UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K/A
(Amendment No. 1)
CURRENT REPORT
Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
Date of Report (Date of earliest event reported): July 1, 2005
Valero L.P.
(Exact name of registrant as specified in its charter)
Delaware |
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1-16417 |
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74-2956831 |
(State or Other Jurisdiction of |
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(Commission File Number) |
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(I.R.S. Employer |
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One Valero Way, San Antonio, Texas |
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78249 |
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(Address of Principal Executive Offices) |
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(Zip Code) |
Registrants Telephone Number, including Area Code: (210) 345-2000
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
o Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
o Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
o Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
o Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))
Explanatory Note
This Form 8-K/A amends the Current Report on Form 8-K of Valero L.P. dated July 1, 2005, and filed with the Securities and Exchange Commission on July 1, 2005. That Form 8-K reported Valero L.Ps completion of its acquisition of Kaneb Services LLC (KSL) and Kaneb Pipe Line Partners, L.P. (KPP). This report provides the financial statements and the pro forma financial information required under Item 9.01.
Item 9.01. |
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Financial Statements and Exhibits. |
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(a) |
Financial statements of businesses acquired. |
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1. |
Audited consolidated financial statements of KSL and KPP as of December 31, 2004 and 2003, and for the years ended December 31, 2004, 2003 and 2002, and the report of the independent registered public accounting firm are filed herewith in Exhibit 99.1. |
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2. |
Unaudited condensed consolidated financial statements of KSL and KPP as of June 30, 2005 and December 31, 2004, and for the three and six months ended June 30, 2005 and 2004 are filed herewith in Exhibit 99.1. |
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(b) |
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Pro forma financial information. |
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Unaudited pro forma condensed consolidated financial statements of Valero L.P. as of and for the six months ended June 30, 2005, and for the year ended December 31, 2004 are filed herewith in Exhibit 99.2. |
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(c) |
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Exhibits. |
Exhibit No. |
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Description |
2.01 |
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Agreement and Plan of Merger dated as of October 31, 2004, by and among Valero L.P.; Riverwalk Logistics, L.P.; Valero GP, LLC; VLI Sub A LLC; and Kaneb Services LLC incorporated by reference to Exhibit 99.1 to Valero L.P.s Current Report on Form 8-K dated October 31, 2004, and filed November 4, 2004. |
2.02 |
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Agreement and Plan of Merger dated as of October 31, 2004, by and among Valero L.P.; Riverwalk Logistics, L.P.; Valero GP, LLC; VLI Sub B LLC; Kaneb Pipe Line Partners, L.P.; and Kaneb Pipe Line Company LLC incorporated by reference to Exhibit 99.2 to Valero L.P.s Current Report on Form 8-K dated October 31, 2004, and filed November 4, 2004. |
23.1 |
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Consent of KPMG LLP |
23.2 |
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Consent of KPMG LLP |
99.1 |
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Financial statements of businesses acquired |
99.2 |
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Pro forma financial information |
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this Report to be signed on its behalf by the undersigned hereunto duly authorized.
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Valero L.P. |
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By: |
Riverwalk Logistics, L.P., its general partner |
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By: |
Valero GP, LLC, its general partner |
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Date: September 16, 2005 |
By: |
/s/ Thomas R. Shoaf |
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Name: |
Thomas R. Shoaf |
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Title: |
Vice President and Controller |
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2
Valero L.P.
23.1 |
Consent of KPMG LLP |
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23.2 |
Consent of KPMG LLP |
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99.1 |
Financial statements of businesses acquired |
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Kaneb Services LLC |
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Condensed Consolidated Statements of Operations Three and Six Months Ended June 30, 2005 and 2004 |
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Condensed Consolidated Balance Sheets June 30, 2005 and December 31, 2004 |
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Condensed Consolidated Statements of Cash Flows Six Months Ended June 30, 2005 and 2004 |
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Notes to Consolidated Financial Statements June 30, 2005 |
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Kaneb Pipe Line Partners, L.P. |
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Condensed Consolidated Statements of Operations Three and Six Months Ended June 30, 2005 and 2004 |
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Condensed Consolidated Balance Sheets June 30, 2005 and December 31, 2004 |
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Condensed Consolidated Statements of Cash Flows Six Months Ended June 30, 2005 and 2004 |
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Notes to Consolidated Financial Statements June 30, 2005 |
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Kaneb Services LLC |
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Report of Independent Registered Public Accounting Firm |
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Consolidated Statements of Income Three Years Ended December 31, 2004 |
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Consolidated Balance Sheets December 31, 2004 and 2003 |
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Consolidated Statements of Cash Flows Three Years Ended December 31, 2004 |
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Consolidated Statements of Stockholders Equity Three Years Ended December 31, 2004 |
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Notes to Consolidated Financial Statements |
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Kaneb Pipe Line Partners, L.P. |
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Report of Independent Registered Public Accounting Firm |
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Consolidated Statements of Income Three Years Ended December 31, 2004 |
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Consolidated Balance Sheets December 31, 2004 and 2003 |
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Consolidated Statements of Cash Flows Three Years Ended December 31, 2004 |
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Consolidated Statements of Partners Capital Three Years Ended December 31, 2004 |
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Notes to Consolidated Financial Statements |
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99.2 |
Unaudited Proforma Combined Balance Sheet as of June 30, 2005 |
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Unaudited Proforma Combined Statement of Income for the Six Months Ended June 30, 2005 |
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Unaudited Proforma Combined Statement of Income for the Year Ended December 31, 2004 |
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Notes to Unaudited Proforma Combined Financial Statements |
3
Exhibit 23.1
Consent of Independent Registered Public Accounting Firm
The Board of Directors of Valero GP, LLC
And Unitholders of Valero L.P.:
We consent to the incorporation by reference in the registration statements on Form S-8 (Nos. 333-109541, 333-88264, and 333-81806) and on Form S-3 (File No. 333-109412) of Valero L.P. and subsidiaries of our reports dated March 11, 2005, with respect to the consolidated balance sheets of Kaneb Services LLC and subsidiaries as of December 31, 2004 and 2003, and the related consolidated statements of income, shareholders equity and cash flows for each of the years in the three-year period ended December 31, 2004, which report appears in the Form 8-K/A of Valero L.P. and subsidiaries dated September 16, 2005.
/s/ KPMG LLP |
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San Antonio, Texas |
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September 15, 2005 |
Exhibit 23.2
Consent of Independent Registered Public Accounting Firm
The Board of Directors of Valero GP, LLC
And Unitholders of Valero L.P.:
We consent to the incorporation by reference in the registration statements on Form S-8 (Nos. 333-109541, 333-88264, and 333-81806) and on Form S-3 (File No. 333-109412) of Valero L.P. and subsidiaries of our reports dated March 11, 2005, with respect to the consolidated balance sheets of Kaneb Pipe Line Partners, L.P. as of December 31, 2004 and 2003, and the related consolidated statements of income, partners capital and cash flows for each of the years in the three-year period ended December 31, 2004, which report appears in the Form 8-K/A of Valero L.P. and subsidiaries dated September 16, 2005.
/s/ KPMG LLP |
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San Antonio, Texas |
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September 15, 2005 |
EXHIBIT 99.1
KANEB SERVICES LLC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(In Thousands Except Per Share Amounts)
(Unaudited)
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Three Months Ended |
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Six Months Ended |
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2005 |
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2004 |
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2005 |
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2004 |
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Revenues: |
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Services |
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$ |
102,183 |
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$ |
94,058 |
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$ |
201,405 |
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$ |
184,756 |
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Products |
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233,012 |
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160,144 |
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424,816 |
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302,625 |
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Total revenues |
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335,195 |
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254,202 |
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626,221 |
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487,381 |
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Costs and expenses: |
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Cost of products sold |
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222,168 |
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153,364 |
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405,165 |
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289,795 |
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Operating costs |
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58,109 |
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43,371 |
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104,731 |
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86,795 |
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Depreciation and amortization |
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14,663 |
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13,738 |
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29,501 |
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27,645 |
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General and administrative |
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29,499 |
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7,195 |
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40,897 |
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13,697 |
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Provision for loss contingencies |
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42,000 |
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42,000 |
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Total costs and expenses |
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366,439 |
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217,668 |
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622,294 |
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417,932 |
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Operating income (loss) |
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(31,244 |
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36,534 |
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3,927 |
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69,449 |
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Interest and other income |
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107 |
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61 |
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313 |
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93 |
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Interest expense |
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(12,636 |
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(10,720 |
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(23,984 |
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(21,349 |
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Income (loss) before income taxes and interest of outside non-controlling partners in KPPs net (income) loss |
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(43,773 |
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25,875 |
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(19,744 |
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48,193 |
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Income tax benefit (expense) |
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14,304 |
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(606 |
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12,778 |
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(1,769 |
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Interest of outside non-controlling partners in KPPs net (income) loss |
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18,012 |
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(17,874 |
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2,158 |
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(33,034 |
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Net income (loss) |
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$ |
(11,457 |
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$ |
7,395 |
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$ |
(4,808 |
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$ |
13,390 |
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Earnings (loss) per share: |
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Basic |
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$ |
(.97 |
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$ |
.63 |
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$ |
(.41 |
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$ |
1.15 |
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Diluted |
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$ |
(.97 |
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$ |
.62 |
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$ |
(.41 |
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$ |
1.12 |
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See Notes to Consolidated Financial Statements
Exhibit 99.1 page 1
KANEB SERVICES LLC AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(In Thousands)
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June 30, |
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December 31, |
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(Unaudited) |
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ASSETS |
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Current assets: |
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Cash and cash equivalents |
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$ |
17,291 |
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$ |
38,415 |
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Accounts receivable |
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88,090 |
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85,976 |
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Inventories |
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26,318 |
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25,448 |
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Prepaid expenses and other |
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20,559 |
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12,614 |
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Total current assets |
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152,258 |
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162,453 |
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Property and equipment |
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1,468,873 |
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1,451,176 |
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Less accumulated depreciation |
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329,352 |
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302,564 |
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Net property and equipment |
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1,139,521 |
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1,148,612 |
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Investment in affiliates |
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26,828 |
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25,939 |
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Excess of cost over fair value of net assets of acquired business and other assets |
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18,313 |
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19,884 |
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$ |
1,336,920 |
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$ |
1,356,888 |
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LIABILITIES AND SHAREHOLDERS EQUITY |
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Current liabilities: |
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Current portion of long-term debt |
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$ |
195,984 |
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$ |
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Accounts payable |
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45,145 |
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54,280 |
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Accrued expenses |
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40,156 |
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46,993 |
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Accrued interest payable |
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8,928 |
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9,374 |
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Accrued distributions payable to shareholders |
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5,801 |
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Accrued distributions payable to outside non-controlling partners in KPP |
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19,863 |
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Total current liabilities |
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290,213 |
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136,311 |
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Long-term debt, less current portion |
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528,723 |
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688,985 |
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Other liabilities and deferred taxes |
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76,086 |
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53,520 |
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Commitments and contingencies (see note 6) |
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Interest of outside non-controlling partners in KPP |
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373,333 |
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397,717 |
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Shareholders equity |
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68,565 |
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80,355 |
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$ |
1,336,920 |
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$ |
1,356,888 |
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See Notes to Consolidated Financial Statements
Exhibit 99.1 page 2
KANEB SERVICES LLC AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In Thousands)
(Unaudited)
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Six Months Ended |
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2005 |
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2004 |
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Operating activities: |
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Net income (loss) |
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$ |
(4,808 |
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$ |
13,390 |
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Adjustments to reconcile net income (loss) to net cash provided by operating activities: |
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Depreciation and amortization |
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29,501 |
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27,645 |
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Provision for loss contingencies |
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42,000 |
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Equity in earnings of affiliates, net of distributions |
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(889 |
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(497 |
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Interest of outside non-controlling partners in KPPs net income (loss) |
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(2,158 |
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33,034 |
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Deferred income taxes |
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(14,449 |
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(230 |
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Other |
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1,334 |
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(792 |
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Changes in working capital components |
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(28,713 |
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(7,617 |
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Net cash provided by operating activities |
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21,818 |
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64,933 |
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Investing activities: |
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Capital expenditures, primarily KPP |
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(22,030 |
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(17,340 |
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Acquisitions by KPP |
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(10,034 |
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(12,478 |
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Other |
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784 |
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(722 |
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Net cash used in investing activities |
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(31,280 |
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(30,540 |
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Financing activities: |
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Issuance of debt |
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39,690 |
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17,923 |
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Payments on debt |
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(2,000 |
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Distributions to shareholders |
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(11,724 |
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(11,134 |
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Distributions to outside non-controlling partners in KPP |
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(39,727 |
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(39,014 |
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Other |
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99 |
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87 |
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Net cash used in financing activities |
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(11,662 |
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(34,138 |
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Increase (decrease) in cash and cash equivalents |
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(21,124 |
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255 |
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Cash and cash equivalents at beginning of period |
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38,415 |
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43,457 |
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Cash and cash equivalents at end of period |
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$ |
17,291 |
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$ |
43,712 |
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Supplemental cash flow information cash paid for interest |
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$ |
22,705 |
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$ |
20,899 |
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See Notes to Consolidated Financial Statements
Exhibit 99.1 page 3
KANEB SERVICES LLC AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. SIGNIFICANT ACCOUNTING POLICIES
The consolidated financial statements reflect the results of operations of Kaneb Services LLC (the Company), its wholly owned subsidiaries and Kaneb Pipe Line Partners, L.P. (KPP). The Company controls the operations of KPP through its 2% general partner interest and 18% limited partner interest in KPP as of June 30, 2005. All significant intercompany transactions and balances have been eliminated.
The unaudited condensed consolidated financial statements of the Company for the three and six month periods ended June 30, 2005 and 2004, have been prepared in accordance with accounting principles generally accepted in the United States of America. Significant accounting policies followed by the Company are disclosed in the notes to the consolidated financial statements included in the Companys Annual Report on Form 10-K for the year ended December 31, 2004. In the opinion of the Companys management, the accompanying condensed consolidated financial statements contain all of the adjustments, consisting of normal recurring accruals, necessary to present fairly the consolidated financial position of the Company and its consolidated subsidiaries at June 30, 2005, and the consolidated results of their operations and cash flows for the periods ended June 30, 2005 and 2004. Operating results for the three and six months ended June 30, 2005 are not necessarily indicative of the results that may be expected for the year ending December 31, 2005.
2. VALERO L.P. MERGER
On July 1, 2005, Valero L.P. acquired all of the outstanding shares of the Company as well as all of the outstanding units of KPP. Consequently, the Company and KPP became wholly owned subsidiaries of Valero L.P.
In connection with the acquisition by Valero L.P., the Company incurred certain costs directly related to the acquisition. For the six months ended June 30, 2005, approximately $23.0 million was included in general and administrative expenses related principally to settling certain outstanding stock awards and settling other employee compensation obligations, and legal fees associated with the acquisition. In addition, on June 30, 2005 the Company and KPP paid approximately $4.4 million in contractual change of control payments. Because these payments were contingent upon the closing of the Valero L.P. merger, these payments were included in prepaid expenses and other at June 30, 2005. To fund a portion of these expenses, the Company and KPP borrowed approximately $39.7 million in the second quarter of 2005.
On July 1, 2005, Valero L.P. sold all of the outstanding equity interests of Martin Oil LLC, an indirect wholly owned subsidiary of KSL, to Valero Marketing and Supply Company, a wholly owned subsidiary of Valero Energy Corporation, for approximately $27 million.
On July 1, 2005, Valero L.P. entered into a definitive agreement to sell certain of KPPs assets to Pacific Energy Partners L.P. for approximately $455 million. These asset sales were required by the U.S. Federal Trade Commission as a condition to closing the merger.
Exhibit 99.1 page 4
3. COMPREHENSIVE INCOME
Comprehensive income (loss) for the three and six months ended June 30, 2005 and 2004, is as follows:
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Three Months Ended |
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Six Months Ended |
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2005 |
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2004 |
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2005 |
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2004 |
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(in thousands) |
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Net income (loss) |
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$ |
(11,457 |
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$ |
7,395 |
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$ |
(4,808 |
) |
$ |
13,390 |
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Foreign currency translation adjustment |
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(443 |
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(402 |
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(596 |
) |
(451 |
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Gain on interest rate hedging transaction |
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12 |
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8 |
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18 |
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17 |
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Comprehensive income (loss) |
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$ |
(11,888 |
) |
$ |
7,001 |
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$ |
(5,386 |
) |
$ |
12,956 |
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Accumulated other comprehensive income aggregated $2.6 million at June 30, 2005 and $3.2 million at December 31, 2004, respectively.
4. CASH DISTRIBUTIONS
Prior to the acquisition by Valero L.P., the Company made quarterly distributions of 100% of its available cash, as defined in the limited liability company agreement, to common shareholders of record on the applicable record date, within 45 days after the end of each quarter. Available cash consisted generally of all the cash receipts of the Company, less all cash disbursements and reserves. Excess cash flow of the Companys wholly owned marketing operations was used to reduce working capital borrowings. Due to the acquisition by Valero L.P., neither the Company nor KPP declared any distributions subsequent to June 30, 2005. Accordingly, the June 30, 2005 consolidated balance sheet of the Company does not reflect any amounts for accrued distributions payable. A cash distribution of $0.495 per share with respect to the fourth quarter of 2004 was paid on February 14, 2005. A cash distribution of $0.495 per share with respect to the first quarter of 2005 was paid on May 13, 2005.
Exhibit 99.1 page 5
5. EARNINGS (LOSS) PER SHARE
Earnings (loss) per share for the three and six months ended June 30, 2005 and 2004, is calculated using the Companys basic and diluted weighted average shares outstanding for the period. For the three months ended June 30, 2005 and 2004, basic weighted average shares outstanding were 11,871,000 and 11,693,000, respectively, and diluted weighted average shares outstanding were 11,871,000 and 11,911,000, respectively. For the six months ended June 30, 2005 and 2004, basic weighted average shares outstanding were 11,871,000 and 11,680,000, respectively, and diluted weighted average shares outstanding were 11,871,000 and 11,907,000, respectively.
6. CONTINGENCIES
GENERAL
The operations of KPP are subject to federal, state and local laws and regulations in the United States and various foreign locations relating to protection of the environment. Although KPP believes its operations are in general compliance with applicable environmental regulations, risks of additional costs and liabilities are inherent in pipeline and terminal operations, and there can be no assurance that significant costs and liabilities will not be incurred by KPP. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies thereunder, and claims for damages to property or persons resulting from the operations of KPP, could result in substantial costs and liabilities to KPP.
LITIGATION AND ENVIRONMENTAL
KPP has contingent liabilities resulting from various litigation, claims and commitments, some of which are incident to the ordinary course of business. Other contingencies, which are considered more significant by KPP, are discussed below. Subsequent to the acquisition of the Company by Valero L.P., new management of the Company determined based on a comprehensive review of the matters disclosed below that an additional $42 million accrual for potential loss contingencies was required, which was recorded in the quarter ended June 30, 2005. Accordingly, KPP has recorded estimated reserves totaling approximately $44 million related to certain of the matters discussed below. These reserves have been recorded in compliance with generally accepted accounting principles, however, management believes that there are defenses in each of these matters and it intends to vigorously defend each matter. As a result, the actual payment of any amounts reserved and the timing of such payments ultimately made is uncertain. Management also believes that should KPP be unable to successfully defend itself in these matters, the ultimate payment of any or all of the
Exhibit 99.1 page 6
amounts reserved would not have a material adverse effect on KPPs financial position. However, given the inherent uncertainty in estimating reserves for such matters, KPP can give no assurance that the amounts recorded will not require adjustment in the future, and such adjustments could be significant and could have a material adverse effect on KPPs financial position and results of operations.
Grace Matter
Certain subsidiaries of KPP were sued in a Texas state court in 1997 by Grace Energy Corporation (Grace), the entity from which KPP acquired ST Services in 1993. The lawsuit involves environmental response and remediation costs allegedly resulting from fuel leaks in the early 1970s from a pipeline. The pipeline, which connected a former Grace terminal with Otis Air Force Base in Massachusetts (the Otis pipeline or the pipeline), ceased operations in 1973 and was abandoned before 1978, when the connecting terminal was sold to an unrelated entity. Grace alleged that subsidiaries of KPP acquired the abandoned pipeline as part of the acquisition of ST Services in 1993 and assumed responsibility for environmental damages allegedly caused by the fuel leaks. Grace sought a ruling from the Texas court that these subsidiaries are responsible for all liabilities, including all present and future remediation expenses, associated with these leaks and that Grace has no obligation to indemnify these subsidiaries for these expenses. In the lawsuit, Grace also sought indemnification for expenses of approximately $3.5 million that it had incurred since 1996 for response and remediation required by the State of Massachusetts and for additional expenses that it expects to incur in the future. The consistent position of KPPs subsidiaries has been that they did not acquire the abandoned pipeline as part of the 1993 ST Services transaction, and therefore did not assume any responsibility for the environmental damage nor any liability to Grace for the pipeline.
At the end of the trial, the jury returned a verdict including findings that (1) Grace had breached a provision of the 1993 acquisition agreement by failing to disclose matters related to the pipeline, and (2) the pipeline was abandoned before 1978 15 years before KPPs subsidiaries acquired ST Services. On August 30, 2000, the Judge entered final judgment in the case that Grace take nothing from the subsidiaries on its claims seeking recovery of remediation costs. Although KPPs subsidiaries have not incurred any expenses in connection with the remediation, the court also ruled, in effect, that the subsidiaries would not be entitled to indemnification from Grace if any such expenses were incurred in the future. Moreover, the Judge let stand a prior summary judgment ruling that the pipeline was an asset acquired by KPPs subsidiaries as part of the 1993 ST Services transaction and that any liabilities associated with the pipeline would have become liabilities of the subsidiaries. Based on that ruling, the Massachusetts Department of Environmental Protection and Samson Hydrocarbons Company (successor to Grace Petroleum Company) wrote letters to ST Services alleging its responsibility for the remediation, and ST Services responded denying any liability in connection with this matter. The Judge also awarded attorney fees to Grace of approximately $1.8 million. Both KPPs subsidiaries and Grace have appealed the trial
Exhibit 99.1 page 7
courts final judgment to the Texas Court of Appeals in Dallas. In particular, the subsidiaries have filed an appeal of the judgment finding that the Otis pipeline and any liabilities associated with the pipeline were transferred to them as well as the award of attorney fees to Grace.
On April 2, 2001, Grace filed a petition in bankruptcy, which created an automatic stay of actions against Grace. This automatic stay covers the appeal of the Dallas litigation, and the Texas Court of Appeals has issued an order staying all proceedings of the appeal because of the bankruptcy. Once that stay is lifted, KPPs subsidiaries that are party to the lawsuit intend to resume vigorous prosecution of the appeal.
The Otis Air Force Base is a part of the Massachusetts Military Reservation (MMR Site), which has been declared a Superfund Site pursuant to CERCLA. The MMR Site contains a number of groundwater contamination plumes, two of which are allegedly associated with the Otis pipeline, and various other waste management areas of concern, such as landfills. The United States Department of Defense, pursuant to a Federal Facilities Agreement, has been responding to the Government remediation demand for most of the contamination problems at the MMR Site. Grace and others have also received and responded to formal inquiries from the United States Government in connection with the environmental damages allegedly resulting from the fuel leaks. KPPs subsidiaries voluntarily responded to an invitation from the Government to provide information indicating that they do not own the pipeline. In connection with a court-ordered mediation between Grace and KPPs subsidiaries, the Government advised the parties in April 1999 that it has identified two spill areas that it believes to be related to the pipeline that is the subject of the Grace suit. The Government at that time advised the parties that it believed it had incurred costs of approximately $34 million, and expected in the future to incur costs of approximately $55 million, for remediation of one of the spill areas. This amount was not intended to be a final accounting of costs or to include all categories of costs. The Government also advised the parties that it could not at that time allocate its costs attributable to the second spill area.
By letter dated July 26, 2001, the United States Department of Justice (DOJ) advised ST Services that the Government intends to seek reimbursement from ST Services under the Massachusetts Oil and Hazardous Material Release Prevention and Response Act and the Declaratory Judgment Act for the Governments response costs at the two spill areas discussed above. The DOJ relied in part on the Texas state court judgment, which in the DOJs view, held that ST Services was the current owner of the pipeline and the successor-in-interest of the prior owner and operator. The Government advised ST Services that it believed it had incurred costs exceeding $40 million, and expected to incur future costs exceeding an additional $22 million, for remediation of the two spill areas. KPP believes that its subsidiaries have substantial defenses. ST Services responded to the DOJ on September 6, 2001, contesting the Governments positions and declining to reimburse any response costs. In 2002, the DOJ asserted that, inclusive of both spill areas, it had incurred over $49 million
Exhibit 99.1 page 8
in costs and expected to incur additional costs of approximately $19 million. The DOJ has not filed a lawsuit against ST Services seeking cost recovery for its environmental investigation and response costs. Representatives of ST Services have met with representatives of the Government on several occasions since September 6, 2001 to discuss the Governments claims and to exchange information related to such claims. Additional exchanges of information may occur in the future and additional meetings may be held to discuss possible resolution of the Governments claims without litigation. KPP does not believe this matter will have a material adverse effect on its financial condition, although there can be no assurances as to the ultimate outcome.
PEPCO Matter
On April 7, 2000, a fuel oil pipeline in Maryland owned by Potomac Electric Power Company (PEPCO) ruptured. Some work performed with regard to the pipeline was conducted by a partnership of which ST Services is general partner. PEPCO alleges that it has incurred costs of approximately $80 million as a result of the spill. PEPCO probably will continue to incur some cleanup related costs for the foreseeable future, primarily in connection with EPA requirements for monitoring the condition of some of the impacted areas. Since May 2000, ST Services has provisionally contributed a minority share of the cleanup expense, which has been funded by ST Services insurance carriers. ST Services and PEPCO have not, however, reached a final agreement regarding ST Services proportionate responsibility for this cleanup effort, if any, and cannot predict the amount, if any, that ultimately may be determined to be ST Services share of the remediation expense, but ST Services believes that such amount will be covered by insurance and therefore will not materially adversely affect KPPs financial condition.
As a result of the rupture, purported class actions were filed against PEPCO and ST Services in federal and state court in Maryland by property and business owners alleging damages in unspecified amounts under various theories, including under the Oil Pollution Act (OPA) and Maryland common law. The federal court consolidated all of the federal cases in a case styled as In re Swanson Creek Oil Spill Litigation. A settlement of the consolidated class action, and a companion state-court class action, was reached and approved by the federal judge. The settlement involved creation and funding by PEPCO and ST Services of a $2,250,000 class settlement fund, from which all participating claimants would be paid according to a court-approved formula, as well as a court-approved payment to plaintiffs attorneys. The settlement has been consummated and the fund, to which PEPCO and ST Services contributed equal amounts, has been distributed. Participating claimants claims have been settled and dismissed with prejudice. A number of class members elected not to participate in the settlement, i.e., to opt out, thereby preserving their claims against PEPCO and ST Services. All non-participant claims have been settled for immaterial amounts with ST Services portion of such settlements provided by its insurance carrier.
Exhibit 99.1 page 9
PEPCO and ST Services agreed with the federal government and the State of Maryland to pay costs of assessing natural resource damages arising from the Swanson Creek oil spill under OPA and of selecting restoration projects. This process was completed in mid-2002. ST Services insurer has paid ST Services agreed 50 percent share of these assessment costs. In late November 2002, PEPCO and ST Services entered into a Consent Decree resolving the federal and state trustees claims for natural resource damages. The decree required payments by ST Services and PEPCO of a total of approximately $3 million to fund the restoration projects and for remaining damage assessment costs. The federal court entered the Consent Decree as a final judgment on December 31, 2002. PEPCO and ST Services have each paid their 50% share and thus fully performed their payment obligations under the Consent Decree. ST Services insurance carrier funded ST Services payment.
The U.S. Department of Transportation (DOT) has issued a Notice of Proposed Violation to PEPCO and ST Services alleging violations over several years of pipeline safety regulations and proposing a civil penalty of $647,000 jointly against the two companies. ST Services and PEPCO have contested the DOT allegations and the proposed penalty. A hearing was held before the Office of Pipeline Safety at the DOT in late 2001. In June of 2004, the DOT issued a final order reducing the penalty to $256,250 jointly against ST Services and PEPCO and $74,000 against ST Services.
By letter dated January 4, 2002, the Attorney Generals Office for the State of Maryland advised ST Services that it intended to seek penalties from ST Services in connection with the April 7, 2000 spill. The State of Maryland subsequently asserted that it would seek penalties against ST Services and PEPCO totaling up to $12 million. A settlement of this claim was reached in mid-2002 under which ST Services insurer will pay a total of slightly more than $1 million in installments over a five year period. PEPCO has also reached a settlement of these claims with the State of Maryland. Accordingly, KPP believes that this matter will not have a material adverse effect on its financial condition.
On December 13, 2002, ST Services sued PEPCO in the Superior Court, District of Columbia, seeking, among other things, a declaratory judgment as to ST Services legal obligations, if any, to reimburse PEPCO for costs of the oil spill. On December 16, 2002, PEPCO sued ST Services in the United States District Court for the District of Maryland, seeking recovery of all its costs for remediation of and response to the oil spill. Pursuant to an agreement between ST Services and PEPCO, ST Services suit was dismissed, subject to refiling. ST Services has moved to dismiss PEPCOs suit. ST Services is vigorously defending against PEPCOs claims and is pursuing its own counterclaims for return of monies ST Services has advanced to PEPCO for settlements and cleanup costs. KPP believes that any costs or damages resulting from these lawsuits will be covered by insurance and therefore will not materially adversely affect KPPs financial condition. The amounts claimed by PEPCO, if recovered, would trigger an excess insurance policy which has a
Exhibit 99.1 page 10
$600,000 retention, but KPP does not believe that such retention, if incurred, would materially adversely affect KPPs financial condition.
