Northern Border Partners, L.P. (NYSE:NBP) today reported
first-quarter 2006 net income of $34.7 million, or $0.67 per unit,
compared with net income of $34.7 million, or $0.69 per unit, for
first-quarter 2005. Cash flow, as measured by earnings before
interest, taxes, depreciation and amortization (EBITDA), was $91.8
million for first-quarter 2006, up from $90.7 million in the first
quarter of 2005. Distributable cash flow (DCF) for first-quarter
2006 was $52.9 million, or $1.05 per unit, compared with $44.1
million, or $0.89 per unit, in first-quarter 2005. First-quarter
2006 net income per unit reflects an increase in income allocated
to the general partners as a result of the recently announced
increase in the partnership's quarterly distribution. "Our
businesses performed very well this quarter," said David Kyle,
chairman and chief executive officer of Northern Border Partners.
"Our gathering and processing segment continues to perform
exceptionally well, due primarily to higher prices and higher
volumes for natural gas and natural gas liquids in the Williston
Basin. The interstate natural gas pipeline segment's earnings were
slightly lower than last year, with Midwestern Gas Transmission's
strong gain being offset by capacity sold at a discount on Northern
Border Pipeline." "The transforming transactions with ONEOK and
TransCanada that were announced in first quarter have been
completed," continued Kyle, "as well as several other growth
projects, such as the acquisition of the remaining equity interest
in Guardian Pipeline and the Chicago III expansion project on
Northern Border Pipeline. Growth efforts such as these provide us
with an expanding asset base from which to increase distributions
to our unitholders." FIRST-QUARTER 2006 HIGHLIGHTS First-quarter
2006 results, compared with first-quarter 2005, included: -- An
operating margin increase of $5.3 million from the partnership's
gathering and processing operations in the Williston Basin.
Gathered and processed volumes from the Basin increased by nearly
seven percent. The average realized price for natural gas and
natural gas liquids increased by 20 percent and 26 percent,
respectively. -- Lower operations and maintenance expenses at the
consolidated level. Due diligence, legal and other costs related to
the transactions with ONEOK, Inc. and affiliates of TransCanada
Corporation of approximately $4 million in first-quarter 2006 were
offset by various other decreases in operations and maintenance
expense including the effect of the suspension of Black Mesa's coal
slurry operations. -- Higher interest expense, due to higher
average debt outstanding and higher average interest rates during
the first quarter of 2006. Interstate Natural Gas Pipeline Segment
The interstate natural gas pipeline segment contributed net income
of $31.9 million for first-quarter 2006, compared with $32.1
million in first-quarter 2005. Operating revenue for the segment
includes a decrease at Northern Border Pipeline of $3.0 million in
first-quarter 2006, primarily related to discounted transportation
rates and transportation capacity that was sold for shorter
distances. Segment operating revenue also includes an increase of
$2.1 million in first-quarter 2006, related to expanded southbound
capacity on Midwestern Gas Transmission that went into service in
late 2005. Average daily throughput for the interstate natural gas
pipeline segment was down slightly quarter over quarter at 3,468
million cubic feet per day (mmcfd) in first-quarter 2006, compared
with 3,501 mmcfd in first-quarter 2005, although Midwestern Gas
Transmission recorded an increase of 86 mmcfd or 27 percent,
quarter over quarter, due to its expanded southbound capacity. As
shown in the table below, Northern Border Pipeline's average daily
contracted capacity for first-quarter 2006 was essentially equal to
first-quarter 2005. The pipeline's weighted average system rate for
firm demand for the first quarter of 2006 was $0.361 per thousand
cubic feet (mcf), four percent below the first-quarter 2005 average
rate of $0.375 per mcf. Changes in the average system rate resulted
from shorter transportation-path contracts and multi-month
discounted contracts in 2006. -0- *T Northern Border Pipeline
Company Total System Revenue Summary
----------------------------------------------------------------------
First Quarter
----------------------------------------------------------------------
2006 2005
----------------------------------------------------------------------
Percent Contracted (1) 104% 103% Weighted Average System Rate
($/mcf) (2) $0.361 $0.375 Total Revenue (Millions) $79.8 $82.8 (1)
Compared with a design capacity of 2,374 million cubic feet (mmcf)
