UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

x                              Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended September 30, 2006

OR

o                                 Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from                      to                      

Commission File Number 1-31345

PACIFIC ENERGY PARTNERS, L.P.

(Exact name of registrant as specified in its charter)

5900 Cherry Avenue
Long Beach, CA 90805-4408

(Address of principal executive offices)

(562) 728-2800

(Registrant’s telephone number, including area code)

None

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days. Yes x  No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act.

Large accelerated filer  o                 Accelerated filer  x                 Non-accelerated filer  o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o  No x

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

PACIFIC ENERGY PARTNERS, L.P.
FORM 10-Q
TABLE OF CONTENTS

PART I.   FINANCIAL INFORMATION

ITEM 1.              Financial Statements

PACIFIC ENERGY PARTNERS, L.P.
CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)

See accompanying notes to condensed consolidated financial statements.

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PACIFIC ENERGY PARTNERS, L.P.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)

See accompanying notes to condensed consolidated financial statements.

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PACIFIC ENERGY PARTNERS, L.P.
CONDENSED CONSOLIDATED STATEMENT OF PARTNERS’ CAPITAL
(Unaudited)

See accompanying notes to condensed consolidated financial statements.

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PACIFIC ENERGY PARTNERS, L.P.
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
(Unaudited)

See accompanying notes to condensed consolidated financial statements.

4

PACIFIC ENERGY PARTNERS, L.P.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

See accompanying notes to condensed consolidated financial statements.

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PACIFIC ENERGY PARTNERS, L.P.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
September 30, 2006
(Unaudited)

1.   SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

Pacific Energy Partners, L.P. and its subsidiaries (collectively, the “Partnership”) are engaged principally in the business of gathering, transporting, storing and distributing crude oil, refined products and other related products. The Partnership generates revenue primarily by transporting such commodities on its pipelines, by leasing storage capacity in its storage tanks, and by providing other terminaling services. The Partnership also buys and sells crude oil, activities that are generally complementary to its other crude oil operations. The Partnership conducts its business through two business units, the West Coast Business Unit, which includes activities in California and the Philadelphia, Pennsylvania area, and the Rocky Mountain Business Unit, which includes activities in five Rocky Mountain states and Alberta, Canada.

The Partnership is managed by its general partner, Pacific Energy GP, LP, a Delaware limited partnership, which is managed by its general partner, Pacific Energy Management LLC (“PEM”), a Delaware limited liability company. Thus, the officers and board of directors of PEM manage the business affairs of Pacific Energy GP, LP and the Partnership. References to the “General Partner” refer to Pacific Energy GP, LP and/or PEM, as the context indicates; and “Board of Directors” refers to the board of directors of PEM.

The unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America for interim financial reporting and with Securities and Exchange Commission (“SEC”) regulations. Accordingly, these statements have been condensed and do not include all of the information and footnotes required for complete financial statements. These statements involve the use of estimates and judgments where appropriate. In the opinion of management, all adjustments, consisting of normal recurring accruals considered necessary for a fair presentation, have been included. The results of operations for the nine months ended September 30, 2006 are not necessarily indicative of the results of operations for the full year. All significant intercompany balances and transactions have been eliminated during the consolidation process.

The condensed consolidated financial statements include the ownership and results of operations of the assets acquired from Valero, L.P., since the acquisition of these assets on September 30, 2005. The assets acquired from Valero, L.P. have been integrated into our West Coast and Rocky Mountain Business Units as Pacific Atlantic Terminals and the Rocky Mountain Products Pipeline.

These financial statements should be read in conjunction with the Partnership’s audited consolidated financial statements and notes thereto included in the Partnership’s annual report on Form 10-K and Form 10-K/A for the year ended December 31, 2005. Certain prior year balances in the accompanying condensed consolidated financial statements have been reclassified to conform to the current year presentation.

New Accounting Pronouncements

In December 2004, the Financial Accounting Standards Board (“FASB”) issued Statement of Financial Accounting Standards No. 123 (revised December 2004), Share-Based Payment (SFAS 123R). This Statement is a revision of SFAS No. 123. SFAS 123R establishes standards for the accounting for

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transactions in which an entity exchanges its equity instruments for goods or services. SFAS 123R is effective for the Partnership as of the beginning of the first interim period or annual reporting period that begins after June 15, 2005. The adoption of SFAS 123R on January 1, 2006 did not have a material impact on the Partnership’s consolidated financial statements. See Notes 5 and 7 to the condensed consolidated financial statements for more details on share-based compensation.

