Exhibit 99.1
Pacific Energy Partners, L.P. Reports Earnings for Second Quarter 2005
LONG BEACH, Calif.--(BUSINESS WIRE)--Aug. 2, 2005--Pacific Energy
Partners, L.P. (NYSE:PPX) ("Pacific") announced that net income for
the three months ended June 30, 2005, was $12.2 million, or $0.40 per
limited partner unit, compared to net income of $9.1 million, or $0.30
per limited partner unit, for the period ended June 30, 2004.
Recurring net income for the three months ended June 30, 2005, was
also $12.2 million, or $0.40 per limited partner unit, compared to
recurring net income of $12.0 million, or $0.40 per limited partner
unit, in the second quarter of 2004. All per unit amounts in the text
of this news release are reported on a diluted basis. Recurring net
income for the second quarter of 2004 excludes a $2.9 million write
off of deferred financing costs associated with last year's bond
offering and term loan repayment.
The results for the quarter ended June 30, 2005, reflect increased
pipeline volumes in the Rocky Mountains, higher tank utilization and
additional storage capacity for Pacific Terminals, and the benefit of
a full quarter of operations in 2005 for the Rangeland system, which
was acquired in May 2004. These increases were offset by lower
pipeline volumes on the West Coast and by $1.4 million of pipeline
repair and maintenance costs associated with earth movement and stream
erosion due to heavy rainfall in Southern California.
For the six months ended June 30, 2005, net income was $15.6
million, or $0.58 per limited partner unit, compared to $17.2 million,
or $0.62 per limited partner unit, for the period ended June 30, 2004.
Recurring net income for the six months ended June 30, 2005, was $22.6
million, or $0.74 per limited partner unit, compared with $20.1
million, or $0.72 per limited partner unit, for the six months ended
June 30, 2004. Net income for the first six months of 2005 reflects
the benefit of a full six months of operations in 2005 for the
Rangeland system, which was acquired in May 2004, higher pipeline
volumes in the Rocky Mountains, and higher storage and terminaling
revenues for Pacific Terminals. Offsetting these increases were
significantly lower gathering and blending margins from PMT compared
to higher than average margins experienced in the same period of 2004,
and $2.0 million of unscheduled repairs and maintenance associated
with earth movement and stream erosion problems caused by the heavy
rainfall in Southern California.
Recurring net income for the six months ended June 30, 2005,
excludes a $2.0 million expense for the insurance deductible
associated with the remediation of the Pyramid Lake oil release on
Line 63, a $3.1 million expense related to the accelerated vesting of
restricted units under Pacific's long-term incentive plan as a result
of the change in control attributable to the purchase of Pacific's
general partner by LB Pacific, LP, and a $1.8 million expense as a
result of the general partner transaction (an item that was required
to be recorded as a partnership expense with the general partner's
payment of it recorded as a capital contribution). Recurring net
income for the six months ended June 30, 2004, excludes the $2.9
million write off of deferred financing costs.
"We are pleased with the continued progress of our two strategic
business units, which we expect will be further enhanced by the
acquisition of storage and pipeline assets from Valero L.P. that was
previously announced. Our May 2004 Rangeland acquisition continues to
exceed expectations, and has also been adding value to our U.S. Rocky
Mountain pipelines. We are currently progressing a series of expansion
projects to increase capacity on the Glacier system, Frontier
pipeline, and the Salt Lake City Core system to be completed in phases
over the next several years," stated Irv Toole, President and CEO of
Pacific. "Our second quarter results continue to show the strength of
the Pacific Terminals storage and distribution system on the West
Coast. That, coupled with the pipeline volume growth that our Rocky
Mountain business unit has experienced, has offset the effect of lower
West Coast pipeline volumes and significant pipeline repair costs
associated with record rainfall in Southern California."
On July 21, 2005, Pacific announced a cash distribution of $0.5125
per unit for the second quarter of 2005, or $2.05 per unit annualized.