per day. (2) Amounts shown in dollars per thousand cubic feet
(mcf). *T Natural Gas Gathering and Processing Segment Net income
from the natural gas gathering and processing segment was $19.6
million in the first-quarter 2006, compared with $13.7 million in
first-quarter 2005. This represents an increase of 43 percent,
resulting from increased volumes in both the Powder River Basin
joint-venture pipelines and in the Williston Basin operations, as
well as increased margins, due to higher natural gas and natural
gas liquids (NGLs) prices, in the Williston Basin. The primary
differences between the periods for the segment were: -- Gathering
and processing volumes in the Williston Basin were 64 mmcfd in the
first quarter of 2006 compared with 60 mmcfd in first-quarter 2005,
a seven percent increase, primarily attributable to increased
production on the Grasslands and Marmarth systems. -- Realized
prices for natural gas and NGLs in the partnership's Williston
Basin operations increased. Natural gas prices increased 20 percent
from $6.65 per million British thermal units (mmBtu) in
first-quarter 2005 to $8.01 per mmBtu in first-quarter 2006, net of
hedging. The average price received for NGLs increased 26 percent,
to $1.11 per gallon in first-quarter 2006 versus $0.88 per gallon
in first-quarter 2005, net of hedging. -- Volumes on the
partnership's wholly-owned gathering systems in the Powder River
Basin declined 15 percent in the quarter to 178 mmcfd, compared
with 210 mmcfd in the first-quarter 2006. This volume decline is
attributable to a producer diverting low-margin gathering business
to its own newly-constructed system in second-quarter 2005.
First-quarter 2006 volumes compared with the fourth quarter of 2005
were stable. -- Equity earnings increased by $1.4 million due
primarily to increased volumes and transportation rates from the
partnership's joint-venture pipelines in the Powder River Basin.
GROWTH ACTIVITIES Effective April 1, 2006, the partnership
completed the acquisition of ONEOK's gathering and processing,
natural gas liquids, and pipelines and storage assets. In
conjunction with that transaction, ONEOK became the sole general
partner and increased its ownership in the partnership to 45.7
percent overall. Also concluded was the sale by Northern Border
Partners to TC PipeLines, LP, of a 20 percent interest in Northern
Border Pipeline Company. Northern Border Partners and TC PipeLines,
LP each now own a 50 percent interest in the pipeline. Northern
Border Pipeline's Chicago III expansion project was placed in
service at the end of April 2006. The Chicago III expansion project
increases Northern Border Pipeline's transportation capacity by 130
mmcfd, to 974 mmcfd, from Harper, Iowa to the Chicago market area.
Increased revenues from the expansion have already been
incorporated into the partnership's financial guidance for 2006.
Northern Border Partners completed its purchase of the remaining
ownership interest in Guardian Pipeline, L.L.C. at the end of
April. The $77 million purchase gave the partnership complete
ownership of the pipeline that transports Chicago area gas to
Wisconsin markets. As a result, the previously announced Guardian
expansion and extension project, estimated to cost $220 million to
$240 million will be a sizable growth opportunity for the
partnership. Construction of that project is targeted to begin in
2008. In March 2006, Midwestern Gas Transmission accepted the FERC
certificate for its eastern extension project. The project will add
31 miles of natural gas pipeline into Tennessee, with 120 mmcfd of
transportation capacity. It is estimated that the project will cost
approximately $28 million. The proposed in-service date of November
2006 will likely be delayed for several months due to the delay in
obtaining the certificate. DISTRIBUTION DECLARATION On April 18,
2006, the partnership policy committee declared a 10 percent
increase in the Partnership's quarterly cash distribution to $0.88
per unit for the first quarter of 2006. The indicated annual rate
is $3.52. The distribution is payable May 15, 2006, to unitholders
of record on April 28, 2006. The partnership policy committee also
announced that it is targeting an indicative annual distribution of
between $3.72 and $3.80 per unit by year end. 2006 GUIDANCE The
partnership is reiterating its previous guidance. Net income for
2006 is still expected to range from $426 million to $446 million,
or $4.43 to $4.69 per unit. Net income and EBITDA are expected to
include a one-time gain of $108 million, or $1.44 per unit, on the
sale of the 20 percent interest in Northern Border Pipeline. EBITDA
is expected to be in the range of $630 million to $650 million.