Paulsboro GATX Matter
In 2003, Exxon Mobil filed a lawsuit in a New Jersey state court against GATX Corporation, Kinder Morgan Liquid Terminals (Kinder Morgan), the successor in interest to GATX Terminals Corporation (GATX), and ST Services, seeking reimbursement for remediation costs associated with the Paulsboro, New Jersey terminal. The terminal was owned and operated by Exxon Mobil from the early 1950s until 1990 when purchased by GATX. ST Services purchased the terminal in 2000 from GATX. GATX was subsequently acquired by Kinder Morgan. As a condition to the sale to GATX in 1990, Exxon Mobil undertook certain remediation obligations with respect to the site. In the lawsuit, Exxon Mobil is claiming that it has complied with its remediation and contractual obligations and is entitled to reimbursement from GATX Corporation, the parent company of GATX, Kinder Morgan, and ST Services for costs in the amount of $400,000 that it claims are related to releases at the site subsequent to its sale of the terminal to GATX. It is also alleging that any remaining remediation requirements are the responsibility of GATX Corporation, Kinder Morgan, or ST Services. Kinder Morgan has alleged that it was relieved of any remediation obligations pursuant to the sale agreement between its predecessor, GATX, and ST Services. ST Services believes that, except for remediation involving immaterial amounts, GATX Corporation or Exxon Mobil are responsible for the remaining remediation of the site. Costs of completing the required remediation depend on a number of factors and cannot be determined at the current time. Discovery is underway in anticipation of mediation scheduled for November 2005.
Surface Transportation Board Matter
A subsidiary of KPP purchased the approximately 2,000-mile ammonia pipeline system from Koch Pipeline Company, L.P. and Koch Fertilizer Storage and Terminal Company in 2002. The rates of the ammonia pipeline are subject to regulation by the Surface Transportation Board (the STB). The STB had issued an order in May 2000, prescribing maximum allowable rates KPPs predecessor could charge for transportation to certain destination points on the pipeline system. In 2003, KPP instituted a 7% general increase to pipeline rates. On August 1, 2003, CF Industries, Inc. (CFI) filed a complaint with the STB challenging these rate increases. On August 11, 2004, STB ordered KPP to pay reparations to CFI and to return CFIs rates to the levels permitted under the rate prescription. KPP has complied with the order. The STB, however, indicated in the order that it would lift the rate prescription in the event KPP could show materially changed circumstances. KPP has submitted evidence of materially changed circumstances, which specifically includes its capital investment in the pipeline. CFI has argued that KPPs acquisition costs should not be considered by the STB as a measure of KPPs investment base.
Exhibit 99.1 page 11
Also, on June 16, 2003, Dyno Nobel Inc. (Dyno) filed a complaint with the STB challenging the 2003 rate increase on the basis that (i) the rate increase constitutes a violation of a contract rate, (ii) rates are discriminatory and (iii) the rates exceed permitted levels. Dyno also intervened in the CFI proceeding described above. Unlike CFI, Dynos rates are not subject to a rate prescription. On May 11, 2005, the STB held a hearing on KPPs request to vacate the existing rate prescription and Dynos contract claims, and post-hearing briefing was completed on June 10, 2005. The case is currently pending before the STB and a ruling is expected later this year. As of June 30, 2005, Dyno would be entitled to approximately $3.1 million in rate refunds, should it be successful. KPP believes, however, that Dynos claims are of limited merit.
Port of Vancouver
ST Services (STS) currently owns a refined products terminal on property owned by the Port of Vancouver (Port) and leases the land under the terminal from the Port. Under an Agreed Order entered into with the Washington Department of Ecology (WDE) when STS purchased the terminal in 1998, STS agreed to investigate and remediate a groundwater plume contaminated by the terminals previous owner and operator. STS has submitted a final remedial action plan to WDE, and is waiting for WDE to approve that plan. The Port also owns property near the STS terminal site that has been contaminated by other parties, some of which are in bankruptcy. Estimated costs to remediate the STS terminal site depend on a number of factors, including the outcome of litigation involving the other properties owned by the Port that are near the STS terminal site. STSs liability for remediation of the STS site is not the subject of any pending litigation. Until formal claims asserting such liability are made, liability is difficult to assess. Accordingly, STSs liability for any portion of total future remediation costs is not reasonably estimable at this time.
KPP has other contingent liabilities resulting from litigation, claims and commitments incident to the ordinary course of business. Management of KPP believes, after consulting with counsel, that the ultimate resolution of such contingencies will not have a material adverse effect on the financial position, results of operations or liquidity of KPP.
Exhibit 99.1 page 12
7. BUSINESS SEGMENT DATA
The Company conducts business through three reportable business segments: the Pipeline Operations Segment of KPP, which consists primarily of the transportation of refined petroleum products and fertilizer in the Midwestern states as a common carrier; the Terminaling Operations Segment of KPP, which provides storage for petroleum products, specialty chemicals and other liquids; and the Companys Product Marketing Services Segment, which provides wholesale motor fuel marketing services throughout the Midwest and Rocky Mountain regions, delivers bunker fuels to ships in the Caribbean and Nova Scotia, Canada, and sells bulk petroleum products to various commercial interests. General corporate includes accounting, tax, finance, legal, investor relations and other corporate expenses not related to the segments. General corporate assets include cash, receivables from affiliates of the Company and other assets not related to the segments.
The Company measures segment profit as operating income. Total assets are those assets controlled by each reportable segment. Business segment data is as follows:
|
|
Three Months Ended |
|
Six Months Ended |
|
||||||||
|
|
2005 |
|
2004 |
|
2005 |
|
2004 |
|
||||
|
|
(in thousands) |
|
||||||||||
|
|
|
|
||||||||||
Business segment revenues: |
|
|
|
|
|
|
|
|
|
||||
Pipeline operations |
|
$ |
32,706 |
|
$ |
30,610 |
|
$ |
62,798 |
|
$ |
58,513 |
|
Terminaling operations |
|
69,477 |
|
63,448 |
|
138,607 |
|
126,243 |
|
||||
Product marketing operations |
|
233,012 |
|
160,144 |
|
424,816 |
|
302,625 |
|
||||
|
|
$ |
335,195 |
|
$ |
254,202 |
|
$ |
626,221 |
|
$ |
487,381 |
|
Business segment profit: |
|
|
|
|
|
|
|
|
|
||||
Pipeline operations |
|
$ |
7,232 |
|
$ |
12,024 |
|
$ |
18,969 |
|
$ |
23,234 |
|
Terminaling operations |
|
(36,260 |
) |
20,876 |
|
(17,533 |
) |
39,360 |
|
||||
Product marketing operations |
|
5,803 |
|
4,156 |
|
11,370 |
|
7,910 |
|
||||
General corporate |
|
(8,019 |
) |
(522 |
) |
(8,879 |
) |
(1,055 |
) |
||||
Operating income |
|
(31,244 |
) |
36,534 |
|
3,927 |
|
69,449 |
|
||||
Interest and other income |
|
107 |
|
61 |
|
313 |
|
93 |
|
||||
Interest expense |
|
(12,636 |
) |
(10,720 |
) |
(23,984 |
) |
(21,349 |
) |
||||
Income (loss) before income taxes and interest of outside non-controlling partners in KPPs net income (loss) |
|
$ |
(43,773 |
) |
$ |
25,875 |
|
$ |
(19,744 |
) |
$ |
48,193 |
|
Exhibit 99.1 page 13
|
|
June 30, |
|
December 31, |
|
||
|
|
(in thousands) |
|
||||
Total assets: |
|
|
|
|
|
||
Pipeline operations |
|
$ |
346,580 |
|
$ |
351,195 |
|
Terminaling operations |
|
886,805 |
|
917,966 |
|
||
Product marketing operations |
|
100,092 |
|
83,404 |
|
||
General corporate |
|
3,443 |
|
4,323 |
|
||
|
|
$ |
1,336,920 |
|
$ |
1,356,888 |
|
The business segment profit of the terminaling operations segment includes the $42 million provision for loss contingencies (see note 6) and a $4 million loss due to an impairment of a terminal in the U.K.
8. ADOPTION OF RECENT ACCOUNTING PRONOUNCEMENTS
In March of 2005, the Financial Accounting Standards Board issued FASB Interpretation No. 47, Accounting for Conditional Asset Retirement Obligations (FIN 47), which requires companies to recognize a liability for the fair value of a legal obligation to perform asset-retirement activities, even though the timing and/or method of settlement are conditional on a future event, if the amount can be reasonably estimated. FIN 47 must be adopted by the Company by the end of fiscal 2005. The impact of adoption of FIN 47 on the Companys consolidated financial statements is still being evaluated.
Exhibit 99.1 page 14
KANEB PIPE LINE PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(In Thousands Except Per Unit Amounts)
(Unaudited)
|
|
Three Months Ended |
|
Six Months Ended |
|
||||||||
|
|
2005 |
|
2004 |
|
2005 |
|
2004 |
|
||||
Revenues: |
|
|
|
|
|
|
|
|
|
||||
Services |
|
$ |
102,183 |
|
$ |
94,058 |
|
$ |
201,405 |
|
$ |
184,756 |
|
Products |
|
103,077 |
|
59,900 |
|
186,873 |
|
115,615 |
|
||||
Total revenues |
|
205,260 |
|
153,958 |
|
388,278 |
|
300,371 |
|
||||
|
|
|
|
|
|
|
|
|
|
||||
Costs and expenses: |
|
|
|
|
|
|
|
|
|
||||
Cost of products sold |
|
94,466 |
|
55,167 |
|
171,551 |
|
106,206 |
|
||||
Operating costs |
|
57,806 |
|
43,105 |
|
104,208 |
|
86,315 |
|
||||
Depreciation and amortization |
|
14,661 |
|
13,729 |
|
29,495 |
|
27,627 |
|
||||
General and administrative |
|
21,131 |
|
6,307 |
|
31,396 |
|
12,011 |
|
||||
Provision for loss contingencies |
|
42,000 |
|
|
|
42,000 |
|
|
|
||||
|
|
|
|
|
|
|
|
|
|
||||
Total costs and expenses |
|
230,064 |
|
118,308 |
|
378,650 |
|
232,159 |
|
||||
|
|
|
|
|
|
|
|
|
|
||||
Operating income (loss) |
|
(24,804 |
) |
35,650 |
|
9,628 |
|
68,212 |
|
||||
Interest and other income |
|
94 |
|
35 |
|
298 |
|
40 |
|
||||
Interest expense |
|
(12,004 |
) |
(10,512 |
) |
(23,109 |
) |
(20,948 |
) |
||||
|
|
|
|
|
|
|
|
|
|
||||
Income (loss) before minority interest and income taxes |
|
(36,714 |
) |
25,173 |
|
(13,183 |
) |
47,304 |
|
||||
Minority interest in net (income) loss |
|
225 |
|
(245 |
) |
5 |
|
(455 |
) |
||||
Income tax benefit (expense) |
|
14,304 |
|
(642 |
) |
12,790 |
|
(1,794 |
) |
||||
|
|
|
|
|
|
|
|
|
|
||||
Net income (loss) |
|
(22,185 |
) |
24,286 |
|
(388 |
) |
45,055 |
|
||||
|
|
|
|
|
|
|
|
|
|
||||
General partners interest in net (income) loss |
|
224 |
|
(2,490 |
) |
(2,242 |
) |
(4,772 |
) |
||||
|
|
|
|
|
|
|
|
|
|
||||
Limited partners interest in net income (loss) |
|
$ |
(21,961 |
) |
$ |
21,796 |
|
$ |
(2,630 |
) |
$ |
40,283 |
|
|
|
|
|
|
|
|
|
|
|
||||
Allocation of net income (loss) per unit |
|
$ |
(.78 |
) |
$ |
.77 |
|
$ |
(.09 |
) |
$ |
1.42 |
|
|
|
|
|
|
|
|
|
|
|
||||
Weighted average number of limited partnership units outstanding |
|
28,328 |
|
28,318 |
|
28,328 |
|
28,318 |
|
See Notes to Consolidated Financial Statements
Exhibit 99.1 page 15
KANEB PIPE LINE PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(In Thousands)
|
|
June 30, |
|
December 31, |
|
||
|
|
(Unaudited) |
|
|
|
||
ASSETS |
|
|
|
|
|
||
Current assets: |
|
|
|
|
|
||
Cash and cash equivalents |
|
$ |
14,727 |
|
$ |
34,336 |
|
Accounts receivable |
|
64,400 |
|
71,035 |
|
||
Inventories |
|
11,431 |
|
15,519 |
|
||
Prepaid expenses and other |
|
19,293 |
|
12,371 |
|
||
|
|
|
|
|
|
||
Total current assets |
|
109,851 |
|
133,261 |
|
||
|
|
|
|
|
|
||
Property and equipment |
|
1,468,669 |
|
1,450,972 |
|
||
Less accumulated depreciation |
|
329,163 |
|
302,381 |
|
||
|
|
|
|
|
|
||
Net property and equipment |
|
1,139,506 |
|
1,148,591 |
|
||
|
|
|
|
|
|
||
Investment in affiliates |
|
26,828 |
|
25,939 |
|
||
|
|
|
|
|
|
||
Excess of cost over fair value of net assets of acquired businesses and other assets |
|
16,341 |
|
17,525 |
|
||
|
|
|
|
|
|
||
|
|
$ |
1,292,526 |
|
$ |
1,325,316 |
|
|
|
|
|
|
|
|
|
LIABILITIES AND PARTNERS CAPITAL |
|
|
|
|
|
||
Current liabilities: |
|
|
|
|
|
||
Current portion of long-term debt |
|
$ |
195,984 |
|
$ |
|
|
Accounts payable |
|
33,540 |
|
44,071 |
|
||
Accrued expenses |
|
33,457 |
|
42,573 |
|
||
Accrued distributions payable |
|
|
|
26,960 |
|
||
Accrued interest payable |
|
8,896 |
|
9,365 |
|
||
Payable to general partner |
|
541 |
|
4,528 |
|
||
|
|
|
|
|
|
||
Total current liabilities |
|
272,418 |
|
127,497 |
|
||
|
|
|
|
|
|
||
Long-term debt, less current portion |
|
500,000 |
|
671,952 |
|
||
|
|
|
|
|
|
||
Other liabilities and deferred taxes |
|
68,439 |
|
44,386 |
|
||
|
|
|
|
|
|
||
Commitments and contingencies (see note 5) |
|
|
|
|
|
||
|
|
|
|
|
|
||
Minority interest |
|
703 |
|
984 |
|
||
|
|
|
|
|
|
||
Partners capital |
|
450,966 |
|
480,497 |
|
||
|
|
|
|
|
|
||
|
|
$ |
1,292,526 |
|
$ |
1,325,316 |
|
See Notes to Consolidated Financial Statements
Exhibit 99.1 page 16
KANEB PIPE LINE PARTNERS, L.P. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In Thousands)
(Unaudited)
|
|
Six Months Ended |
|
||||
|
|
2005 |
|
2004 |
|
||
|
|
|
|
|
|
||
Operating activities: |
|
|
|
|
|
||
Net income (loss) |
|
$ |
(388 |
) |
$ |
45,055 |
|
Adjustments to reconcile net income (loss) to net cash provided by operating activities: |
|
|
|
|
|
||
Depreciation and amortization |
|
29,495 |
|
27,627 |
|
||
Provision for loss contingencies |
|
42,000 |
|
|
|
||
Minority interest in net income (loss) |
|
(5 |
) |
455 |
|
||
Equity in earnings of affiliates, net of distributions |
|
(889 |
) |
(497 |
) |
||
Deferred income taxes |
|
(14,449 |
) |
(230 |
) |
||
Other |
|
3,495 |
|
(792 |
) |
||
Changes in working capital components |
|
(21,669 |
) |
(1,905 |
) |
||
|
|
|
|
|
|
||
Net cash provided by operating activities |
|
37,590 |
|
69,713 |
|
||
|
|
|
|
|
|
||
Investing activities: |
|
|
|
|
|
||
Capital expenditures |
|
(22,030 |
) |
(17,340 |
) |
||
Acquisitions |
|
(10,034 |
) |
(12,478 |
) |
||
Other |
|
785 |
|
(737 |
) |
||
Net cash used in investing activities |
|
(31,279 |
) |
(30,555 |
) |
||
|
|
|
|
|
|
||
Financing activities: |
|
|
|
|
|
||
Issuance of debt |
|
28,000 |
|
14,500 |
|
||
Distributions, including minority interest |
|
(53,920 |
) |
(52,688 |
) |
||
|
|
|
|
|
|
||
Net cash used in financing activities |
|
(25,920 |
) |
(38,188 |
) |
||
|
|
|
|
|
|
||
Increase (decrease) in cash and cash equivalents |
|
(19,609 |
) |
970 |
|
||
Cash and cash equivalents at beginning of period |
|
34,336 |
|
38,626 |
|
||
|
|
|
|
|
|
||
Cash and cash equivalents at end of period |
|
$ |
14,727 |
|
$ |
39,596 |
|
|
|
|
|
|
|
||
Supplemental cash flow information cash paid for interest |
|
$ |
22,197 |
|
$ |
20,558 |
|
Exhibit 99.1 page 17
KANEB PIPE LINE PARTNERS, L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. SIGNIFICANT ACCOUNTING POLICIES
Kaneb Pipe Line Partners, L.P. (the Partnership), a master limited partnership, owns and operates a refined petroleum products and fertilizer pipeline business, a petroleum products and specialty liquids storage and terminaling business and a petroleum product sales operation. Kaneb Pipe Line Company LLC (KPL), a wholly owned subsidiary of Kaneb Services LLC (KSL), manages and controls the Partnership through its general partner interest and an 18% (at June 30, 2005) limited partner interest. The Partnership operates through Kaneb Pipe Line Operating Partnership, L.P. (KPOP), a limited partnership in which the Partnership holds a 99% interest as limited partner. KPL owns a 1% interest as general partner of the Partnership and a 1% interest as general partner of KPOP. KPLs 1% interest in KPOP is reflected as the minority interest in the financial statements.
The unaudited condensed consolidated financial statements of the Partnership for the three and six month periods ended June 30, 2005 and 2004, have been prepared in accordance with accounting principles generally accepted in the United States of America. Significant accounting policies followed by the Partnership are disclosed in the notes to the consolidated financial statements included in the Partnerships Annual Report on Form 10-K for the year ended December 31, 2004. In the opinion of the Partnerships management, the accompanying condensed consolidated financial statements contain all of the adjustments, consisting of normal recurring accruals, necessary to present fairly the consolidated financial position of the Partnership and its consolidated subsidiaries at June 30, 2005, and the consolidated results of their operations and cash flows for the periods ended June 30, 2005 and 2004. Operating results for the three and six months ended June 30, 2005 are not necessarily indicative of the results that may be expected for the year ending December 31, 2005.
2. VALERO L.P. MERGER
On July 1, 2005, Valero L.P. acquired all of the outstanding units of the Partnership as well as all of the outstanding shares of KSL. Consequently, the Partnership and KSL became wholly owned subsidiaries of Valero L.P.
In connection with the acquisition by Valero L.P., the Partnership incurred certain costs directly related to the acquisition. For the six months ended June 30, 2005, approximately $15.7 million was included in general and administrative expenses related principally to settling certain outstanding stock awards and settling other employee compensation obligations, and legal fees associated with the acquisition. In addition, on June 30, 2005 the Partnership paid approximately $3.6 million in contractual change of control payments. Because these payments were contingent upon the closing of the Valero L.P. merger, these payments were included in prepaid expenses and other at June 30, 2005. To fund a portion of these expenses, the Partnership borrowed approximately $28.0 million in the second quarter of 2005.
On July 1, 2005, Valero L.P. entered into a definitive agreement to sell certain of the Partnerships assets to Pacific Energy Partners L.P. for approximately $455 million. These asset sales were required by the U.S. Federal Trade Commission as a condition to closing the merger.
Exhibit 99.1 page 18
3. COMPREHENSIVE INCOME
Comprehensive income (loss) for the three and six months ended June 30, 2005 and 2004, is as follows:
|
|
Three Months Ended |
|
Six Months Ended |
|
||||||||
|
|
2005 |
|
2004 |
|
2005 |
|
2004 |
|
||||
|
|
(in thousands) |
|
||||||||||
|
|
|
|
||||||||||
Net income (loss) |
|
$ |
(22,185 |
) |
$ |
24,286 |
|
$ |
(388 |
) |
$ |
45,055 |
|
Foreign currency translation adjustment |
|
(2,233 |
) |
(2,036 |
) |
(3,001 |
) |
(2,269 |
) |
||||
Gain on interest rate hedging transaction |
|
57 |
|
37 |
|
90 |
|
82 |
|
||||
|
|
|
|
|
|
|
|
|
|
||||
Comprehensive income (loss) |
|
$ |
(24,361 |
) |
$ |
22,287 |
|
$ |
(3,299 |
) |
$ |
42,868 |
|
Accumulated other comprehensive income aggregated $13.3 million and $16.2 million at June 30, 2005 and December 31, 2004, respectively.
4. CASH DISTRIBUTIONS
Prior to the acquisition by Valero L.P., the Partnership made quarterly distributions of 100% of its available cash, as defined in its partnership agreement, to holders of limited Partnership units and the general partner. Available cash consisted generally of all the cash receipts of the Partnership, plus the beginning cash balance, less all of its cash disbursements and reserves. Due to the acquisition by Valero L.P., the Partnership did not declare any distributions subsequent to June 30, 2005. Accordingly, the June 30, 2005 consolidated balance sheet of the Partnership does not reflect an amount for accrued distributions payable. A cash distribution of $0.855 per unit with respect to the fourth quarter of 2004 was paid on February 14, 2005. A cash distribution of $0.855 per unit with respect to the first quarter of 2005 was declared to holders of record on April 30, 2005 and was paid on May 13, 2005.
Exhibit 99.1 page 19
5. CONTINGENCIES
GENERAL
The operations of the Partnership are subject to federal, state and local laws and regulations in the United States and various foreign locations relating to protection of the environment. Although the Partnership believes its operations are in general compliance with applicable environmental regulations, risks of additional costs and liabilities are inherent in pipeline and terminal operations, and there can be no assurance that significant costs and liabilities will not be incurred by the Partnership. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies thereunder, and claims for damages to property or persons resulting from the operations of the Partnership, could result in substantial costs and liabilities to the Partnership.
LITIGATION AND ENVIRONMENTAL
The Partnership has contingent liabilities resulting from various litigation, claims and commitments, some of which are incident to the ordinary course of business. Other contingencies, which are considered more significant by the Partnership, are discussed below. Subsequent to the acquisition of the Partnership by Valero L.P., new management of the Partnership determined based on a comprehensive review of the matters disclosed below that an additional $42 million accrual for potential loss contingencies was required, which was recorded in the quarter ended June 30, 2005. Accordingly, KPP has recorded estimated reserves totaling approximately $44 million related to certain of the matters discussed below. These reserves have been recorded in compliance with generally accepted accounting principles, however, management believes that there are defenses in each of these matters and it intends to vigorously defend each matter. As a result, the actual payment of any amounts reserved and the timing of such payments ultimately made is uncertain. Management also believes that should KPP be unable to successfully defend itself in these matters, the ultimate payment of any or all of the amounts reserved would not have a material adverse effect on KPPs financial position. However, given the inherent uncertainty in estimating reserves for such matters, KPP can give no assurance that the amounts recorded will not require adjustment in the future, and such adjustments could be significant and could have a material adverse effect on KPPs financial position and results of operations.
Grace Matter
Certain subsidiaries of the Partnership were sued in a Texas state court in 1997 by Grace Energy Corporation (Grace), the entity from which the Partnership acquired ST Services in 1993. The lawsuit involves environmental response and remediation costs allegedly resulting from fuel leaks in the early 1970s from a pipeline. The pipeline, which connected a former Grace terminal with Otis Air Force Base in Massachusetts (the Otis pipeline or the
Exhibit 99.1 page 20
pipeline), ceased operations in 1973 and was abandoned before 1978, when the connecting terminal was sold to an unrelated entity. Grace alleged that subsidiaries of the Partnership acquired the abandoned pipeline as part of the acquisition of ST Services in 1993 and assumed responsibility for environmental damages allegedly caused by the fuel leaks. Grace sought a ruling from the Texas court that these subsidiaries are responsible for all liabilities, including all present and future remediation expenses, associated with these leaks and that Grace has no obligation to indemnify these subsidiaries for these expenses. In the lawsuit, Grace also sought indemnification for expenses of approximately $3.5 million that it had incurred since 1996 for response and remediation required by the State of Massachusetts and for additional expenses that it expects to incur in the future. The consistent position of the Partnerships subsidiaries has been that they did not acquire the abandoned pipeline as part of the 1993 ST Services transaction, and therefore did not assume any responsibility for the environmental damage nor any liability to Grace for the pipeline.
At the end of the trial, the jury returned a verdict including findings that (1) Grace had breached a provision of the 1993 acquisition agreement by failing to disclose matters related to the pipeline, and (2) the pipeline was abandoned before 1978 15 years before the Partnerships subsidiaries acquired ST Services. On August 30, 2000, the Judge entered final judgment in the case that Grace take nothing from the subsidiaries on its claims seeking recovery of remediation costs. Although the Partnerships subsidiaries have not incurred any expenses in connection with the remediation, the court also ruled, in effect, that the subsidiaries would not be entitled to indemnification from Grace if any such expenses were incurred in the future. Moreover, the Judge let stand a prior summary judgment ruling that the pipeline was an asset acquired by the Partnerships subsidiaries as part of the 1993 ST Services transaction and that any liabilities associated with the pipeline would have become liabilities of the subsidiaries. Based on that ruling, the Massachusetts Department of Environmental Protection and Samson Hydrocarbons Company (successor to Grace Petroleum Company) wrote letters to ST Services alleging its responsibility for the remediation, and ST Services responded denying any liability in connection with this matter. The Judge also awarded attorney fees to Grace of approximately $1.8 million. Both the Partnerships subsidiaries and Grace have appealed the trial courts final judgment to the Texas Court of Appeals in Dallas. In particular, the subsidiaries have filed an appeal of the judgment finding that the Otis pipeline and any liabilities associated with the pipeline were transferred to them as well as the award of attorney fees to Grace.
On April 2, 2001, Grace filed a petition in bankruptcy, which created an automatic stay of actions against Grace. This automatic stay covers the appeal of the Dallas litigation, and the Texas Court of Appeals has issued an order staying all proceedings of the appeal because of the bankruptcy. Once that stay is lifted, the Partnerships subsidiaries that are party to the lawsuit intend to resume vigorous prosecution of the appeal.
Exhibit 99.1 page 21
The Otis Air Force Base is a part of the Massachusetts Military Reservation (MMR Site), which has been declared a Superfund Site pursuant to CERCLA. The MMR Site contains a number of groundwater contamination plumes, two of which are allegedly associated with the Otis pipeline, and various other waste management areas of concern, such as landfills. The United States Department of Defense, pursuant to a Federal Facilities Agreement, has been responding to the Government remediation demand for most of the contamination problems at the MMR Site. Grace and others have also received and responded to formal inquiries from the United States Government in connection with the environmental damages allegedly resulting from the fuel leaks. The Partnerships subsidiaries voluntarily responded to an invitation from the Government to provide information indicating that they do not own the pipeline. In connection with a court-ordered mediation between Grace and the Partnerships subsidiaries, the Government advised the parties in April 1999 that it has identified two spill areas that it believes to be related to the pipeline that is the subject of the Grace suit. The Government at that time advised the parties that it believed it had incurred costs of approximately $34 million, and expected in the future to incur costs of approximately $55 million, for remediation of one of the spill areas. This amount was not intended to be a final accounting of costs or to include all categories of costs. The Government also advised the parties that it could not at that time allocate its costs attributable to the second spill area.
By letter dated July 26, 2001, the United States Department of Justice (DOJ) advised ST Services that the Government intends to seek reimbursement from ST Services under the Massachusetts Oil and Hazardous Material Release Prevention and Response Act and the Declaratory Judgment Act for the Governments response costs at the two spill areas discussed above. The DOJ relied in part on the Texas state court judgment, which in the DOJs view, held that ST Services was the current owner of the pipeline and the successor-in-interest of the prior owner and operator. The Government advised ST Services that it believed it had incurred costs exceeding $40 million, and expected to incur future costs exceeding an additional $22 million, for remediation of the two spill areas. KPP believes that its subsidiaries have substantial defenses. ST Services responded to the DOJ on September 6, 2001, contesting the Governments positions and declining to reimburse any response costs. In 2002, the DOJ asserted that, inclusive of both spill areas, it had incurred over $49 million in costs and expected to incur additional costs of approximately $19 million. The DOJ has not filed a lawsuit against ST Services seeking cost recovery for its environmental investigation and response costs. Representatives of ST Services have met with representatives of the Government on several occasions since September 6, 2001 to discuss the Governments claims and to exchange information related to such claims. Additional exchanges of information may occur in the future and additional meetings may be held to discuss possible resolution of the Governments claims without litigation. The Partnership does not believe this matter will have a material adverse effect on its financial condition, although there can be no assurances as to the ultimate outcome.
Exhibit 99.1 page 22
PEPCO Matter
On April 7, 2000, a fuel oil pipeline in Maryland owned by Potomac Electric Power Company (PEPCO) ruptured. Some work performed with regard to the pipeline was conducted by a partnership of which ST Services is general partner. PEPCO alleges that it has incurred costs of approximately $80 million as a result of the spill. PEPCO probably will continue to incur some cleanup related costs for the foreseeable future, primarily in connection with EPA requirements for monitoring the condition of some of the impacted areas. Since May 2000, ST Services has provisionally contributed a minority share of the cleanup expense, which has been funded by ST Services insurance carriers. ST Services and PEPCO have not, however, reached a final agreement regarding ST Services proportionate responsibility for this cleanup effort, if any, and cannot predict the amount, if any, that ultimately may be determined to be ST Services share of the remediation expense, but ST Services believes that such amount will be covered by insurance and therefore will not materially adversely affect the Partnerships financial condition.
As a result of the rupture, purported class actions were filed against PEPCO and ST Services in federal and state court in Maryland by property and business owners alleging damages in unspecified amounts under various theories, including under the Oil Pollution Act (OPA) and Maryland common law. The federal court consolidated all of the federal cases in a case styled as In re Swanson Creek Oil Spill Litigation. A settlement of the consolidated class action, and a companion state-court class action, was reached and approved by the federal judge. The settlement involved creation and funding by PEPCO and ST Services of a $2,250,000 class settlement fund, from which all participating claimants would be paid according to a court-approved formula, as well as a court-approved payment to plaintiffs attorneys. The settlement has been consummated and the fund, to which PEPCO and ST Services contributed equal amounts, has been distributed. Participating claimants claims have been settled and dismissed with prejudice. A number of class members elected not to participate in the settlement, i.e., to opt out, thereby preserving their claims against PEPCO and ST Services. All non-participant claims have been settled for immaterial amounts with ST Services portion of such settlements provided by its insurance carrier.
