussion
of this matter.
We continue to investigate other capital improvements to our existing
facilities. The amount of capital projects that are actually undertaken in
2004 will depend on, among other things, general business conditions and
results of operations.
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DIVIDENDS
We currently do not pay dividends on our common stock. The board of
directors will periodically review our policy regarding the payment of
dividends. Any future dividends are subject to the results of our
operations, declaration by the board of directors, and existing debt
covenants.
RISK MANAGEMENT
We are exposed to various market risks, including changes in certain
commodity prices and interest rates. To manage these normal business
exposures, we may, from time to time, use commodity futures and options
contracts to reduce price volatility, to fix margins in our refining and
marketing operations, and to protect against price declines associated
with our crude oil and finished products inventories.
In the first half of 2003, we entered into various crude oil futures
contracts in order to economically hedge crude oil inventories and
purchases for the Yorktown refinery operations. For the nine months ended
September 30, 2003, we recognized losses on these contracts of
approximately $1,594,000 in cost of products sold. These transactions did
not qualify for hedge accounting in accordance with SFAS No. 133
"Accounting for Derivative Instruments and Hedging Activities," as
amended, and accordingly were marked to market each month. There were no
similar transactions in the first nine months of 2004, and there were no
open crude oil futures contracts or other commodity derivative contracts
at September 30, 2004.
Our credit facility is floating-rate debt tied to various short-term
indices. As a result, our annual interest costs associated with this debt
may fluctuate. At September 30, 2004, there were no direct borrowings
outstanding under this facility.
Our operations are subject to the normal hazards, including fire,
explosion and weather-related perils. We maintain various insurance
coverages, including business interruption insurance, subject to certain
deductibles. We are not fully insured against some risks because some
risks are not fully insurable, coverage is unavailable, or premium costs,
in our judgment, do not justify such expenditures.
Credit risk with respect to customer receivables is concentrated in
the geographic areas in which we operate and relates primarily to
customers in the oil and gas industry. To minimize this risk, we perform
ongoing credit evaluations of our customers' financial position and
require collateral, such as letters of credit, in certain circumstances.
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ENVIRONMENTAL, HEALTH AND SAFETY
Federal, state and local laws and regulations relating to health,
safety and the environment affect nearly all of our operations. As is the
case with other companies engaged in our industry, we face significant
exposure from actual or potential claims and lawsuits, brought by either
governmental authorities or private parties, alleging non-compliance with
environmental, health, and safety laws and regulations, or property damage
or personal injury caused by the environmental, health, or safety impacts
of current or historic operations. These matters include soil and water
contamination, air pollution, and personal injuries or property damage
allegedly caused by substances manufactured, handled, used, released, or
disposed of by us or by our predecessors.
Applicable laws and regulations govern the investigation and
remediation of contamination at our current and former properties, as well
as at third-party sites to which we send or sent waste for disposal. We
may be held liable for contamination existing at current or former
properties, notwithstanding that a prior operator of the site, or other
third party, caused the contamination. We also may be held responsible for
costs associated with contamination clean up at third-party disposal
sites, notwithstanding that the original disposal activities were in
accordance with all applicable regulatory requirements at such time. We
are currently engaged in a number of such remediation projects.
Future expenditures related to compliance with environmental, health
and safety laws and regulations, the investigation and remediation of
contamination, and the defense or settlement of governmental or private
party claims and lawsuits cannot be reasonably quantified in many
circumstances for various reasons. These reasons include the speculative
nature of remediation and clean up cost estimates and methods, imprecise
and conflicting data regarding the hazardous nature of various types of
substances, the number of other potentially responsible parties involved,
various defenses that may be available to us, and changing environmental,
health and safety laws, regulations, and their respective interpretations.
We cannot provide assurance that compliance with such laws or regulations,
such investigations or cleanups, or such enforcement proceedings or
private-party claims will not have a material adverse effect on our
business, financial condition or results of operations.
Rules and regulations implementing federal, state and local laws
relating to the environment, health, and safety will continue to affect
our operations. We cannot predict what new environmental, health, or
safety legislation or regulations will be enacted or become effective in
the future or how existing or future laws or regulations will be
administered or enforced with respect to products or activities to which
they have not been previously applied. Compliance with more stringent laws
or regulations, as well as more vigorous enforcement policies of
regulatory agencies, could have an adverse effect on our financial
position and the results of our operations and could require substantial
expenditures by us for, among other things:
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- the installation and operation of refinery equipment, pollution
control systems and other equipment not currently possessed by us;
- the acquisition or modification of permits applicable to our
activities; and
- the initiation or modification of clean-up activities.