This is unchanged from the first quarter 2005 distribution level and
is 5.1% higher than the second quarter 2004 distribution level. The
distribution will be paid on August 12, 2005, to holders of record as
of August 1, 2005.
Distributable cash flow available to the limited partners'
interest for the second quarter of 2005 was $18.2 million. On a
diluted weighted average basis, there were 29,742,000 limited partner
units outstanding during the second quarter of 2005.
Pursuant to the terms of the partnership agreement, on August 12,
2005, 2,616,250 subordinated units owned by LB Pacific, LP will
convert on a one-for-one basis to common units. The conversion of the
subordinated units will not affect future cash distributions.
OPERATING RESULTS BY SEGMENT
WEST COAST BUSINESS UNIT
Operating income was $12.4 million for the three months ended June
30, 2005, compared to $14.1 million in the corresponding period in
2004.
West Coast pipeline volumes for the three months ended June 30,
2005, were approximately 14% lower than in the second quarter of 2004.
During the quarter, volumes were impacted by unplanned Los Angeles
area refinery maintenance, lower Outer Continental Shelf (OCS)
production due to maintenance activities, natural production decline,
and diversion of some volumes north to San Francisco. In addition,
although Pacific was able to shift significant volumes of crude oil
from Line 63 to Line 2000 during the period that Line 63 was out of
service due to the landslide at Pyramid Lake, some volumes were lost
during this quarter as customers sought to ensure their supply.
In March 2005, Pacific experienced a significant oil release on
Line 63 in northern Los Angeles County in the Pyramid Lake area, which
was caused by a rain-induced landslide. In addition, record rainfall
in Southern California caused stream erosion and earth movement,
exposing Pacific's pipelines in multiple locations. The total costs
associated with the oil recovery and restoration effort at Pyramid
Lake is now estimated at $15 million. Pacific believes that its
insurance carrier will pay these costs, excluding a $2.0 million
deductible, and has been receiving timely reimbursements to date.
Additionally, Pacific estimates that the cost of pipeline repairs and
improvements associated with the Pyramid Lake landslide and the costs
to address earth movement and stream erosion problems at other
locations along Line 63 and Line 2000 will total approximately $5.5
million, of which $3.7 million is expected to be expensed and $1.8
million is expected to be capitalized. Of the expense portion, $1.4
million and $2.0 million were incurred during the second quarter and
year-to-date periods, respectively. The California Public Utilities
Commission recently approved our application to implement a temporary
surcharge of $0.10 per barrel on Line 63 long haul tariff rates,
effective August 1, 2005, to recover the repair costs and insurance
deductible.
Pacific Terminals' storage facilities had a higher rate of
utilization during the quarter, as well as increased storage capacity.
The higher utilization was primarily the result of refinery
maintenance in the Los Angeles Basin.
PMT margins were unchanged in the second quarter of 2005 from the
second quarter of 2004. On July 1, 2005, Pacific purchased certain
crude oil contracts and crude oil inventories for $2.2 million plus
additional future payments to be made over the next three-and-one-half
years, based on the performance of the contracts. The purchase
contracts were integrated into PMT's business.
Pacific continues to advance the Pier 400 deepwater import
terminal project in the environmental permitting process, as well as
in securing additional customer commitments. Pacific expects to have
the permits necessary to begin construction in the second quarter of
2006, with completion and start-up expected in the fourth quarter of
2007.
ROCKY MOUNTAIN BUSINESS UNIT
Operating income was $9.0 million for the three months ended June
30, 2005, compared to $5.7 million in the corresponding period in
2004. The increase included a full quarter's results of the Rangeland
system which was acquired in May 2004, as well as increased market
share for pipeline shipments of crude oil to Billings, Montana, and
increased crude oil demand by Salt Lake City refiners. Pipeline
volumes in the U.S. Rocky Mountains for the second quarter of 2005
were approximately 5% higher than in the corresponding quarter of
2004. Salt Lake City Core and Frontier Pipeline volumes improved due
to an increase in capacity resulting from an agreement in June 2005
with the connecting carrier.