Distributable cash flow is expected to be in the range of $324
million to $344 million, or $3.96 to $4.23 per unit. CONFERENCE
CALL Northern Border Partners and ONEOK, Inc. (NYSE:OKE) will host
a joint conference call on Wednesday May 3, 2006 at 11:00 a.m.
Eastern Time to review first-quarter 2006 results and to discuss
the 2006 outlook. This call may be accessed via the partnership's
website at http://www.northernborderpartners.com. The webcast will
be available on the partnership's website through June 3, 2006. The
call-in number for the live conference call is 866-836-4700, pass
code 890050. An audio replay of the call will be available through
May 10, 2006 by dialing 866-837-8032 and entering pass code 890050.
NON-GAAP FINANCIAL MEASURES The partnership has disclosed in this
press release EBITDA and DCF amounts that are non-GAAP financial
measures. Management believes EBITDA and DCF provide useful
information to investors as a measure of comparison with peer
companies. However, these calculations may vary from company to
company, so the partnership's computations may not be comparable
with those of other companies. DCF is not necessarily the same as
available cash as defined in the Partnership Agreements. Management
further uses EBITDA to compare the financial performance of its
segments and to internally manage those business segments.
Reconciliations of EBITDA to net income, and EBITDA to cash flow
from operating activities, and computations of DCF for the three
months ended March 31, 2006 and 2005, are included in the financial
information with this release. On a consolidated basis, EBITDA is
reconciled to cash flow from operating activities determined under
GAAP. For segment information of this press release, EBITDA is
reconciled to net income rather than to cash flow from operating
activities, since the Partnership does not determine segment cash
flow from operating activities due to its inter-company
cash-management activity. Reconciliations of projected 2006 EBITDA
to projected net income and computations of projected DCF are also
included with this release. Northern Border Partners, L.P. is a
publicly traded partnership that owns and operates: natural gas
gathering and processing facilities; natural gas liquids gathering,
fractionation, transportation, and storage; and inter- and
intra-state natural gas pipelines. Its general partner is ONEOK,
Inc., a diversified energy company, which owns 45.7 percent of the
overall partnership interest. ONEOK is one of the largest natural
gas distributors in the United States, and its energy services
operation focuses primarily on marketing natural gas and related
services throughout the U.S. More information may be found at
http://www.northernborderpartners.com. FORWARD-LOOKING STATEMENT
This press release includes forward-looking statements within the
meaning of Section 27A of the Securities Act of 1933 and Section
21E of the Securities Exchange Act of 1934. Although Northern
Border Partners believes that its expectations regarding future
events are based on reasonable assumptions, it can give no
assurance that its goals will be achieved. Important factors that
could cause actual results to differ materially from those in the
forward-looking statements herein include: -- the effects of
weather and other natural phenomena on our operations, energy
prices and demand for our services; -- competition from other U.S.