In September 2005, the Emerging Issues Task Force (“EITF”) issued Issue No. 04-13 (“EITF 04-13”), Accounting for Purchases and Sales of Inventory with the Same Counterparty. The issues addressed by the EITF are (i) the circumstances under which two or more exchange transactions involving inventory with the same counterparty should be viewed as a single exchange transaction for the purposes of evaluating the effect of APB No. 29; and (ii) whether there are circumstances under which nonmonetary exchanges of inventory within the same line of business should be recognized at fair value. EITF 04-13 is effective for new arrangements entered into in the reporting periods beginning after March 15, 2006, and to all inventory transactions that are completed after December 15, 2006, for arrangements entered into prior to March 15, 2006. The adoption of EITF 04-13 did not have a material impact on the Partnership’s consolidated financial statements.

In June 2006, the FASB issued FASB Interpretation No. 48 (“FIN 48”), Accounting for Uncertainty in Income Taxes. This Interpretation prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This Interpretation also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure, and transition. FIN 48 will apply to the Partnership’s Canadian subsidiaries, which are taxable entities in Canada. The Partnership is in the process of determining the impact of FIN 48 on its financial statements, but does not expect it to have a material impact. FIN 48 is effective for the Partnership as of the beginning of the first fiscal year beginning on January 1, 2007.

In June 2006, the EITF issued Issue No. 06-3 (“EITF 06-3”), How Taxes Collected from Customers and Remitted to Governmental Authorities Should Be Presented in the Income Statement (That Is, Gross versus Net Presentation). The issues addressed by the EITF are (i) whether the scope of this Issue should include (a) all nondiscretionary amounts assessed by governmental authorities, (b) all nondiscretionary amounts assessed by governmental authorities in connection with a transaction with a customer, or (c) only sales, use, and value added taxes, and (ii) how taxes assessed by a governmental authority within the scope of this issue should be presented in the income statement (that is, gross versus net presentation). EITF 06-3 is effective for interim and annual financial periods beginning after December 15, 2006. The Partnership is in the process of determining the impact of EITF 06-3 on its financial statements, but does not expect it to have a material impact.

In September 2006, the FASB issued Statement of Financial Accounting Standards No. 157, Fair Value Measurements (“SFAS 157”). SFAS 157 defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles, and expands disclosures about fair value measurements. SFAS 157 applies under other accounting pronouncements that require or permit fair value measurements in those accounting pronouncements. Accordingly, SFAS 157 does not require any new fair value measurements. However, the Partnership is in the process of determing what impact the application of SFAS 157 will have on its current fair value practices. The Partnership does not expect the application of SFAS 157 to have a material impact. SFAS 157 is effective for financial statements issued for fiscal years beginning after November 15, 2007.

In September 2006, the Securities and Exchange Commission issued Staff Accounting Bulletin No. 108, Considering the Effects of Prior Year Misstatements when Quantifying Misstatements in Current year Financial Statements (“SAB 108”), which provides interpretive guidance on how the effects of the carryover or reversal of prior year misstatements should be considered in quantifying a current year misstatement. The guidance is effective for fiscal years beginning after November 15, 2006 and it allows a one-time

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transitional cumulative effect adjustment to beginning-of-year retained earnings at the first fiscal year ending after November 15, 2006 for errors that were not previously deemed material, but are material under the guidance in SAB 108. The Partnership is currently evaluating the impact, if any, of adopting SAB 108 on its consolidated financial statements.