In Canada, the new receiving terminal and pump station for
Rangeland, which will provide access to synthetic and other types of
crude oil in Edmonton, is expected to begin operations in the middle
of the fourth quarter of 2005.
LOOKING FORWARD
For the full year ending December 31, 2005, Pacific is forecasting
recurring net income of $1.37 to $1.45 per unit. Included in the full
year guidance is $0.15 per limited partner unit of unusual and
unanticipated expense, including $3.7 million of pipeline repairs on
Line 63 and Line 2000 associated with earth movement and stream
erosion and $0.7 million of similar repairs on Rangeland pipeline,
which was also impacted by record-setting rains late in the second
quarter. For the quarter ending September 30, 2005, Pacific is
forecasting net income of $0.24 to $0.28 per unit. This guidance does
not include the benefit of the acquisition of assets from Valero L.P.
discussed further below. Reconciling items between projected recurring
net income and net income for full year 2005 are unchanged from those
set out in the attached schedule for the six months ended June 30,
2005.
As previously announced, management intends to recommend a
distribution increase of $0.03 per limited partner unit per quarter,
associated with the acquisition of assets from Valero L.P., and an
additional $0.0125 per quarter increase associated with the start-up
of the initiating synthetic crude oil facility in Edmonton. These
expected increases are unchanged by the unusual costs described above.
For the full year, Pacific is projecting total capital
expenditures of $57 million, including $42 million for expansion
projects, $12 million for transition capital projects, and $3 million
for sustaining capital projects. The Partnership is increasing its
profit generating capital forecast by $17 million, principally in the
Rocky Mountains and for Pier 400. These estimates exclude any planned
expansion projects associated with the assets being acquired from
Valero L.P.
ACQUISITION OF CERTAIN ASSETS FROM VALERO L.P.
On July 5, 2005, Pacific announced that it had signed a definitive
agreement to acquire certain terminal and pipeline assets from
subsidiaries of Valero L.P. consisting of two California terminals
handling refined products, refinery blend stocks, and crude oil with
4.1 million barrels of storage, three East Coast refined and specialty
products terminals with 3.2 million barrels of storage, and a 550-mile
refined products pipeline with four truck terminals and 1.7 million
barrels of storage in the U.S. Rocky Mountains. The aggregate purchase
price is $455 million. Pacific expects to fund the acquisition by
issuing common units for approximately 60-65% of the acquisition price
and debt securities for approximately 35-40% of the acquisition price.
The acquisition of these assets is expected to close by the end of
September 2005.
Pacific will host a conference call at 2:00 p.m. EDT (11:00 a.m.
PDT) on Wednesday, August 3, 2005, to discuss the results of the
second quarter of 2005. Please join us at www.PacificEnergy.com for
the live broadcast. The call, with questions and answers, will
continue to be available on Pacific's web site following the call.
About Pacific Energy:
Pacific Energy Partners, L.P. is a master limited partnership
headquartered in Long Beach. Pacific is engaged principally in the
business of gathering, transporting, storing, and distributing crude
oil and other related products in California and the Rocky Mountain
region, including Alberta, Canada. Pacific generates revenues
primarily by transporting crude oil on its pipelines and by leasing
capacity in its storage facilities. Pacific also buys, blends, and
sells crude oil, activities that are complementary to its pipeline
transportation business. Pacific Energy recently announced the signing
of a definitive agreement to purchase several refined products
terminals and a pipeline for $455 million. Closing is expected by the
end of September 2005 following receipt of regulatory approvals.
This news release may include "forward-looking" statements within
the meaning of Section 27A of the Securities Act of 1933, as amended,
and Section 21E of the Securities Exchange Act of 1934, as amended.
All statements other than statements of historical fact included or
incorporated herein may constitute forward-looking statements.