A fire occurred at our Ciniza refinery on April 8, 2004 in the
alkylation unit that produces high octane blending stock for gasoline.
Repairs to the alkylation unit were completed in the third quarter and the
unit is back in service. The fire was investigated by the Occupational
Health and Safety Bureau of the New Mexico Environment Department ("OHSB")
and remains under investigation by the U.S. Chemical Safety and Hazard
Investigation Board ("CSB"). CSB does not have authority to issue any
monetary fines, and we anticipate that any fines ultimately imposed by
OHSB will be less than $65,000. For a further discussion of this matter,
see Note 12 to our Condensed Consolidated Financial Statements,
"Commitments and Contingencies".
OHSB has issued safety regulations that will require us to incur
additional expenses for security at our retail stores. These regulations
may be subject to legal challenge. For a further discussion of this
matter, see Note 12 to our Condensed Consolidated Financial Statements,
captioned "Commitments and Contingencies".
In September 2004, EPA and BLM issued the Record of Decision for the
Lee Acres Landfill Superfund site, which is adjacent to our old Farmington
refinery site. The Record of Decision selects the cleanup plan to be used
at the Lee Acres site. For a further discussion of this matter, see Note
12 to our Condensed Consolidated financial Statements, captioned
"Commitments and Contingencies".
In August 2004, hydrocarbon discharges were discovered seeping from
the ground on the north side of our Bloomfield refinery. We took immediate
containment and other corrective action and are discussing a permanent
remediation plan with the New Mexico Oil Conservation Division ("OCD").
OCD has indicated that it will be issuing a compliance order, including a
possible penalty, in connection with the discharges. For a further
discussion of this matter, see Note 12 to our Condensed Consolidated
financial Statements, captioned "Commitments and Contingencies".
We have been added as a defendant in a number of lawsuits filed in
various East Coast and Midwest states. These lawsuits allege that numerous
refiners and sellers of MTBE or gasoline containing MTBE are responsible
for water contamination. We intend to vigorously defend these lawsuits. It
is possible that we could be named as a defendant in other MTBE suits. For
a further discussion of this matter, see Note 12 to our Condensed
Consolidated financial Statements, captioned "Commitments and
Contingencies".
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In October 2004, the President signed the American Jobs Creation Act
of 2004 (the "Act"), which includes energy related tax provisions. Under
the Act, small refiners are allowed to expense up to 75% of capital
expenditures spent to comply with highway diesel low sulfur regulations
adopted by the Environmental Protection Agency. Small refiners are also
allowed to take an environmental tax credit of five cents on each gallon
of low sulfur diesel fuel they sell, up to a maximum of 25% of the capital
costs incurred to comply with the regulations. These regulations and our
estimated capital expenditure compliance costs are discussed in our Annual
Report on Form 10-K for the year ended December 31, 2003 under the caption
"Regulatory, Environmental and Other Matters." Since we satisfy the Act's
definition of small refiner, we should be able to take advantage of the
favorable tax provisions contained in the Act. At this time, however, we
cannot estimate the effect, if any, these tax provisions may have on our
future earnings.
OTHER
The trustee in the James E. Acridge bankruptcy proceeding previously
advised us that he believed that the bankruptcy estate may have potential
claims against us. We evaluated the trustee's contentions and did not
believe that the potential claims had any merit. Nonetheless, in an effort
to avoid the considerable expense associated with litigation, we recently
entered into a settlement agreement. For a further discussion of matters
relating to James E. Acridge, our former President, Chief Executive
Officer, and Chairman of the Board, see Note 12 to our Condensed
Consolidated Financial Statements, captioned "Commitments and
Contingencies".
Our Ciniza and Bloomfield refineries continue to be affected by
reduced crude oil production in the Four Corners area. The Four Corners
basin is a mature production area and, as a result, is subject to a
natural decline in production over time. This natural decline is being
offset to some extent by new drilling, field workovers, and secondary
recovery projects, which have resulted in additional production from
existing reserves.
As a result of the declining production of crude oil in the Four
Corners area in recent years, we have not been able to cost-effectively
obtain sufficient amounts of crude oil to operate our Four Corners
refineries at full capacity. Crude oil utilization rates for our Four
Corners refineries have declined from approximately 67% for 2003 to
approximately 61% for the first nine months of 2004. Our current
projections of Four Corners crude oil production indicate that our crude
oil demand will exceed the crude oil supply that is available from local
sources for the foreseeable future and that our crude oil capacity
utilization rates at our Four Corners refineries will continue to decline.