and Canadian energy suppliers and transporters as well as
alternative forms of energy; -- the timing and extent of changes in
commodity prices for natural gas, natural gas liquids, electricity
and crude oil; -- impact on drilling and production by factors
beyond our control, including the demand for natural gas and
refinery-grade crude oil; producers' desire and ability to obtain
necessary permits; reserve performance; and capacity constraints on
the pipelines that transport natural gas, crude oil and natural gas
liquids from producing areas and our facilities; -- risks of
trading and hedging activities as a result of changes in energy
prices or the financial condition of our counterparties; -- the
ability to recover operating costs and amounts equivalent to income
taxes, costs of property, plant and equipment and regulatory assets
in our FERC-regulated rates; -- the timely receipt of approval by
the FERC for construction and operation of our interstate natural
gas pipeline projects and required regulatory clearances; our
ability to acquire all necessary rights-of-way and obtain
agreements for interconnects in a timely manner, our ability to
promptly obtain all necessary materials and supplies required for
construction; -- the impact of unsold or discounted capacity on
Northern Border Pipeline being greater than expected; -- the
ability to market pipeline capacity on favorable terms; -- orders
by the FERC related to Northern Border Pipeline's November 2005
rate case which are significantly different than our assumptions;
-- risks associated with adequate supply to our gathering,
processing, fractionation and pipeline facilities, including
production declines which outpace new drilling; -- impact of
potential impairment charge if we are unable to renew our coal
slurry pipeline contract; -- the effects of changes in governmental
policies and regulatory actions, including changes with respect to
income taxes, environmental compliance, authorized rates or
recovery of gas costs; -- the results of administrative proceedings
and litigation, regulatory actions and receipt of expected
clearances involving regulatory authorities or any other local,
state or federal regulatory body, including the FERC; -- actions by
rating agencies concerning our credit ratings; -- the impact of
unforeseen changes in interest rates, equity markets, inflation
rates, economic recession and other external factors over which we
have no control, including the effect on pension expense and
funding resulting from changes in stock and bond market returns; --
our ability to access capital at competitive rates or on terms
acceptable to us; -- demand for our services in the proximity of
our facilities; -- the profitability of assets or businesses
acquired by us; -- the risk that material weaknesses or significant
deficiencies in our internal controls over financial reporting
could emerge or that minor problems could become significant; --
the impact and outcome of pending and future litigation; -- our
ability to successfully integrate the operations of the assets
acquired from ONEOK with our current operations; -- performance of
contractual obligations by our customers; -- ability to control
operating costs; and -- acts of nature, sabotage, terrorism or
other similar acts causing damage to our facilities or our
suppliers' or shippers' facilities. These factors are not
necessarily all of the important factors that could cause actual
results to differ materially from those expressed in any of our
forward-looking statements. Other factors could also have material
adverse effects on our future results. These and other risks are
described in greater detail under Item 1A, "Risk Factors," in Part
II of our quarterly reports on Form 10-Q and under Item 1A, "Risk
Factors," in Part I of our annual report on Form 10-K for the year
ended December 31, 2005. All forward-looking statements
attributable to us or persons acting on our behalf are expressly
qualified in their entirety by these factors. Other than as
required under securities laws, we undertake no obligation to
update publicly any forward-looking statement whether as a result
of new information, subsequent events or change in circumstances,
expectations or otherwise. -0- *T Northern Border Partners, L.P.
Financial Highlights --------------------- (Unaudited: In Millions
Except Per Unit Amounts) First Quarter 2006 2005 ------------
------------ Operating Revenue $170.8 $160.4 Net Income $34.7 $34.7
Per Unit Net Income $0.67 $0.69 Cash Flows From Operating
Activities $70.2 $67.1 EBITDA (1) $91.8 $90.7 Distributable Cash
Flow $52.9 $44.1 Distributable Cash Flow Per Unit $1.05 $0.89
Consolidated Statement of Income ----------------------------------
(Unaudited: In Millions Except Per Unit Amounts) First Quarter 2006
2005 ------------ ------------ Operating Revenue $170.8 $160.4
------------ ------------ Operating Expenses Product Purchases 44.0
32.5 Operations and Maintenance 31.6 33.1 Depreciation and
Amortization 21.3 21.4 Taxes Other Than Income 10.2 9.8
------------ ------------ Total Operating Expenses 107.1 96.8
------------ ------------ Operating Income 63.7 63.6 Interest
Expense, Net (22.7) (21.2) Other Income (Expense), Net 0.7 0.5
Equity Earnings from Investments 6.2 4.5 Minority Interest (11.2)
(12.2) ------------ ------------ Income From Continuing Operations
Before Income Taxes 36.7 35.2 Income Taxes 2.0 0.9 ------------
------------ Income From Continuing Operations 34.7 34.3
Discontinued Operations, net of tax 0.0 0.4 ------------
------------ Net Income (4) $34.7 $34.7 ============ ============
Per Unit Income From Continuing Operations $0.67 $0.68 ============
============ Per Unit Net Income $0.67 $0.69 ============
============ Average Units Outstanding 46.4 46.4 ============
============ Footnotes to Financial Tables
----------------------------- (1) EBITDA is computed from net
income plus minority interest; interest expense, net; income taxes;
and depreciation and amortization less equity AFUDC. (2) Management
classifies expenditures that are expected to generate additional
revenues or significant operating efficiency as growth capital
expenditures and equity investments. Any remaining capital
expenditures are classified as maintenance. (3) Volume information
presented in operating results includes 100% of the volumes for
joint ventures and equity investments as well as for wholly-owned
subsidiaries. (4) Financial and operating information for our two
reportable segments is included with our earnings tables.
Consolidated net income is reduced by amounts not allocated to our
two reportable segments including: interest expense on our debt;
certain general and administrative expenses; and operating results
for our coal slurry business. Northern Border Partners, L.P.
Reconciliation of non-GAAP Financial Measures
----------------------------------------------- (Unaudited: In
Millions Except Per Unit Amounts) Reconciliation of EBITDA to Net
Income First Quarter 2006 2005 ------------ ------------ EBITDA (1)
$91.8 $90.7 Minority Interest (11.2) (12.2) Interest Expense, Net
(22.7) (21.2) Depreciation and Amortization (including amounts in
Other Income, Net and Discontinued Operations) (21.4) (21.4) Income
taxes (including amounts in Discontinued Operations) (2.0) (1.2)
Equity AFUDC (included in Other Income, Net) 0.2 0.0 ------------
------------ Net Income $34.7 $34.7 ============ ============
Reconciliation of EBITDA to Cash Flows From Operating Activities
EBITDA (1) $91.8 $90.7 Interest Expense, Net (22.7) (21.2) Changes
in Current Assets and Liabilities 1.6 3.7 Equity Earnings from
Investments (6.2) (4.5) Distributions Received from Equity
Investments 9.2 1.2 Changes in Reserves and Deferred Credits 0.7
(0.3) Other (4.2) (2.5) ------------ ------------ Cash Flows From
Operating Activities $70.2 $67.1 ============ ============
Reconciliation of EBITDA to Distributable Cash Flow EBITDA (1)
$91.8 $90.7 Interest Expense, Net (22.7) (21.2) Maintenance Capital
(5.8) (6.1) Distributions to Minority Interest (13.5) (16.2) Equity
Earnings from Investments (6.2) (4.5) Distributions Received from
Equity Investments 9.2 1.2 Other 0.1 0.2 ------------ ------------
Distributable Cash Flow $52.9 $44.1 ============ ============
Distributable Cash Flow Per Unit $1.05 $0.89 ============
============ Northern Border Partners, L.P. Other Financial
Information ----------------------------- (Unaudited: In Millions)
March 31, December 31, 2006 2005 ------------ ------------ Summary
Balance Sheet Data Total assets by segment: Interstate Natural Gas
Pipeline $1,873.4 $1,889.0 Natural Gas Gathering and Processing
589.2 594.4 Other (assets not allocated to segments) 25.8 44.4
------------ ------------ Total consolidated assets $2,488.4
$2,527.8 ============ ============ Consolidated capitalization:
Long-term debt, including current maturities $1,328.9 $1,355.0
Partners' capital 762.3 767.6 Minority interests in partners'
equity 275.2 274.5 Accumulated other comprehensive income 3.1 (2.0)
------------ ------------ Total capitalization 2,369.5 2,395.1
Consolidated other current liabilities and reserves and deferred
credits 118.9 132.7 ------------ ------------ Total liabilities and
capitalization $2,488.4 $2,527.8 ============ ============ First
Quarter 2006 2005 ------------ ------------ Capital Expenditures
and Equity Investments (2) Maintenance - Interstate Natural Gas
Pipeline $3.9 $4.6 Natural Gas Gathering and Processing 1.6 1.0
Other 0.3 0.5 ------------ ------------ 5.8 6.1 ------------
------------ Growth - Interstate Natural Gas Pipeline 9.1 0.8
Natural Gas Gathering and Processing 3.5 4.4 ------------
------------ 12.6 5.2 ------------ ------------ Total $18.4 $11.3
============ ============ Northern Border Partners, L.P. Summary
Segment Information --------------------------- (Unaudited) First
Quarter 2006 2005 --------- --------- Interstate Natural Gas
Pipeline Segment Operating Results (3): Gas Delivered (mmcf)