Although Pacific believes that the forward-looking statements are
reasonable, it can give no assurance that such expectations will prove
to be correct. The estimates associated with the acquisition are based
on facts known at the time of estimation and Pacific's assessment of
the ultimate outcome. Among the factors that could cause results to
differ materially are regulatory and other closing requirements and
the successful integration and future performance of the assets
acquired. The forward-looking statements involve risks and
uncertainties that may affect Pacific's operations and financial
performance. Among the factors that could cause results to differ
materially are those risks discussed in Pacific's filings with the
Securities and Exchange Commission, including our Annual Report on
Form 10-K for the year ended December 31, 2004.
The estimates associated with the oil release 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 and repair plans, the amount of data
available at the time of the assessment of the impact of soil and
water contamination, the current uncertainty of the geological
conditions that will be encountered during the final repairs of the
Line 63 pipeline, 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 the estimated
costs, if any, would not have a material adverse effect on the
Partnership's financial condition, results of operations, or cash
flows, although the Partnership believes it is likely 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. As new information becomes available in future periods, the
Partnership may change its expense accrual and recovery estimates.
For additional information about Pacific Energy, please visit our
Web site at www.PacificEnergy.com.
PACIFIC ENERGY PARTNERS, L.P.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(Unaudited)
(Amounts in thousands, except per unit amounts)
Three Months Six Months
Ended June 30, Ended June 30,
----------------- -----------------
2005 2004 2005 2004
-------- -------- -------- --------
Operating revenues:
Pipeline transportation
revenue $27,747 $26,992 $55,784 $51,719
Storage and distribution
revenue 10,870 9,259 21,192 19,382
Pipeline buy/sell
transportation revenue 8,116 3,690 17,222 3,690
Crude oil sales, net of
purchases 6,042 6,056 7,824 10,868
-------- -------- -------- --------
Net revenues 52,775 45,997 102,022 85,659
-------- -------- -------- --------
Expenses:
Operating 25,292 20,867 47,046 39,784
Line 63 oil release costs -- -- 2,000 --
General and administrative 3,700 3,636 8,872 7,490
Accelerated long-term incentive
plan compensation expense -- -- 3,115 --
Transaction costs(1) -- -- 1,807 --
Depreciation and amortization 6,606 5,713 13,135 10,955
-------- -------- -------- --------
Total expenses 35,598 30,216 75,975 58,229
-------- -------- -------- --------
Share of net income of Frontier 490 391 847 784
-------- -------- -------- --------
Operating income 17,667 16,172 26,894 28,214
Net interest expense (5,844) (4,383) (11,442) (8,509)
Write-off of deferred financing
cost and interest rate swap
termination expense -- (2,901) -- (2,901)
Other income 540 226 893 387
-------- -------- -------- --------
Income before foreign income tax
expense 12,363 9,114 16,345 17,191
-------- -------- -------- --------
Foreign income tax benefit
(expense):
Current 245 (32) (487) (32)
Deferred (388) 46 (217) 46
-------- -------- -------- --------
(143) 14 (704) 14
-------- -------- -------- --------
Net income $12,220 $9,128 $15,641 $17,205
======== ======== ======== ========
Net income (loss) for the general
partner interest(2) $244 $183 $(1,458) $344
======== ======== ======== ========
Net income for the limited partner
interests(2) $11,976 $8,945 $17,099 $16,861
======== ======== ======== ========
Weighted average units
outstanding:
Basic 29,723 29,479 29,689 27,239
Diluted 29,742 29,632 29,708 27,402
Basic and Diluted net income per
limited partner unit $0.40 $0.30 $0.58 $0.62
======== ======== ======== ========
(1) Pursuant to an Ancillary Agreement, our general partner
reimbursed us $1.8 million for costs incurred in connection with
the sale of our general partner. Generally accepted accounting
principles require us to record an expense with the reimbursement
shown as a partner's capital contribution.
(2) See "General Partner and Limited Partners Allocation of Net
Income" schedule included herein.
PACIFIC ENERGY PARTNERS, L.P.