PEPCO and ST Services agreed with the federal government and the State of Maryland to pay costs of assessing natural resource damages arising from the Swanson Creek oil spill under OPA and of selecting restoration projects. This process was completed in mid-2002. ST Services insurer has paid ST Services agreed 50 percent share of these assessment costs. In late November 2002, PEPCO and ST Services entered into a Consent Decree resolving the federal and state trustees claims for natural resource damages. The decree required payments by ST Services and PEPCO of a total of approximately $3 million to fund the restoration projects and for remaining damage assessment costs. The federal court entered the Consent Decree as a final judgment on December 31, 2002. PEPCO and ST Services have each paid their 50% share and thus fully performed their payment obligations under the Consent Decree. ST Services insurance carrier funded ST Services payment.
Exhibit 99.1 page 23
The U.S. Department of Transportation (DOT) has issued a Notice of Proposed Violation to PEPCO and ST Services alleging violations over several years of pipeline safety regulations and proposing a civil penalty of $647,000 jointly against the two companies. ST Services and PEPCO have contested the DOT allegations and the proposed penalty. A hearing was held before the Office of Pipeline Safety at the DOT in late 2001. In June of 2004, the DOT issued a final order reducing the penalty to $256,250 jointly against ST Services and PEPCO and $74,000 against ST Services.
By letter dated January 4, 2002, the Attorney Generals Office for the State of Maryland advised ST Services that it intended to seek penalties from ST Services in connection with the April 7, 2000 spill. The State of Maryland subsequently asserted that it would seek penalties against ST Services and PEPCO totaling up to $12 million. A settlement of this claim was reached in mid-2002 under which ST Services insurer will pay a total of slightly more than $1 million in installments over a five year period. PEPCO has also reached a settlement of these claims with the State of Maryland. Accordingly, the Partnership believes that this matter will not have a material adverse effect on its financial condition.
On December 13, 2002, ST Services sued PEPCO in the Superior Court, District of Columbia, seeking, among other things, a declaratory judgment as to ST Services legal obligations, if any, to reimburse PEPCO for costs of the oil spill. On December 16, 2002, PEPCO sued ST Services in the United States District Court for the District of Maryland, seeking recovery of all its costs for remediation of and response to the oil spill. Pursuant to an agreement between ST Services and PEPCO, ST Services suit was dismissed, subject to refiling. ST Services has moved to dismiss PEPCOs suit. ST Services is vigorously defending against PEPCOs claims and is pursuing its own counterclaims for return of monies ST Services has advanced to PEPCO for settlements and cleanup costs. The Partnership believes that any costs or damages resulting from these lawsuits will be covered by insurance and therefore will not materially adversely affect the Partnerships financial condition. The amounts claimed by PEPCO, if recovered, would trigger an excess insurance policy which has a $600,000 retention, but the Partnership does not believe that such retention, if incurred, would materially adversely affect the Partnerships financial condition.
Paulsboro GATX Matter
In 2003, Exxon Mobil filed a lawsuit in a New Jersey state court against GATX Corporation, Kinder Morgan Liquid Terminals (Kinder Morgan), the successor in interest to GATX Terminals Corporation (GATX), and ST Services, seeking reimbursement for remediation costs associated with the Paulsboro, New Jersey terminal. The terminal was owned and operated by Exxon Mobil from the early 1950s until 1990 when purchased by GATX. ST Services purchased the terminal in 2000 from GATX. GATX was subsequently acquired by Kinder Morgan. As a condition to the sale to GATX in 1990, Exxon Mobil undertook certain remediation obligations with respect to the site. In the lawsuit, Exxon Mobil is claiming that it has complied with its remediation and contractual obligations and is entitled to
Exhibit 99.1 page 24
reimbursement from GATX Corporation, the parent company of GATX, Kinder Morgan, and ST Services for costs in the amount of $400,000 that it claims are related to releases at the site subsequent to its sale of the terminal to GATX. It is also alleging that any remaining remediation requirements are the responsibility of GATX Corporation, Kinder Morgan, or ST Services. Kinder Morgan has alleged that it was relieved of any remediation obligations pursuant to the sale agreement between its predecessor, GATX, and ST Services. ST Services believes that, except for remediation involving immaterial amounts, GATX Corporation or Exxon Mobil are responsible for the remaining remediation of the site. Costs of completing the required remediation depend on a number of factors and cannot be determined at the current time. Discovery is underway in anticipation of mediation scheduled for November 2005.
Exhibit 99.1 page 25
Surface Transportation Board Matter
A subsidiary of the Partnership purchased the approximately 2,000-mile ammonia pipeline system from Koch Pipeline Company, L.P. and Koch Fertilizer Storage and Terminal Company in 2002. The rates of the ammonia pipeline are subject to regulation by the Surface Transportation Board (the STB). The STB had issued an order in May 2000, prescribing maximum allowable rates the Partnerships predecessor could charge for transportation to certain destination points on the pipeline system. In 2003, the Partnership instituted a 7% general increase to pipeline rates. On August 1, 2003, CF Industries, Inc. (CFI) filed a complaint with the STB challenging these rate increases. On August 11, 2004, STB ordered the Partnership to pay reparations to CFI and to return CFIs rates to the levels permitted under the rate prescription. The Partnership has complied with the order. The STB, however, indicated in the order that it would lift the rate prescription in the event the Partnership could show materially changed circumstances. The Partnership has submitted evidence of materially changed circumstances, which specifically includes its capital investment in the pipeline. CFI has argued that the Partnerships acquisition costs should not be considered by the STB as a measure of the Partnerships investment base.
Also, on June 16, 2003, Dyno Nobel Inc. (Dyno) filed a complaint with the STB challenging the 2003 rate increase on the basis that (i) the rate increase constitutes a violation of a contract rate, (ii) rates are discriminatory and (iii) the rates exceed permitted levels. Dyno also intervened in the CFI proceeding described above. Unlike CFI, Dynos rates are not subject to a rate prescription. On May 11, 2005, the STB held a hearing on the Partnerships request to vacate the existing rate prescription and Dynos contract claims, and post-hearing briefing was completed on June 10, 2005. The case is currently pending before the STB and a ruling is expected later this year. As of June 30, 2005, Dyno would be entitled to approximately $3.1 million in rate refunds, should it be successful. The Partnership believes, however, that Dynos claims are of limited merit.
Port of Vancouver
ST Services (STS) currently owns a refined products terminal on property owned by the Port of Vancouver (Port) and leases the land under the terminal from the Port. Under an Agreed Order entered into with the Washington Department of Ecology (WDE) when STS purchased the terminal in 1998, STS agreed to investigate and remediate a groundwater plume contaminated by the terminals previous owner and operator. STS has submitted a final remedial action plan to WDE, and is waiting for WDE to approve that plan. The Port also owns property near the STS terminal site that has been contaminated by other parties, some of which are in bankruptcy. Estimated costs to remediate the STS terminal site depend on a number of factors, including the outcome of litigation involving the other properties owned by the Port that are near the STS terminal site. STSs liability for remediation of the STS site is not the subject of any pending litigation. Until formal claims asserting such
Exhibit 99.1 page 26
liability are made, liability is difficult to assess. Accordingly, STSs liability for any portion of total future remediation costs is not reasonably estimable at this time.
The Partnership has other contingent liabilities resulting from litigation, claims and commitments incident to the ordinary course of business. Management of the Partnership believes, after consulting with counsel, that the ultimate resolution of such contingencies will not have a material adverse effect on the financial position, results of operations or liquidity of the Partnership.
Exhibit 99.1 page 27
6. BUSINESS SEGMENT DATA
The Partnership conducts business through three reportable business segments: the Pipeline Operations Segment, which consists primarily of the transportation of refined petroleum products and fertilizer in the Midwestern states as a common carrier; the Terminaling Operations Segment, which provides storage for petroleum products, specialty chemicals and other liquids; and the Product Sales Operations Segment, which delivers bunker fuels to ships in the Caribbean and Nova Scotia, Canada, and sells bulk petroleum products to various commercial interests.
The Partnership measures segment profit as operating income. Total assets are those controlled by each reportable segment. Business segment data is as follows:
|
|
Three Months Ended |
|
Six Months Ended |
|
||||||||
|
|
2005 |
|
2004 |
|
2005 |
|
2004 |
|
||||
|
|
(in thousands) |
|
||||||||||
Business segment revenues: |
|
|
|
|
|
|
|
|
|
||||
Pipeline operations |
|
$ |
32,706 |
|
$ |
30,610 |
|
$ |
62,798 |
|
$ |
58,513 |
|
Terminaling operations |
|
69,477 |
|
63,448 |
|
138,607 |
|
126,243 |
|
||||
Product sales operations |
|
103,077 |
|
59,900 |
|
186,873 |
|
115,615 |
|
||||
|
|
$ |
205,260 |
|
$ |
153,958 |
|
$ |
388,278 |
|
$ |
300,371 |
|
|
|
|
|
|
|
|
|
|
|
||||
Business segment profit: |
|
|
|
|
|
|
|
|
|
||||
Pipeline operations |
|
$ |
7,230 |
|
$ |
12,024 |
|
$ |
18,967 |
|
$ |
23,234 |
|
Terminaling operations |
|
(36,260 |
) |
20,876 |
|
(17,533 |
) |
39,360 |
|
||||
Product sales operations |
|
4,226 |
|
2,750 |
|
8,194 |
|
5,618 |
|
||||
Operating income (loss) |
|
(24,804 |
) |
35,650 |
|
9,628 |
|
68,212 |
|
||||
Interest and other income |
|
94 |
|
35 |
|
298 |
|
40 |
|
||||
Interest expense |
|
(12,004 |
) |
(10,512 |
) |
(23,109 |
) |
(20,948 |
) |
||||
|
|
|
|
|
|
|
|
|
|
||||
Income (loss) before minority interest and income taxes |
|
$ |
(36,714 |
) |
$ |
25,173 |
|
$ |
(13,183 |
) |
$ |
47,304 |
|
Exhibit 99.1 page 28
|
|
June 30, |
|
December 31, |
|
||
|
|
(in thousands) |
|
||||
Total assets: |
|
|
|
|
|
||
Pipeline operations |
|
$ |
346,580 |
|
$ |
351,195 |
|
Terminaling operations |
|
886,803 |
|
917,966 |
|
||
Product sales operations |
|
59,143 |
|
56,155 |
|
||
|
|
$ |
1,292,526 |
|
$ |
1,325,316 |
|
The business segment profit of the terminaling operations segment includes the $42 million provision for loss contingencies (see note 5) and a $4 million loss due to an impairment of a terminal in the U.K.
7. ADOPTION OF RECENT ACCOUNTING PRONOUNCEMENTS
In March of 2005, the Financial Accounting Standards Board issued FASB Interpretation No. 47, Accounting for Conditional Asset Retirement Obligations (FIN 47), which requires companies to recognize a liability for the fair value of a legal obligation to perform asset-retirement activities, even though the timing and/or method of settlement are conditional on a future event, if the amount can be reasonably estimated. FIN 47 must be adopted by the Partnership by the end of fiscal 2005. The impact of adoption of FIN 47 on the Partnerships consolidated financial statements is still being evaluated.
Exhibit 99.1 page 29
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors of Kaneb Services LLC
We have audited the accompanying consolidated balance sheets of Kaneb Services LLC and its subsidiaries (the Company) as of December 31, 2004 and 2003, and the related consolidated statements of income, stockholders equity and cash flows for each of the years in the three-year period ended December 31, 2004. These consolidated financial statements are the responsibility of the Companys management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.
We conducted our audits in accordance with standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2004 and 2003, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2004, in conformity with U.S. generally accepted accounting principles.
As described in Note 2, the Company adopted Statement of Financial Accounting Standards No. 143 Accounting for Asset Retirement Obligations in 2003.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the effectiveness of the Companys internal control over financial reporting as of December 31, 2004, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated March 11, 2005 expressed an unqualified opinion on managements assessment of, and the effective operation of, internal control over financial reporting.
/s/ KPMG LLP |
|
|
|
Dallas, Texas |
|
March 11, 2005 |
Exhibit 99.1 page 30
KANEB SERVICES LLC
CONSOLIDATED STATEMENTS OF INCOME
|
|
Year Ended December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Revenues: |
|
|
|
|
|
|
|
|||
Services |
|
$ |
379,155,000 |
|
$ |
354,591,000 |
|
$ |
288,669,000 |
|
Products |
|
676,093,000 |
|
511,200,000 |
|
381,159,000 |
|
|||
Total revenues |
|
1,055,248,000 |
|
865,791,000 |
|
669,828,000 |
|
|||
|
|
|
|
|
|
|
|
|||
Costs and expenses: |
|
|
|
|
|
|
|
|||
Cost of products sold |
|
647,733,000 |
|
486,310,000 |
|
367,870,000 |
|
|||
Operating costs |
|
177,829,000 |
|
169,380,000 |
|
132,269,000 |
|
|||
Depreciation and amortization |
|
56,676,000 |
|
53,195,000 |
|
39,471,000 |
|
|||
Gain on sale of assets |
|
|
|
|
|
(609,000 |
) |
|||
General and administrative |
|
36,231,000 |
|
28,402,000 |
|
24,468,000 |
|
|||
Total costs and expenses |
|
918,469,000 |
|
737,287,000 |
|
563,469,000 |
|
|||
|
|
|
|
|
|
|
|
|||
Operating income |
|
136,779,000 |
|
128,504,000 |
|
106,359,000 |
|
|||
|
|
|
|
|
|
|
|
|||
Interest and other income |
|
336,000 |
|
365,000 |
|
3,664,000 |
|
|||
Interest expense |
|
(43,579,000 |
) |
(39,576,000 |
) |
(29,171,000 |
) |
|||
Loss on debt extinguishment |
|
|
|
|
|
(3,282,000 |
) |
|||
|
|
|
|
|
|
|
|
|||
Income before gain on issuance of units by KPP, income taxes, interest of outside non-controlling partners in KPPs net income and cumulative effect of change in accounting principle |
|
93,536,000 |
|
89,293,000 |
|
77,570,000 |
|
|||
|
|
|
|
|
|
|
|
|||
Gain on issuance of units by KPP |
|
|
|
10,898,000 |
|
24,882,000 |
|
|||
Income tax expense |
|
(3,251,000 |
) |
(4,887,000 |
) |
(2,585,000 |
) |
|||
Interest of outside non-controlling partners in KPPs net income |
|
(65,933,000 |
) |
(61,908,000 |
) |
(52,639,000 |
) |
|||
Income before cumulative effect of change in accounting principle |
|
24,352,000 |
|
33,396,000 |
|
47,228,000 |
|
|||
|
|
|
|
|
|
|
|
|||
Cumulative effect of change in accounting principle - adoption of new accounting standard for asset retirement obligations |
|
|
|
(313,000 |
) |
|
|
|||
Net income |
|
$ |
24,352,000 |
|
$ |
33,083,000 |
|
$ |
47,228,000 |
|
Earnings per share: |
|
|
|
|
|
|
|
|||
Basic: |
|
|
|
|
|
|
|
|||
Before cumulative effect of change in accounting principle |
|
$ |
2.07 |
|
$ |
2.89 |
|
$ |
4.13 |
|
Cumulative effect of change in accounting principle |
|
|
|
(.03 |
) |
|
|
|||
|
|
$ |
2.07 |
|
$ |
2.86 |
|
$ |
4.13 |
|
Diluted: |
|
|
|
|
|
|
|
|||
Before cumulative effect of change in accounting principle |
|
$ |
2.03 |
|
$ |
2.84 |
|
$ |
4.02 |
|
Cumulative effect of change in accounting principle |
|
|
|
(.03 |
) |
|
|
|||
|
|
$ |
2.03 |
|
$ |
2.81 |
|
$ |
4.02 |
|
See notes to consolidated financial statements.
Exhibit 99.1 page 31
KANEB SERVICES LLC
CONSOLIDATED BALANCE SHEETS
|
|
December 31, |
|
||||
|
|
2004 |
|
2003 |
|
||
ASSETS |
|
|
|
|
|
||
Current assets: |
|
|
|
|
|
||
Cash and cash equivalents |
|
$ |
38,415,000 |
|
$ |
43,457,000 |
|
Accounts receivable (net of allowance for doubtful accounts of $2,255,000 in 2004 and $3,777,000 in 2003) |
|
85,976,000 |
|
60,684,000 |
|
||
Inventories |
|
25,448,000 |
|
18,637,000 |
|
||
Prepaid expenses and other |
|
12,614,000 |
|
9,650,000 |
|
||
Total current assets |
|
162,453,000 |
|
132,428,000 |
|
||
Property and equipment |
|
1,451,176,000 |
|
1,360,523,000 |
|
||
Less accumulated depreciation |
|
302,564,000 |
|
247,503,000 |
|
||
Net property and equipment |
|
1,148,612,000 |
|
1,113,020,000 |
|
||
Investment in affiliates |
|
25,939,000 |
|
25,456,000 |
|
||
|
|
|
|
|
|
||
Excess of cost over fair value of net assets of acquired businesses and other assets |
|
19,884,000 |
|
20,663,000 |
|
||
|
|
$ |
1,356,888,000 |
|
$ |
1,291,567,000 |
|
|
|
|
|
|
|
||
LIABILITIES AND SHAREHOLDERS EQUITY |
|
|
|
|
|
||
|
|
|
|
|
|
||
Current liabilities: |
|
|
|
|
|
||
Accounts payable |
|
$ |
54,280,000 |
|
$ |
36,916,000 |
|
Accrued expenses |
|
38,142,000 |
|
39,307,000 |
|
||
Accrued interest payable |
|
9,374,000 |
|
9,303,000 |
|
||
Accrued distributions payable to shareholders |
|
5,801,000 |
|
5,567,000 |
|
||
Accrued distributions payable to outside non-controlling partners in KPPs net income |
|
19,863,000 |
|
19,507,000 |
|
||
Deferred terminaling fees |
|
8,851,000 |
|
7,061,000 |
|
||
Total current liabilities |
|
136,311,000 |
|
117,661,000 |
|
||
Long-term debt |
|
688,985,000 |
|
636,308,000 |
|
||
Other liabilities and deferred taxes |
|
53,520,000 |
|
52,242,000 |
|
||
Interest of outside non-controlling partners in KPP |
|
397,717,000 |
|
407,635,000 |
|
||
Commitments and contingencies |
|
|
|
|
|
||
Shareholders equity: |
|
|
|
|
|
||
Shareholders investment |
|
77,136,000 |
|
75,291,000 |
|
||
Accumulated other comprehensive income |
|
3,219,000 |
|
2,430,000 |
|
||
Total shareholders equity |
|
80,355,000 |
|
77,721,000 |
|
||
|
|
$ |
1,356,888,000 |
|
$ |
1,291,567,000 |
|
See notes to consolidated financial statements.
Exhibit 99.1 page 32
KANEB SERVICES LLC
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|
Year Ended December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Operating activities: |
|
|
|
|
|
|
|
|||
Net income |
|
$ |
24,352,000 |
|
$ |
33,083,000 |
|
$ |
47,228,000 |
|
Adjustments to reconcile net income to net cash provided by operating activities: |
|
|
|
|
|
|
|
|||
Depreciation and amortization |
|
56,676,000 |
|
53,195,000 |
|
39,471,000 |
|
|||
Equity in earnings of affiliates, net of distributions |
|
(483,000 |
) |
148,000 |
|
(3,164,000 |
) |
|||
Interest of outside non-controlling partners in KPPs net income |
|
65,933,000 |
|
61,908,000 |
|
52,639,000 |
|
|||
Gain on issuance of units by KPP |
|
|
|
(10,898,000 |
) |
(24,882,000 |
) |
|||
Gain on sale of assets |
|
|
|
|
|
(609,000 |
) |
|||
Deferred income taxes |
|
(671,000 |
) |
1,683,000 |
|
3,105,000 |
|
|||
Cumulative effect of change in accounting principle |
|
|
|
313,000 |
|
|
|
|||
Other |
|
(1,191,000 |
) |
1,468,000 |
|
(559,000 |
) |
|||
Changes in working capital components: |
|
|
|
|
|
|
|
|||
Accounts receivable |
|
(25,292,000 |
) |
1,151,000 |
|
(16,403,000 |
) |
|||
Inventories, prepaid expenses and other |
|
(9,775,000 |
) |
(4,766,000 |
) |
(7,643,000 |
) |
|||
Accounts payable and accrued expenses |
|
17,135,000 |
|
7,639,000 |
|
(165,000 |
) |
|||
Net cash provided by operating activities |
|
126,684,000 |
|
144,924,000 |
|
89,018,000 |
|
|||
|
|
|
|
|
|
|
|
|||
Investing activities: |
|
|
|
|
|
|
|
|||
Acquisitions, net of cash acquired |
|
(41,853,000 |
) |
(1,644,000 |
) |
(468,477,000 |
) |
|||
Capital expenditures |
|
(42,214,000 |
) |
(44,747,000 |
) |
(31,101,000 |
) |
|||
Proceeds from sale of assets |
|
|
|
|
|
1,107,000 |
|
|||
Other, net |
|
2,684,000 |
|
(1,388,000 |
) |
361,000 |
|
|||
Net cash used in investing activities |
|
(81,383,000 |
) |
(47,779,000 |
) |
(498,110,000 |
) |
|||
Financing activities: |
|
|
|
|
|
|
|
|||
Issuance of debt |
|
52,001,000 |
|
291,377,000 |
|
756,087,000 |
|
|||
Payments of debt |
|
(2,500,000 |
) |
(388,051,000 |
) |
(427,493,000 |
) |
|||
Distributions to shareholders |
|
(22,860,000 |
) |
(20,473,000 |
) |
(18,351,000 |
) |
|||
Distributions to outside non-controlling partners in KPP |
|
(78,732,000 |
) |
(73,004,000 |
) |
(52,827,000 |
) |
|||
Changes in long-term payables and other liabilities |
|
|
|
|
|
(10,026,000 |
) |
|||
Net proceeds from issuance of units by KPP |
|
|
|
109,056,000 |
|
175,527,000 |
|
|||
Issuance of common shares upon exercise of stock options |
|
111,000 |
|
164,000 |
|
648,000 |
|
|||
Net cash provided by (used in) financing activities |
|
(51,980,000 |
) |
(80,931,000 |
) |
423,565,000 |
|
|||
Effect of exchange rate changes on cash |
|
1,637,000 |
|
2,766,000 |
|
|
|
|||
Increase (decrease) in cash and cash equivalents |
|
(5,042,000 |
) |
18,980,000 |
|
14,473,000 |
|
|||
Cash and cash equivalents at beginning of period |
|
43,457,000 |
|
24,477,000 |
|
10,004,000 |
|
|||
Cash and cash equivalents at end of period |
|
$ |
38,415,000 |
|
$ |
43,457,000 |
|
$ |
24,477,000 |
|
Supplemental cash flow information - cash paid for interest |
|
$ |
42,122,000 |
|
$ |
35,712,000 |
|
$ |
27,070,000 |
|
See notes to consolidated financial statements.
Exhibit 99.1 page 33
KANEB SERVICES LLC
CONSOLIDATED STATEMENTS OF SHAREHOLDERS EQUITY
|
|
Shareholders |
|
Accumulated |
|
Total |
|
Comprehensive |
|
||||
Balance at January 1, 2002 |
|
$ |
34,428,000 |
|
$ |
(496,000 |
) |
$ |
33,932,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||
Net income for the year |
|
47,228,000 |
|
|
|
47,228,000 |
|
$ |
47,228,000 |
|
|||
Distributions declared |
|
(18,954,000 |
) |
|
|
(18,954,000 |
) |
|
|
||||
Issuance of common shares and other |
|
648,000 |
|
|
|
648,000 |
|
|
|
||||
Foreign currency translation adjustment |
|
|
|
800,000 |
|
800,000 |
|
800,000 |
|
||||
Comprehensive income for the year |
|
|
|
|
|
|
|
$ |
48,028,000 |
|
|||
|
|
|
|
|
|
|
|
|
|
||||
Balance at December 31, 2002 |
|
63,350,000 |
|
304,000 |
|
63,654,000 |
|
|
|
||||
|
|
|
|
|
|
|
|
|
|
||||
Net income for the year |
|
33,083,000 |
|
|
|
33,083,000 |
|
$ |
33,083,000 |
|
|||
Distributions declared |
|
(21,306,000 |
) |
|
|
(21,306,000 |
) |
|
|
||||
Issuance of common shares and other |
|
164,000 |
|
|
|
164,000 |
|
|
|
||||
Foreign currency translation adjustment |
|
|
|
2,457,000 |
|
2,457,000 |
|
2,457,000 |
|
||||
Interest rate hedging transaction |
|
|
|
(331,000 |
) |
(331,000 |
) |
(331,000 |
) |
||||
Comprehensive income for the year |
|
|
|
|
|
|
|
$ |
35,209,000 |
|
|||
|
|
|
|
|
|
|
|
|
|
||||
Balance at December 31, 2003 |
|
75,291,000 |
|
2,430,000 |
|
77,721,000 |
|
|
|
||||
|
|
|
|
|
|
|
|
|
|
||||
Net income for the year |
|
24,352,000 |
|
|
|
24,352,000 |
|
$ |
24,352,000 |
|
|||
Distributions declared |
|
(23,094,000 |
) |
|
|
(23,094,000 |
) |
|
|
||||
Issuance of common shares and other |
|
587,000 |
|
|
|
587,000 |
|
|
|
||||
Foreign currency translation adjustment |
|
|
|
753,000 |
|
753,000 |
|
753,000 |
|
||||
Interest rate hedging transaction |
|
|
|
36,000 |
|
36,000 |
|
36,000 |
|
||||
Comprehensive income for the year |
|
|
|
|
|
|
|
$ |
25,141,000 |
|
|||
|
|
|
|
|
|
|
|
|
|
||||
Balance at December 31, 2004 |
|
$ |
77,136,000 |
|
$ |
3,219,000 |
|
$ |
80,355,000 |
|
|
|
See notes to consolidated financial statements.
Exhibit 99.1 page 34
KANEB SERVICES LLC
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. COMPANY ORGANIZATION
General
On November 27, 2000, the Board of Directors of Kaneb Services, Inc. authorized the distribution of its pipeline, terminaling and product marketing businesses (the Distribution) to its stockholders in the form of a new limited liability company, Kaneb Services LLC (the Company). On June 29, 2001, the Distribution was completed, with each stockholder of Kaneb Services, Inc. receiving one common share of the Company for each three shares of Kaneb Services, Inc.s common stock held on June 20, 2001, the record date for the Distribution, resulting in the distribution of 10.85 million shares of the Company. On August 7, 2001, the stockholders of Kaneb Services, Inc. approved an amendment to its certificate of incorporation to change its name to Xanser Corporation (Xanser).
In September 1989, Kaneb Pipe Line Company LLC (KPL), now a wholly owned subsidiary of the Company, formed Kaneb Pipe Line Partners, L.P. (KPP) to own and operate its refined petroleum products pipeline business. KPL manages and controls the operations of KPP through its general partner interests and a 18% (at December 31, 2004) limited partnership interest. KPP operates through Kaneb Pipe Line Operating Partnership, L.P. (KPOP), a limited partnership in which KPP holds a 99% interest as limited partner. KPL owns a 1% interest as general partner of KPP and a 1% interest as general partner of KPOP.
KPL owns a petroleum product marketing business which provides wholesale motor fuel marketing services in the Great Lakes and Rocky Mountain regions of the United States. KPPs product sales business delivers bunker fuels to ships in the Caribbean and Nova Scotia, Canada, and sells bulk petroleum products to various commercial customers at those locations. In the bunkering business, KPP competes with ports offering bunker fuels along the route of the vessel. Vessel owners or charterers are charged berthing and other fees for associated services such as pilotage, tug assistance, line handling, launch service and emergency response services.
Valero L.P. Merger Agreement
On October 31, 2004, Valero L.P. agreed to acquire by merger (the KSL Merger) all of the outstanding common shares of the Company for cash. Under the terms of that agreement, Valero L.P. is offering to purchase all of the outstanding shares of the Company at $43.31 per share.
In a separate definitive agreement, on October 31, 2004, Valero L.P. and KPP agreed to merge (the KPP Merger). Under the terms of that agreement, each holder of units of limited partnership interests in KPP will receive a number of Valero L.P. common units based on an exchange ratio that fluctuates within a fixed range to provide $61.50 in value of Valero L.P. units for each unit of KPP. The actual exchange ratio will be determined at the time of the closing of the proposed merger and is subject to a fixed value collar of plus or minus five percent of Valero L.P.s per unit price of $57.25 as of October 7, 2004. Should Valero L.P.s per unit price fall below $54.39 per unit, the exchange ratio will remain fixed at 1.1307 Valero L.P. units for each unit of KPP. Likewise, should Valero L.P.s per unit price exceed $60.11 per unit, the exchange ratio will remain fixed at 1.0231 Valero L.P. units for each unit of KPP.
The completion of the KSL Merger is subject to the customary regulatory approvals including those under the Hart-Scott-Rodino Antitrust Improvements Act. The completion of the KSL Merger is also subject to completion of the KPP Merger. All required shareholder and unitholder approvals have been obtained. Upon completion of the mergers, the general partner of the combined partnership will be owned by affiliates of Valero Energy Corporation and the Company and KPP will become wholly owned subsidiaries of Valero L.P.
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
The following significant accounting policies are followed by the Company in the preparation of the consolidated financial statements.
Cash and Cash Equivalents
The Companys policy is to invest cash in highly liquid investments with original maturities of three months or less. Accordingly, uninvested cash balances are kept at minimum levels. Such investments are valued at cost, which approximates market, and are classified as cash equivalents.
Exhibit 99.1 page 35
Inventories
Inventories consist primarily of petroleum products purchased for resale in the product marketing business and are valued at the lower of cost or market. Cost is determined by using the weighted-average cost method.
Property and Equipment
Property and equipment are carried at historical cost. Additions of new equipment and major renewals and replacements of existing equipment are capitalized. Repairs and minor replacements that do not materially increase values or extend useful lives are expensed. Depreciation of property and equipment is provided on a straight-line basis at rates based upon expected useful lives of various classes of assets, as discussed in Note 5. The rates used for pipeline and certain storage facilities, which are subject to regulation, are the same as those which have been promulgated by the Federal Energy Regulatory Commission. Upon disposal of assets depreciated on an individual basis, the gains and losses are included in current operating income. Upon disposal of assets depreciated on a group basis, unless unusual in nature or amount, residual cost, less salvage, is charged against accumulated depreciation.