2.   PROPOSED MERGER WITH PLAINS ALL AMERICAN PIPELINE, L.P.

On June 12, 2006, the Partnership announced that it had entered into an Agreement and Plan of Merger with Plains All American Pipeline, L.P. (“PAA”), Plains AAP, L.P., Plains All American GP LLC (“PAA GP LLC”), PEM, and Pacific Energy GP, LP, pursuant to which the Partnership will be merged with and into PAA. In the merger, each common unitholder of the Partnership, except LB Pacific, LP (“LB Pacific”), the owner of the Partnership’s General Partner, will receive 0.77 common units of PAA for each common unit of the Partnership that the unitholder owns. In addition, pursuant to a purchase agreement between LB Pacific and PAA, PAA will acquire from LB Pacific the general partner interest and incentive distribution rights of the Partnership, as well as 5,232,500 common units and 5,232,500 subordinated units, for total consideration of $700 million in cash. The merger agreement was unanimously approved by the Board of Directors of PEM, as well as by the board of directors of PAA’s general partner.

Each of the Partnership and PAA made customary representations, warranties and covenants in the merger agreement, which are described in the joint proxy statement/prospectus filed by the Partnership and PAA with the Securities and Exchange Commission (the “SEC”). The merger is subject to the satisfaction or waiver of certain conditions, including the receipt of various regulatory approvals or the expiration of various regulatory waiting periods, all of which approvals or waiting periods have been obtained, and the adoption and approval of the merger agreement and the merger by the holders of at least a majority of the Partnership’s outstanding common units (excluding common units held by LB Pacific) and outstanding subordinated units, each voting as a separate class. The merger agreement and the merger must also be adopted and approved by the holders of at least a majority of PAA’s outstanding common units.

The Partnership’s and PAA’s special meetings of unitholders to consider the merger agreement and the merger are scheduled to occur on November 9, 2006. Although the Partnership and PAA cannot be sure when all of the conditions to the merger will be satisfied, the parties expect to complete the merger on November 15, 2006 (assuming the proposals are approved by the unitholders and all other conditions to closing are satisfied).

During the three and nine months ended September 30, 2006, the Partnership incurred approximately $1.1 million and $4.5 million, respectively, in costs directly relating to the merger for investment banking fees, legal fees and other transaction costs. Approximately $0.7 million of investment banking fees were paid to affiliates of Lehman Brothers Inc., an affiliate of the General Partner (see “Note 5—Related Party Transactions”). These costs are included in the condensed consolidated statements of income under the caption “Merger costs”.

3.   INCOME TAXES

The Partnership and its U.S. and Canadian subsidiaries are not taxable entities in the U.S. and are not subject to U.S. federal or state income taxes, as the tax effect of operations is passed through to its unitholders. However, the Partnership’s Canadian subsidiaries are taxable entities in Canada and are subject to Canadian federal and provincial income taxes. In addition, inter-company interest payments and repatriation of funds through dividend payments are subject to withholding tax.

Income taxes for the Partnership’s Canadian subsidiaries are accounted for under the asset and liability method. Under this method, deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing

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assets and liabilities and their respective tax bases, and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates on deferred tax assets and liabilities is recognized in operations in the period that includes the enactment date. The Partnership intends to repatriate its Canadian subsidiaries’ earnings in the future and accordingly has recorded a provision for Canadian withholding taxes.

In the second quarter of 2006, the Canadian and Alberta governments enacted legislation which will reduce federal and provincial income taxes. The Partnership adjusted the future income tax rates used in the estimates of deferred tax assets and liabilities and recognized a $4.6 million deferred tax benefit in the quarter ended June 30, 2006.

4.   NET INCOME PER LIMITED PARTNER UNIT

Net income is allocated to the Partnership’s General Partner and limited partners based on their respective interests in the Partnership. The Partnership’s General Partner is also directly charged with specific costs that it has individually assumed and for which the limited partners are not responsible.

Basic net income per limited partner unit is determined by dividing net income, after adding back costs and deducting certain amounts allocated to the General Partner (including incentive distribution payments in excess of its 2% ownership interest), by the weighted average number of outstanding limited partner units.

Diluted net income per limited partner unit is calculated in the same manner as basic net income per limited partner unit above, except that the weighted average number of outstanding limited partner units is increased to include the dilutive effect of outstanding options, if any, and restricted units by application of the treasury stock method.

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Set forth below is the computation of net income allocated to limited partners and net income per basic and diluted limited partner unit. The table also shows the reconciliation of basic average limited partner units to diluted weighted average limited partner units.

(1)          See “Note 5—Related Party Transactions” for a description of transaction costs reimbursed by the General Partner.