(Unaudited)
(In thousands)
CONDENSED CONSOLIDATED BALANCE SHEETS
June 30, December 31,
2005 2004
---------------- --------------
Assets
Current assets $115,711 $95,545
Property and equipment, net 713,070 718,624
Investment in Frontier Pipeline
Company 7,998 7,886
Other assets 47,516 47,850
---------------- --------------
Total assets $884,295 $869,905
================ ==============
Liabilities and Partners' Capital
Current liabilities $75,445 $48,045
Long-term debt 359,209 357,163
Deferred income taxes 34,189 34,556
Other long-term liabilities 7,243 7,675
Partners' capital 408,209 422,466
---------------- --------------
Total liabilities and
partners' capital $884,295 $869,905
================ ==============
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Six Months Ended June 30,
-------------------------------
2005 2004
---------------- --------------
Cash flows from operating activities:
Net income $15,641 $17,205
Depreciation, amortization, non-
cash employee compensation under
long-term incentive plan,
deferred income taxes, and
Frontier(1) adjustment 15,619 12,814
Non-cash write-off of deferred
financing costs -- 2,321
Working capital adjustments 14,958 (3,075)
---------------- --------------
Net cash provided by operating
activities 46,218 29,265
Cash flows from investing activities:
Acquisitions -- (139,050)
Net additions to property and
equipment (9,877) (7,896)
Other (98) --
---------------- --------------
Net cash used in investing
activities (9,975) (146,946)
Cash flows from financing activities:
Issuance of common units, net of
fees and offering expenses -- 125,881
Capital contribution from the
general partner 2,438 2,690
Net proceeds from 7 1/8% Senior
Notes, due June 2014 -- 241,086
Repayment of term loan -- (225,000)
Proceeds from bank credit
facilities 66,283 154,168
Repayment of bank credit facilities (64,326) (141,500)
Deferred financing costs (600) (1,008)
Distributions to partners (30,658) (27,081)
Related parties (686) 607
---------------- --------------
Net cash provided by (used in)
financing activities (27,549) 129,843
Net increase in cash and cash
equivalents 8,694 12,162
Cash and cash equivalents, beginning
of period 23,383 9,699
---------------- --------------
Cash and cash equivalents, end of
period $32,077 $21,861
================ ==============
(1) Net Cash received from Frontier was $650 and $668 for the six
months ended June 30, 2005 and 2004, respectively.
PACIFIC ENERGY PARTNERS, L.P.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
AND OPERATING HIGHLIGHTS BY SEGMENT
Three Months Ended June 30, 2005 and 2004
(Unaudited)
(In thousands)
Intersegment
Rocky and
West Coast Mountain Intrasegment
Operations Operations Eliminations(1) Total
---------- ---------- --------------- --------
Three Months Ended
June 30, 2005:
Segment revenue:
Pipeline
transportation
revenue $15,194 $14,006 $(1,453) $27,747
Storage and
distribution
revenue 10,870 -- 10,870
Pipeline buy/sell
transportation
revenue -- 8,116 8,116
Crude oil sales, net
of purchases 5,866 206 (30) 6,042
---------- ---------- --------
Net revenue 31,930 22,328 52,775
---------- ---------- --------
Segment expenses:
Operating expenses 15,996 10,779 (1,483) 25,292
Depreciation and
amortization 3,529 3,077 6,606
---------- ---------- --------
Total expenses 19,525 13,856 31,898
---------- ---------- --------
Share of net income
of Frontier -- 490 490
---------- ---------- --------
Operating income(3) $12,405 $8,962 $21,367
========== ========== ========
Operating Data (barrels
per day, in thousands)
Line 2000 and Line 63
pipeline volume 120.0
Rangeland pipeline
system:
Sundre - North 23.1
Sundre - South 39.7
Western Corridor system
volume 22.2
Salt Lake City Core
system volume 124.4
Frontier pipeline
volume 51.3
Three Months Ended
June 30, 2004:
Segment revenue:
Pipeline
transportation
revenue $16,494 $11,804 (1,306) $26,992
Storage and
distribution
revenue 9,359 -- (100) 9,259
Pipeline buy/sell
transportation
revenue -- 3,690 3,690
Crude oil sales, net
of purchases 6,056 -- 6,056
---------- ---------- --------
Net revenue 31,909 15,494 45,997
---------- ---------- --------
Segment expenses:
Operating expenses 14,182 8,091 (1,406) 20,867
Depreciation and
amortization 3,635 2,078 5,713
---------- ---------- --------
Total expenses 17,817 10,169 26,580
---------- ---------- --------
Share of net income
of Frontier -- 391 391
---------- ---------- --------
Operating income(3) $14,092 $5,716 $19,808
========== ========== ========
Operating Data (barrels
per day, in thousands)
Line 2000 and Line 63
pipeline volume 139.5
Rangeland pipeline
system:
Sundre - North 21.2
Sundre - South 48.8
Western Corridor system
volume 19.8
Salt Lake City Core
system volume 119.2
Frontier pipeline
volume 50.0
PACIFIC ENERGY PARTNERS, L.P.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
AND OPERATING HIGHLIGHTS BY SEGMENT
Six Months Ended June 30, 2005 and 2004
(Unaudited)
(In thousands)
Intersegment
Rocky and
West Coast Mountain Intrasegment
Operations Operations Eliminations(1) Total
---------- ---------- --------------- --------
Six Months Ended
June 30, 2005:
Segment revenue:
Pipeline
transportation
revenue $32,638 $26,461 $(3,315) $55,784
Storage and
distribution
revenue 21,342 -- (150) 21,192
Pipeline buy/sell
transportation
revenue -- 17,222 17,222
Crude oil sales, net
of purchases 7,678 206 (60) 7,824
---------- ---------- --------
Net revenue 61,658 43,889 102,022
---------- ---------- --------
Segment expenses:
Operating expenses 30,503 20,068 (3,525) 47,046
Line 63 oil release
costs(2) 2,000 -- 2,000
Depreciation and
amortization 7,006 6,129 13,135
---------- ---------- --------
Total expenses 39,509 26,197 62,181
---------- ---------- --------
Share of net income
of Frontier -- 847 847
---------- ---------- --------
Operating income(3) $22,149 $18,539 $40,688
========== ========== ========
Operating Data (barrels
per day, in thousands)
Line 2000 and Line 63
pipeline volume 129.2
Rangeland pipeline
system:
Sundre - North 22.2
Sundre - South 43.9
Western Corridor system
volume 22.4
Salt Lake City Core
system volume 116.7
Frontier pipeline
volume 44.8
Six Months Ended
June 30, 2004:
Segment revenue:
Pipeline
transportation
revenue $32,185 $22,347 $(2,813) $51,719
Storage and
distribution
revenue 19,582 -- (200) 19,382
Pipeline buy/sell
transportation
revenue -- 3,690 3,690
Crude oil sales, net
of purchases 10,868 -- 10,868
---------- ---------- --------
Net revenue 62,635 26,037 85,659
---------- ---------- --------
Segment expenses:
Operating expenses 28,888 13,909 (3,013) 39,784
Depreciation and
amortization 7,400 3,555 10,955
---------- ---------- --------
Total expenses 36,288 17,464 50,739
---------- ---------- --------
Share of net income
of Frontier -- 784 784
---------- ---------- --------
Operating income(3) $26,347 $9,357 $35,704
========== ========== ========
Operating Data (barrels
per day, in thousands)
Line 2000 and Line 63
pipeline volume 136.6
Rangeland pipeline
system:
Sundre - North 21.2
Sundre - South 48.8
Western Corridor system
volume 18.0
Salt Lake City Core
system volume 113.0
Frontier pipeline
volume 47.0
(1) Eliminations are required to account for revenue on services
provided by one subsidiary to another.
(2) On March 23, 2005, there was an oil release of approximately
3,400 barrels in northern Los Angeles County.
(3) General and administrative expense, accelerated long-term
incentive plan compensation expense, and transaction costs are not
allocated to segments. See "Reconciliation of Operating Income By
Segment to Condensed Consolidated Statements of Income" included
herein.