Effective January 1, 2002, the Company adopted Statement of Financial Accounting Standards (SFAS) No. 144, Accounting for the Impairment or Disposal of Long-Lived Assets, which addresses financial accounting and reporting for the impairment or disposal of long-lived assets. The adoption of SFAS No. 144 did not have a material impact on the consolidated financial statements of the Company. Under SFAS No. 144, the carrying value of the Companys property and equipment is periodically evaluated using undiscounted future cash flows as the basis for determining if impairment exists. To the extent impairment is indicated to exist, an impairment loss will be recognized by the Company based on fair value.
Revenue and Income Recognition
The pipeline business provides pipeline transportation of refined petroleum products, liquified petroleum gases, and anhydrous ammonia fertilizer. Pipeline revenues are recognized as services are provided. KPPs terminaling services business provides terminaling and other ancillary services. Storage fees are generally billed one month in advance and are reported as deferred income. Terminaling revenues are recognized in the month services are provided. Revenues for the product marketing business are recognized when product is sold and title and risk pass to the customer.
Sales of Securities by Subsidiaries
The Company recognizes gains and losses in the consolidated statements of income resulting from subsidiary sales of additional equity interest, including KPP limited partnership units, to unrelated parties.
Foreign Currency Translation
The Company translates the balance sheet of KPPs foreign subsidiaries using year-end exchange rates and translates income statement amounts using the average exchange rates in effect during the year. The gains and losses resulting from the change in exchange rates from year to year have been reported separately as a component of accumulated other comprehensive income (loss) in Shareholders Equity. Gains and losses resulting from foreign currency transactions are included in the consolidated statements of income. The local currency is considered to be the functional currency, except in the Netherland Antilles and Canada, where the U.S. dollar is the functional currency.
Excess of Cost Over Fair Value of Net Assets of Acquired Businesses
Effective January 1, 2002, the Company adopted SFAS No. 142, Goodwill and Other Intangible Assets, which eliminates the amortization of goodwill (excess of cost over fair value of net assets of acquired businesses) and other intangible assets with indefinite lives. Under SFAS No. 142, intangible assets with lives restricted by contractual, legal, or other means will continue to be amortized over their useful lives. At December 31, 2004, the Company had no intangible assets subject to amortization under SFAS No. 142. Goodwill and other intangible assets not subject to amortization are tested for impairment annually or more frequently if events or changes in circumstances indicate that the assets might be impaired. SFAS No. 142 requires a two-step process for testing impairment. First, the fair value of each reporting unit is compared to its carrying value to determine whether an indication of impairment exists. If an impairment is indicated, then the fair value of the reporting units goodwill is determined by allocating the units fair value to its assets and liabilities (including any unrecognized intangible assets) as if the reporting unit had been acquired in a business combination. The amount of impairment for goodwill is measured as the excess of its carrying value over its fair value. Based on valuations and analysis performed by the Company at initial adoption date and at each annual evaluation date, including December 31, 2004, the Company determined that the implied fair value of its goodwill exceeded carrying value and, therefore, no impairment charge was necessary.
Exhibit 99.1 page 36
Environmental Matters
KPP environmental expenditures that relate to current operations are expensed or capitalized, as appropriate. Expenditures that relate to an existing condition caused by past operations, and which do not contribute to current or future revenue generation, are expensed. Liabilities are recorded by KPP when environmental assessments and/or remedial efforts are probable, and the costs can be reasonably estimated. Generally, the timing of these accruals coincides with the completion of a feasibility study or KPPs commitment to a formal plan of action.
Asset Retirement Obligations
Effective January 1, 2003, the Company adopted SFAS No. 143 Accounting for Asset Retirement Obligations, which establishes requirements for the removal-type costs associated with asset retirements. At the initial adoption date of SFAS No. 143, the Company recorded an asset retirement obligation of approximately $5.5 million and recognized a cumulative effect of change in accounting principle of $0.3 million, after interest of outside non-controlling partners in KPPs net income, for its legal obligations to dismantle, dispose of, and restore certain leased KPP pipeline and terminaling facilities, including petroleum and chemical storage tanks, terminaling facilities and barges. The Company did not record a retirement obligation for certain of KPPs pipeline and terminaling assets because sufficient information is presently not available to estimate a range of potential settlement dates for the obligation. In these cases, the obligation will be initially recognized in the period in which sufficient information exists to estimate the obligation. At December 31, 2004, the Company had no assets which were legally restricted for purposes of settling asset retirement obligations. The effect of SFAS No. 143, assuming adoption on January 1, 2002, was not material to the results of operations of the Company for the years ended December 31, 2004, 2003 and 2002. In 2004 and 2003, accretion expense of $0.2 million and $0.4 million, respectively, was included in operating costs.
Comprehensive Income
The Company follows the provisions of SFAS No. 130, Reporting Comprehensive Income, for the reporting and display of comprehensive income and its components in a full set of general purpose financial statements. SFAS No. 130 requires additional disclosure and does not affect the Companys financial position or results of operations.
Income Taxes
Limited liability company operations are not subject to federal or state income taxes. However, certain KPP terminaling operations are conducted through separate taxable wholly-owned corporate subsidiaries. The income before tax expense for these subsidiaries was $18.4 million, $18.9 million and $6.3 million for the years ended December 31, 2004, 2003 and 2002, respectively. The income tax expense for KPPs taxable subsidiaries for the years ended December 31, 2004, 2003 and 2002 was $3.3 million, $5.2 million and $4.1 million, respectively. KPP has recorded a net deferred tax liability of $21.5 million and $20.6 million at December 2004 and 2003, respectively, which is associated with these subsidiaries.
On June 1, 1989, the governments of the Netherlands Antilles and St. Eustatius approved a Free Zone and Profit Tax Agreement retroactive to January 1, 1989, which expired on December 31, 2000. This agreement required a subsidiary of KPP, which was acquired with Statia on February 28, 2002 (see Note 4), to pay a 2% rate on taxable income, as defined therein, or a minimum payment of 500,000 Netherlands Antilles guilders ($0.3 million) per year. The agreement further provided that any amounts paid in order to meet the minimum annual payment were available to offset future tax liabilities under the agreement to the extent that the minimum annual payment is greater than 2% of taxable income. The subsidiary is currently engaged in discussions with representatives appointed by the Island Territory of St. Eustatius regarding the renewal or modification of the agreement, but the ultimate outcome cannot be predicted at this time. The subsidiary has accrued amounts assuming a new agreement becomes effective, and continues to make payments, as required, under the previous agreement.
Cash Distributions
The Company makes quarterly distributions of 100% of available cash, as defined in the limited liability agreement, to the common shareholders of record on the applicable record date, within 45 days after the end of each quarter. Available cash consists generally of all the cash receipts of the Company, less all cash disbursements and reserves. Excess cash flow of the Companys wholly-owned product marketing operations is being used to reduce working capital borrowings. Distributions of $1.96, $1.825 and $1.65 per share were declared and paid to shareholders with respect to the years ended December 31, 2004, 2003 and 2002, respectively.
Exhibit 99.1 page 37
Earnings Per Share
Earnings per share has been calculated using basic and diluted weighted average shares outstanding for each of the periods presented. For the years ended December 31, 2004, 2003 and 2002, basic weighted average shares outstanding were 11,746,000, 11,554,000 and 11,448,000 and diluted weighted average shares outstanding were 11,981,000, 11,792,000 and 11,755,000, respectively.
Derivative Instruments
The Company follows the provisions of SFAS No. 133, Accounting For Derivative Instruments and Hedging Activities, which establishes the accounting and reporting standards for such activities. Under SFAS No. 133, companies must recognize all derivative instruments on their balance sheet at fair value. Changes in the value of derivative instruments, which are considered hedges, are offset against the change in fair value of the hedged item through earnings, or recognized in other comprehensive income until the hedged item is recognized in earnings, depending on the nature of the hedge. SFAS No. 133 requires that unrealized gains and losses on derivatives not qualifying for hedge accounting be recognized currently in earnings.
On May 19, 2003, KPP issued $250 million of 5.875% senior unsecured notes due June 1, 2013 (see Note 6). In connection with the offering, on May 8, 2003, KPP entered into a treasury lock contract for the purpose of locking in the US Treasury interest rate component on $100 million of the debt. The treasury lock contract, which qualified as a cash flow hedging instrument under SFAS No. 133, was settled on May 19, 2003 with a cash payment by KPP of $1.8 million. The settlement cost of the contract, net of interest of outside non-controlling partners in KPPs accumulated other comprehensive income, has been recorded as a component of accumulated other comprehensive income and is being amortized, as interest expense, over the life of the debt. For the year ended December 31, 2004 and 2003, $0.2 million and $0.1 million, respectively, of amortization is included in interest expense.
In September of 2002, KPP entered into a treasury lock contract, maturing on November 4, 2002, for the purpose of locking in the US Treasury interest rate component on $150 million of anticipated thirty-year public debt offerings. The treasury lock contract originally qualified as a cash flow hedging instrument under SFAS No. 133. In October of 2002, KPP, due to various market factors, elected to defer issuance of the public debt securities, effectively eliminating the cash flow hedging designation for the treasury lock contract. On October 29, 2002, the contract was settled resulting in a net realized gain of $3.0 million, before interest of outside non-controlling partners in KPPs net income, which was recognized as a component of interest and other income.
Stock Option Plans
In December of 2004, the Financial Accounting Standards Board (FASB) issued SFAS No. 123 (revised 2004), Share-Based Payment (SFAS No. 123R), which addresses the accounting for share-based payment transactions in which an enterprise receives employee services in exchange for equity instruments of the enterprise, or liabilities that are based on the fair value of the enterprises equity instruments or that may be settled by the issuance of such equity instruments. SFAS No. 123R eliminates the ability to account for share-based compensation transactions using the intrinsic value method under Accounting Principles Board (APB) Opinion 25, Accounting for Stock Issued to Employees, and generally requires that such transactions be accounted for using a fair-value-based method. The Company is currently evaluating the provisions of SFAS No. 123R to determine which fair-value-based model and transitional provision to follow upon adoption. The alternatives for transition include either the modified prospective or the modified retrospective methods. The modified prospective method requires that compensation expense be recorded for all unvested stock options and restricted stock as the requisite service is rendered beginning with the first quarter of adoption. The modified retrospective method requires recording compensation expense for stock options and restricted stock beginning with the first period restated. Under the modified retrospective method, prior periods may be restated either as of the beginning of the year of adoption or for all periods presented. SFAS No. 123R will be effective for the Company beginning in the third quarter of 2005. The impact of adoption on the Companys consolidated financial statements is still being evaluated.
In accordance with the provisions of SFAS No. 123, Accounting for Stock-Based Compensation, the Company currently applies the provisions of APB Opinion 25 and related interpretations in accounting for its stock option plans and, accordingly, does not recognize compensation cost based on the fair value of the options granted at grant date as prescribed by SFAS 123. The Company also applies the disclosure provisions of SFAS No. 123, as amended by SFAS No. 148, Accounting for Stock-based Compensation - Transition and Disclosure as if the fair-value-based method had been applied in measuring compensation expense. The Black-Scholes option pricing model has been used to estimate the fair value of stock options issued and the assumptions in the calculations under such model include stock price variance or volatility ranging from 3.40% to 4.39%, based on weekly average variances of KPPs units prior to the Distribution and the Companys common shares after the Distribution for the ten year period preceding issuance, a risk-free rate of return ranging from 3.75% to 4.78%, based on the 30-year U.S. treasury bill rate for the ten-year expected life of the options, and an annual dividend yield ranging from 6.89% to 8.36%.
Exhibit 99.1 page 38
The following illustrates the effect on net income and basic and diluted earnings per share if the fair value based method had been applied:
|
|
Year Ended December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Reported net income |
|
$ |
24,352,000 |
|
$ |
33,083,000 |
|
$ |
47,228,000 |
|
|
|
|
|
|
|
|
|
|||
Share-based employee compensation expense determined under the fair value based method |
|
(178,000 |
) |
(85,000 |
) |
(49,000 |
) |
|||
Pro forma net income |
|
$ |
24,174,000 |
|
$ |
32,998,000 |
|
$ |
47,179,000 |
|
Earning per share: |
|
|
|
|
|
|
|
|||
Basic - as reported |
|
$ |
2.07 |
|
$ |
2.86 |
|
$ |
4.13 |
|
Basic - pro forma |
|
$ |
2.06 |
|
$ |
2.86 |
|
$ |
4.03 |
|
Diluted - as reported |
|
$ |
2.03 |
|
$ |
2.81 |
|
$ |
4.02 |
|
Diluted - pro forma |
|
$ |
2.02 |
|
$ |
2.80 |
|
$ |
3.92 |
|
Estimates
The preparation of the Companys financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Recent Accounting Pronouncements
Effective January 1, 2003, the Company adopted SFAS No. 146, Accounting for Costs Associated with Exit or Disposal Activities, which requires that all restructurings initiated after December 31, 2002 be recorded when they are incurred and can be measured at fair value. The adoption of SFAS No. 146 had no effect on the consolidated financial statements of the Company.
The Company has adopted the provisions of FASB Interpretation No. 45, Guarantors Accounting and Disclosure Requirements of Guarantees, Including Indirect Guarantees of Indebtedness to Others, an interpretation of FASB Statements No. 5, 57, and 107, and a rescission of FASB Interpretation No. 34. This interpretation elaborates on the disclosures to be made by a guarantor in its interim and annual financial statements about its obligations under guarantees issued. The interpretation also clarifies that a guarantor is required to recognize, at inception of a guarantee, a liability for the fair value of the obligation undertaken. The initial recognition and measurement provisions of the interpretation are applicable to guarantees issued or modified after December 31, 2002. The application of this interpretation had no effect on the consolidated financial statements of the Company.
In December 2003, the FASB issued Interpretation No. 46 (Revised December 2003), Consolidation of Variable Interest Entities (FIN 46R), primarily to clarify the required accounting for interests in variable interest entities (VIEs). This standard replaces FASB Interpretation No. 46, Consolidation of Variable Interest Entities, that was issued in January 2003 to address certain situations in which a company should include in its financial statements the assets, liabilities and activities of another entity. For the Company, application of FIN 46R is required for interests in certain VIEs that are commonly referred to as special-purpose entities, or SPEs, as of December 31, 2003 and for interests in all other types of VIEs as of March 31, 2004. The application of FIN 46R has not and is not expected to have a material impact on the consolidated financial statements of the Company.
The Company has adopted the provisions of SFAS No. 149, Amendment of Statement 133 on Derivative Instruments and Hedging Activities, which amends and clarifies financial accounting and reporting for derivative instruments and hedging activities. The adoption of SFAS No. 149, which was effective for derivative contracts and hedging relationships entered into or modified after June 30, 2003, had no impact on the Companys consolidated financial statements.
On July 1, 2003, the Company adopted SFAS No. 150, Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity, which requires certain financial instruments, which were previously accounted for as equity, to be classified as liabilities. The adoption of SFAS No. 150 had no effect on the consolidated financial statements of the Company.
3. PUBLIC OFFERING OF UNITS BY KPP
In March of 2003, KPP issued 3,122,500 limited partnership units in a public offering at $36.54 per unit, generating approximately $109.1 million in net proceeds. The proceeds were used to reduce bank borrowings (See Note 6). As a result of KPP issuing additional units to unrelated parties, the Companys share of net assets of KPP increased by $10.9 million. Accordingly, the Company recognized a $10.9 million gain in 2003.
In November of 2002, KPP issued 2,095,000 limited partnership units in a public offering at $33.36 per unit, generating approximately $66.7 million in net proceeds. The offering proceeds were used to reduce KPP bank borrowings for the November 2002 fertilizer pipeline acquisition (see Notes 4 and 6). As a result of KPP issuing additional units to unrelated parties, the Companys share of net assets of KPP increased by $7.5 million. Accordingly, the Company recognized a $7.5 million gain in 2002.
In May of 2002, KPP issued 1,565,000 limited partnership units in a public offering at a price of $39.60 per unit, generating approximately $59.1 million in net proceeds. A portion of the offering proceeds were used to fund KPPs September 2002 acquisition of the Australia and New Zealand terminals (see Note 4). As a result of KPP issuing additional units to unrelated parties, the Companys share of net assets of KPP increased by $8.8 million. Accordingly, the Company recognized an $8.8 million gain in 2002.
In January of 2002, KPP issued 1,250,000 limited partnership units in a public offering at $41.65 per unit, generating approximately $49.7 million in net proceeds. The proceeds were used to reduce borrowings under KPPs revolving credit agreement (see Note 6). As a result of KPP issuing additional units to unrelated parties, the Companys share of net assets of KPP increased by $8.6 million. Accordingly, the Company recognized an $8.6 million gain in 2002.
Exhibit 99.1 page 39
4. ACQUISITIONS
On December 24, 2002, KPP acquired a 400-mile petroleum products pipeline and four terminals in North Dakota and Minnesota from Tesoro Refining and Marketing Company for approximately $100 million in cash, subject to normal post-closing adjustments. The acquisition was initially funded with KPP bank debt (see Note 6). The results of operations and cash flows of the acquired business are included in the consolidated financial statements of the Company since the date of acquisition. Based on the evaluations performed, no amounts were assigned to goodwill or to other intangible assets in the purchase price allocation.
On November 1, 2002, KPP acquired an approximately 2,000-mile anhydrous ammonia pipeline system from Koch Pipeline Company, L.P. for approximately $139 million in cash. This fertilizer pipeline system originates in southern Louisiana, proceeds north through Arkansas and Missouri, and then branches east into Illinois and Indiana and north and west into Iowa and Nebraska. The acquisition was initially funded with KPP bank debt (see Note 6). The results of operations and cash flows of the acquired business are included in the consolidated financial statements of the Company since the date of acquisition. Based on the evaluations performed, no amounts were assigned to goodwill or to other intangible assets in the purchase price allocation.
On September 18, 2002, KPP acquired eight bulk liquid storage terminals in Australia and New Zealand from Burns Philp & Co. Ltd. for approximately $47 million in cash. The results of operations and cash flows of the acquired business are included in the consolidated financial statements of the Company since the date of acquisition. Based on the evaluations performed, no amounts were assigned to goodwill or to other intangible assets in the purchase price allocation.
On February 28, 2002, KPP acquired all of the liquids terminaling subsidiaries of Statia Terminals Group NV (Statia) for approximately $178 million in cash (net of acquired cash). The acquired Statia subsidiaries had approximately $107 million in outstanding debt, including $101 million of 11.75% notes due in November 2003. The cash portion of the purchase price was initially funded by KPPs revolving credit agreement and proceeds from KPPs February 2002 public debt offering (see Note 6). In April of 2002, KPP redeemed all of Statias 11.75% notes at 102.938% of the principal amount, plus accrued interest. The redemption was funded by KPPs revolving credit facility (see Note 6). Under the provisions of the 11.75% notes, the Company incurred a $3.0 million prepayment penalty, of which $2.0 million, before interest of outside non-controlling partners in KPPs net income, was recognized as loss on debt extinguishment in 2002.
The results of operations and cash flows of Statia are included in the consolidated financial statements of the Company since the date of acquisition. Based on the valuations performed, no amounts were assigned to goodwill or to other tangible assets. A summary of the allocation of the Statia purchase price, net of cash acquired, is as follows:
Current assets |
|
$ |
10,898,000 |
|
Property and equipment |
|
320,008,000 |
|
|
Other assets |
|
53,000 |
|
|
Current liabilities |
|
(39,052,000 |
) |
|
Long-term debt |
|
(107,746,000 |
) |
|
Other liabilities |
|
(5,957,000 |
) |
|
Purchase price |
|
$ |
178,204,000 |
|
Exhibit 99.1 page 40
5. PROPERTY AND EQUIPMENT
The cost of property and equipment is summarized as follows:
|
|
Estimated |
|
|
|
|
|
||
|
|
useful |
|
December 31, |
|
||||
|
|
life (years) |
|
2004 |
|
2003 |
|
||
Land |
|
|
|
$ |
84,893,000 |
|
$ |
75,912,000 |
|
Buildings |
|
25 - 35 |
|
39,077,000 |
|
36,244,000 |
|
||
Pipeline and terminaling equipment |
|
15 - 40 |
|
1,187,323,000 |
|
1,115,458,000 |
|
||
Marine equipment |
|
15 - 30 |
|
87,937,000 |
|
87,204,000 |
|
||
Furniture and fixtures |
|
5 - 15 |
|
15,390,000 |
|
11,577,000 |
|
||
Transportation equipment |
|
3 - 6 |
|
7,790,000 |
|
7,360,000 |
|
||
Construction and work-in-progress |
|
|
|
28,766,000 |
|
26,768,000 |
|
||
Total property and equipment |
|
|
|
1,451,176,000 |
|
1,360,523,000 |
|
||
Less accumulated depreciation |
|
|
|
302,564,000 |
|
247,503,000 |
|
||
Net property and equipment |
|
|
|
$ |
1,148,612,000 |
|
$ |
1,113,020,000 |
|
6. LONG-TERM DEBT
Long-term debt is summarized as follows:
|
|
December 31, |
|
||||
|
|
2004 |
|
2003 |
|
||
Revolving credit facility, due in July of 2008 |
|
$ |
14,000,000 |
|
$ |
16,500,000 |
|
Revolving credit facility of subsidiary, due in April of 2007 |
|
3,033,000 |
|
2,112,000 |
|
||
KPP $400 million revolving credit facility, due in April of 2006 |
|
95,669,000 |
|
54,169,000 |
|
||
KPP $250 million 5.875% senior unsecured notes, due in June of 2013 |
|
250,000,000 |
|
250,000,000 |
|
||
KPP $250 million 7.75% senior unsecured notes, due in February of 2012 |
|
250,000,000 |
|
250,000,000 |
|
||
KPP term loans, due in April of 2006 |
|
40,770,000 |
|
29,243,000 |
|
||
KPP Australian bank facility, due in April of 2006 |
|
35,513,000 |
|
34,284,000 |
|
||
Total long-term debt |
|
$ |
688,985,000 |
|
$ |
636,308,000 |
|
The Company has an agreement with a bank that provides for a $50 million revolving credit facility through July 1, 2008. The credit facility, which bears interest at variable rates, is secured by 4.6 million KPP limited partnership units and has a variable rate commitment fee on unused amounts. At December 31, 2004, $14.0 million was drawn on the credit facility.
The Companys product marketing subsidiary has a credit agreement with a bank that, as amended, provides for a $15 million revolving credit facility through April of 2007. The credit facility bears interest at variable rates, has a commitment fee of 0.25% per annum on unutilized amounts and contains certain financial and operational covenants. At December 31, 2004, the subsidiary was in compliance with all covenants. The credit facility, which is without recourse to the Company, is secured by essentially all of the tangible and intangible assets of the product marketing business and by 250,000 KPP limited partnership units held by a subsidiary of the Company. At December 31, 2004, $3.0 million was drawn on the facility.
In April of 2003, KPP entered into a credit agreement with a group of banks that provides for a $400 million unsecured revolving credit facility through April of 2006. The credit facility, which provides for an increase in the commitment up to an aggregate of $450 million by mutual agreement between KPP and the banks, bears interest at variable rates and has a variable commitment fee on unused amounts. The credit facility is without recourse to the Company and contains certain financial and operating covenants, including limitations on investments, sales of assets and transactions with affiliates and, absent an event of default, does not restrict distributions to the Company or to other partners. At December 31, 2004, KPP was in compliance with all covenants. Initial borrowings on the credit agreement ($324.2 million) were used to repay all amounts outstanding under KPPs $275 million credit agreement and $175 million bridge loan agreement. At December 31, 2004, $95.7 million was outstanding under the credit agreement.
On May 19, 2003, KPP issued $250 million of 5.875% senior unsecured notes due June 1, 2013. The net proceeds from the public offering, $247.6 million, were used to reduce amounts due under KPPs revolving credit agreement. Under the note indenture, interest is payable semi-annually in arrears on June 1 and December 1 of each year. The notes are redeemable, as a whole or in part, at the option of KPP, at any time, at a redemption price equal to the greater of 100% of the principal amount of the notes, or the sum of the present value of the remaining scheduled payments of principal and interest, discounted to the redemption date at the applicable U.S. Treasury rate, as defined in the indenture, plus 30 basis points. The note indenture contains certain financial and operational covenants, including certain limitations on investments, sales of assets and transactions with affiliates and, absent an event of default, such covenants do not restrict distributions to the Company or to other partners. At December 31, 2004, KPP was in compliance with all covenants.
Exhibit 99.1 page 41
In February of 2002, KPP issued $250 million of 7.75% senior unsecured notes due February 15, 2012. The net proceeds from the public offering, $248.2 million, were used to repay the KPPs revolving credit agreement and to partially fund the Statia acquisition (see Note 3). Under the note indenture, interest is payable semi-annually in arrears on February 15 and August 15 of each year. The notes, which are without recourse to the Company, are redeemable, as a whole or in part, at the option of KPP, at any time, at a redemption price equal to the greater of 100% of the principal amount of the notes, or the sum of the present value of the remaining scheduled payments of principal and interest, discounted to the redemption date at the applicable U.S. Treasury rate, as defined in the indenture, plus 30 basis points. The note indenture contains certain financial and operational covenants, including certain limitations on investments, sales of assets and transactions with affiliates and, absent an event of default, such covenants do not restrict distributions to the Company or to other partners. At December 31, 2004, KPP was in compliance with all covenants.
7. RETIREMENT PLANS
Substantially all of the Companys domestic employees are covered by a defined contribution plan, which provides for varying levels of employer matching. The Companys contributions under these plans were $1.6 million, $1.6 million and $1.2 million for 2004, 2003 and 2002, respectively.
8. SHAREHOLDERS EQUITY
The changes in the number of issued and outstanding common shares of the Company are summarized as follows:
|
|
Common Shares |
|
Balance at January 1, 2002 |
|
11,242,746 |
|
Common shares issued |
|
73,091 |
|
Balance at December 31, 2002 |
|
11,315,837 |
|
Common shares issued |
|
206,628 |
|
Balance at December 31, 2003 |
|
11,522,465 |
|
Common shares issued |
|
169,863 |
|
Balance at December 31, 2004 |
|
11,692,328 |
|
On June 27, 2001, the Board of Directors of the Company declared a distribution of one right for each of its outstanding common shares to each shareholder of record on June 27, 2001. Each right entitles the holder, upon the occurrence of certain events, to purchase from the Company one of its common shares at a purchase price of $60.00 per common share, subject to adjustment. The rights will not separate from the common shares or become exercisable until a person or group either acquires beneficial ownership of 15% or more of the Companys common shares or commences a tender or exchange offer that would result in ownership of 20% or more, whichever occurs earlier. The rights, which expire on June 27, 2011, are redeemable in whole, but not in part, at the Companys option at any time for a price of $0.01 per right. On October 28, 2004, the rights agreement was amended to generally provide that events referred to in the Valero L.P. merger agreement (see Note 1) would not cause the rights to become exercisable.
The Company has various plans for officers, directors and key employees under which stock options, deferred stock units and restricted shares may be issued.
Stock Options
The options granted under the plan generally expire ten years from date of grant. All options were granted at prices greater than or equal to the market price at the date of grant.
At December 31, 2004, options on 506,307 shares at prices ranging from $5.26 to $28.75 were outstanding, of which 137,405 were exercisable at prices ranging from $5.26 to $19.73. At December 31, 2003, options on 374,200 shares at prices ranging from $3.27 to $19.73 were outstanding, of which 195,332 were exercisable at prices ranging from $3.27 to $19.73. At December 31, 2002, options on 701,286 shares at prices ranging from $3.27 to $19.73 were outstanding, of which 412,836 were exercisable at prices ranging from $3.27 to $14.33.
Deferred Stock Unit Plans
In 2002, the Company initiated a Deferred Stock Unit Plan (the DSU Plan), pursuant to which key employees of the Company have, from time to time, been given the opportunity to defer a portion of their compensation for a specified period toward the purchase of deferred stock units (DSUs), an instrument designed to track the Companys common shares. Under the plan, DSUs are purchased at a value equal to the closing price of the Companys common shares on the day by which the employee must elect (if they so desire) to participate in the DSU Plan; which date is established by the Compensation Committee, from time to time (the Election Date). During a vesting period of one to three years following the Election Date, a participants DSUs vest only in an amount equal to the lesser of the compensation actually deferred to date or the value (based upon the then-current closing price of the Companys common shares) of the pro-rata portion (as of such date) of the number of DSUs acquired. After the expiration of the vesting period, which is typically the same length as the deferral period, the DSUs become fully vested, but may only be distributed through the issuance of a like number of shares of the Companys common shares on a pre-selected date, which is irrevocably selected by the participant on the Election Date and which is typically at or after the expiration of the vesting period and no later than ten years after the Election Date, or at the time of a change of control of the Company, if earlier. DSU accounts are unfunded by the Company. Each person that elects to participate in the DSU Plan is awarded, under the Companys Share Incentive Plan, an option to purchase a number of shares ranging from one-half to one and one-half times the number of DSUs purchased by such person at 100% of the closing price of the Companys common shares on the Election Date, which options become exercisable over a specified period after the grant, according to a schedule determined by the Compensation Committee. At December 31, 2004, 3,802 DSUs had vested under the 2002 Plan.
Exhibit 99.1 page 42
In 1996, Kaneb Services, Inc. implemented a DSU plan whereby officers, directors and key executives were permitted to defer compensation on a pretax basis to receive shares of Kaneb Services, Inc. common stock at a predetermined date after the end of the compensation deferral period. In connection with the Distribution, the Company agreed to issue DSUs equivalent in price to the Companys common shares at that time. For every three Kaneb Services, Inc. DSUs held, the Company issued one DSU, such that the intrinsic value of each holders deferred compensation account remained unchanged as a result of the Distribution. In addition, upon the payment date of any distributions on the Companys common shares, the Company agreed to credit each deferred account with the equivalent value of the distribution. Upon the scheduled payment of the deferred accounts, the Company agreed to issue one common share for each DSU relative to Company DSUs previously issued and to pay the equivalent of the accumulated deferred distributions, plus interest, to the previously deferred account holder. All other terms of the DSU plan remained unchanged. Similarly, Kaneb Services, Inc. agreed to issue to employees of the Company who hold DSUs, the number of shares of Kaneb Services, Inc. (now Xanser) common stock subject to the Kaneb Services, Inc. DSUs held by those employees. At December 31, 2004, approximately 122,000 common shares of the Company are issuable under this arrangement.