5.   RELATED PARTY TRANSACTIONS

Cost Reimbursements

Managing General Partner:   The Partnership’s General Partner employs all U.S.-based employees. All employee expenses incurred by the General Partner on behalf of the Partnership are charged back to the Partnership.

LB Pacific, LP Option Plan:   LB Pacific, LP (“LB Pacific”), the owner of the Partnership’s General Partner, has adopted an option plan for certain officers, directors, employees, advisors, and consultants of PEM, LB Pacific, and their affiliates. Under the plan, participants may be granted options to acquire partnership interests in LB Pacific. The Partnership is not obligated to pay any amounts to LB Pacific for the benefits granted or paid to any participants under the plan, although generally accepted accounting principles require that the Partnership record an expense in its financial statements for benefits granted to employees of PEM or the Partnership who provide services to the Partnership, with a corresponding increase in the General Partner’s capital account.

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The option plan is administered by the board of directors of LB Pacific GP, LLC, the general partner of LB Pacific. The terms, conditions, performance goals, restrictions, limitations, forfeiture, vesting or exercise schedule, and other provisions of grants under the plan, as well as eligibility to participate, are determined by the board of directors of LB Pacific GP, LLC. The board of directors of LB Pacific GP, LLC may determine to grant options under the plan to participants containing such terms as the board of LB Pacific GP, LLC shall determine. Options will have an exercise price that may not be less than the fair market value of the units on the date of grant.

Information concerning the plan and grants is shared by LB Pacific, LP with the General Partner’s Compensation Committee and Board of Directors, and considered in determining the long term incentive compensation paid by the Partnership to participants in the plan.

In January 2006, LB Pacific granted options representing a maximum 24% interest in LB Pacific (assuming all options vest and are exercised), which options vest over a period of 10 years from the date of grant (except in limited circumstances such as a change in control), to certain officers and key employees of PEM and the Partnership. The grants, qualified as equity-classified awards, had a grant date fair value of $8.6 million. The fair value of the options was determined using valuation techniques that included the discounted present value of estimated future cash flows for LB Pacific and fundamental analysis. It was measured using the Black-Scholes option pricing model with the following assumptions:

For the three and nine months ended September 30, 2006, the Partnership recognized $0.4 million and $1.3 million in compensation expense relating to the LB Pacific options and recorded a capital contribution from the General Partner for the same amounts. At September 30, 2006, all granted LB Pacific options remained outstanding. At September 30, 2006, there was $7.3 million of total unrecognized compensation cost related to nonvested options granted under the plan, which cost was expected to be recognized over the remaining period of 9.25 years. Upon the close of the proposed merger with PAA, the options will become immediately exercisable. Total unrecognized compensation expense on the closing date will be immediately recognized in the income statement.

LB Pacific, LP and Anschutz:   Prior to March 3, 2005, the General Partner was owned by The Anschutz Corporation (“Anschutz”). On March 3, 2005, Anschutz sold its interest in the Partnership, including its interest in the General Partner, to LB Pacific. In connection with the sale of Anschutz’s interest in the Partnership to LB Pacific, LB Pacific and Anschutz reimbursed the Partnership for certain costs incurred in connection with the acquisition. The Partnership was reimbursed $1.2 million for costs incurred in connection with the consent solicitation, $0.3 million of legal and other costs, and $0.9 million relating to severance costs, for a total of $2.4 million. Of the $2.4 million total incurred, $1.8 million was expensed, as shown on the income statement as “reimbursed general partner transaction costs,” and $0.6 million of the consent solicitation costs were capitalized as deferred financing costs.

Special Agreement:   On March 3, 2005, Douglas L. Polson, previously the Chairman of the Board of Directors, entered into a Special Agreement and a Consulting Agreement with PEM. In accordance with the Special Agreement, Mr. Polson resigned as Chairman of the Board of Directors effective March 3, 2005. Mr. Polson was paid approximately $0.9 million, representing accrued salary through March 3, 2005, accrued but unused vacation, and payment in satisfaction of other obligations under his employment agreement. The latter portion of this payment was recorded as an expense in “Reimbursed general partner transaction costs” in the accompanying condensed consolidated income statements. LB Pacific reimbursed this amount, which was recorded as a partner’s capital contribution. Pursuant to the Consulting

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Agreement, Mr. Polson agreed to perform advisory services to PEM from time to time as mutually agreed between Mr. Polson and the Chief Executive Officer of PEM. In consideration for Mr. Polson’s services under the Consulting Agreement, which had a one-year term, Mr. Polson received a monthly consulting fee of $12,500 and reimbursement of all reasonable business expenses incurred or paid by Mr. Polson in the course of performing his duties thereunder.