If additional crude oil or other refinery feedstocks become available in
the future, we may increase production runs at our Four Corners refineries
depending on the demand for finished products and the refining margins
attainable. To that end, we continue to assess short-term and long-term
options to address the continuing decline in Four Corners crude oil
production. The options being considered include:
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- evaluating potentially economic sources of crude oil produced
outside the Four Corners area, including ways to reduce raw
material transportation costs to our refineries;
- evaluating ways to encourage further production in the Four
Corners area;
- changing equipment operation/configuration at one or both
refineries to further the integration of the two refineries and
reduce fixed costs; and
- with sufficient further decline in raw material supply,
temporarily, partially or permanently discontinue operations at
these refineries.
None of these options, however, may prove to be economically viable.
We cannot assure you that the Four Corners crude oil supply for our Ciniza
and Bloomfield refineries will continue to be available at all or on
acceptable terms for the long term. Because large portions of the
refineries' costs are fixed, any significant interruption or decline in
the supply of crude oil or other feedstocks would have an adverse effect
on our Four Corners refinery operations and on our overall operations.
The Longhorn Pipeline project that runs from Houston, Texas to El
Paso, Texas and connects the Chevron pipeline to the Albuquerque area and
to the Kinder-Morgan pipeline to the Phoenix and Tucson, Arizona markets
had a start-up date of August 2004. The pipeline is now transporting
diesel and conventional gasoline to El Paso, Texas. The completion of this
project could result in increased competition by increasing the amount of
refined products potentially available in certain of our markets, as well
as improving competitor access to these areas. It also could result in new
opportunities for us, as we are a net purchaser of refined products in
some of these areas.
Our refining activities are conducted at our two refinery locations
in New Mexico and the Yorktown refinery in Virginia. These refineries
constitute a significant portion of our operating assets, and the two New
Mexico refineries supply a significant portion of our retail operations.
As a result, our operations would be significantly interrupted if any of
the refineries were to experience a major accident, be damaged by severe
weather or other natural disaster, or otherwise be forced to shutdown. If
any of the refineries were to experience an interruption in supply or
operations, our business, financial condition and operating results could
be materially and adversely affected.
FORWARD-LOOKING STATEMENTS
This report includes forward-looking statements within the meaning of
Section 27A of the Securities Act and Section 21E of the Securities and
Exchange Act of 1934. These statements are included throughout this
report, including in the section entitled "Management's Discussion and
Analysis of Financial Condition and Results of Operations." These
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statements relate to projections of capital expenditures and other
financial items. These statements also relate to, among other things, our
business strategy, goals and expectations concerning our market position,
future operations, acquisitions, dispositions, margins, profitability,
liquidity and capital resources. We have used the words "believe,"
"expect," "anticipate," "estimate," "could," "plan," "intend," "may,"
"project," "predict," "will" and similar terms and phrases to identify
forward-looking statements in this report.
Although we believe the assumptions upon which these forward-looking
statements are based are reasonable, any of these assumptions could prove
to be inaccurate, and the forward-looking statements based on these
assumptions could be incorrect. While we have made these forward-looking
statements in good faith and they reflect our current judgment regarding
such matters, actual results could vary materially from the forward-
looking statements.