PACIFIC ENERGY PARTNERS, L.P.
(Unaudited)
(In thousands)
RECONCILIATION OF OPERATING INCOME BY SEGMENT TO CONDENSED
CONSOLIDATED STATEMENTS OF INCOME
Three Months Six Months
Ended June 30, Ended June 30,
----------------- -----------------
2005 2004 2005 2004
-------- -------- -------- --------
Operating income by segment:
West Coast $12,405 $14,092 $22,149 $26,347
Rocky Mountain 8,962 5,716 18,539 9,357
-------- -------- -------- --------
21,367 19,808 40,688 35,704
General expenses and other
income/(expense):(1)
General and administrative
expense (3,700) (3,636) (8,872) (7,490)
Accelerated long-term incentive
plan compensation expense(2) -- -- (3,115) --
Transaction costs(3) -- -- (1,807) --
Interest expense (5,844) (4,383) (11,442) (8,509)
Write-off of deferred financing
cost and interest rate swap
termination expense -- (2,901) -- (2,901)
Other income 540 226 893 387
Foreign income tax (expense)
benefit (143) 14 (704) 14
-------- -------- -------- --------
Net income $12,220 $9,128 $15,641 $17,205
======== ======== ======== ========
GENERAL PARTNER AND LIMITED PARTNERS ALLOCATION OF NET INCOME
Three Months Six Months
Ended June 30, Ended June 30,
---------------- -----------------
2005 2004 2005 2004
-------- ------- -------- --------
Net income $12,220 $9,128 $15,641 $17,205
-------- ------- -------- --------
Transaction costs reimbursed by
general partner:
Senior Notes consent solicitation
and other costs -- -- 893 --
Severance costs -- -- 914 --
-------- ------- -------- --------
Total transaction costs reimbursed
by general partner -- -- 1,807 --
-------- ------- -------- --------
Income before transaction costs
reimbursed by general partner 12,220 9,128 17,448 17,205
General partner's share of income 2% 2% 2% 2%
-------- ------- -------- --------
General partner allocated share of
net income before transaction
costs 244 183 349 344
Transaction costs reimbursed by
general partner -- -- (1,807) --
-------- ------- -------- --------
Net income (loss) allocated to
general partner $244 $183 $(1,458) $344
======== ======= ======== ========
Income before transaction costs
reimbursed by general partner $12,220 $9,128 $17,448 $17,205
Limited partners' share of income 98% 98% 98% 98%
-------- ------- -------- --------
Limited partners' share of net
income $11,976 $8,945 $17,099 $16,861
======== ======= ======== ========
Net income (loss) allocated to
general partner $244 $183 $(1,458) $344
Net income allocated to limited
partners 11,976 8,945 17,099 16,861
-------- ------- -------- --------
Net income $12,220 $9,128 $15,641 $17,205
======== ======= ======== ========
(1) General and administrative expenses, accelerated long-term
incentive plan expense, transaction costs, interest expense, other
income, and foreign income tax expense are not allocated among the
West Coast and Rocky Mountain business units.
(2) On March 3, 2005, in connection with the change in control of
the Partnership's general partner, all restricted units
outstanding under the Long-Term Incentive Plan became immediately
vested pursuant to the terms of the grants. The Partnership
recognized accelerated compensation expense of $3.1 million
relating to the vesting.
(3) Pursuant to an Ancillary Agreement, our general partner reimbursed
us $1.8 million for costs incurred in connection with the sale of
our general partner. Generally accepted accounting principles
require us to record an expense with the reimbursement shown as a
partner's capital contribution.
PACIFIC ENERGY PARTNERS, L.P.
RECONCILIATION OF NET INCOME TO NON-GAAP FINANCIAL MEASURES
(Unaudited)
(Amounts in thousands, except per unit amounts)
RECONCILIATION OF NET INCOME
TO RECURRING NET INCOME
Three Months Six Months Ended
Ended June 30, June 30, 2005
----------------- -----------------
2005 2004 2005 2004
-------- -------- -------- --------
Net income $12,220 $9,128 $15,641 $17,205
Add: Line 63 oil release costs(1) -- -- 2,000 --
Add: Accelerated long-term
incentive plan compensation
expense(2) -- -- 3,115 --
Add: Transaction costs(3) -- -- 1,807 --
Add: Write-off of deferred
financing cost and interest rate
swap termination expense(4) -- 2,901 -- 2,901
-------- -------- -------- --------
Recurring net income $12,220 $12,029 $22,563 $20,106
======== ======== ======== ========
Recurring net income for the
general partner interest $244 $241 $451 $402
======== ======== ======== ========
Recurring net income for the
limited partner interest $11,976 $11,788 $22,112 $19,704
======== ======== ======== ========
Basic and diluted recurring net
income per limited partner unit $0.40 $0.40 $0.74 $0.72
======== ======== ======== ========
RECONCILIATION OF NET INCOME
TO DISTRIBUTABLE CASH FLOW(5)
Three Months Six Months
Ended June 30, Ended June 30,
----------------- -----------------
2005 2004 2005 2004
-------- -------- -------- --------
Net income $12,220 $9,128 $15,641 $17,205
Add: Line 63 oil release costs(1) -- -- 2,000 --
Add: Accelerated long-term
incentive plan compensation
expense(2) -- -- 3,115 --
Add: Transaction costs(3) -- -- 1,807 --
Add: Write-off of deferred
financing cost and interest rate
swap termination expense(4) -- 2,901 -- 2,901
-------- -------- -------- --------
Recurring net income 12,220 12,029 22,563 20,106
Plus: depreciation and
amortization 6,606 5,713 13,135 10,955
Plus: amortization of bond
discount and debt issue costs 478 359 937 670
Plus: non-cash employee
compensation under long-term
incentive plan -- 692 229 1,351
Plus: deferred income tax expense
(benefit) 388 (46) 217 (46)
Less: sustaining capital
expenditures (587) (178) (827) (725)
-------- -------- -------- --------
Distributable Cash Flow $19,105 $18,569 $36,254 $32,311
======== ======== ======== ========
General Partner interest in
Distributable Cash Flow $936 $817 $1,491 $1,169
======== ======== ======== ========
Limited partner interests in
Distributable Cash Flow $18,169 $17,752 $34,763 $31,142
======== ======== ======== ========
(1) On March 23, 2005, there was an oil release of approximately
3,400 barrels in northern Los Angeles County. Although this event
will involve an outlay of cash, we believe these costs are unusual
and are not indicative of the Partnership's recurring earnings.
(2) The cash cost associated with the accelerated vesting of units
is $2.0 million. However, we have not deducted this amount in
determining distributable cash flow as the accelerated vesting was
unusual and not indicative of the Partnership's recurring
earnings.
(3) Pursuant to an Ancillary Agreement, our general partner reimbursed
us $1.8 million for costs incurred in connection with the sale of
our general partner. Generally accepted accounting principles
require us to record an expense with the reimbursement shown as a
partner's capital contribution.
(4) In June 2004, in connection with the repayment of our term loan,
we had a $2.3 million non-cash write-down of deferred financing
costs and incurred a $0.6 million cash expense to terminate
related interest rate swaps.
(5) Distributable Cash Flow provides additional information for
evaluating our ability to make the minimum quarterly distribution
and is presented solely as a supplemental measure. You should not
consider Distributable Cash Flow as an alternative to net income,
income before taxes, cash flow from operations, or any other
measure of financial performance presented in accordance with
accounting principles generally accepted in the United States. Our
Distributable Cash Flow may not be comparable to similarly titled
measures of other entities. Additional information regarding
distributable cash flow is included in our annual report on Form
10-K for the year ended December 31, 2004.
CONTACT: Pacific Energy Partners, L.P.
Aubrye Harris, 562-728-2871
Fax: 562-728-2881
Email: AHarris@PacificEnergy.com