Lehman Brothers, Inc.

Lehman Brothers, Inc. is deemed to be an affiliate of the Partnership’s General Partner through a 59% ownership interest in LB Pacific, which is controlled by Lehman Brothers Holdings Inc., the parent entity of Lehman Brothers, Inc. Lehman Brothers, Inc. acted as financial advisor to LB Pacific and the Partnership in connection with the proposed merger and the transactions related to the merger (see Note 2—Proposed Merger With Plains All American, L.P.). As part of its services, Lehman Brothers, Inc. delivered an opinion to the Board of Directors to the effect that, as of the date of its opinion and based on and subject to various assumptions made, the aggregate consideration to be offered to all of the holders of the partnership interests in the Partnership in the proposed merger transaction is fair to such holders. The agreement with Lehman Brothers, Inc. was reviewed and approved by the Conflicts Committee of the Board of Directors and the fees charged were customary for the type of services provided. The Partnership incurred $0.7 million in fees with Lehman Brothers, Inc. for the nine months ended September 30, 2006, none of which was incurred in the three months ended September 30, 2006. The Partnership has agreed to pay Lehman Brothers, Inc. an additional $7.7 million success fee contingent on the successful consummation of the merger.

In connection with the purchase and the associated financing of the Partnership’s purchase of certain terminal and pipeline assets from Valero, L.P. in September 2005, including a private equity offering, public equity offering, debt offering and new credit facility, Lehman Brothers, Inc. and its affiliates provided advisory and underwriting services to the Partnership. Additionally, an affiliate of Lehman Brothers, Inc. is a participant in the syndicate that provided the Partnership’s new senior secured credit facility. These agreements with Lehman Brothers, Inc. were reviewed and approved by the Conflicts Committee of the Board of Directors and the fees charged were customary for the types of services provided. For the three and nine months ended September 30, 2005, the Partnership incurred $9.8 million in fees with Lehman Brothers, Inc. and its affiliates, a portion of which was paid to non-affiliated financial institutions in the syndication of the new credit facility and in the public offering of equity.

Other Related Party Transactions

RMPS receives an operating fee and management fee from Frontier Pipeline Company (“Frontier”) in connection with time spent by RMPS management and for other services related to Frontier’s activities. RMPS received $0.2 million for each of the three months ended September 30, 2006 and 2005 and $0.6 million for each of the nine months ended September 30, 2006 and 2005, respectively. The Partnership owns a 22.22% partnership interest in Frontier.

6.   CONTINGENCIES

Line 63 Oil Release

In March 2005, a release of approximately 3,400 barrels of crude oil occurred on the Partnership’s Line 63 when it was severed as a result of a landslide caused by heavy rainfall in the Pyramid Lake area of Los Angeles County. Over the period March 2005 through anticipated completion in June 2007, the Partnership expects to incur an estimated total of $25.5 million for oil containment and clean-up of the impacted areas, future monitoring costs, potential third-party claims and penalties, and other costs, excluding pipeline repair costs. As of September 30, 2006, the Partnership had incurred

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approximately 22.3 illion of the total expected remediation costs related to the oil release for work performed through that date. The Partnership estimates that the $3.2 million of remaining remediation cost will substantially be incurred before June 2007.

In March 2006, Pacific Pipeline System LLC (“PPS”), a subsidiary of the Partnership, was served with a four count misdemeanor action by the state of California, which alleges that PPS violated various state statutes by depositing oil or substances harmful to wildlife into the environment and by the willful and intentional discharge of pollution into state waters. The Partnership estimates that the maximum fine and penalties that could be assessed for these actions is approximately $0.9 million in the aggregate. The Partnership believes, however, that certain of the alleged violations are without merit and intends to defend against them, and that mitigating factors should otherwise reduce the amounts of any potential fines or penalties that might be assessed. At this time, the Partnership cannot reasonably determine the outcome of these allegations. The estimated range of possible fines or penalties including amounts not covered by insurance is between $0 and $0.9 million.