Restricted Stock
In August 2004 and September 2001, the Company issued 60,000 and 30,000, respectively, of restricted common shares to the outside Directors of the Company. All of such shares vest or become transferable in one-third increments on each anniversary date after issuance. In conjunction will the issuance and commencement of vesting of the restricted shares, the Company recognized an expense of $0.5 million in 2004, $0.1 million in 2003 and $0.2 million in 2002.
9. COMMITMENTS AND CONTINGENCIES
Total rent expense under operating leases amounted to $9.5 million, $14.6 million and $13.5 million for the years ended December 31, 2002, 2003 and 2004, respectively.
The following is a schedule by years of future minimum lease payments under the Companys, and KPPs, operating leases as of December 31, 2004:
Year ending December 31: |
|
|
|
|
2005 |
|
$ |
9,822,000 |
|
2006 |
|
8,593,000 |
|
|
2007 |
|
6,238,000 |
|
|
2008 |
|
5,338,000 |
|
|
2009 |
|
4,058,000 |
|
|
Thereafter |
|
18,140,000 |
|
|
Total minimum lease payments |
|
$ |
52,189,000 |
|
The operations of KPP are subject to federal, state and local laws and regulations in the United States and various foreign locations relating to protection of the environment. Although KPP believes its operations are in general compliance with applicable environmental regulations, risks of additional costs and liabilities are inherent in pipeline and terminal operations, and there can be no assurance that significant costs and liabilities will not be incurred by KPP. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies thereunder, and claims for damages to property or persons resulting from the operations of KPP, could result in substantial costs and liabilities to KPP. KPP has recorded an undiscounted reserve for environmental claims in the amount of $23.0 million at December 31, 2004, including $16.9 million related to acquisitions of pipelines and terminals. During 2004, 2003 and 2002, respectively, KPP incurred $6.7 million, $2.1 million and $2.4 million of costs related to such acquisition reserves and reduced the liability accordingly.
Certain subsidiaries of KPP were sued in a Texas state court in 1997 by Grace Energy Corporation (Grace), the entity from which KPP acquired ST Services in 1993. The lawsuit involves environmental response and remediation costs allegedly resulting from jet fuel leaks in the early 1970s from a pipeline. The pipeline, which connected a former Grace terminal with Otis Air Force Base in Massachusetts (the Otis pipeline or the pipeline), ceased operations in 1973 and was abandoned before 1978, when the connecting terminal was sold to an unrelated entity. Grace alleged that subsidiaries of KPP acquired the abandoned pipeline as part of the acquisition of ST Services in 1993 and assumed responsibility for environmental damages allegedly caused by the jet fuel leaks. Grace sought a ruling from the Texas court that these subsidiaries are responsible for all liabilities, including all present and future remediation expenses, associated with these leaks and that Grace has no obligation to indemnify these subsidiaries for these expenses. In the lawsuit, Grace also sought indemnification for expenses of approximately $3.5 million that it had incurred since 1996 for response and remediation required by the State of Massachusetts and for additional expenses that it expects to incur in the future. The consistent position of KPPs subsidiaries has been that they did not acquire the abandoned pipeline as part of the 1993 ST Services transaction, and therefore did not assume any responsibility for the environmental damage nor any liability to Grace for the pipeline.
At the end of the trial, the jury returned a verdict including findings that (1) Grace had breached a provision of the 1993 acquisition agreement by failing to disclose matters related to the pipeline, and (2) the pipeline was abandoned before 1978 15 years before KPPs subsidiaries acquired ST Services. On August 30, 2000, the Judge entered final judgment in the case that Grace take nothing from the subsidiaries on its claims seeking recovery of remediation costs. Although KPPs subsidiaries have not incurred any expenses in connection with the remediation, the court also ruled, in effect, that the subsidiaries would not be entitled to indemnification from Grace if any such expenses were incurred in the future. Moreover, the Judge let stand a prior summary judgment ruling that the pipeline was an asset acquired by KPPs subsidiaries as part of the 1993 ST Services transaction and that any liabilities associated with the pipeline would have become liabilities of the subsidiaries. Based on that ruling, the Massachusetts Department of Environmental Protection and Samson Hydrocarbons Company (successor to Grace Petroleum Company) wrote letters to ST Services alleging its responsibility for the remediation, and ST Services responded denying any liability in connection with this matter. The Judge also awarded attorney fees to Grace of more than $1.5 million. Both KPPs subsidiaries and Grace have appealed the trial courts final judgment to the Texas Court of Appeals in Dallas. In particular, the subsidiaries have filed an appeal of the judgment finding that the Otis pipeline and any liabilities associated with the pipeline were transferred to them as well as the award of attorney fees to Grace.
Exhibit 99.1 page 43
On April 2, 2001, Grace filed a petition in bankruptcy, which created an automatic stay of actions against Grace. This automatic stay covers the appeal of the Dallas litigation, and the Texas Court of Appeals has issued an order staying all proceedings of the appeal because of the bankruptcy. Once that stay is lifted, KPPs subsidiaries that are party to the lawsuit intend to resume vigorous prosecution of the appeal.
The Otis Air Force Base is a part of the Massachusetts Military Reservation (MMR Site), which has been declared a Superfund Site pursuant to CERCLA. The MMR Site contains a number of groundwater contamination plumes, two of which are allegedly associated with the Otis pipeline, and various other waste management areas of concern, such as landfills. The United States Department of Defense, pursuant to a Federal Facilities Agreement, has been responding to the Government remediation demand for most of the contamination problems at the MMR Site. Grace and others have also received and responded to formal inquiries from the United States Government in connection with the environmental damages allegedly resulting from the jet fuel leaks. KPPs subsidiaries voluntarily responded to an invitation from the Government to provide information indicating that they do not own the pipeline. In connection with a court-ordered mediation between Grace and KPPs subsidiaries, the Government advised the parties in April 1999 that it has identified two spill areas that it believes to be related to the pipeline that is the subject of the Grace suit. The Government at that time advised the parties that it believed it had incurred costs of approximately $34 million, and expected in the future to incur costs of approximately $55 million, for remediation of one of the spill areas. This amount was not intended to be a final accounting of costs or to include all categories of costs. The Government also advised the parties that it could not at that time allocate its costs attributable to the second spill area.
By letter dated July 26, 2001, the United States Department of Justice (DOJ) advised ST Services that the Government intends to seek reimbursement from ST Services under the Massachusetts Oil and Hazardous Material Release Prevention and Response Act and the Declaratory Judgment Act for the Governments response costs at the two spill areas discussed above. The DOJ relied in part on the Texas state court judgment, which in the DOJs view, held that ST Services was the current owner of the pipeline and the successor-in-interest of the prior owner and operator. The Government advised ST Services that it believes it has incurred costs exceeding $40 million, and expects to incur future costs exceeding an additional $22 million, for remediation of the two spill areas. KPP believes that its subsidiaries have substantial defenses. ST Services responded to the DOJ on September 6, 2001, contesting the Governments positions and declining to reimburse any response costs. The DOJ has not filed a lawsuit against ST Services seeking cost recovery for its environmental investigation and response costs. Representatives of ST Services have met with representatives of the Government on several occasions since September 6, 2001 to discuss the Governments claims and to exchange information related to such claims. Additional exchanges of information are expected to occur in the future and additional meetings may be held to discuss possible resolution of the Governments claims without litigation. KPP does not believe this matter will have a materially adverse effect on its financial condition, although there can be no assurances as to the ultimate outcome.
On April 7, 2000, a fuel oil pipeline in Maryland owned by Potomac Electric Power Company (PEPCO) ruptured. Work performed with regard to the pipeline was conducted by a partnership of which ST Services is general partner. PEPCO has reported that it has incurred total cleanup costs of $70 million to $75 million. PEPCO probably will continue to incur some cleanup related costs for the foreseeable future, primarily in connection with EPA requirements for monitoring the condition of some of the impacted areas. Since May 2000, ST Services has provisionally contributed a minority share of the cleanup expense, which has been funded by ST Services insurance carriers. ST Services and PEPCO have not, however, reached a final agreement regarding ST Services proportionate responsibility for this cleanup effort, if any, and cannot predict the amount, if any, that ultimately may be determined to be ST Services share of the remediation expense, but ST Services believes that such amount will be covered by insurance and therefore will not materially adversely affect KPPs financial condition.
As a result of the rupture, purported class actions were filed against PEPCO and ST Services in federal and state court in Maryland by property and business owners alleging damages in unspecified amounts under various theories, including under the Oil Pollution Act (OPA) and Maryland common law. The federal court consolidated all of the federal cases in a case styled as In re Swanson Creek Oil Spill Litigation. A settlement of the consolidated class action, and a companion state-court class action, was reached and approved by the federal judge. The settlement involved creation and funding by PEPCO and ST Services of a $2,250,000 class settlement fund, from which all participating claimants would be paid according to a court-approved formula, as well as a court-approved payment to plaintiffs attorneys. The settlement has been consummated and the fund, to which PEPCO and ST Services contributed equal amounts, has been distributed. Participating claimants claims have been settled and dismissed with prejudice. A number of class members elected not to participate in the settlement, i.e., to opt out, thereby preserving their claims against PEPCO and ST Services. All non-participant claims have been settled for immaterial amounts with ST Services portion of such settlements provided by its insurance carrier.
PEPCO and ST Services agreed with the federal government and the State of Maryland to pay costs of assessing natural resource damages arising from the Swanson Creek oil spill under OPA and of selecting restoration projects. This process was completed in mid-2002. ST Services insurer has paid ST Services agreed 50 percent share of these assessment costs. In late November 2002, PEPCO and ST Services entered into a Consent Decree resolving the federal and state trustees claims for natural resource damages. The decree required payments by ST Services and PEPCO of a total of approximately $3 million to fund the restoration projects and for remaining damage assessment costs. The federal court entered the Consent Decree as a final judgment on December 31, 2002. PEPCO and ST Services have each paid their 50% share and thus fully performed their payment obligations under the Consent Decree. ST Services insurance carrier funded ST Services payment.
Exhibit 99.1 page 44
The U.S. Department of Transportation (DOT) has issued a Notice of Proposed Violation to PEPCO and ST Services alleging violations over several years of pipeline safety regulations and proposing a civil penalty of $647,000 jointly against the two companies. ST Services and PEPCO have contested the DOT allegations and the proposed penalty. A hearing was held before the Office of Pipeline Safety at the DOT in late 2001. In June of 2004, the DOT issued a final order reducing the penalty to $256,250 jointly against ST Services and PEPCO and $74,000 against ST Services. On September 14, 2004, ST Services petitioned for reconsideration of the order.
By letter dated January 4, 2002, the Attorney Generals Office for the State of Maryland advised ST Services that it intended to seek penalties from ST Services in connection with the April 7, 2000 spill. The State of Maryland subsequently asserted that it would seek penalties against ST Services and PEPCO totaling up to $12 million. A settlement of this claim was reached in mid-2002 under which ST Services insurer will pay a total of slightly more than $1 million in installments over a five year period. PEPCO has also reached a settlement of these claims with the State of Maryland. Accordingly, KPP believes that this matter will not have a material adverse effect on its financial condition.
On December 13, 2002, ST Services sued PEPCO in the Superior Court, District of Columbia, seeking, among other things, a declaratory judgment as to ST Services legal obligations, if any, to reimburse PEPCO for costs of the oil spill. On December 16, 2002, PEPCO sued ST Services in the United States District Court for the District of Maryland, seeking recovery of all its costs for remediation of and response to the oil spill. Pursuant to an agreement between ST Services and PEPCO, ST Services suit was dismissed, subject to refiling. ST Services has moved to dismiss PEPCOs suit. ST Services is vigorously defending against PEPCOs claims and is pursuing its own counterclaims for return of monies ST Services has advanced to PEPCO for settlements and cleanup costs. KPP believes that any costs or damages resulting from these lawsuits will be covered by insurance and therefore will not materially adversely affect KPPs financial condition. The amounts claimed by PEPCO, if recovered, would trigger an excess insurance policy which has a $600,000 retention, but KPP does not believe that such retention, if incurred, would materially adversely affect KPPs financial condition.
In 2003, Exxon Mobil filed a lawsuit in a New Jersey state court against GATX Corporation, Kinder Morgan Liquid Terminals (Kinder Morgan), the successor in interest to GATX Terminals Corporation (GATX), and ST Services, seeking reimbursement for remediation costs associated with the Paulsboro, New Jersey terminal. The terminal was owned and operated by Exxon Mobil from the early 1950s until 1990 when purchased by GATX. ST Services purchased the terminal in 2000 from GATX. GATX was subsequently acquired by Kinder Morgan. As a condition to the sale to GATX in 1990, Exxon Mobil undertook certain remediation obligations with respect to the site. In the lawsuit, Exxon Mobil is claiming that it has complied with its remediation and contractual obligations and is entitled to reimbursement from GATX Corporation, the parent company of GATX, Kinder Morgan, and ST Services for costs in the amount of $400,000 that it claims are related to releases at the site subsequent to its sale of the terminal to GATX. It is also alleging that any remaining remediation requirements are the responsibility of GATX Corporation, Kinder Morgan, or ST Services. Kinder Morgan has alleged that it was relieved of any remediation obligations pursuant to the sale agreement between its predecessor, GATX, and ST Services. ST Services believes that, except for remediation involving immaterial amounts, GATX Corporation or Exxon Mobil are responsible for the remaining remediation of the site. Costs of completing the required remediation depend on a number of factors and cannot be determined at the current time.
A subsidiary of KPP purchased the approximately 2,000-mile ammonia pipeline system from Koch Pipeline Company, L.P. and Koch Fertilizer Storage and Terminal Company in 2002. The rates of the ammonia pipeline are subject to regulation by the Surface Transportation Board (the STB). The STB had issued an order in May 2000, prescribing maximum allowable rates KPPs predecessor could charge for transportation to certain destination points on the pipeline system. In 2003, KPP instituted a 7% general increase to pipeline rates. On August 1, 2003, CF Industries, Inc. (CFI) filed a complaint with the STB challenging these rate increases. On August 11, 2004, STB ordered KPP to pay reparations to CFI and to return CFIs rates to the levels permitted under the rate prescription. KPP has complied with the order. The STB, however, indicated in the order that it would lift the rate prescription in the event KPP could show materially changed circumstances. KPP has submitted evidence of materially changed circumstances, which specifically includes its capital investment in the pipeline. CFI has argued that KPPs acquisition costs should not be considered by the STB as a measure of KPPs investment base. The STB is expected to decide the issue within the second quarter of 2005.
Exhibit 99.1 page 45
Also, on June 16, 2003, Dyno Nobel Inc. (Dyno) filed a complaint with the STB challenging the 2003 rate increase on the basis that (i) the rate increase constitutes a violation of a contract rate, (ii) rates are discriminatory and (iii) the rates exceed permitted levels. Dyno also intervened in the CFI proceeding described above. Unlike CFI, Dynos rates are not subject to a rate prescription. As of December 31, 2004, Dyno would be entitled to approximately $2 million in rate refunds, should it be successful. KPP believes, however, that Dynos claims are without merit.
Pursuant to the Distribution, the Company entered into an agreement (the Distribution Agreement) with Xanser whereby the Company is obligated to pay Xanser amounts equal to certain expenses and tax liabilities incurred by Xanser in connection with the Distribution. In January of 2002, the Company paid Xanser $10 million in tax liabilities due in connection with the Distribution Agreement. The Distribution Agreement also requires the Company to pay Xanser an amount calculated based on any income tax liability of Xanser that, in the sole judgment of Xanser, (i) is attributable to increases in income tax from past years arising out of adjustments required by federal and state tax authorities, to the extent that such increases are properly allocable to the businesses that became part of the Company, or (ii) is attributable to the distribution of the Companys common shares and the operations of the Companys businesses prior to the distribution date. In the event of an examination of Xanser by federal or state tax authorities, Xanser will have unfettered control over the examination, administrative appeal, settlement or litigation that may be involved, notwithstanding that the Company has agreed to pay any additional tax.
The Company, primarily KPP, has other contingent liabilities resulting from litigation, claims and commitments incident to the ordinary course of business. Management believes, after consulting with counsel, that the ultimate resolution of such contingencies will not have a materially adverse effect on the financial position, results of operations or liquidity of the Company.
10. BUSINESS SEGMENT DATA
The Company conducts business through three principal operations: the Pipeline Operations, which consists primarily of the transportation of refined petroleum products and fertilizer in the Midwestern states as a common carrier; the Terminaling Operations, which provide storage for petroleum products, specialty chemicals and other liquids; and the Product Marketing Operations, which provides wholesale motor fuel marketing services throughout the Midwest and Rocky Mountain regions and, since KPPs acquisition of Statia (see Note 4), delivers bunker fuel to ships in the Caribbean and Nova Scotia, Canada and sells bulk petroleum products to various commercial interests. General corporate includes general and administrative costs, including accounting, tax, finance, legal, investor relations and employee benefit services. General corporate assets include cash and other assets not related to the segments.
The Company measures segment profit as operating income. Total assets are those assets controlled by each reportable segment. Business segment data is as follows:
|
|
Year Ended December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Business segment revenues: |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
119,803,000 |
|
$ |
119,633,000 |
|
$ |
82,698,000 |
|
Terminaling operations |
|
259,352,000 |
|
234,958,000 |
|
205,971,000 |
|
|||
Product marketing operations |
|
676,093,000 |
|
511,200,000 |
|
381,159,000 |
|
|||
|
|
$ |
1,055,248,000 |
|
$ |
865,791,000 |
|
$ |
669,828,000 |
|
Business segment profit: |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
48,853,000 |
|
$ |
51,860,000 |
|
$ |
38,623,000 |
|
Terminaling operations |
|
74,663,000 |
|
66,532,000 |
|
65,040,000 |
|
|||
Product marketing operations |
|
17,262,000 |
|
12,233,000 |
|
4,692,000 |
|
|||
General corporate |
|
(3,999,000 |
) |
(2,121,000 |
) |
(1,996,000 |
) |
|||
Operating income |
|
136,779,000 |
|
128,504,000 |
|
106,359,000 |
|
|||
Interest and other income |
|
336,000 |
|
365,000 |
|
3,664,000 |
|
|||
Interest expense |
|
(43,579,000 |
) |
(39,576,000 |
) |
(29,171,000 |
) |
|||
Loss on debt extinguishment |
|
|
|
|
|
(3,282,000 |
) |
|||
Income before gain on issuance of units by KPP, income taxes, interest of outside non-controlling partners in KPPs net income and cumulative effect of change in accounting principle |
|
$ |
93,536,000 |
|
$ |
89,293,000 |
|
$ |
77,570,000 |
|
Business segment assets: |
|
|
|
|
|
|
|
|||
Depreciation and amortization: |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
14,538,000 |
|
$ |
14,117,000 |
|
$ |
6,408,000 |
|
Terminaling operations |
|
41,232,000 |
|
38,089,000 |
|
32,368,000 |
|
|||
Product marketing operations |
|
906,000 |
|
989,000 |
|
695,000 |
|
|||
|
|
$ |
56,676,000 |
|
$ |
53,195,000 |
|
$ |
39,471,000 |
|
Capital expenditures (excluding acquisitions): |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
10,334,000 |
|
$ |
9,584,000 |
|
$ |
9,469,000 |
|
Terminaling operations |
|
29,511,000 |
|
34,572,000 |
|
20,953,000 |
|
|||
Product marketing operations |
|
2,369,000 |
|
591,000 |
|
679,000 |
|
|||
|
|
$ |
42,214,000 |
|
$ |
44,747,000 |
|
$ |
31,101,000 |
|
Exhibit 99.1 page 46
|
|
December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Total assets: |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
351,195,000 |
|
$ |
352,901,000 |
|
$ |
352,657,000 |
|
Terminaling operations |
|
917,966,000 |
|
874,185,000 |
|
844,321,000 |
|
|||
Product marketing operations |
|
83,404,000 |
|
58,161,000 |
|
41,297,000 |
|
|||
General corporate |
|
4,323,000 |
|
6,320,000 |
|
5,826,000 |
|
|||
|
|
$ |
1,356,888,000 |
|
$ |
1,291,567,000 |
|
$ |
1,244,101,000 |
|
The following geographical area data includes revenues and operating income based on location of the operating segment and net property and equipment based on physical location.
|
|
Year Ended December 31, |
|
|||||||||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||||||||
Geographical area revenues: |
|
|
|
|
|
|
|
|||||||||
United States |
|
$ |
658,814,000 |
|
$ |
535,895,000 |
|
$ |
485,322,000 |
|
||||||
United Kingdom |
|
29,540,000 |
|
26,392,000 |
|
23,937,000 |
|
|||||||||
Netherlands Antilles |
|
298,273,000 |
|
241,693,000 |
|
132,387,000 |
|
|||||||||
Canada |
|
43,671,000 |
|
41,689,000 |
|
23,207,000 |
|
|||||||||
Australia and New Zealand |
|
24,950,000 |
|
20,122,000 |
|
4,975,000 |
|
|||||||||
|
|
$ |
1,055,248,000 |
|
$ |
865,791,000 |
|
$ |
669,828,000 |
|
||||||
|
|
|
|
|
|
|
|
|||||||||
Geographical area operating income: |
|
|
|
|
|
|
|
|||||||||
United States |
|
$ |
93,954,000 |
|
$ |
87,965,000 |
|
$ |
83,544,000 |
|
||||||
United Kingdom |
|
7,704,000 |
|
8,583,000 |
|
7,318,000 |
|
|||||||||
Netherlands Antilles |
|
22,629,000 |
|
19,223,000 |
|
9,616,000 |
|
|||||||||
Canada |
|
5,248,000 |
|
6,777,000 |
|
4,398,000 |
|
|||||||||
Australia and New Zealand |
|
7,244,000 |
|
5,956,000 |
|
1,483,000 |
|
|||||||||
|
|
$ |
136,779,000 |
|
$ |
128,504,000 |
|
$ |
106,359,000 |
|
||||||
|
|
December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Geographical area net property and equipment: |
|
|
|
|
|
|
|
|||
United States |
|
$ |
718,257,000 |
|
$ |
693,345,000 |
|
$ |
690,262,000 |
|
United Kingdom |
|
63,968,000 |
|
51,392,000 |
|
46,543,000 |
|
|||
Netherlands Antilles |
|
211,382,000 |
|
217,143,000 |
|
224,810,000 |
|
|||
Canada |
|
71,374,000 |
|
74,995,000 |
|
78,789,000 |
|
|||
Australia and New Zealand |
|
83,631,000 |
|
76,145,000 |
|
51,872,000 |
|
|||
|
|
$ |
1,148,612,000 |
|
$ |
1,113,020,000 |
|
$ |
1,092,276,000 |
|
11. FAIR VALUE OF FINANCIAL INSTRUMENTS AND CONCENTRATION OF CREDIT RISK
The estimated fair value of all debt as of December 31, 2004 and 2003 was approximately $745 million and $654 million, as compared to the carrying value of $689 million and $636 million, respectively. These fair values were estimated using discounted cash flow analysis, based on the Companys current incremental borrowing rates for similar types of borrowing arrangements. These estimates are not necessarily indicative of the amounts that would be realized in a current market exchange. See Note 2 regarding derivative instruments.
The Company markets and sells its services to a broad base of customers and performs ongoing credit evaluations of its customers. The Company does not believe it has a significant concentration of credit risk at December 31, 2004. No customer constituted 10% of the Companys consolidated revenues in 2004, 2003 or 2002.
12. QUARTERLY FINANCIAL DATA (unaudited)
Quarterly operating results for 2004 and 2003 are summarized as follows:
|
|
Quarter Ended |
|
||||||||||
|
|
March 31, |
|
June 30, |
|
September 30, |
|
December 31, |
|
||||
2004: |
|
|
|
|
|
|
|
|
|
||||
Revenues |
|
$ |
233,179,000 |
|
$ |
254,202,000 |
|
$ |
272,242,000 |
|
$ |
295,625,000 |
|
Operating income |
|
$ |
32,915,000 |
|
$ |
36,534,000 |
|
$ |
34,927,000 |
|
$ |
32,403,000 |
|
Net income |
|
$ |
5,995,000 |
|
$ |
7,395,000 |
|
$ |
6,811,000 |
|
$ |
4,151,000 |
|
Earnings per share: |
|
|
|
|
|
|
|
|
|
||||
Basic |
|
$ |
0.51 |
|
$ |
0.63 |
|
$ |
0.58 |
|
$ |
0.35 |
|
Diluted |
|
$ |
0.50 |
|
$ |
0.62 |
|
$ |
0.57 |
|
$ |
0.34 |
|
2003: |
|
|
|
|
|
|
|
|
|
||||
Revenues |
|
$ |
218,469,000 |
|
$ |
218,654,000 |
|
$ |
214,592,000 |
|
$ |
214,076,000 |
|
Operating income |
|
$ |
33,724,000 |
|
$ |
32,705,000 |
|
$ |
32,251,000 |
|
$ |
29,824,000 |
|
Net income |
|
$ |
16,559,000 |
(a)(b) |
$ |
5,488,000 |
|
$ |
5,862,000 |
|
$ |
5,174,000 |
|
Earnings per share: |
|
|
|
|
|
|
|
|
|
||||
Basic |
|
$ |
1.44 |
|
$ |
0.48 |
|
$ |
0.50 |
|
$ |
0.44 |
|
Diluted |
|
$ |
1.41 |
|
$ |
0.47 |
|
$ |
0.49 |
|
$ |
0.43 |
|
Exhibit 99.1 page 47
(a) Includes cumulative effect of change in accounting principle - adoption of new accounting standard for asset retirement obligations of approximately $0.3 million.
(b) See Note 3 regarding gains on issuance of units by KPP.
Exhibit 99.1 page 48
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Partners of
Kaneb Pipe Line Partners, L.P.
We have audited the consolidated balance sheet of Kaneb Pipe Line Partners, L.P. and its subsidiaries (the Partnership) as of December 31, 2004 and 2003, and the related consolidated statements of income, partners capital and cash flows for each of the years in the three year period ended December 31, 2004. These consolidated financial statements are the responsibility of the Partnerships management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.
We conducted our audits in accordance with standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Partnership as of December 31, 2004 and 2003, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2004, in conformity with U.S. generally accepted accounting principles.
As described in Note 2, the Partnership adopted Statement of Financial Accounting Standards No. 143 Accounting for Asset Retirement Obligations in 2003.
We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the effectiveness of the Partnerships internal control over financial reporting as of December 31, 2004, based on criteria established in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO), and our report dated March 11, 2005 expressed an unqualified opinion on managements assessment of, and the effective operation of, internal control over financial reporting.
/s/ KPMG LLP |
|
|
|
Dallas, Texas |
|
March 11, 2005 |
Exhibit 99.1 page 49
KANEB PIPE LINE PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF INCOME
|
|
Year Ended December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Revenues: |
|
|
|
|
|
|
|
|||
Services |
|
$ |
379,155,000 |
|
$ |
354,591,000 |
|
$ |
288,669,000 |
|
Products |
|
269,054,000 |
|
215,823,000 |
|
97,961,000 |
|
|||
Total revenues |
|
648,209,000 |
|
570,414,000 |
|
386,630,000 |
|
|||
Costs and expenses: |
|
|
|
|
|
|
|
|||
Cost of products sold |
|
246,858,000 |
|
195,100,000 |
|
90,898,000 |
|
|||
Operating costs |
|
176,976,000 |
|
168,537,000 |
|
131,326,000 |
|
|||
Depreciation and amortization |
|
56,648,000 |
|
53,155,000 |
|
39,425,000 |
|
|||
Gain on sale of assets |
|
|
|
|
|
(609,000 |
) |
|||
General and administrative |
|
30,937,000 |
|
25,121,000 |
|
19,869,000 |
|
|||
Total costs and expenses |
|
511,419,000 |
|
441,913,000 |
|
280,909,000 |
|
|||
Operating income |
|
136,790,000 |
|
128,501,000 |
|
105,721,000 |
|
|||
Interest and other income |
|
267,000 |
|
261,000 |
|
3,570,000 |
|
|||
Interest expense |
|
(42,750,000 |
) |
(38,757,000 |
) |
(28,110,000 |
) |
|||
Loss on debt extinguishment |
|
|
|
|
|
(3,282,000 |
) |
|||
Income before minority interest, income taxes and cumulative effect of change in accounting principle |
|
94,307,000 |
|
90,005,000 |
|
77,899,000 |
|
|||
|
|
|
|
|
|
|
|
|||
Minority interest in net income |
|
(910,000 |
) |
(848,000 |
) |
(738,000 |
) |
|||
|
|
|
|
|
|
|
|
|||
Income tax expense |
|
(3,282,000 |
) |
(5,223,000 |
) |
(4,083,000 |
) |
|||
Income before cumulative effect of change in accounting principle |
|
90,115,000 |
|
83,934,000 |
|
73,078,000 |
|
|||
|
|
|
|
|
|
|
|
|||
Cumulative effect of change in accounting principle - adoption of new accounting standard for asset retirement obligations |
|
|
|
(1,577,000 |
) |
|
|
|||
Net income |
|
90,115,000 |
|
82,357,000 |
|
73,078,000 |
|
|||
|
|
|
|
|
|
|
|
|||
General partners interest in net income |
|
(9,718,000 |
) |
(8,426,000 |
) |
(5,638,000 |
) |
|||
|
|
|
|
|
|
|
|
|||
Limited partners interest in net income |
|
$ |
80,397,000 |
|
$ |
73,931,000 |
|
$ |
67,440,000 |
|
Allocation of net income per unit: |
|
|
|
|
|
|
|
|||
Before cumulative effect of change in accounting principle |
|
$ |
2.84 |
|
$ |
2.74 |
|
$ |
2.96 |
|
Cumulative effect of change in accounting principle |
|
|
|
(.06 |
) |
|
|
|||
|
|
$ |
2.84 |
|
$ |
2.68 |
|
$ |
2.96 |
|
Weighted average number of limited Partnership units outstanding |
|
28,322,000 |
|
27,633,000 |
|
22,763,000 |
|
See notes to consolidated financial statements.
Exhibit 99.1 page 50
KANEB PIPE LINE PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
|
|
December 31, |
|
||||
|
|
2004 |
|
2003 |
|
||
ASSETS |
|
|
|
|
|
||
Current assets: |
|
|
|
|
|
||
Cash and cash equivalents |
|
$ |
34,336,000 |
|
$ |
38,626,000 |
|
Accounts receivable (net of allowance for doubtful accounts of $1,283,000 in 2004 and $1,693,000 in 2003) |
|
71,035,000 |
|
51,864,000 |
|
||
Inventories |
|
15,519,000 |
|
9,324,000 |
|
||
Prepaid expenses and other |
|
12,371,000 |
|
9,205,000 |
|
||
Total current assets |
|
133,261,000 |
|
109,019,000 |
|
||
Property and equipment |
|
1,450,972,000 |
|
1,360,319,000 |
|
||
Less accumulated depreciation |
|
302,381,000 |
|
247,349,000 |
|
||
Net property and equipment |
|
1,148,591,000 |
|
1,112,970,000 |
|
||
|
|
|
|
|
|
||
Investment in affiliates |
|
25,939,000 |
|
25,456,000 |
|
||
|
|
|
|
|
|
||
Excess of cost over fair value of net assets of acquired business and other assets |
|
17,525,000 |
|
17,237,000 |
|
||
|
|
$ |
1,325,316,000 |
|
$ |
1,264,682,000 |
|
|
|
|
|
|
|
||
LIABILITIES AND PARTNERS CAPITAL |
|
|
|
|
|
||
|
|
|
|
|
|
||
Current liabilities: |
|
|
|
|
|
||
Accounts payable |
|
$ |
44,071,000 |
|
$ |
27,941,000 |
|
Accrued expenses |
|
28,894,000 |
|
31,642,000 |
|
||
Accrued distributions payable |
|
26,960,000 |
|
26,344,000 |
|
||
Accrued interest payable |
|
9,365,000 |
|
9,297,000 |
|
||
Accrued taxes, other than income taxes |
|
4,828,000 |
|
4,031,000 |
|
||
Deferred terminaling fees |
|
8,851,000 |
|
7,061,000 |
|
||
Payable to general partner |
|
4,528,000 |
|
3,630,000 |
|
||
Total current liabilities |
|
127,497,000 |
|
109,946,000 |
|
||
|
|
|
|
|
|
||
Long-term debt |
|
671,952,000 |
|
617,696,000 |
|
||
|
|
|
|
|
|
||
Other liabilities and deferred taxes |
|
44,386,000 |
|
43,451,000 |
|
||
|
|
|
|
|
|
||
Minority interest |
|
984,000 |
|
1,018,000 |
|
||
|
|
|
|
|
|
||
Commitments and contingencies |
|
|
|
|
|
||
|
|
|
|
|
|
||
Partners capital: |
|
|
|
|
|
||
Limited partners |
|
463,441,000 |
|
479,427,000 |
|
||
General partner |
|
822,000 |
|
896,000 |
|
||
Accumulated other comprehensive income |
|
16,234,000 |
|
12,248,000 |
|
||
Total partners capital |
|
480,497,000 |
|
492,571,000 |
|
||
|
|
$ |
1,325,316,000 |
|
$ |
1,264,682,000 |
|
See notes to consolidated financial statements.
Exhibit 99.1 page 51
KANEB PIPE LINE PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
|
|
Year Ended December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Operating activities: |
|
|
|
|
|
|
|
|||
Net income |
|
$ |
90,115,000 |
|
$ |
82,357,000 |
|
$ |
73,078,000 |
|
Adjustments to reconcile net income to net cash provided by operating activities: |
|
|
|
|
|
|
|
|||
Depreciation and amortization |
|
56,648,000 |
|
53,155,000 |
|
39,425,000 |
|
|||
Minority interest in net income |
|
910,000 |
|
848,000 |
|
738,000 |
|
|||
Equity in earnings of affiliates, net of distributions |
|
(483,000 |
) |
148,000 |
|
(3,164,000 |
) |
|||
Gain on sale of assets |
|
|
|
|
|
(609,000 |
) |
|||
Deferred income taxes |
|
(671,000 |
) |
1,683,000 |
|
3,105,000 |
|
|||
Cumulative effect of change in accounting principle |
|
|
|
1,577,000 |
|
|
|
|||
Other liabilities |
|
(1,666,000 |
) |
1,190,000 |
|
(1,341,000 |
) |
|||
Changes in working capital components: |
|
|
|
|
|
|
|
|||
Accounts receivable |
|
(19,171,000 |
) |
(2,938,000 |
) |
(12,379,000 |
) |
|||
Inventories, prepaid expenses and other |
|
(9,361,000 |
) |
(5,109,000 |
) |
(6,601,000 |
) |
|||
Accounts payable and accrued expenses |
|
15,112,000 |
|
10,829,000 |
|
(1,192,000 |
) |
|||
Payable to general partner |
|
898,000 |
|
(1,773,000 |
) |
702,000 |
|
|||
Net cash provided by operating activities |
|
132,331,000 |
|
141,967,000 |
|
91,762,000 |
|
|||
Investing activities: |
|
|
|
|
|
|
|
|||
Acquisitions, net of cash acquired |
|
(41,853,000 |
) |
(1,644,000 |
) |
(468,477,000 |
) |
|||
Capital expenditures |
|
(42,214,000 |
) |
(44,741,000 |
) |
(31,101,000 |
) |
|||
Proceeds from sale of assets |
|
|
|
|
|
1,107,000 |
|
|||
Other, net |
|
1,327,000 |
|
(1,109,000 |
) |
306,000 |
|
|||
Net cash used in investing activities |
|
(82,740,000 |
) |
(47,494,000 |
) |
(498,165,000 |
) |
|||
Financing activities: |
|
|
|
|
|
|
|
|||
Issuance of debt |
|
51,080,000 |
|
291,377,000 |
|
746,087,000 |
|
|||
Payments of debt |
|
|
|
(382,831,000 |
) |
(426,647,000 |
) |
|||
Distributions, including minority interest |
|
(106,598,000 |
) |
(98,243,000 |
) |
(74,439,000 |
) |
|||
Net proceeds from issuance of limited partnership units |
|
|
|
109,056,000 |
|
175,527,000 |
|
|||
Net cash provided by (used in) financing activities |
|
(55,518,000 |
) |
(80,641,000 |
) |
420,528,000 |
|
|||
Effect of exchange rate changes on cash |
|
1,637,000 |
|
2,766,000 |
|
|
|
|||
Increase (decrease) in cash and cash equivalents |
|
(4,290,000 |
) |
16,598,000 |
|
14,125,000 |
|
|||
Cash and cash equivalents at beginning of period |
|
38,626,000 |
|
22,028,000 |
|
7,903,000 |
|
|||
Cash and cash equivalents at end of period |
|
$ |
34,336,000 |
|
$ |
38,626,000 |
|
$ |
22,028,000 |
|
|
|
|
|
|
|
|
|
|||
Supplemental cash flow information - cash paid for interest |
|
$ |
41,321,000 |
|
$ |
34,818,000 |
|
$ |
25,942,000 |
|
See notes to consolidated financial statements.
Exhibit 99.1 page 52
KANEB PIPE LINE PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF PARTNERS CAPITAL
|
|
|
|
|
|
Accumulated |
|
|
|
|
|
|||||
|
|
|
|
|
|
Other |
|
|
|
|
|
|||||
|
|
Limited |
|
General |
|
Comprehensive |
|
|
|
Comprehensive |
|
|||||
|
|
Partners |
|
Partner (a) |
|
Income |
|
Total |
|
Income |
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||
Partners capital at January 1, 2002 |
|
$ |
220,336,000 |
|
$ |
1,027,000 |
|
$ |
(1,846,000 |
) |
$ |
219,517,000 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||||
2002 income allocation |
|
67,440,000 |
|
5,638,000 |
|
|
|
73,078,000 |
|
$ |
73,078,000 |
|
||||
Distributions declared |
|
(73,415,000 |
) |
(5,649,000 |
) |
|
|
(79,064,000 |
) |
|
|
|||||
Issuance of units, net of offering costs |
|
175,527,000 |
|
|
|
|
|
175,527,000 |
|
|
|
|||||
Foreign currency translation adjustment |
|
|
|
|
|
3,226,000 |
|
3,226,000 |
|
3,226,000 |
|
|||||
Comprehensive income for the year |
|
|
|
|
|
|
|
|
|
$ |
76,304,000 |
|
||||
Partners capital at December 31, 2002 |
|
389,888,000 |
|
1,016,000 |
|
1,380,000 |
|
392,284,000 |
|
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||
2003 income allocation |
|
73,931,000 |
|
8,426,000 |
|
|
|
82,357,000 |
|
$ |
82,357,000 |
|
||||
Distributions declared |
|
(93,448,000 |
) |
(8,546,000 |
) |
|
|
(101,994,000 |
) |
|
|
|||||
Issuance of units, net of offering costs |
|
109,056,000 |
|
|
|
|
|
109,056,000 |
|
|
|
|||||
Foreign currency translation adjustment |
|
|
|
|
|
12,535,000 |
|
12,535,000 |
|
12,535,000 |
|
|||||
Interest rate hedging transaction |
|
|
|
|
|
(1,667,000 |
) |
(1,667,000 |
) |
(1,667,000 |
) |
|||||
Comprehensive income for the year |
|
|
|
|
|
|
|
|
|
$ |
93,225,000 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||
Partners capital at December 31, 2003 |
|
479,427,000 |
|
896,000 |
|
12,248,000 |
|
492,571,000 |
|
|
|
|||||
|
|
|
|
|
|
|
|
|
|
|
|
|||||
2004 income allocation |
|
80,397,000 |
|
9,718,000 |
|
|
|
90,115,000 |
|
$ |
90,115,000 |
|
||||
Distributions declared |
|
(96,438,000 |
) |
(9,792,000 |
) |
|
|
(106,230,000 |
) |
|
|
|||||
Foreign currency translation adjustment |
|
|
|
|
|
3,808,000 |
|
3,808,000 |
|
3,808,000 |
|
|||||
Interest rate hedging transaction |
|
|
|
|
|
178,000 |
|
178,000 |
|
178,000 |
|
|||||
Amortization of restricted limited partnership units |
|
55,000 |
|
|
|
|
|
55,000 |
|
|
|
|||||
Comprehensive income for the year |
|
|
|
|
|
|
|
|
|
$ |
94,101,000 |
|
||||
Partners capital at December 31, 2004 |
|
$ |
463,441,000 |
|
$ |
822,000 |
|
$ |
16,234,000 |
|
$ |
480,497,000 |
|
|
|
|
Limited partnership units outstanding at January 1, 2002 |
|
20,285,090 |
|
|
|
|
|
20,285,090 |
|
|
|
|||||
Units issued in 2002 |
|
4,910,000 |
|
|
|
|
|
4,910,000 |
|
|
|
|||||
Limited Partnership units outstanding at December 31, 2002 |
|
25,195,090 |
|
|
|
|
|
25,195,090 |
|
|
|
|||||
Units issued in 2003 |
|
3,122,500 |
|
|
|
|
|
3,122,500 |
|
|
|
|||||
Limited partnership units outstanding at December 31, 2003 |
|
28,317,590 |
|
|
|
|
|
28,317,590 |
|
|
|
|||||
Units issued in 2004 |
|
10,000 |
|
|
|
|
|
10,000 |
|
|
|
|||||
Limited partnership units outstanding at December 31, 2004 |
|
28,327,590 |
|
|
|
|
|
28,327,590 |
|
|
|
(a) KPL owns a combined 2% interest in the Partnership as general partner.
See notes to consolidated financial statements.
Exhibit 99.1 page 53
KANEB PIPE LINE PARTNERS, L.P.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. PARTNERSHIP ORGANIZATION
General
Kaneb Pipe Line Partners, L.P. (the Partnership), a master limited partnership, owns and operates a refined petroleum products and fertilizer pipeline business, a petroleum products and specialty liquids storage and terminaling business and a petroleum product sales operation. Kaneb Pipe Line Company LLC (KPL), a wholly owned subsidiary of Kaneb Services LLC (KSL), manages and controls the Partnership through its general partners interest and a 18% (at December 31, 2004) limited partner interest. The Partnership operates through Kaneb Pipe Line Operating Partnership, L.P. (KPOP), a limited partnership in which the Partnership holds a 99% interest as limited partner. KPL owns a 1% interest as general partner of the Partnership and a 1% interest as general partner of KPOP. KPLs 1% interest in KPOP is reflected as the minority interest in the financial statements.
Valero L.P. Merger Agreement
On October 31, 2004, Valero L.P. and the Partnership entered into a definitive agreement to merge (the KPP Merger)Valero L.P. and the Partnership. Under the terms of the agreement, each holder of units of limited partnership interests in the Partnership will receive a number of Valero L.P. common units based on an exchange ratio that fluctuates within a fixed range to provide $61.50 in value of Valero L.P. units for each unit of the Partnership. The actual exchange ratio will be determined at the time of the closing of the proposed merger and is subject to a fixed value collar of plus or minus five percent of Valero L.P.s per unit price of $57.25 as of October 7, 2004. Should Valero L.P.s per unit price fall below $54.39 per unit, the exchange ratio will remain fixed at 1.1307 Valero L.P. units for each unit of the Partnership. Likewise, should Valero L.P.s per unit price exceed $60.11 per unit of the Partnership, the exchange ratio will remain fixed at 1.0231 Valero L.P. units for each unit of the Partnership.
In a separate definitive agreement, on October 31, 2004, Valero L.P. agreed to acquire by merger (the KSL Merger) all of the outstanding common shares of KSL for cash. Under the terms of that agreement, Valero L.P. is offering to purchase all of the outstanding shares of KSL at $43.31 per share.
The completion of the KPP Merger is subject to the customary regulatory approvals including those under the Hart-Scott-Rodino Antitrust Improvements Act. The completion of the KPP Merger is also subject to completion of the KSL Merger. All required unitholder and shareholder approvals have been obtained. Upon completion of the mergers, the general partner of the combined partnership will be owned by affiliates of Valero Energy Corporation and the Partnership and KSL will become wholly owned subsidiaries of Valero L.P.
Issuance of Limited Partnership Units
In March of 2003, the Partnership issued 3,122,500 limited Partnership units in a public offering at $36.54 per unit, generating approximately $109.1 million in net proceeds. The proceeds were used to reduce bank borrowings (See Note 5).
In November of 2002, the Partnership issued 2,095,000 limited Partnership units in a public offering at $33.36 per unit, generating approximately $66.7 million in net proceeds. The offering proceeds were used to reduce bank borrowings for the November 2002 fertilizer pipeline acquisition (see Notes 3 and 5).
In May of 2002, the Partnership issued 1,565,000 limited Partnership units in a public offering at a price of $39.60 per unit, generating approximately $59.1 million in net proceeds. A portion of the offering proceeds were used to fund its September 2002 acquisition of the Australia and New Zealand terminals (see Note 3).
In January of 2002, the Partnership issued 1,250,000 limited Partnership units in a public offering at $41.65 per unit, generating approximately $49.7 million in net proceeds. The proceeds were used to reduce borrowings under the Partnerships revolving credit agreement (see Note 5).
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
The following significant accounting policies are followed by the Partnership in the preparation of the consolidated financial statements.
Cash and Cash Equivalents
The Partnerships policy is to invest cash in highly liquid investments with original maturities of three months or less. Accordingly, uninvested cash balances are kept at minimum levels. Such investments are valued at cost, which approximates market, and are classified as cash equivalents.
Exhibit 99.1 page 54
Inventories
Inventories consist primarily of petroleum products purchased for resale in the product sales operations and are valued at the lower of cost or market. Cost is determined by using the weighted-average cost method.
Property and Equipment
Property and equipment are carried at historical cost. Additions of new equipment and major renewals and replacements of existing equipment are capitalized. Repairs and minor replacements that do not materially increase values or extend useful lives are expensed. Depreciation of property and equipment is provided on a straight-line basis at rates based upon expected useful lives of various classes of assets, as disclosed in Note 4. The rates used for pipeline and storage facilities are the same as those which have been promulgated by the Federal Energy Regulatory Commission. Upon disposal of assets depreciated on an individual basis, the gains and losses are included in current operating income. Upon disposal of assets depreciated on a group basis, unless unusual in nature or amount, residual cost, less salvage, is charged against accumulated depreciation.
Effective January 1, 2002, the Partnership adopted Statement of Financial Accounting Standards (SFAS) No. 144, Accounting for the Impairment or Disposal of Long-Lived Assets, which addresses financial accounting and reporting for the impairment or disposal of long-lived assets. The adoption of SFAS No. 144 did not have a material impact on the consolidated financial statements of the Partnership. Under SFAS No. 144, the carrying value of property and equipment is periodically evaluated using undiscounted future cash flows as the basis for determining if impairment exists. To the extent impairment is indicated to exist, an impairment loss will be recognized based on fair value.
Revenue and Income Recognition
The pipeline business provides pipeline transportation of refined petroleum products, liquified petroleum gases, and anhydrous ammonia fertilizer. Pipeline revenues are recognized as services are provided. The Partnerships terminaling services business provides terminaling and other ancillary services. Storage fees are generally billed one month in advance and are reported as deferred income. Terminaling revenues are recognized in the month services are provided. Revenues for the product sales business are recognized when product is sold and title and risk pass to the customer.
Foreign Currency Translation
The Partnership translates the balance sheet of its foreign subsidiaries using year-end exchange rates and translates income statement amounts using the average exchange rates in effect during the year. The gains and losses resulting from the change in exchange rates from year to year have been reported separately as a component of accumulated other comprehensive income (loss) in Partners Capital. Gains and losses resulting from foreign currency transactions are included in the consolidated statements of income. The local currency is considered to be the functional currency, except in the Netherland Antilles and Canada, where the U.S. dollar is the functional currency.
Excess of Cost Over Fair Value of Net Assets of Acquired Business
Effective January 1, 2002, the Partnership adopted SFAS No. 142, Goodwill and Other Intangible Assets, which eliminates the amortization of goodwill (excess of cost over fair value of net assets of acquired business) and other intangible assets with indefinite lives. Under SFAS No. 142, intangible assets with lives restricted by contractual, legal, or other means will continue to be amortized over their useful lives. At December 31, 2004, the Partnership had no intangible assets subject to amortization under SFAS No. 142. Goodwill and other intangible assets not subject to amortization are tested for impairment annually or more frequently if events or changes in circumstances indicate that the assets might be impaired. SFAS No. 142 requires a two-step process for testing impairment. First, the fair value of each reporting unit is compared to its carrying value to determine whether an indication of impairment exists. If an impairment is indicated, then the fair value of the reporting units goodwill is determined by allocating the units fair value to its assets and liabilities (including any unrecognized intangible assets) as if the reporting unit had been acquired in a business combination. The amount of impairment for goodwill is measured as the excess of its carrying value over its fair value. Based on valuations and analysis performed by the Partnership at initial adoption date and at each annual evaluation date, including December 31, 2004, the Partnership determined that the implied fair value of its goodwill exceeded carrying value and, therefore, no impairment charge was necessary.
Environmental Matters
Environmental expenditures that relate to current operations are expensed or capitalized, as appropriate. Expenditures that relate to an existing condition caused by past operations, and which do not contribute to current or future revenue generation, are expensed. Liabilities are recorded when environmental assessments and/or remedial efforts are probable, and the costs can be reasonably estimated. Generally, the timing of these accruals coincides with the completion of a feasibility study or the Partnerships commitment to a formal plan of action.
Asset Retirement Obligations
Effective January 1, 2003, the Partnership adopted SFAS No. 143 Accounting for Asset Retirement Obligations, which establishes requirements for the removal-type costs associated with asset retirements. At the initial adoption date of SFAS No. 143, the Partnership recorded an asset retirement obligation of approximately $5.5 million and recognized a cumulative effect of change in accounting principle of $1.6 million for its legal obligations to dismantle, dispose of, and restore certain leased pipeline and terminaling facilities, including petroleum and chemical storage tanks, terminaling facilities and barges. The Partnership did not record a retirement obligation for certain of its pipeline and terminaling assets because sufficient information is presently not available to estimate a range of potential settlement dates for the obligation. In these cases, the obligation will be initially recognized in the period in which sufficient information exists to estimate the obligation. At December 31, 2004, the Partnership had no assets which were legally restricted for purposes of settling asset retirement obligations. The effect of SFAS No. 143, assuming adoption on January 1, 2002, was not material to the results of operations of the Partnership for the years ended December 31, 2004, 2003 and 2002. For the years ended December 31, 2004 and 2003, accretion expense of $0.2 million and $0.4 million, respectively, was included in operating costs.
Exhibit 99.1 page 55
Comprehensive Income
The Partnership follows the provisions of SFAS No. 130, Reporting Comprehensive Income, for the reporting and display of comprehensive income and its components in a full set of general purpose financial statements. SFAS No. 130 requires additional disclosure and does not affect the Partnerships financial position or results of operations.
Income Taxes
Income (loss) before income tax expense and extraordinary items, is made up of the following components:
|
|
Year Ended December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
|
|
|
|
|
|
|
|
|||
Partnership operations |
|
$ |
75,007,000 |
|
$ |
70,256,000 |
|
$ |
70,876,000 |
|
Corporate operations: |
|
|
|
|
|
|
|
|||
Domestic |
|
(4,888,000 |
) |
(3,055,000 |
) |
2,046,000 |
|
|||
Foreign |
|
23,278,000 |
|
21,956,000 |
|
4,239,000 |
|
|||
|
|
$ |
93,397,000 |
|
$ |
89,157,000 |
|
$ |
77,161,000 |
|
Partnership operations are not subject to federal or state income taxes. However, certain operations of terminaling operations are conducted through wholly-owned corporate subsidiaries which are taxable entities. The provision for income taxes for the periods ended December 31, 2004, 2003 and 2002 primarily consists of U.S. and foreign income taxes of $3.3 million, $5.2 million and $4.1 million, respectively. The net deferred tax liability of $21.5 million, $20.6 million and $17.8 million at December 31, 2004, 2003 and 2002, respectively, consists of deferred tax liabilities of $35.1 million, $48.8 million and $41.7 million, respectively, and deferred tax assets of $13.6 million, $28.2 million and $23.9 million, respectively. The deferred tax liabilities consist primarily of tax depreciation in excess of book depreciation. The deferred tax assets consist primarily of net operating loss carryforwards.The U.S.corporate operations have net operating loss carryforwards for tax purposes totaling approximately $42.8 million, which are subject to various limitations on use and expire in years 2008 through 2023.
On June 1, 1989, the governments of the Netherlands Antilles and St. Eustatius approved a Free Zone and Profit Tax Agreement retroactive to January 1, 1989, which expired on December 31, 2000. This agreement required a subsidiary of the Partnership, which was acquired with Statia on February 28, 2002 (see Note 3), to pay a 2% rate on taxable income, as defined therein, or a minimum payment of 500,000 Netherlands Antilles guilders ($0.3 million) per year. The agreement further provided that any amounts paid in order to meet the minimum annual payment were available to offset future tax liabilities under the agreement to the extent that the minimum annual payment is greater than 2% of taxable income. The subsidiary is currently engaged in discussions with representatives appointed by the Island Territory of St. Eustatius regarding the renewal or modification of the agreement, but the ultimate outcome cannot be predicted at this time. The subsidiary has accrued amounts assuming a new agreement becomes effective, and continues to make payments, as required, under the previous agreement.
Since the income or loss of the operations which are conducted through limited partnerships will be included in the tax returns of the individual partners of the Partnership, no provision for income taxes has been recorded in the accompanying financial statements on these earnings. The tax returns of the Partnership are subject to examination by federal and state taxing authorities. If any such examination results in adjustments to distributive shares of taxable income or loss, the tax liability of the partners would be adjusted accordingly.
The tax attributes of the Partnerships net assets flow directly to each individual partner. Individual partners will have different investment bases depending upon the timing and prices of acquisition of Partnership units. Further, each partners tax accounting, which is partially dependent upon their individual tax position, may differ from the accounting followed in the financial statements. Accordingly, there could be significant differences between each individual partners tax basis and their proportionate share of the net assets reported in the financial statements. SFAS No. 109, Accounting for Income Taxes, requires disclosure of the aggregate difference in the basis of its net assets for financial and tax reporting purposes. Management of the Partnership does not believe that, in the Partnerships circumstances, the aggregate difference would be meaningful information.
Cash Distributions
The Partnership makes quarterly distributions of 100% of its available cash, as defined in the Partnership agreement, to holders of limited partnership units and KPL. Available cash consists generally of all the cash receipts of the Partnership, plus the beginning cash balance, less all of its cash disbursements and reserves. The Partnership expects to make distributions of all available cash within 45 days after the end of each quarter to unitholders of record on the applicable record date. Distributions of $3.405, $3.30 and $3.16 per unit were declared and paid to unitholders with respect to the years ended December 31, 2004, 2003 and 2002, respectively.
Exhibit 99.1 page 56
Allocation of Net Income and Earnings
Net income or loss is allocated between limited partner interests and the general partner pro rata based on the aggregate amount of cash distributions declared (including general partner incentive distributions). Beginning in 1997, distributions by the Partnership of its available cash reached the Second Target Distribution, as defined in the Partnership agreement, which entitled the general partner to certain incentive distributions at different levels of cash distributions. Earnings per unit shown on the consolidated statements of income are calculated by dividing the amount of limited partners interest in net income, by the weighted average number of units outstanding.
Derivative Instruments
The Partnership follows the provisions of SFAS No. 133, Accounting for Derivative Instruments and Hedging Activities, which establishes the accounting and reporting standards for such activities. Under SFAS No. 133, companies must recognize all derivative instruments on their balance sheet at fair value. Changes in the value of derivative instruments, which are considered hedges, are offset against the change in fair value of the hedged item through earnings, or recognized in other comprehensive income until the hedged item is recognized in earnings, depending on the nature of the hedge. SFAS No. 133 requires that unrealized gains and losses on derivatives not qualifying for hedge accounting be recognized currently in earnings.
On May 19, 2003, KPOP issued $250 million of 5.875% senior unsecured notes due June 1, 2013 (see Note 5.) In connection with the offering, on May 8, 2003, KPOP entered into a treasury lock contract for the purpose of locking in the US Treasury interest rate component on $100 million of the debt. The treasury lock contract, which qualified as a cash flow hedging instrument under SFAS No. 133, was settled on May 19, 2003 with a cash payment by KPOP of $1.8 million. The settlement cost of the contract has been recorded as a component of accumulated other comprehensive income and is being amortized, as interest expense, over the life of the debt. For the years ended December 31, 2004 and 2003, $0.2 million and $0.1 million, respectively, of amortization is included in interest expense.
In September of 2002, KPOP entered into a treasury lock contract, maturing on November 4, 2002, for the purpose of locking in the US Treasury interest rate component on $150 million of anticipated thirty-year public debt offerings. The treasury lock contract originally qualified as a cash flow hedging instrument under SFAS No. 133. In October of 2002, KPOP, due to various market factors, elected to defer issuance of the public debt securities, effectively eliminating the cash flow hedging designation for the treasury lock contract. On October 29, 2002, the contract was settled resulting in a net realized gain of $3.0 million, which was recognized as a component of interest and other income. Estimates
The preparation of the Partnerships financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Recent Accounting Pronouncements
Effective January 1, 2003, the Partnership adopted SFAS No. 146, Accounting for Costs Associated with Exit or Disposal Activities, which requires that all restructurings initiated after December 31, 2002 be recorded when they are incurred and can be measured at fair value. The adoption of SFAS No. 146 had no effect on the consolidated financial statements of the Partnership.
The Partnership has adopted the provisions of FASB Interpretation No. 45, Guarantors Accounting and Disclosure Requirements of Guarantees, Including Indirect Guarantees of Indebtedness to Others, an interpretation of FASB Statements No. 5, 57, and 107, and a rescission of FASB Interpretation No. 34. This interpretation elaborates on the disclosures to be made by a guarantor in its interim and annual financial statements about its obligations under guarantees issued. The interpretation also clarifies that a guarantor is required to recognize, at inception of a guarantee, a liability for the fair value of the obligation undertaken. The initial recognition and measurement provisions of the interpretation are applicable to guarantees issued or modified after December 31, 2002. The application of this interpretation had no effect on the consolidated financial statements of the Partnership.
In December 2003, the FASB issued Interpretation No. 46 (Revised December 2003), Consolidation of Variable Interest Entities (FIN 46R), primarily to clarify the required accounting for interests in variable interest entities (VIEs). This standard replaces FASB Interpretation No. 46, Consolidation of Variable Interest Entities, that was issued in January 2003 to address certain situations in which a company should include in its financial statements the assets, liabilities and activities of another entity. For the Partnership, application of FIN 46R is required for interests in certain VIEs that are commonly referred to as special-purpose entities, or SPEs, as of December 31, 2003 and for interests in all other types of VIEs as of March 31, 2004. The application of FIN 46R did not have a material impact on the consolidated financial statements of the Partnership.
Exhibit 99.1 page 57
The Partnership has adopted the provisions of SFAS No. 149, Amendment of Statement 133 on Derivative Instruments and Hedging Activities, which amends and clarifies financial accounting and reporting for derivative instruments and hedging activities. The adoption of SFAS No. 149, which was effective for derivative contracts and hedging relationships entered into or modified after June 30, 2003, had no impact on the Partnerships consolidated financial statements.
On July 1, 2003, the Partnership adopted SFAS No. 150, Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity, which requires certain financial instruments, which were previously accounted for as equity, to be classified as liabilities. The adoption of SFAS No. 150 had no effect on the consolidated financial statements of the Partnership.
3. ACQUISITIONS
On December 24, 2002, the Partnership acquired a 400-mile petroleum products pipeline and four terminals in North Dakota and Minnesota from Tesoro Refining and Marketing Company for approximately $100 million in cash, subject to normal post-closing adjustments. The acquisition was initially funded with bank debt (see Note 5). Based on the evaluations performed, no amounts were assigned to goodwill or to other intangible assets in the purchase price allocation.
On November 1, 2002, the Partnership acquired an approximately 2,000-mile anhydrous ammonia pipeline system from Koch Pipeline Company, L.P. for approximately $139 million in cash. This fertilizer pipeline system originates in southern Louisiana, proceeds north through Arkansas and Missouri, and then branches east into Illinois and Indiana and north and west into Iowa and Nebraska. The acquisition was initially funded with bank debt (see Note 5). The results of operations and cash flows of the acquired business are included in the consolidated financial statements of the Partnership since the date of acquisition. Based on the evaluations performed, no amounts were assigned to goodwill or to other intangible assets in the purchase price allocation.
On September 18, 2002, the Partnership acquired eight bulk liquid storage terminals in Australia and New Zealand from Burns Philp & Co. Ltd. for approximately $47 million in cash. The results of operations and cash flows of the acquired business are included in the consolidated financial statements of the Partnership since the date of acquisition. Based on the evaluations performed, no amounts were assigned to goodwill or to other intangible assets in the purchase price allocation.
On February 28, 2002, the Partnership acquired all of the liquids terminaling subsidiaries of Statia Terminals Group NV (Statia) for approximately $178 million in cash (net of acquired cash). The acquired Statia subsidiaries had approximately $107 million in outstanding debt, including $101 million of 11.75% notes due in November 2003. The cash portion of the purchase price was initially funded by the Partnerships revolving credit agreement and proceeds from KPOPs February 2002 public debt offering (see Note 5). In April of 2002, the Partnership redeemed all of Statias 11.75% notes at 102.938% of the principal amount, plus accrued interest. The redemption was funded by the Partnerships revolving credit facility (see Note 5). Under the provisions of the 11.75% notes, the Partnership incurred a $3.0 million prepayment penalty, of which $2.0 million was recognized as loss on debt extinguishment in 2002.
The results of operations and cash flows of Statia are included in the consolidated financial statements of the Partnership since the date of acquisition. Based on the valuations performed, no amounts were assigned to goodwill or to other tangible assets. A summary of the allocation of the Statia purchase price, net of cash acquired, is as follows:
Current assets |
|
$ |
10,898,000 |
|
Property and equipment |
|
320,008,000 |
|
|
Other assets |
|
53,000 |
|
|
Current liabilities |
|
(39,052,000 |
) |
|
Long-term debt |
|
(107,746,000 |
) |
|
Other liabilities |
|
(5,957,000 |
) |
|
Purchase price |
|
$ |
178,204,000 |
|
Exhibit 99.1 page 58
4. PROPERTY AND EQUIPMENT
The cost of property and equipment is summarized as follows:
|
|
Estimated |
|
|
|
|
|
||
|
|
Useful |
|
|
|
|
|
||
|
|
Life |
|
December 31, |
|
||||
|
|
(Years) |
|
2004 |
|
2003 |
|
||
Land |
|
|
|
$ |
84,878,000 |
|
$ |
75,912,000 |
|
Buildings |
|
25 - 35 |
|
39,077,000 |
|
36,229,000 |
|
||
Pipeline and terminaling equipment |
|
15 - 40 |
|
1,187,323,000 |
|
1,115,458,000 |
|
||
Marine equipment |
|
15 - 30 |
|
87,937,000 |
|
87,204,000 |
|
||
Furniture and fixtures |
|
5 - 15 |
|
15,201,000 |
|
11,388,000 |
|
||
Transportation equipment |
|
3 - 6 |
|
7,790,000 |
|
7,360,000 |
|
||
Construction work-in-progress |
|
|
|
28,766,000 |
|
26,768,000 |
|
||
Total property and equipment |
|
|
|
1,450,972,000 |
|
1,360,319,000 |
|
||
Less accumulated depreciation |
|
|
|
302,381,000 |
|
247,349,000 |
|
||
Net property and equipment |
|
|
|
$ |
1,148,591,000 |
|
$ |
1,112,970,000 |
|
5. LONG-TERM DEBT
Long-term debt is summarized as follows:
|
|
December 31, |
|
||||
|
|
2004 |
|
2003 |
|
||
$400 million revolving credit facility, due in April of 2006 |
|
$ |
95,669,000 |
|
$ |
54,169,000 |
|
$250 million 5.875% senior unsecured notes, due in June of 2013 |
|
250,000,000 |
|
250,000,000 |
|
||
$250 million 7.75% senior unsecured notes, due in February of 2012. |
|
250,000,000 |
|
250,000,000 |
|
||
Term loans, due in April of 2006 |
|
40,770,000 |
|
29,243,000 |
|
||
Australian bank facility, due in April of 2006 |
|
35,513,000 |
|
34,284,000 |
|
||
Total long-term debt |
|
$ |
671,952,000 |
|
$ |
617,696,000 |
|
In April of 2003, the Partnership entered into a credit agreement with a group of banks that provides for a $400 million unsecured revolving credit facility through April of 2006. The credit facility, which provides for an increase in the commitment up to an aggregate of $450 million by mutual agreement between the Partnership and the banks, bears interest at variable rates and has a variable commitment fee on unused amounts. The credit facility contains certain financial and operating covenants, including limitations on investments, sales of assets and transactions with affiliates and, absent an event of default, does not restrict distributions to unitholders. At December 31, 2004, the Partnership was in compliance with all covenants. Initial borrowings on the credit agreement ($324.2 million) were used to repay all amounts outstanding under the Partnerships $275 million credit agreement and $175 million bridge loan agreement. At December 31, 2004, $95.7 million was outstanding under the credit agreement.
On May 19, 2003, KPOP issued $250 million of 5.875% senior unsecured notes due June 1, 2013. The net proceeds from the public offering, $247.6 million, were used to reduce amounts due under the revolving credit agreement. Under the note indenture, interest is payable semi-annually in arrears on June 1 and December 1 of each year. The notes are redeemable, as a whole or in part, at the option of KPOP, at any time, at a redemption price equal to the greater of 100% of the principal amount of the notes, or the sum of the present value of the remaining scheduled payments of principal and interest, discounted to the redemption date at the applicable U.S. Treasury rate, as defined in the indenture, plus 30 basis points. The note indenture contains certain financial and operational covenants, including certain limitations on investments, sales of assets and transactions with affiliates and, absent an event of default, such covenants do not restrict distributions to unitholders. At December 31, 2004, the Partnership was in compliance with all covenants.
Exhibit 99.1 page 59
In February of 2002, KPOP issued $250 million of 7.75% senior unsecured notes due February 15, 2012. The net proceeds from the public offering, $248.2 million, were used to repay the Partnerships revolving credit agreement and to partially fund the Statia acquisition (see Note 3). Under the note indenture, interest is payable semi-annually in arrears on February 15 and August 15 of each year. The notes are redeemable, as a whole or in part, at the option of KPOP, at any time, at a redemption price equal to the greater of 100% of the principal amount of the notes, or the sum of the present value of the remaining scheduled payments of principal and interest, discounted to the redemption date at the applicable U.S. Treasury rate, as defined in the indenture, plus 30 basis points. The note indenture contains certain financial and operational covenants, including certain limitations on investments, sales of assets and transactions with affiliates and, absent an event of default, such covenants do not restrict distributions to unitholders. At December 31, 2004, the Partnership was in compliance with all covenants.
6. COMMITMENTS AND CONTINGENCIES
Total rent expense under operating leases amounted to $9.4 million, $14.5 million and $13.4 million for the years ended December 31, 2002, 2003 and 2004, respectively.
The following is a schedule by years of future minimum lease payments under operating leases as of December 31, 2004:
Year ending December 31: |
|
|
|
|
2005 |
|
$ |
9,756,000 |
|
2006 |
|
8,536,000 |
|
|
2007 |
|
6,181,000 |
|
|
2008 |
|
5,279,000 |
|
|
2009 |
|
4,013,000 |
|
|
Thereafter |
|
18,140,000 |
|
|
Total minimum lease payments |
|
$ |
51,905,000 |
|
The operations of the Partnership are subject to federal, state and local laws and regulations in the United States and the various foreign locations relating to protection of the environment. Although the Partnership believes its operations are in general compliance with applicable environmental regulations, risks of additional costs and liabilities are inherent in pipeline and terminal operations, and there can be no assurance that significant costs and liabilities will not be incurred by the Partnership. Moreover, it is possible that other developments, such as increasingly stringent environmental laws, regulations and enforcement policies thereunder, and claims for damages to property or persons resulting from the operations of the Partnership, could result in substantial costs and liabilities to the Partnership. The Partnership has recorded an undiscounted reserve for environmental claims in the amount of $23.0 million at December 31, 2004, including $16.9 million related to acquisitions of pipelines and terminals. During 2004, 2003 and 2002, respectively, the Partnership incurred $6.7 million, $2.1 million and $2.4 million of costs related to such acquisition reserves and reduced the liability accordingly.
KPL has indemnified the Partnership against liabilities for damage to the environment resulting from operations of the pipeline prior to October 3, 1989 (the date of formation of the Partnership). The indemnification does not extend to any liabilities that arise after such date to the extent that the liabilities result from changes in environmental laws and regulations.
Certain subsidiaries of the Partnership were sued in a Texas state court in 1997 by Grace Energy Corporation (Grace), the entity from which the Partnership acquired ST Services in 1993. The lawsuit involves environmental response and remediation costs allegedly resulting from jet fuel leaks in the early 1970s from a pipeline. The pipeline, which connected a former Grace terminal with Otis Air Force Base in Massachusetts (the Otis pipeline or the pipeline), ceased operations in 1973 and was abandoned before 1978, when the connecting terminal was sold to an unrelated entity. Grace alleged that subsidiaries of the Partnership acquired the abandoned pipeline as part of the acquisition of ST Services in 1993 and assumed responsibility for environmental damages allegedly caused by the jet fuel leaks. Grace sought a ruling from the Texas court that these subsidiaries are responsible for all liabilities, including all present and future remediation expenses, associated with these leaks and that Grace has no obligation to indemnify these subsidiaries for these expenses. In the lawsuit, Grace also sought indemnification for expenses of approximately $3.5 million that it had incurred since 1996 for response and remediation required by the State of Massachusetts and for additional expenses that it expects to incur in the future. The consistent position of the Partnerships subsidiaries has been that they did not acquire the abandoned pipeline as part of the 1993 ST Services transaction, and therefore did not assume any responsibility for the environmental damage nor any liability to Grace for the pipeline.
Exhibit 99.1 page 60
At the end of the trial, the jury returned a verdict including findings that (1) Grace had breached a provision of the 1993 acquisition agreement by failing to disclose matters related to the pipeline, and (2) the pipeline was abandoned before 1978 15 years before the Partnerships subsidiaries acquired ST Services. On August 30, 2000, the Judge entered final judgment in the case that Grace take nothing from the subsidiaries on its claims seeking recovery of remediation costs. Although the Partnerships subsidiaries have not incurred any expenses in connection with the remediation, the court also ruled, in effect, that the subsidiaries would not be entitled to indemnification from Grace if any such expenses were incurred in the future. Moreover, the Judge let stand a prior summary judgment ruling that the pipeline was an asset acquired by the Partnerships subsidiaries as part of the 1993 ST Services transaction and that any liabilities associated with the pipeline would have become liabilities of the subsidiaries. Based on that ruling, the Massachusetts Department of Environmental Protection and Samson Hydrocarbons Company (successor to Grace Petroleum Company) wrote letters to ST Services alleging its responsibility for the remediation, and ST Services responded denying any liability in connection with this matter. The Judge also awarded attorney fees to Grace of more than $1.5 million. Both the Partnerships subsidiaries and Grace have appealed the trial courts final judgment to the Texas Court of Appeals in Dallas. In particular, the subsidiaries have filed an appeal of the judgment finding that the Otis pipeline and any liabilities associated with the pipeline were transferred to them as well as the award of attorney fees to Grace.
On April 2, 2001, Grace filed a petition in bankruptcy, which created an automatic stay of actions against Grace. This automatic stay covers the appeal of the Dallas litigation, and the Texas Court of Appeals has issued an order staying all proceedings of the appeal because of the bankruptcy. Once that stay is lifted, the Partnerships subsidiaries that are party to the lawsuit intend to resume vigorous prosecution of the appeal.
The Otis Air Force Base is a part of the Massachusetts Military Reservation (MMR Site), which has been declared a Superfund Site pursuant to CERCLA. The MMR Site contains a number of groundwater contamination plumes, two of which are allegedly associated with the Otis pipeline, and various other waste management areas of concern, such as landfills. The United States Department of Defense, pursuant to a Federal Facilities Agreement, has been responding to the Government remediation demand for most of the contamination problems at the MMR Site. Grace and others have also received and responded to formal inquiries from the United States Government in connection with the environmental damages allegedly resulting from the jet fuel leaks. The Partnerships subsidiaries voluntarily responded to an invitation from the Government to provide information indicating that they do not own the pipeline. In connection with a court-ordered mediation between Grace and the Partnerships subsidiaries, the Government advised the parties in April 1999 that it has identified two spill areas that it believes to be related to the pipeline that is the subject of the Grace suit. The Government at that time advised the parties that it believed it had incurred costs of approximately $34 million, and expected in the future to incur costs of approximately $55 million, for remediation of one of the spill areas. This amount was not intended to be a final accounting of costs or to include all categories of costs. The Government also advised the parties that it could not at that time allocate its costs attributable to the second spill area.
By letter dated July 26, 2001, the United States Department of Justice (DOJ) advised ST Services that the Government intends to seek reimbursement from ST Services under the Massachusetts Oil and Hazardous Material Release Prevention and Response Act and the Declaratory Judgment Act for the Governments response costs at the two spill areas discussed above. The DOJ relied in part on the Texas state court judgment, which in the DOJs view, held that ST Services was the current owner of the pipeline and the successor-in-interest of the prior owner and operator. The Government advised ST Services that it believes it has incurred costs exceeding $40 million, and expects to incur future costs exceeding an additional $22 million, for remediation of the two spill areas. The Partnership believes that its subsidiaries have substantial defenses. ST Services responded to the DOJ on September 6, 2001, contesting the Governments positions and declining to reimburse any response costs. The DOJ has not filed a lawsuit against ST Services seeking cost recovery for its environmental investigation and response costs. Representatives of ST Services have met with representatives of the Government on several occasions since September 6, 2001 to discuss the Governments claims and to exchange information related to such claims. Additional exchanges of information are expected to occur in the future and additional meetings may be held to discuss possible resolution of the Governments claims without litigation. The Partnership does not believe this matter will have a materially adverse effect on its financial condition, although there can be no assurances as to the ultimate outcome.
On April 7, 2000, a fuel oil pipeline in Maryland owned by Potomac Electric Power Company (PEPCO) ruptured. Work performed with regard to the pipeline was conducted by a partnership of which ST Services is general partner. PEPCO has reported that it has incurred total cleanup costs of $70 million to $75 million. PEPCO probably will continue to incur some cleanup related costs for the foreseeable future, primarily in connection with EPA requirements for monitoring the condition of some of the impacted areas. Since May 2000, ST Services has provisionally contributed a minority share of the cleanup expense, which has been funded by ST Services insurance carriers. ST Services and PEPCO have not, however, reached a final agreement regarding ST Services proportionate responsibility for this cleanup effort, if any, and cannot predict the amount, if any, that ultimately may be determined to be ST Services share of the remediation expense, but ST Services believes that such amount will be covered by insurance and therefore will not materially adversely affect the Partnerships financial condition.
Exhibit 99.1 page 61
As a result of the rupture, purported class actions were filed against PEPCO and ST Services in federal and state court in Maryland by property and business owners alleging damages in unspecified amounts under various theories, including under the Oil Pollution Act (OPA) and Maryland common law. The federal court consolidated all of the federal cases in a case styled as In re Swanson Creek Oil Spill Litigation. A settlement of the consolidated class action, and a companion state-court class action, was reached and approved by the federal judge. The settlement involved creation and funding by PEPCO and ST Services of a $2,250,000 class settlement fund, from which all participating claimants would be paid according to a court-approved formula, as well as a court-approved payment to plaintiffs attorneys. The settlement has been consummated and the fund, to which PEPCO and ST Services contributed equal amounts, has been distributed. Participating claimants claims have been settled and dismissed with prejudice. A number of class members elected not to participate in the settlement, i.e., to opt out, thereby preserving their claims against PEPCO and ST Services. All non-participant claims have been settled for immaterial amounts with ST Services portion of such settlements provided by its insurance carrier.
PEPCO and ST Services agreed with the federal government and the State of Maryland to pay costs of assessing natural resource damages arising from the Swanson Creek oil spill under OPA and of selecting restoration projects. This process was completed in mid-2002. ST Services insurer has paid ST Services agreed 50 percent share of these assessment costs. In late November 2002, PEPCO and ST Services entered into a Consent Decree resolving the federal and state trustees claims for natural resource damages. The decree required payments by ST Services and PEPCO of a total of approximately $3 million to fund the restoration projects and for remaining damage assessment costs. The federal court entered the Consent Decree as a final judgment on December 31, 2002. PEPCO and ST Services have each paid their 50% share and thus fully performed their payment obligations under the Consent Decree. ST Services insurance carrier funded ST Services payment.
The U.S. Department of Transportation (DOT) has issued a Notice of Proposed Violation to PEPCO and ST Services alleging violations over several years of pipeline safety regulations and proposing a civil penalty of $647,000 jointly against the two companies. ST Services and PEPCO have contested the DOT allegations and the proposed penalty. A hearing was held before the Office of Pipeline Safety at the DOT in late 2001. In June of 2004, the DOT issued a final order reducing the penalty to $256,250 jointly against ST Services and PEPCO and $74,000 against ST Services. On September 14, 2004, ST Services petitioned for reconsideration of the order.
By letter dated January 4, 2002, the Attorney Generals Office for the State of Maryland advised ST Services that it intended to seek penalties from ST Services in connection with the April 7, 2000 spill. The State of Maryland subsequently asserted that it would seek penalties against ST Services and PEPCO totaling up to $12 million. A settlement of this claim was reached in mid-2002 under which ST Services insurer will pay a total of slightly more than $1 million in installments over a five year period. PEPCO has also reached a settlement of these claims with the State of Maryland. Accordingly, the Partnership believes that this matter will not have a material adverse effect on its financial condition.
On December 13, 2002, ST Services sued PEPCO in the Superior Court, District of Columbia, seeking, among other things, a declaratory judgment as to ST Services legal obligations, if any, to reimburse PEPCO for costs of the oil spill. On December 16, 2002, PEPCO sued ST Services in the United States District Court for the District of Maryland, seeking recovery of all its costs for remediation of and response to the oil spill. Pursuant to an agreement between ST Services and PEPCO, ST Services suit was dismissed, subject to refiling. ST Services has moved to dismiss PEPCOs suit. ST Services is vigorously defending against PEPCOs claims and is pursuing its own counterclaims for return of monies ST Services has advanced to PEPCO for settlements and cleanup costs. The Partnership believes that any costs or damages resulting from these lawsuits will be covered by insurance and therefore will not materially adversely affect the Partnerships financial condition. The amounts claimed by PEPCO, if recovered, would trigger an excess insurance policy which has a $600,000 retention, but the Partnership does not believe that such retention, if incurred, would materially adversely affect the Partnerships financial condition.
In 2003, Exxon Mobil filed a lawsuit in a New Jersey state court against GATX Corporation, Kinder Morgan Liquid Terminals (Kinder Morgan), the successor in interest to GATX Terminals Corporation (GATX), and ST Services, seeking reimbursement for remediation costs associated with the Paulsboro, New Jersey terminal. The terminal was owned and operated by Exxon Mobil from the early 1950s until 1990 when purchased by GATX. ST Services purchased the terminal in 2000 from GATX. GATX was subsequently acquired by Kinder Morgan. As a condition to the sale to GATX in 1990, Exxon Mobil undertook certain remediation obligations with respect to the site. In the lawsuit, Exxon Mobil is claiming that it has complied with its remediation and contractual obligations and is entitled to reimbursement from GATX Corporation, the parent company of GATX, Kinder Morgan, and ST Services for costs in the amount of $400,000 that it claims are related to releases at the site subsequent to its sale of the terminal to GATX. It is also alleging that any remaining remediation requirements are the responsibility of GATX Corporation, Kinder Morgan, or ST Services. Kinder Morgan has alleged that it was relieved of any remediation obligations pursuant to the sale agreement between its predecessor, GATX, and ST Services. ST Services believes that, except for remediation involving immaterial amounts, GATX Corporation or Exxon Mobil are responsible for the remaining remediation of the site. Costs of completing the required remediation depend on a number of factors and cannot be determined at the current time.
A subsidiary of the Partnership purchased the approximately 2,000-mile ammonia pipeline system from Koch Pipeline Company, L.P. and Koch Fertilizer Storage and Terminal Company in 2002. The rates of the ammonia pipeline are subject to regulation by the Surface Transportation Board (the STB). The STB had issued an order in May 2000, prescribing maximum allowable rates the Partnerships predecessor could charge for transportation to certain destination points on the pipeline system. In 2003, the Partnership instituted a 7% general increase to pipeline rates. On August 1, 2003, CF Industries, Inc. (CFI) filed a complaint with the STB challenging these rate increases. On August 11, 2004, STB ordered the Partnership to pay reparations to CFI and to return CFIs rates to the levels permitted under the rate prescription. The Partnership has complied with the order. The STB, however, indicated in the order that it would lift the rate prescription in the event the Partnership could show materially changed circumstances. The Partnership has submitted evidence of materially changed circumstances, which specifically includes its capital investment in the pipeline. CFI has argued that the Partnerships acquisition costs should not be considered by the STB as a measure of the Partnerships investment base. The STB is expected to decide the issue within the second quarter of 2005.
Exhibit 99.1 page 62
Also, on June 16, 2003, Dyno Nobel Inc. (Dyno) filed a complaint with the STB challenging the 2003 rate increase on the basis that (i) the rate increase constitutes a violation of a contract rate, (ii) rates are discriminatory and (iii) the rates exceed permitted levels. Dyno also intervened in the CFI proceeding described above. Unlike CFI, Dynos rates are not subject to a rate prescription. As of December 31, 2004, Dyno would be entitled to approximately $2 million in rate refunds, should it be successful. The Partnership believes, however, that Dynos claims are without merit.
The Partnership has other contingent liabilities resulting from litigation, claims and commitments incident to the ordinary course of business. Management of the Partnership believes, after consulting with counsel, that the ultimate resolution of such contingencies will not have a materially adverse effect on the financial position, results of operations or liquidity of the Partnership.
7. RELATED PARTY TRANSACTIONS
The Partnership has no employees and is managed and controlled by KPL. KPL and KSL are entitled to reimbursement of all direct and indirect costs related to the business activities of the Partnership. These costs, which totaled $36.0 million, $36.3 million and $27.3 million for the years ended December 31, 2004, 2003 and 2002, respectively, include compensation and benefits paid to officers and employees of KPL and KSL, insurance premiums, general and administrative costs, tax information and reporting costs, legal and audit fees. Included in this amount is $24.2 million, $26.6 million and $17.7 million of compensation and benefits, paid to officers and employees of KPL and KSL for the years ended December 31, 2004, 2003 and 2002, respectively. In addition, the Partnership paid $0.8 million in 2004, $0.6 million in 2003 and $0.6 million in 2002 for an allocable portion of KPLs overhead expenses. At December 31, 2004 and 2003, the Partnership owed KPL and KSL $4.5 million and $3.6 million, respectively, for these expenses which are due under normal invoice terms.
8. BUSINESS SEGMENT DATA
The Partnership conducts business through three principal segments; the Pipeline Operations, which consists primarily of the transportation of refined petroleum products and fertilizer in the Midwestern states as a common carrier, the Terminaling Operations, which provides storage for petroleum products, specialty chemicals and other liquids, and the Product Sales Operations, which delivers bunker fuel to ships in the Caribbean and Nova Scotia, Canada and sells bulk petroleum products to various commercial interests.
The Partnership measures segment profit as operating income. Total assets are those assets controlled by each reportable segment. Business segment data is as follows:
Exhibit 99.1 page 63
|
|
Year Ended December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Business segment revenues: |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
119,803,000 |
|
$ |
119,633,000 |
|
$ |
82,698,000 |
|
Terminaling operations |
|
259,352,000 |
|
234,958,000 |
|
205,971,000 |
|
|||
Product sales operations |
|
269,054,000 |
|
215,823,000 |
|
97,961,000 |
|
|||
|
|
$ |
648,209,000 |
|
$ |
570,414,000 |
|
$ |
386,630,000 |
|
Business segment profit: |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
48,853,000 |
|
$ |
51,860,000 |
|
$ |
38,623,000 |
|
Terminaling operations |
|
74,663,000 |
|
66,532,000 |
|
65,040,000 |
|
|||
Product sales operations |
|
13,274,000 |
|
10,109,000 |
|
2,058,000 |
|
|||
Operating income |
|
136,790,000 |
|
128,501,000 |
|
105,721,000 |
|
|||
Interest and other income |
|
267,000 |
|
261,000 |
|
3,570,000 |
|
|||
Interest expense |
|
(42,750,000 |
) |
(38,757,000 |
) |
(28,110,000 |
) |
|||
Loss on debt extinguishment |
|
|
|
|
|
(3,282,000 |
) |
|||
Income before minority interest, income taxes and cumulative effect of change in accounting principle |
|
$ |
94,307,000 |
|
$ |
90,005,000 |
|
$ |
77,899,000 |
|
Business segment assets: |
|
|
|
|
|
|
|
|||
Depreciation and amortization: |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
14,538,000 |
|
$ |
14,117,000 |
|
$ |
6,408,000 |
|
Terminaling operations |
|
41,232,000 |
|
38,089,000 |
|
32,368,000 |
|
|||
Product sales operations |
|
878,000 |
|
949,000 |
|
649,000 |
|
|||
|
|
$ |
56,648,000 |
|
$ |
53,155,000 |
|
$ |
39,425,000 |
|
Capital expenditures (excluding acquisitions): |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
10,334,000 |
|
$ |
9,584,000 |
|
$ |
9,469,000 |
|
Terminaling operations |
|
29,511,000 |
|
34,572,000 |
|
20,953,000 |
|
|||
Product sales operations |
|
2,369,000 |
|
585,000 |
|
679,000 |
|
|||
|
|
$ |
42,214,000 |
|
$ |
44,741,000 |
|
$ |
31,101,000 |
|
Total assets: |
|
|
|
|
|
|
|
|||
Pipeline operations |
|
$ |
351,195,000 |
|
$ |
352,901,000 |
|
$ |
352,657,000 |
|
Terminaling operations |
|
917,966,000 |
|
874,185,000 |
|
844,321,000 |
|
|||
Product sales operations |
|
56,155,000 |
|
37,596,000 |
|
18,432,000 |
|
|||
|
|
$ |
1,325,316,000 |
|
$ |
1,264,682,000 |
|
$ |
1,215,410,000 |
|
The following geographical area data includes revenues and operating income based on location of the operating segment and net property and equipment based on physical location.
|
|
Year Ended December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Geographical area revenues: |
|
|
|
|
|
|
|
|||
United States |
|
$ |
251,775,000 |
|
$ |
240,518,000 |
|
$ |
202,124,000 |
|
United Kingdom |
|
29,540,000 |
|
26,392,000 |
|
23,937,000 |
|
|||
Netherlands Antilles |
|
298,273,000 |
|
241,693,000 |
|
132,387,000 |
|
|||
Canada |
|
43,671,000 |
|
41,689,000 |
|
23,207,000 |
|
|||
Australia and New Zealand |
|
24,950,000 |
|
20,122,000 |
|
4,975,000 |
|
|||
|
|
$ |
648,209,000 |
|
$ |
570,414,000 |
|
$ |
386,630,000 |
|
Geographical area operating income: |
|
|
|
|
|
|
|
|||
United States |
|
$ |
93,965,000 |
|
$ |
87,962,000 |
|
$ |
82,906,000 |
|
United Kingdom |
|
7,704,000 |
|
8,583,000 |
|
7,318,000 |
|
|||
Netherlands Antilles |
|
22,629,000 |
|
19,223,000 |
|
9,616,000 |
|
|||
Canada |
|
5,248,000 |
|
6,777,000 |
|
4,398,000 |
|
|||
Australia and New Zealand |
|
7,244,000 |
|
5,956,000 |
|
1,483,000 |
|
|||
|
|
$ |
136,790,000 |
|
$ |
128,501,000 |
|
$ |
105,721,000 |
|
|
|
December 31, |
|
|||||||
|
|
2004 |
|
2003 |
|
2002 |
|
|||
Geographical area net property and equipment: |
|
|
|
|
|
|
|
|||
United States |
|
$ |
718,236,000 |
|
$ |
693,295,000 |
|
$ |
690,178,000 |
|
United Kingdom |
|
63,968,000 |
|
51,392,000 |
|
46,543,000 |
|
|||
Netherlands Antilles |
|
211,382,000 |
|
217,143,000 |
|
224,810,000 |
|
|||
Canada |
|
71,374,000 |
|
74,995,000 |
|
78,789,000 |
|
|||
Australia and New Zealand |
|
83,631,000 |
|
76,145,000 |
|
51,872,000 |
|
|||
|
|
$ |
1,148,591,000 |
|
$ |
1,112,970,000 |
|
$ |
1,092,192,000 |
|
Exhibit 99.1 page 64
9. FAIR VALUE OF FINANCIAL INSTRUMENTS AND CONCENTRATION OF CREDIT RISK
The estimated fair value of all debt as of December 31, 2004 and 2003 was approximately $728 million and $630 million, as compared to the carrying value of $672 million and $618 million, respectively. These fair values were estimated using discounted cash flow analysis, based on the Partnerships current incremental borrowing rates for similar types of borrowing arrangements. These estimates are not necessarily indicative of the amounts that would be realized in a current market exchange. See Note 2 regarding derivative instruments.
The Partnership markets and sells its services to a broad base of customers and performs ongoing credit evaluations of its customers. The Partnership does not believe it has a significant concentration of credit risk at December 31, 2004. No customer constituted 10 percent or more of consolidated revenues in 2004, 2003 or 2002.
10. QUARTERLY FINANCIAL DATA (unaudited)
Quarterly operating results for 2004 and 2003 are summarized as follows:
|
|
Quarter Ended |
|
||||||||||
|
|
March 31, |
|
June 30, |
|
September 30, |
|
December 31, |
|
||||
2004: |
|
|
|
|
|
|
|
|
|
||||
Revenues |
|
$ |
146,413,000 |
|
$ |
153,958,000 |
|
$ |
167,668,000 |
|
$ |
180,170,000 |
|
Operating income |
|
$ |
32,562,000 |
|
$ |
35,650,000 |
|
$ |
34,146,000 |
|
$ |
34,432,000 |
|
Net income |
|
$ |
20,769,000 |
|
$ |
24,286,000 |
|
$ |
22,068,000 |
|
$ |
22,992,000 |
|
Allocation of net income per unit |
|
$ |
0.65 |
|
$ |
0.77 |
|
$ |
0.69 |
|
$ |
0.72 |
|
2003: |
|
|
|
|
|
|
|
|
|
||||
Revenues |
|
$ |
140,757,000 |
|
$ |
146,948,000 |
|
$ |
140,404,000 |
|
$ |
142,305,000 |
|
Operating income |
|
$ |
33,598,000 |
|
$ |
33,041,000 |
|
$ |
32,016,000 |
|
$ |
29,846,000 |
|
Net income |
|
$ |
21,829,000 |
(a) |
$ |
22,600,000 |
|
$ |
20,120,000 |
|
$ |
17,808,000 |
|
Allocation of net income per unit |
|
$ |
0.78 |
|
$ |
0.73 |
|
$ |
0.63 |
|
$ |
0.55 |
|
(a) Includes cumulative effect of change in accounting principle - adoption of new accounting standard for asset retirement obligations of approximately $1.6 million in expense.
Exhibit 99.1 page 65
EXHIBIT 99.2
VALERO L.P.
UNAUDITED PRO FORMA CONDENSED COMBINED FINANCIAL STATEMENTS
Introduction
The following unaudited pro forma condensed combined financial statements give effect to the acquisition by Valero L.P. of Kaneb Services LLC (KSL) and Kaneb Pipe Line Partners, L.P. (KPP) (collectively referred to herein as Kaneb), on July 1, 2005. Valero L.P. acquired all of the equity securities of KSL in a fixed cash merger for $43.31 per share. Immediately subsequent to the KSL merger, unitholders of KPP exchanged their units for Valero L.P. common units receiving 1.0231 common units of Valero L.P. for each KPP unit tendered in the exchange.
As a condition to complete the acquisition of Kaneb, Valero L.P. and the United States Federal Trade Commission agreed that Valero L.P. would divest certain Kaneb assets within six months of the close of the acquisition. The assets to be divested include Kaneb terminals located in Richmond, CA; Martinez, CA; Paulsboro, NJ; two terminals in Philadelphia, PA; and Kanebs West Pipeline System collectively, the Held Separate Businesses. On July 5, 2005, Valero L.P. and Pacific Energy Partners, L.P. (Pacific) announced that Pacific would acquire the Held Separate Businesses for approximately $455 million. Additionally, on July 1, 2005 Valero L.P. sold the stock of Martin Oil LLC (MOC), a wholly owned subsidiary of KSL, which was acquired as part of the acquisitions of Kaneb, to a subsidiary of Valero Energy Corporation (Valero Energy) for approximately $27 million. The unaudited pro forma condensed combined income statements for the periods ended December 31, 2004 and June 30, 2005 exclude the results of operations of the Held Separate Businesses and MOC. The unaudited pro forma condensed combined balance sheet as of June 30, 2005 assumes the Held Separate Businesses and MOC were sold on that date and that the proceeds were used to reduce debt.
The KSL historical information reflects the consolidation of KPP and KSL with all intercompany transactions being eliminated. The first set of pro forma adjustments in the unaudited pro forma condensed combined financial statements reflects the effect of the KSL merger. The second set of pro forma adjustments reflects the effect of the KPP merger that occurred immediately upon the closing of the KSL merger. The unaudited pro forma condensed combined balance sheet as of June 30, 2005 is presented as if the Kaneb acquisitions had occurred on that date. The unaudited pro forma condensed combined statements of income assume that the acquisitions occurred on January 1, 2004. The estimates of fair value of the assets acquired and liabilities assumed are based on preliminary assumptions, pending the completion of an independent appraisal, with any excess of purchase price over the net fair value of assets acquired and liabilities assumed assigned to goodwill.
The unaudited pro forma condensed combined financial statements should be read in conjunction with (i) the audited historical consolidated financial statements of Valero L.P. included in its Annual Report on Form 10-K for the year ended December 31, 2004; (ii) the audited historical consolidated financial statements of KPP included in its Annual Report on Form 10-K for the year ended December 31, 2004; (iii) the audited historical consolidated financial statements of KSL included in its Annual Report on Form 10-K for the year ended December 31, 2004; and (iv) the unaudited historical consolidated financial statements of Valero L.P., included in its quarterly report on Form 10-Q for the period ended June 30, 2005. The unaudited pro forma condensed combined financial statements are not necessarily indicative of the financial position that would have been obtained or the financial results that would have occurred if the Kaneb acquisitions had been consummated on the dates indicated, nor are they necessarily indicative of the financial position or results of operations in the future. The pro forma adjustments, as described in the notes to unaudited pro forma condensed combined financial statements, are based upon available information and certain assumptions that Valero L.P.s management believes are reasonable.
The unaudited pro forma condensed combined financial statements do not give effect to any anticipated cost savings or other financial benefits expected to result from the Kaneb mergers.
Exhibit 99.2 page 1
VALERO L.P.
UNAUDITED PRO FORMA CONDENSED COMBINED BALANCE SHEET
JUNE 30, 2005
(Thousands of Dollars)
|
|
Valero |
|
Kaneb |
|
KSL |
|
Valero L.P. |
|
KPP |
|
Valero L.P. |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Assets |
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Current assets: |
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Cash and cash equivalents |
|
$ |
21,612 |
|
$ |
17,291 |
|
$ |
525,000 |
(a) |
$ |
53,786 |
|
$ |
29,197 |
(e) |
$ |
73,393 |
|
|
|
|
|
|
|
(810 |
)(a) |
|
|
(9,590 |
)(n) |
|
|
||||||
|
|
|
|
|
|
(509,307 |
)(b) |
|
|
|
|
|
|
||||||
Receivable from Valero Energy |
|
19,666 |
|
|
|
|
|
19,666 |
|
|
|
19,666 |
|
||||||
Accounts receivable |
|
2,393 |
|
88,090 |
|
|
|
90,483 |
|
(23,690 |
)(n) |
66,793 |
|
||||||
Other current assets |
|
1,658 |
|
46,877 |
|
|
|
48,535 |
|
(4,403 |
)(d) |
29,226 |
|
||||||
|
|
|
|
|
|
|
|
|
|
(14,906 |
)(n) |
|
|
||||||
Total current assets |
|
45,329 |
|
152,258 |
|
14,883 |
|
212,470 |
|
(23,392 |
) |
189,078 |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Property and equipment |
|
995,900 |
|
1,468,873 |
|
|
|
2,464,773 |
|
409,933 |
(d) |
2,419,502 |
|
||||||
|
|
|
|
|
|
|
|
|
|
(455,204 |
)(n) |
|
|
||||||
Less accumulated depreciation and amortization |
|
(213,564 |
) |
(329,352 |
) |
|
|
(542,916 |
) |
329,352 |
(d) |
(213,564 |
) |
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Property and equipment, net |
|
782,336 |
|
1,139,521 |
|
|
|
1,921,857 |
|
284,081 |
|
2,205,938 |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Goodwill |
|
4,715 |
|
10,622 |
|
440,742 |
(b) |
456,079 |
|
423,672 |
(d) |
868,820 |
|
||||||
|
|
|
|
|
|
|
|
|
|
(10,622 |
)(d) |
|
|
||||||
|
|
|
|
|
|
|
|
|
|
3,900 |
(f) |
|
|
||||||
|
|
|
|
|
|
|
|
|
|
(4,209 |
)(n) |
|
|
||||||
Investment in joint ventures |
|
16,360 |
|
26,828 |
|
|
|
43,188 |
|
|
|
43,188 |
|
||||||
Other noncurrent assets, net |
|
19,935 |
|
7,691 |
|
810 |
(a) |
28,436 |
|
(15,016 |
)(d) |
13,420 |
|
||||||
Total assets |
|
$ |
868,675 |
|
$ |
1,336,920 |
|
$ |
456,435 |
|
$ |
2,662,030 |
|
$ |
658,414 |
|
$ |
3,320,444 |
|
See Accompanying Notes to Pro Forma Condensed Combined Financial Statements.
Exhibit 99.2 page 2
|
|
Valero |
|
Kaneb |
|
KSL |
|
Valero L.P. |
|
KPP |
|
Valero L.P. |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Liabilities and Equity |
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Current liabilities: |
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Current portion of long- term debt |
|
$ |
524 |
|
$ |
195,984 |
|
$ |
|
|
$ |
196,508 |
|
$ |
|
|
$ |
196,508 |
|
Accounts payable |
|
18,227 |
|
45,145 |
|
|
|
63,372 |
|
(11,583 |
)(n) |
51,789 |
|
||||||
Payable to Valero Energy |
|
4,536 |
|
|
|
|
|
4,536 |
|
|
|
4,536 |
|
||||||
Accrued liabilities |
|
11,229 |
|
49,084 |
|
|
|
60,313 |
|
3,900 |
(f) |
59,420 |
|
||||||
|
|
|
|
|
|
|
|
|
|
(4,793 |
)(n) |
|
|
||||||
Total current liabilities |
|
34,516 |
|
290,213 |
|
|
|
324,729 |
|
(12,476 |
) |
312,253 |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Long-term debt, less current portion |
|
397,459 |
|
528,723 |
|
525,000 |
(a) |
1,451,182 |
|
55,000 |
(d) |
1,014,959 |
|
||||||
|
|
|
|
|
|
|
|
|
|
(491,223 |
)(n) |
|
|
||||||
Deferred income taxes |
|
|
|
6,159 |
|
|
|
6,159 |
|
|
|
6,159 |
|
||||||
Other long-term liabilities |
|
121 |
|
69,927 |
|
|
|
70,048 |
|
|
|
70,048 |
|
||||||
Interest of outside non-controlling partners in Kaneb Pipeline Partners, L.P. |
|
|
|
373,333 |
|
|
|
373,333 |
|
(373,333 |
)(d) |
|
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Equity: |
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Common units |
|
309,337 |
|
|
|
|
|
309,337 |
|
1,451,249 |
(d) |
1,760,586 |
|
||||||
Subordinated units |
|
117,105 |
|
|
|
|
|
117,105 |
|
|
|
117,105 |
|
||||||
General partners equity |
|
10,137 |
|
|
|
|
|
10,137 |
|
29,197 |
(e) |
39,334 |
|
||||||
Shareholders equity |
|
|
|
68,565 |
|
(68,565 |
)(b) |
|
|
|
|
|
|
||||||
Total equity |
|
436,579 |
|
68,565 |
|
(68,565 |
) |
436,579 |
|
1,480,446 |
|
1,917,025 |
|
||||||
Total liabilities and equity |
|
$ |
868,675 |
|
$ |
1,336,920 |
|
$ |
456,435 |
|
$ |
2,662,030 |
|
$ |
658,414 |
|
$ |
3,320,444 |
|
See Accompanying Notes to Pro Forma Condensed Combined Financial Statements.
Exhibit 99.2 page 3
VALERO L.P.
UNAUDITED PRO FORMA CONDENSED COMBINED STATEMENT OF INCOME
FOR THE SIX MONTHS ENDED JUNE 30, 2005
(Thousands of Dollars, except unit and per unit data)
|
|
Valero L.P. |
|
Kaneb |
|
KSL |
|
Valero L.P. |
|
KPP |
|
Valero L.P. |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Revenue |
|
$ |
114,941 |
|
$ |
626,221 |
|
$ |
|
|
$ |
741,162 |
|
$ |
(2,797 |
)(g) |
$ |
473,701 |
|
|
|
|
|
|
|
|
|
|
|
(264,664 |
)(m) |
|
|
||||||
Costs and expenses: |
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Cost of products sold |
|
|
|
405,165 |
|
|
|
405,165 |
|
(233,614 |
)(m) |
171,551 |
|
||||||
Operating expenses |
|
41,330 |
|
104,731 |
|
|
|
146,061 |
|
(10,688 |
)(m) |
135,373 |
|
||||||
General and administrative expenses |
|
7,064 |
|
40,897 |
|
|
|
47,961 |
|
(938 |
)(m) |
47,023 |
|
||||||
Depreciation and amortization |
|
17,523 |
|
29,501 |
|
|
|
47,024 |
|
2,896 |
(h) |
47,135 |
|
||||||
|
|
|
|
|
|
|
|
|
|
(2,785 |
)(m) |
|
|
||||||
Provision for loss contingencies |
|
|
|
42,000 |
|
|
|
42,000 |
|
|
|
42,000 |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Total costs and expenses |
|
65,917 |
|
622,294 |
|
|
|
688,211 |
|
(245,129 |
) |
443,082 |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Operating income |
|
49,024 |
|
3,927 |
|
|
|
52,951 |
|
(22,332 |
) |
30,619 |
|
||||||
Equity income from joint ventures |
|
799 |
|
|
|
|
|
799 |
|
2,797 |
(g) |
3,596 |
|
||||||
Interest and other expense, net |
|
(11,707 |
) |
(23,671 |
) |
(933 |
)(c) |
(36,311 |
) |
3,953 |
(i) |
(32,186 |
) |
||||||
|
|
|
|
|
|
|
|
|
|
172 |
(m) |
|
|
||||||
Income (loss) before interest of outside non-controlling partners and income taxes |
|
38,116 |
|
(19,744 |
) |
(933 |
) |
17,439 |
|
(15,410 |
) |
2,029 |
|
||||||
Interest of outside non-controlling partners |
|
|
|
2,158 |
|
|
|
2,158 |
|
(2,158 |
)(j) |
|
|
||||||
Income tax benefit |
|
|
|
12,778 |
|
|
|
12,778 |
|
|
(k) |
12,778 |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Income (loss) from continuing operations |
|
$ |
38,116 |
|
$ |
(4,808 |
) |
$ |
(933 |
) |
$ |
32,375 |
|
$ |
(17,568 |
) |
$ |
14,807 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Allocation of income from continuing operations: |
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Income (loss) from continuing operations |
|
$ |
38,116 |
|
$ |
(4,808 |
) |
$ |
(933 |
) |
$ |
32,375 |
|
$ |
(17,568 |
) |
$ |
14,807 |
|
General partners interest in income from continuing operations |
|
(3,323 |
) |
|
|
|
|
(3,323 |
) |
(2,949 |
)(l) |
(6,272 |
) |
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Limited partners interest in income (loss) from continuing operations |
|
$ |
34,793 |
|
$ |
(4,808 |
) |
$ |
(933 |
) |
$ |
29,052 |
|
$ |
(20,517 |
) |
$ |
8,535 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Income from continuing operations per unit applicable to limited partners |
|
$ |
1.51 |
|
|
|
|
|
|
|
|
|
$ |
0.18 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Weighted average number of limited partnership units outstanding |
|
23,041,394 |
|
|
|
|
|
23,041,394 |
|
23,768,751 |
(d) |
46,810,145 |
|
See Accompanying Notes to Pro Forma Condensed Combined Financial Statements.
Exhibit 99.2 page 4
VALERO L.P.
UNAUDITED PRO FORMA CONDENSED COMBINED STATEMENT OF INCOME
FOR THE YEAR ENDED DECEMBER 31, 2004
(Thousands of Dollars, except unit and per unit data)
|
|
Valero L.P. |
|
Kaneb |
|
KSL |
|
Valero L.P. |
|
KPP |
|
Valero L.P. |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Revenues |
|
$ |
220,792 |
|
$ |
1,055,248 |
|
$ |
|
|
$ |
1,276,040 |
|
$ |
(5,478 |
)(g) |
$ |
812,425 |
|
|
|
|
|
|
|
|
|
|
|
(458,137 |
)(m) |
|
|
||||||
Costs and expenses: |
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Cost of products sold |
|
|
|
647,733 |
|
|
|
647,733 |
|
(400,875 |
)(m) |
246,858 |
|
||||||
Operating expenses |
|
78,298 |
|
177,829 |
|
|
|
256,127 |
|
(17,783 |
)(m) |
238,344 |
|
||||||
General and administrative expenses |
|
11,321 |
|
36,231 |
|
|
|
47,552 |
|
(1,295 |
)(m) |
46,257 |
|
||||||
Depreciation and amortization |
|
33,149 |
|
56,676 |
|
|
|
89,825 |
|
5,791 |
(h) |
90,280 |
|
||||||
|
|
|
|
|
|
|
|
|
|
(5,336 |
)(m) |
|
|
||||||
Total costs and expenses |
|
122,768 |
|
918,469 |
|
|
|
1,041,237 |
|
(419,498 |
) |
621,739 |
|
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Operating income |
|
98,024 |
|
136,779 |
|
|
|
234,803 |
|
(44,117 |
) |
190,686 |
|
||||||
Equity income from joint ventures |
|
1,344 |
|
|
|
|
|
1,344 |
|
5,478 |
(g) |
6,822 |
|
||||||
Interest and other expense, net |
|
(20,950 |
) |
(43,243 |
) |
(1,867 |
)(c) |
(66,060 |
) |
7,906 |
(i) |
(57,934 |
) |
||||||
|
|
|
|
|
|
|
|
|
|
220 |
(m) |
|
|
||||||
Income before interest of outside non-controlling partners and income taxes |
|
78,418 |
|
93,536 |
|
(1,867 |
) |
170,087 |
|
(30,513 |
) |
139,574 |
|
||||||
Interest of outside non-controlling partners in Kaneb Pipeline Partners, L.P. |
|
|
|
(65,933 |
) |
|
|
(65,933 |
) |
65,933 |
(j) |
|
|
||||||
Income tax expense |
|
|
|
(3,251 |
) |
|
|
(3,251 |
) |
|
(k) |
(3,251 |
) |
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Income from continuing operations |
|
$ |
78,418 |
|
$ |
24,352 |
|
$ |
(1,867 |
) |
$ |
100,903 |
|
$ |
35,420 |
|
$ |
136,323 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Allocation of income from continuing operations: |
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Income from continuing operations |
|
$ |
78,418 |
|
$ |
24,352 |
|
$ |
(1,867 |
) |
$ |
100,903 |
|
$ |
35,420 |
|
$ |
136,323 |
|
General partners interest in income from continuing operations |
|
(5,927 |
) |
|
|
|
|
(5,927 |
) |
(8,751 |
)(l) |
(14,678 |
) |
||||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Limited partners interest in income from continuing operations |
|
$ |
72,491 |
|
$ |
24,352 |
|
$ |
(1,867 |
) |
$ |
94,976 |
|
$ |
26,669 |
|
$ |
121,645 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Income from continuing operations per unit applicable to limited partners |
|
$ |
3.15 |
|
|
|
|
|
|
|
|
|
$ |
2.60 |
|
||||
|
|
|
|
|
|
|
|
|
|
|
|
|
|
||||||
Weighted average number of limited partnership units outstanding |
|
23,041,394 |
|
|
|
|
|
23,041,394 |
|
23,768,751 |
(d) |
46,810,145 |
|
See Accompanying Notes to Pro Forma Condensed Combined Financial Statements.
Exhibit 99.2 page 5
VALERO L.P.
NOTES TO UNAUDITED PRO FORMA CONDENSED COMBINED FINANCIAL STATEMENTS
(Thousands of Dollars, except unit and per unit data)
Kaneb Services LLC Merger Pro Forma Adjustments:
(a) To reflect the issuance of $525,000 principal amount of 5-year term debt and the payment of $810 of associated debt issuance costs, the proceeds from which were used to acquire the equity securities of KSL. The debt issuance costs were capitalized and will be amortized over the life of the new term debt.
(b) To reflect the acquisition of 100% of the outstanding equity securities of KSL, the assets of which include a 2% general partner interest in KPP, and an approximate 18% limited partner interest in KPP. The following is a preliminary estimate of the purchase price allocation for the KSL merger:
Estimated purchase price (based on $43.31 per share applied to KSLs 11,759,570 shares outstanding at closing) |
|
$ |
509,307 |
|
Less: Carrying value of KSL net assets, including ownership interest in KPP |
|
(68,565 |
) |
|
Excess of estimated purchase price over carrying value of net assets acquired |
|
$ |
440,742 |
|
Under the terms of the KSL Merger Agreement, the aggregate amount of cash paid to KSLs shareholders in the merger did not vary with the market price of Valero L.P. common units at completion of the merger. The KSL shares reflected above include all shares outstanding at the closing date. For purposes of this pro forma analysis, the above excess of estimated purchase price over carrying value of net assets acquired has been allocated to goodwill. All adjustments of the carrying values of the acquired assets and liabilities to fair value, including additional goodwill, are reflected in the KPP merger pro forma adjustments.
(c) To reflect interest expense at approximately 4.0% on net borrowings of $43,000 ($525,000 of new term debt, less $455,000 due to proceeds from the sale of the Held Separate Businesses, less $27,000 due to proceeds from the sale of MOC) of $852 for the six months ended June 30, 2005 and $1,705 for the year ended December 31, 2004, as well as the amortization of deferred debt issuance costs of $81 for the six months ended June 30, 2005 and $162 for the year ended December 31, 2004. A 1/8% change in the interest rate associated with these borrowings would have a $27 and $54 effect on interest expense for the six months ended June 30, 2005 and the year ended December 31, 2004, respectively.
Exhibit 99.2 page 6
Kaneb Pipe Line Partners, L.P. Merger Pro Forma Adjustments:
(d) To reflect the purchase of KPPs remaining 82% limited partner interest through an exchange of Valero L.P. common units. The following is a preliminary estimate of the purchase price for the KPP merger:
KPPs limited partner units outstanding as of June 30, 2005 |
|
28,327,590 |
|
|
Less: KSLs ownership of KPPs limited partner units acquired by Valero L.P. in the KSL merger |
|
5,095,500 |
|
|
Number of KPP limited partner units exchanged for Valero L.P. common units |
|
23,232,090 |
|
|
|
|
|
|
|
Multiplied by the exchange ratio |
|
1.0231 |
(1) |
|
Number of Valero L.P. common units issued in the exchange |
|
23,768,751 |
|
|
|
|
|
|
|
Multiplied by Valero L.P.s common unit value |
|
$ |
61.057 |
(2) |
|
|
|
|
|
Estimated purchase price of KPP merger before transaction-related costs |
|
$ |
1,451,249 |
|
|
|
|
|
|
Estimated transaction-related costs |
|
11,182 |
|
|
Total estimated purchase price of KPP merger |
|
1,462,431 |
|
|
Less: Carrying value of non-controlling partners interest in KPP net assets |
|
(373,333 |
) |
|
Excess of estimated purchase price over carrying value of net assets acquired |
|
$ |
1,089,098 |
(3) |
(1) Under the terms of the merger agreement with KPP, each unit of KPP was exchanged for 1.0231 Valero L.P. common units.
(2) The value of Valero L.P.s common units was determined as the average common unit price (as defined in the merger agreement) from two days before to two days after January 21, 2005, which was determined to be the measurement date.
(3) For purposes of this pro forma analysis, the above estimated purchase price has been allocated based on a preliminary assessment of the fair value of the assets to be acquired and liabilities to be assumed, pending the completion of an independent appraisal. Management does not expect to allocate a significant amount of the purchase price to identifiable intangible assets, as there is little intellectual property involved in the operation of the acquired business. However, the results of the pending appraisal may reflect a value for certain customer contracts or other identifiable intangible assets, the quantification of which cannot be determined at this time. The preliminary purchase price allocation results in the following pro forma adjustments:
Increase in property and equipment |
|
$ |
409,933 |
|
Elimination of Kanebs historical accumulated depreciation |
|
329,352 |
|
|
Decrease in other current assets |
|
(4,403 |
) |
|
Decrease in other noncurrent assets |
|
(3,834 |
) |
|
Elimination of Kanebs historical goodwill |
|
(10,622 |
) |
|
Increase in long-term debt related to the fair value premium |
|
(55,000 |
) |
|
Goodwill resulting from KPP merger |
|
423,672 |
|
|
Excess of estimated purchase price over carrying value of net assets acquired |
|
$ |
1,089,098 |
|
Exhibit 99.2 page 7
(e) To record a capital contribution from the general partner of Valero L.P. of $29,197 to maintain its 2% ownership interest in Valero L.P.
(f) To reflect an accrual of $3,900 for estimated relocation and other costs related mainly to relocating Kaneb employees to Valero L.P.s headquarters.
(g) To reclassify equity earnings from investments in joint ventures of $2,797 and $5,478 for the six months ended June 30, 2005 and the year ended December 31, 2004, respectively in order to conform the financial statement presentations to that of Valero L.P.
(h) To record depreciation expense on the excess purchase price allocated to property and equipment (exclusive of the Held Separate Businesses and MOC) of $2,896 for the six months ended June 30, 2005 and $5,791 for the year ended December 31, 2004 based on an estimated life of 25 years and no salvage value.
(i) To reflect interest expense reductions attributable to amortization of the $55,000 excess of fair value over carrying value of Kanebs debt at June 30, 2005 (i.e., the fair value premium) of $3,953 for the six months ended June 30, 2005 and $7,906 for the year ended December 31, 2004. For pro forma presentation purposes, the fair value premium associated with each Kaneb debt instrument assumed has been amortized from January 1, 2004 or the date of issuance of the debt, whichever is later, over the remaining term of the instrument using the effective interest method. If market rates underlying the fair value of each debt instrument were to increase 1/8%, the pro forma increase in interest expense would be $266 and $533 for the six months ended June 30, 2005 and for the year ended December 31, 2004, respectively.
(j) To eliminate the deduction from income representing the interest of outside non-controlling partners in KPP of $2,158 for the six months ended June 30, 2005 and $65,933 for the year ended December 31, 2004. As a result of the Kaneb mergers, Valero L.P. owns 100% of KSLs and KPPs ownership interests.
(k) The pro forma adjustments to the statements of income have not been tax-effected as the effect on income tax is not material.
(l) To reflect the adjustment to the general partners interest in income from continuing operations that has been calculated assuming quarterly distributions per limited partner unit of $0.855, which was declared and approved by Valero L.P.s board of directors on July 21, 2005. The general partners incentive distribution rights have been calculated as defined by Valero L.P.s partnership agreement. The income from continuing operations applicable to the general partner is reflected in the KPP merger pro forma adjustments to reflect the effect of both mergers. The following reflects the general partners total interest in the pro forma combined income from continuing operations:
|
|
For the Six |
|
For the Year |
|
||
General partners 2% ownership interest in net income from continuing operations |
|
$ |
174 |
|
$ |
2,482 |
|
General partners incentive distribution |
|
6,098 |
|
12,196 |
|
||
Total general partner interest in net income from continuing operations |
|
$ |
6,272 |
|
$ |
14,678 |
|
Exhibit 99.2 page 8
(m) To eliminate the revenues and expenses of the Held Separate Businesses and MOC. The following table summarizes the amount of income before interest of outside non-controlling partners and income taxes associated with the Held Separate Businesses and MOC:
|
|
For the Six |
|
For the Year |
|
||
Held Separate Businesses |
|
$ |
13,451 |
|
$ |
28,860 |
|
MOC |
|
3,016 |
|
3,768 |
|
||
Total |
|
$ |
16,467 |
|
$ |
32,628 |
|
(n) To reflect the assumed sale of the assets of the Held Separate Businesses and MOC and the related reduction of outstanding indebtedness from the sale proceeds. Immediately prior to the sale of MOC, Valero L.P. repaid the outstanding indebtedness of MOC, totaling $9,223, which is included in the adjustment.
(o) Certain of the pro forma adjustments incorporate preliminary estimates of the fair value of assets acquired. The excess of the purchase price over the preliminary fair values (excess cost) may be assigned to non-amortizable goodwill as opposed to depreciable fixed assets or amortizable intangible assets. Shortly after completion of the merger, Valero L.P. will obtain an independent appraisal of Kanebs assets and liabilities in order to develop a definitive allocation of the purchase price. As a result, the final purchase price allocation may result in some amounts being assigned to tangible or amortizable intangible assets apart from goodwill. To the extent that any amount is assigned to a tangible or amortizable intangible asset, this amount will ultimately be depreciated or amortized (as appropriate) to earnings over the expected useful life of the asset. To the extent that any amount remains as goodwill, this amount would not be subject to amortization, but would be subject to periodic impairment testing and if necessary, written down to a lower fair value should circumstances warrant.
The following table shows the preliminary calculation of the estimated pro forma goodwill amount:
Amount
Allocated to Goodwill in Preliminary |
|
|
|
Pro Forma Reference |
|
|
|
|
|
|
|
|
|
Estimated purchase price of KSL merger |
|
$ |
509,307 |
|
Note (b) |
|
Estimated purchase price of KPP merger before transaction-related costs |
|
1,451,249 |
|
Note (d) |
|
|
Estimated transaction-related costs |
|
11,182 |
|
Note (d) |
|
|
Total purchase price |
|
1,971,738 |
|
|
|
|
Estimated fair value of Kaneb net assets at June 30, 2005 |
|
1,107,633 |
|
|
|
|
Excess of purchase price over net assets of Kaneb preliminarily assigned to goodwill |
|
$ |
864,105 |
|
|
|
Valero L.P. historical goodwill prior to the Kaneb Mergers |
|
4,715 |
|
|
|
|
Valero L.P. pro forma combined company goodwill |
|
$ |
868,820 |
|
|
|
Exhibit 99.2 page 9
The tables below show the potential increase in pro forma depreciation or amortization expense if certain amounts of the $864,105 of goodwill identified in the notes above were ultimately assigned to fixed assets or amortizable intangible assets. For purposes of calculating this sensitivity, the straight-line method of cost allocation (i.e., depreciation or amortization) has been applied using an estimated useful life of 25 years and no salvage value. The decrease in basic income per unit is predicated on the income per unit applicable to limited partners reflected in the Valero L.P. Pro Forma Combined with Kaneb column of the unaudited pro forma condensed combined statements of income.
For the Six Months Ended June 30, 2005
Amount
Allocated to Tangible or Intangible Assets Out of |
|
Decrease in |
|
Decrease in |
|
||
|
|
|
|
|
|
||
$172,821 or 20% of preliminary goodwill |
|
$ |
3,457 |
|
$ |
0.07 |
|
$345,642 or 40% of preliminary goodwill |
|
6,913 |
|
0.14 |
|
||
$518,463 or 60% of preliminary goodwill |
|
10,369 |
|
0.21 |
|
||
$691,284 or 80% of preliminary goodwill |
|
13,826 |
|
0.29 |
|
||
$864,105 or 100% of preliminary goodwill |
|
17,282 |
|
0.36 |
|
||
For the Year Ended December 31, 2004
Amount
Allocated to Tangible or Intangible Assets Out of |
|
Decrease in |
|
Decrease in |
|
||
|
|
|
|
|
|
||
$172,821 or 20% of preliminary goodwill |
|
$ |
6,913 |
|
$ |
0.15 |
|
$345,642 or 40% of preliminary goodwill |
|
13,826 |
|
0.29 |
|
||
$518,463 or 60% of preliminary goodwill |
|
20,738 |
|
0.44 |
|
||
$691,284 or 80% of preliminary goodwill |
|
27,651 |
|
0.58 |
|
||
$864,105 or 100% of preliminary goodwill |
|
34,564 |
|
0.72 |
|
||
Exhibit 99.2 page 10