Actual results and trends in the future may differ materially
depending on a variety of important factors. These important factors
include the following:
- the availability of crude oil and the adequacy and costs of raw
material supplies generally;
- our ability to negotiate new crude oil supply contracts;
- the risk that our long-term crude oil supply agreement with
Statoil will not supply a significant portion of the crude oil
needs of our Yorktown refinery over the term of the agreement, and
will not reduce our crude oil costs, improve our high-value
product output, contribute significantly to higher earnings,
improve our competitiveness, or reduce the impact of crude oil
markets' pricing volatility;
- our ability to successfully manage the liabilities, including
environmental liabilities, that we assumed in the Yorktown
acquisition;
- our ability to obtain anticipated levels of indemnification;
- competitive pressures from existing competitors and new entrants,
including the potential effects of the start-up of the Longhorn
pipeline;
- volatility in the difference, or spread, between market prices for
refined products and crude oil and other feedstocks;
- the risk that our operations will not remain competitive and
realize acceptable sales volumes and margins in those markets
where they currently do so;
- our ability to adequately control capital and operating expenses,
including the cost to comply with the Sarbanes-Oxley Act;
- the risk of increased costs resulting from employee matters,
including unionization efforts and increased employee benefit
costs;
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- state, federal or tribal legislation or regulation, or findings,
including penalties, by a regulator with respect to our
operations, including the impact of government-mandated
specifications for gasoline and diesel fuel on our operations;
- unplanned or extended shutdowns in refinery operations;
- the risk that we will not remain in compliance with covenants, and
other terms and conditions, contained in our notes and our credit
facility;
- the risk that we will not be able to post satisfactory letters of
credit;
- general economic factors affecting our operations, markets,
products, services and prices;
- unexpected environmental remediation costs;
- weather conditions affecting our operations or the areas in which
our products are refined or marketed;
- the risk we will be found to have substantial liability in
connection with existing or pending litigation;
- the occurrence of events that cause losses for which we are not
fully insured;
- the risk that costs associated with environmental projects,
including costs associated with EPA's national refinery
enforcement program, will be higher than currently estimated;
- other risks described elsewhere in this report or described from
time to time in our other filings with the Securities and Exchange
Commission;
- the risk that we will not receive anticipated amounts of
reimbursement from our insurance carriers for the Ciniza fire
incident;
- the risk that will be added as a defendant in additional MTBE
lawsuits, and that we will incur substantial liabilities and
substantial defense costs in connection with these suits; and
- the possibility that we will have borrowings on our revolving
credit facility.
All subsequent written and oral forward-looking statements
attributable to us or persons acting on our behalf are expressly qualified
in their entity by the previous statements. Forward-looking statements we
make represent our judgment on the dates such statements are made. We
assume no obligation to update any information contained in this report or
to publicly release the results of any revisions to any forward-looking
statements to reflect events or circumstances that occur, or that we
become aware of, after the date of this report.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
The information required by this item is incorporated herein by
reference to the section entitled "Risk Management" in the Company's
Management's Discussion and Analysis of Financial Condition and Results of
Operations in Part I, Item 2.
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ITEM 4. CONTROLS AND PROCEDURES
(a) Evaluation of Disclosure Controls and Procedures
In order to ensure that the information we must disclose in our
filings with the SEC is recorded, processed, summarized and reported on a
timely basis, we have developed and implemented disclosure controls and
procedures. Our management, with the participation of our Chief Executive
Officer and Chief Financial Officer, evaluated the effectiveness of our
disclosure controls and procedures as of the end of the period covered by
this report. Based on that evaluation, the Chief Executive Officer and
Chief Financial Officer concluded that our disclosure controls and
procedures as of the end of the period covered by this report were
effective as of the date of that evaluation.
(b) Change in Internal Control Over Financial Reporting
We are in the process of implementing the Internal Control for
Financial Reporting provisions of the Sarbanes-Oxley Act of 2003. We
continue to make good progress in our remediation activities on the two
reportable conditions that were disclosed in our previous quarterly
filings. The conditions, which were not material weaknesses, were related
to our corporate accounting review process and our information systems. We
do not yet know whether the mitigating controls and procedures and the
corrective actions and organizational changes will be adequate.
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PART II
OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
We are a party to ordinary routine litigation incidental to our
business, as well as other litigation more fully described in Note 12 to
the Condensed Consolidated Financial Statements set forth in Part I, Item
1, and the discussion of certain contingencies contained in Part I, Item
2, under the heading "Liquidity and Capital Resources - Other."
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits:
31.1* Certification of Principal Executive Officer Pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002.
31.2* Certification of Principal Financial Officer Pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002.
32.1* Certification of Principal Executive Officer Pursuant to 18
U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002.
32.2* Certification of Principal Financial Officer Pursuant to 18
U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002.
*Filed herewith.
(b) Reports on Form 8-K: We filed the following reports on Form
8-K during the quarter for which this report is being filed and
subsequently:
(i) On August 10, 2004, we filed a Form 8-K, dated August 9,
2004, containing a press release detailing our earnings for the
three and six months ended June 30, 2004.
(ii) On November 10, 2004, we filed a Form 8-K, dated November 10,
2004, containing a press release detailing our earnings for the
three and nine months ended September 30, 2004.
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SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934,
the Registrant has duly caused this report on Form 10-Q for the quarter
ended September 30, 2004 to be signed on its behalf by the undersigned
thereunto duly authorized.
GIANT INDUSTRIES, INC.
/s/ MARK B. COX
---------------------------------------------
Mark B. Cox, Executive Vice President,
Treasurer, Chief Financial Officer and
Assistant Secretary, on behalf of the
Registrant and as the Registrant's Principal
Financial Officer
Date: November 12, 2004
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