The Partnership has a pollution liability insurance policy with a $2.0 million per-occurrence deductible that covers containment and clean-up costs, third-party claims and certain penalties. The insurance carrier has, subject to the terms of the insurance policy, acknowledged coverage of the incident and is processing and paying invoices related to the clean-up. The Partnership believes that, subject to the $2.0 million deductible, it will be entitled to recover substantially all of its clean-up costs and any third-party claims associated with the release. As of September 30, 2006, the Partnership has recovered $18.6 million from insurance and recorded net receivables of $4.6 million for future insurance recoveries it deems probable.

The foregoing estimates are based on facts known at the time of estimation and the Partnership’s assessment of the ultimate outcome. Among the many uncertainties that impact the estimates are the necessary regulatory approvals for, and potential modification of, remediation plans, the ongoing assessment of the impact of soil and water contamination, changes in costs associated with environmental remediation services and equipment, and the possibility of third-party legal claims giving rise to additional expenses. Therefore, no assurance can be made that costs incurred in excess of this provision, if any, would not have a material adverse effect on the Partnership’s financial condition, results of operations, or cash flows, though the Partnership believes that most, if not all, of any such excess cost, to the extent attributable to clean-up and third-party claims, would be recoverable through insurance. In March 2006, A.M. Best Company, an insurance company rating agency, announced it had downgraded the financial strength rating assigned to the Partnership’s insurance carrier, Quanta Specialty Lines Company, including its parent and affiliates. The downgrade was from an “A” to a “B++, under review with negative implications.” During the second quarter of 2006, Quanta announced that their Board of Directors decided to cease underwriting or seeking new business and to place most of its remaining specialty insurance and reinsurance lines into orderly run-off. On June 7, 2006 A. M. Best further downgraded Quanta from B++ to B. Subsequent to this downgrading, Quanta was removed from A. M. Best’s interactive rating process, at Quanta’s request. Based on management’s further analysis of Quanta’s financial condition, the Partnership believes that Quanta will continue to meet its obligations relating to the Line 63 oil release, although there can be no assurance that this will be the case. As new information becomes available in future periods, the Partnership may change its provision and recovery estimates.

Product Contamination

In June 2006, approximately 44,000 barrels of a customer’s product at our Martinez terminal was contaminated. The Partnership has insurance coverage for the damage or loss of its customers’ products while in its care, custody and control at certain of its terminals subject to a $0.1 million per-occurrence deductible. The Partnership recognized a loss of $0.2 million to cover the insurance deductible and other associated costs. At this time, the Partnership believes costs related to the contamination of the property will be covered under the insurance policy, and has accrued an estimated $1.1 million in total costs, which

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is included in “Other current liabilities” in the accompanying condensed consolidated balance sheet. The Partnership has recorded a receivable of $0.9 million for future insurance recoveries it deems probable.

Litigation

On June 15, 2006, a lawsuit was filed in the Superior court of California, County of Los Angeles, entitled Kosseff v. Pacific Energy, et al, case no. BC 3544016. The plaintiff alleged that he was a unitholder of the Partnership and he sought to represent a class comprising all of the Partnership’s unitholders. The complaint named as defendants the Partnership and certain of the officers and directors of the Partnership’s general partner, and asserted claims of self-dealing and breach of fiduciary duty in connection with the pending merger with PAA and related transactions. The plaintiff sought injunctive relief against completing the merger or, if the merger was completed, rescission of the merger, other equitable relief, and recovery of the plaintiff’s costs and attorneys’ fees. On September 14, 2006, the Partnership and the other defendants entered into a memorandum of settlement with the plaintiff to settle the lawsuit. As part of the settlement, the Partnership and the other defendants deny all allegations of wrongdoing and maintain that they are willing to settle the lawsuit solely because the settlement would eliminate the burden and expense of further litigation. The settlement is subject to customary conditions, including court approval. As part of the settlement, the Partnership will, subject to the consummation of the merger, pay $475,000 to the plaintiff’s counsel for their fees and expenses, and incur approximately $0.1 to $0.2 million for costs of mailing materials to unitholders. If finally approved by the court, the settlement will resolve all claims that were or could have been brought on behalf of the proposed settlement class in the actions being settled, including all claims relating to the merger, the merger agreement and any disclosure made by the Partnership in connection with the merger. The settlement will not change any of the terms or conditions of the merger. The Partnership will record the settlement amount and associated costs upon completion of the merger.