305,280 306,692 Average Throughput (mmcfd) 3,468 3,501 Financial
Results (In Millions): Operating Revenue $95.6 $96.6 ---------
--------- Operating Expenses Operations and Maintenance 14.1 15.7
Depreciation and Amortization 16.8 16.5 Taxes Other Than Income 9.4
8.8 --------- --------- Total Operating Expenses 40.3 41.0
--------- --------- Operating Income 55.3 55.6 Interest Expense,
Net (11.2) (11.2) Other Income, Net 0.4 0.2 Equity Earnings from
Investments 0.8 0.5 --------- --------- Income Before Income Taxes
45.3 45.1 Income Taxes 2.2 0.8 --------- --------- Net Income 43.1
44.3 Net income to Minority Interest (11.2) (12.2) ---------
--------- Net Income to Northern Border Partners $31.9 $32.1
========= ========= EBITDA (1) $73.2 $72.8 ========= =========
Distributions from Northern Border Pipeline: Paid to Northern
Border Partners $31.5 $37.9 Paid to Minority Interest $13.5 $16.2
--------- --------- Total Distributions $45.0 $54.1 =========
========= Reconciliation of EBITDA to Net Income EBITDA (1) $73.2
$72.8 Minority Interest (11.2) (12.2) Interest Expense, Net (11.2)
(11.2) Depreciation and Amortization (16.9) (16.5) Income taxes
(2.2) (0.8) Equity AFUDC (included in Other Income (Expense)) 0.2
0.0 --------- --------- Net Income $31.9 $32.1 ========= =========
Northern Border Partners, L.P. Summary Segment Information
--------------------------- (Unaudited) First Quarter 2006 2005
--------- --------- Natural Gas Gathering and Processing Segment
Operating Results (3): Volumes (mmcfd): Gathering 1,094 1,049
Processing 64 60 Financial Results (In Millions): Operating Revenue
$73.5 $57.6 --------- --------- Operating Expenses Product
Purchases 44.0 32.5 Operations and Maintenance 10.6 10.9
Depreciation and Amortization 4.3 3.9 Taxes Other Than Income 0.6
0.7 --------- --------- Total Operating Expenses 59.5 48.0
--------- --------- Operating Income 14.0 9.6 Interest Expense, Net
0.0 (0.1) Other Income (Expense) 0.2 0.2 Equity Earnings from
Investments 5.4 4.0 --------- --------- Income Before Income Taxes
19.6 13.7 Income Taxes 0.0 0.0 --------- --------- Net Income $19.6
$13.7 ========= ========= EBITDA (1) $23.9 $17.7 =========
========= Distributions Received from Equity Investments $9.2 $1.2
========= ========= Reconciliation of EBITDA to Net Income EBITDA
(1) $23.9 $17.7 Interest Expense, Net 0.0 (0.1) Depreciation and
Amortization (4.3) (3.9) Income taxes 0.0 0.0 --------- ---------
Net Income $19.6 $13.7 ========= ========= Northern Border
Partners, L.P. Reconciliation of non-GAAP Financial Measures
---------------------------------------------- (Unaudited: In
Millions Except Per Unit Amounts) Reconciliation of EBITDA to Net
Income - Projected 2006 Projected 2006(a) ------------ EBITDA $640
Interest Expense, Net (95) Depreciation and Amortization Expense
(106) Income Taxes (3) ------------ Net Income $436 ============
Reconciliation of EBITDA to Distributable Cash Flow - Projected
2006 Projected 2006(a) ------------ EBITDA $640 Gain on Sale of
Northern Border Pipeline (108) Interest Expense, Net (95)
Maintenance Capital (52) Equity Earnings from Investments (96)
Distributions Received from Equity Investments 119 Other 3 Cash
Flow to ONEOK for partial year ownership (77) ------------
Distributable Cash Flow $334 ============ Distributable Cash Flow
per Unit $4.09 ============ (a) Amounts shown are midpoints of
ranges of projected results *T
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