In August, 2005, Rangeland Pipeline Company (“RPC”), a wholly-owned subsidiary of the Partnership, learned that a Statement of Claim was filed by Desiree Meier and Robert Meier in the Alberta Court of Queen’s Bench, Judicial District of Red Deer, naming RPC as defendant, and alleging personal injury and property damage caused by an alleged release of petroleum substances onto plaintiff’s land by a prior owner and operator of the pipeline that is currently owned and operated by the Partnership. The claim seeks Cdn$1 million (approximately U.S.$0.9 million at September 30, 2006) in general damages, Cdn$2 million (approximately U.S.$1.8 million at September 30, 2006) in special damages, and, in addition, unspecified amounts for punitive, exemplary and aggravated damages, costs and interest. RPC believes the claim is without merit, and intends to vigorously defend against it. RPC also believes that certain of the claims, if successfully proven by the plaintiffs, would be liabilities retained by the pipeline’s prior owner under the terms of the agreement whereby the Partnership acquired the pipeline in question.

In connection with the acquisition of assets from Valero, L.P. in September 2005, the Partnership assumed responsibility for the defense of a lawsuit filed in 2003 against Support Terminals Services, Inc. (“ST Services”) by ExxonMobil Corporation (“ExxonMobil”) in New Jersey state court. The Partnership has also assumed any liability that might be imposed on ST Services as a result of the suit. In the suit, ExxonMobil seeks reimbursement of approximately $400,000 for remediation costs it has incurred, from GATX Corporation, Kinder Morgan Liquid Terminals, the successor in interest to GATX Terminals Corporation, and ST Services. ExxonMobil also seeks a ruling imposing liability for any future remediation and related liabilities on the same defendants. These costs are associated with the Paulsboro, New Jersey terminal that was acquired by the Partnership on September 30, 2005. ExxonMobil claims that the costs and future remediation requirements are related to releases at the site subsequent to its sale of the terminal to GATX in 1990 and that, therefore, any remaining remediation requirements are the responsibility of GATX Corporation, Kinder Morgan and ST Services. The Partnership believes the claims against ST Services are without merit, and intends to vigorously defend against them.

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In 2001, Big West Oil Company and Chevron Products Company (the “Complainants”) filed complaints against Frontier Pipeline Company (“Frontier”) with the Federal Energy Regulatory Commission (“FERC”) challenging rates contained in joint tariffs in which Frontier was a participating carrier and rates contained in local tariffs filed by Frontier. On February 18, 2004, the FERC found against Frontier on certain of the Complainants’ claims and ordered Frontier to pay reparations to Complainants in the aggregate amount of approximately $4.2 million, plus interest, which Frontier paid in August 2004. On October 5, 2004, Frontier filed a petition for review of the FERC’s reparations orders in the U.S. Court of Appeals for the D.C. Circuit, and on May 26, 2006 the Court of Appeals held that the FERC’s reparation ruling was inconsistent with applicable law, and thus vacated the FERC’s order and remanded the matter back to the FERC for further consideration consistent with the Court of Appeals’ decision. On July 25, 2006, Frontier filed a motion asking the FERC to dismiss the reparations complaints of the Complainants on the grounds that their complaints fail to state claims that can be sustained consistent with the ruling of the Court of Appeals. Frontier’s motion also asked the FERC to order the refund by the Complainants of the reparations previously paid by Frontier, plus interest. The Complainants have, in a response to Frontier’s motion, asserted for various reasons that the FERC should essentially reinstate its original ruling that ordered Frontier to pay reparations to the Complainants. No action on the motions has been taken by the FERC. If Frontier prevails on its motion or in any remand proceeding conducted by the FERC, it would be entitled to repayment in the amount of $5.4 million, plus interest thereon from August 23, 2004. The Partnership owns 22.22% of Frontier. Although the Partnership believes Frontier’s motion to dismiss the complaints, as well as the defenses it would assert in a remand proceeding before the FERC, are meritorious, the Partnership cannot predict the outcome of any such actions, and has not recorded any amount for this contingency.

The Partnership is involved in various other regulatory disputes, litigation and claims arising out of its operations in the normal course of business. The Partnership is not currently a party to any legal or regulatory proceedings the resolution of which could be expected to have a material adverse effect on its business, financial condition, liquidity or results of operations.

7.   RESTRICTED UNITS

A restricted unit is a “phantom” unit under the Partnership’s long term incentive compensation plan. A phantom unit entitles the grantee to receive a common unit upon the vesting of the phantom unit. The Partnership intends the issuance of the restricted units under the plan to serve as a means of incentive compensation for performance and not primarily as an opportunity to participate in the equity appreciation of the common units. Therefore, plan participants will not pay any consideration for the common units they receive, and the Partnership will receive no remuneration for such units.

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In January 2006 and May 2006, the General Partner awarded 89,110 restricted units to key employees and outside directors that vest over a three-year period, beginning on March 1, 2006 and March 1, 2007, respectively. The number of units to be delivered to key employees in any year, if any, will be based on accomplishment of performance targets (measured by distributable cash flow) for the previous calendar year, subject to the Compensation Committee’s authority to subsequently adjust performance targets as it may deem appropriate, in its discretion. Restricted unit activity during the nine months ended September 30, 2006 is as follows:

Compensation expense recognized for outstanding restricted units is based on grant date fair value of the common units to be awarded to the grantee upon vesting of the phantom unit, adjusted for the expected target performance level for each year. For the three and nine months ended September 30, 2006, the Partnership incurred $0.2 million and $0.8 million, respectively, in compensation expense for restricted units it deemed probable of achieving the performance criteria, including the amount for the first vesting of these awards which occurred on March 1, 2006.

The outstanding unit grants include change of control provisions that require immediate vesting of units in the event of a change in control of the Partnership or its General Partner. Upon the close of the proposed merger with PAA, all outstanding restricted units will immediately vest pursuant to the terms of the grants, and any remaining unamortized compensation expense will be immediately recognized.

On March 3, 2005, in connection with LB Pacific’s acquisition of the Partnership’s General Partner, all restricted units then outstanding under the Partnership’s Long-Term Incentive Plan immediately vested pursuant to the terms of the grants. The Partnership issued 99,583 common units and recognized a compensation expense of $3.1 million, which is included in “Accelerated long-term incentive plan compensation expense” in the accompanying condensed consolidated statements of income. Of the total $3.1 million, the compensation expense categorization was $0.6 million for operating personnel and $2.5 million for general and administrative personnel.

8.   SEGMENT INFORMATION

The Partnership’s business and operations are organized into two business segments: the West Coast Business Unit and the Rocky Mountain Business Unit. The West Coast Business Unit includes: (i) Pacific Pipeline System LLC, owner of Line 2000 and Line 63, (ii) Pacific Marketing and Transportation LLC (West Coast Business Unit operations), owner of the PMT gathering system and marketer of crude oil, (iii) Pacific Terminals LLC, owner of the Pacific Terminals storage and distribution system, and (iv) Pacific Atlantic Terminals LLC, owner of the San Francisco and Philadelphia area terminals, which were acquired on September 30, 2005. The Rocky Mountain Business Unit includes: (i) Rocky Mountain Pipeline System LLC, owner of the Partnership’s interest in various pipelines that make up the Western Corridor and Salt Lake City Core systems, and the Rocky Mountain Products Pipeline, which was acquired on September 30, 2005, (ii) Ranch Pipeline LLC, the owner of a 22.22% partnership interest in Frontier Pipeline Company, (iii) PEG Canada, L.P. and its Canadian subsidiaries, which own and operate the Rangeland system, and

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(iv) Pacific Marketing and Transportation LLC (Rocky Mountain Business Unit operations), a marketer of crude oil.

General and administrative costs, which consist of executive management, accounting and finance, human resources, information technology, investor relations, legal, and business development, are not allocated to the individual business units. Information regarding these two business units is summarized below: