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 MARCH 31, 2005
[ ] 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 1-12202
NORTHERN BORDER PARTNERS, L.P.
(Exact name of registrant as specified in its charter)
Delaware 93-1120873
------------------------------------- -------------------------------
(State or other jurisdiction of (I.R.S. Employer Identification
incorporation or organization) Number)
13710 FNB Parkway
Omaha, Nebraska 68154-5200
------------------------------------- -------------------------------
(Address of principal executive (Zip code)
offices)
(402) 492-7300
-----------------------------------------------------
(Registrant's telephone number, including area code)
Not applicable
- --------------------------------------------------------------------------------
(Former name, 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 [ ]
Indicate by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act). Yes [X] No [ ]
The number of common units outstanding as of May 1, 2005 was 46,397,214.
1 OF 29
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
TABLE OF CONTENTS
Page No.
--------
PART I. FINANCIAL INFORMATION
ITEM 1. Financial Statements
Consolidated Statement of Income -
Three Months Ended March 31, 2005 and 2004 3
Consolidated Statement of Comprehensive Income -
Three Months Ended March 31, 2005 and 2004 4
Consolidated Balance Sheet -
March 31, 2005 and December 31, 2004 5
Consolidated Statement of Cash Flows -
Three Months Ended March 31, 2005 and 2004 6
Consolidated Statement of Changes in Partners'
Equity - Three Months Ended March 31, 2005 7
Notes to Consolidated Financial Statements 8
ITEM 2. Management's Discussion and Analysis of Financial Condition
and Results of Operations 13
ITEM 3. Quantitative and Qualitative Disclosures About Market Risk 25
ITEM 4. Controls and Procedures 26
PART II. OTHER INFORMATION
ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds 27
ITEM 5. Other Information 27
ITEM 6. Exhibits 28
2
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF INCOME
(IN THOUSANDS, EXCEPT PER UNIT AMOUNTS)
(UNAUDITED)
THREE MONTHS ENDED
MARCH 31,
--------------------------
2005 2004
--------- ---------
OPERATING REVENUES $ 160,379 $ 143,773
--------- ---------
OPERATING EXPENSES
Product purchases 32,465 21,413
Operations and maintenance 33,172 29,399
Depreciation and amortization 21,392 21,506
Taxes other than income 9,812 9,694
--------- ---------
Operating expenses 96,841 82,012
--------- ---------
OPERATING INCOME 63,538 61,761
--------- ---------
INTEREST EXPENSE 21,166 18,568
--------- ---------
OTHER INCOME (EXPENSE)
Equity earnings of unconsolidated
affiliates 4,477 6,363
Other income 741 521
Other expense (223) (135)
--------- ---------
Other income, net 4,995 6,749
--------- ---------
MINORITY INTERESTS IN NET INCOME 12,189 12,527
--------- ---------
INCOME FROM CONTINUING OPERATIONS BEFORE
INCOME TAXES 35,178 37,415
INCOME TAXES 899 1,563
--------- ---------
INCOME FROM CONTINUING OPERATIONS 34,279 35,852
DISCONTINUED OPERATIONS, NET OF TAX 390 763
--------- ---------
NET INCOME TO PARTNERS $ 34,669 $ 36,615
========= =========
CALCULATION OF LIMITED PARTNERS' INTEREST
IN NET INCOME:
Net income to partners $ 34,669 $ 36,615
Less: general partners' interest in
net income 2,683 2,722
--------- ---------
Limited partners' interest in
net income $ 31,986 $ 33,893
========= =========
LIMITED PARTNERS' PER UNIT NET INCOME:
Income from continuing operations $ 0.68 $ 0.71
Discontinued operations, net of tax 0.01 0.02
--------- ---------
Net income $ 0.69 $ 0.73
========= =========
NUMBER OF UNITS USED IN COMPUTATION 46,397 46,397
========= =========
The accompanying notes are an integral part of these consolidated financial
statements.
3
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
(IN THOUSANDS)
(UNAUDITED)
THREE MONTHS ENDED
MARCH 31,
------------------------
2005 2004
-------- --------
Net income to partners $ 34,669 $ 36,615
Other comprehensive income:
Change associated with current period
hedging transactions (2,725) 479
Change associated with current period
foreign currency translation (21) (300)
-------- --------
Total comprehensive income $ 31,923 $ 36,794
======== ========
The accompanying notes are an integral part of these consolidated financial
statements.
4
PART I. FINANCIAL INFORMATION (CONTINUED)
ITEM 1. FINANCIAL STATEMENTS (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEET
(IN THOUSANDS)
(UNAUDITED)
MARCH 31, DECEMBER 31,
2005 2004
---------- ------------
ASSETS
CURRENT ASSETS
Cash and cash equivalents $ 37,313 $ 33,980
Accounts receivable, net of allowance for doubtful
accounts of $9,237 and $9,175 at March 31, 2005
and December 31, 2004, respectively 66,738 70,007
Materials and supplies, at cost 5,161 5,654
Prepaid expenses and other 5,266 5,650
Derivative financial instruments -- 1,996
---------- ----------
Total current assets 114,478 117,287
---------- ----------
PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment 2,948,413 2,939,465
Less: Accumulated provision for
depreciation and amortization 1,023,453 1,002,041
---------- ----------
Property, plant and equipment, net 1,924,960 1,937,424
---------- ----------
INVESTMENTS AND OTHER ASSETS
Investment in unconsolidated affiliates 278,217 273,202
Goodwill 152,782 152,782
Derivative financial instruments 1,787 2,555
Other 28,263 27,306
---------- ----------
Total investments and other assets 461,049 455,845
---------- ----------
Total assets $2,500,487 $2,510,556
========== ==========
LIABILITIES AND PARTNERS' EQUITY
CURRENT LIABILITIES
Current maturities of long-term debt $ 9,474 $ 5,126
Accounts payable 29,177 35,095
Accrued taxes other than income 32,162 32,563
Accrued interest 22,609 16,530
Derivative financial instruments 2,915 --
---------- ----------
Total current liabilities 96,337 89,314
---------- ----------
LONG-TERM DEBT, net of current maturities 1,319,356 1,325,232
---------- ----------
MINORITY INTERESTS IN PARTNERS' EQUITY 285,993 290,142
---------- ----------
RESERVES AND DEFERRED CREDITS
Deferred income taxes 7,702 7,186
Derivative financial instruments 1,588 840
Other 8,160 8,508
---------- ----------
Total reserves and deferred credits 17,450 16,534
---------- ----------
COMMITMENTS AND CONTINGENCIES (Note 5)
PARTNERS' EQUITY
General partners 15,498 15,603
Common units (46,397,214 units issued and
outstanding at March 31, 2005 and
December 31, 2004) 759,418 764,550
Accumulated other comprehensive income 6,435 9,181
---------- ----------
Total partners' equity 781,351 789,334
---------- ----------
Total liabilities and partners' equity $2,500,487 $2,510,556
========== ==========
The accompanying notes are an integral part of these consolidated financial
statements.
5
PART I. FINANCIAL INFORMATION (CONTINUED)
ITEM 1. FINANCIAL STATEMENTS (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CASH FLOWS
(IN THOUSANDS)
(UNAUDITED)
THREE MONTHS ENDED
MARCH 31,
------------------------
2005 2004
-------- --------
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income to partners $ 34,669 $ 36,615
-------- --------
Adjustments to reconcile net income to partners
to net cash provided by operating activities:
Depreciation and amortization 21,482 21,704
Minority interests in net income 12,189 12,527
Reserves and deferred credits (340) (968)
Equity earnings in unconsolidated affiliates (4,477) (6,363)
Distributions received from unconsolidated affiliates 1,187 4,332
Changes in components of working capital 3,726 6,441
Non-cash losses (gains) from derivative financial
instruments 40 (32)
Other (1,406) (982)
-------- --------
Total adjustments 32,401 36,659
-------- --------
Net cash provided by operating activities 67,070 73,274
-------- --------
CASH FLOWS FROM INVESTING ACTIVITIES:
Investment in unconsolidated affiliates (1,454) --
Capital expenditures for property, plant
and equipment (9,846) (2,076)
-------- --------
Net cash used in investing activities (11,300) (2,076)
-------- --------
CASH FLOWS FROM FINANCING ACTIVITIES:
Cash distributions
General and limited partners (39,906) (39,906)
Minority Interests (16,229) (14,459)
Equity contributions from Minority Interests -- 19,500
Issuance of long-term debt 13,000 50,000
Retirement of long-term debt (9,302) (58,920)
-------- --------
Net cash used in financing activities (52,437) (43,785)
-------- --------
NET CHANGE IN CASH AND CASH EQUIVALENTS 3,333 27,413
Cash and cash equivalents-beginning of period 33,980 35,895
-------- --------
Cash and cash equivalents-end of period $ 37,313 $ 63,308
======== ========
Supplemental Disclosures of Cash Flow Information:
Cash paid for:
Interest (net of amount capitalized) $ 16,294 $ 14,842
======== ========
Changes in components of working capital:
Accounts receivable $ 3,663 $ (804)
Materials and supplies, prepaid expenses and other 877 2,054
Accounts payable (6,492) 45
Accrued taxes other than income (401) 181
Accrued interest 6,079 4,965
-------- --------
Total $ 3,726 $ 6,441
======== ========
The accompanying notes are an integral part of these consolidated financial
statements.
6
PART I. FINANCIAL INFORMATION (CONTINUED)
ITEM 1. FINANCIAL STATEMENTS (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF CHANGES IN PARTNERS' EQUITY
(IN THOUSANDS)
(UNAUDITED)
ACCUMULATED
OTHER TOTAL
GENERAL COMMON COMPREHENSIVE PARTNERS'
PARTNERS UNITS INCOME EQUITY
-------- --------- ------------- ---------
Balance at December 31, 2004 $ 15,603 $ 764,550 $ 9,181 $ 789,334
Net income to partners 2,683 31,986 -- 34,669
Change associated with current period
hedginx transactions -- -- (2,725) (2,725)
Change associated with current
period foreign currency translation -- -- (21) (21)
Distributions to partners (2,788) (37,118) -- (39,906)
-------- --------- ------- ---------
Balance at March 31, 2005 $ 15,498 $ 759,418 $ 6,435 $ 781,351
======== ========= ======= =========
The accompanying notes are an integral part of these consolidated financial
statements.
7
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 1. FINANCIAL STATEMENTS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. BASIS OF PRESENTATION
In this report, references to "we", "us", "our" or the "Partnership"
collectively refer to Northern Border Partners, L.P. and our subsidiary,
Northern Border Intermediate Limited Partnership.
We have prepared the consolidated financial statements included herein
without audit pursuant to the rules and regulations of the Securities and
Exchange Commission. The consolidated financial statements reflect all normal
and recurring adjustments that are, in the opinion of management, necessary for
a fair presentation of the financial results for the interim periods presented.
Certain information and notes normally included in financial statements prepared
in accordance with U.S. generally accepted accounting principles ("U.S. GAAP")
have been condensed or omitted pursuant to such rules and regulations. However,
we believe that the disclosures are adequate to make the information presented
not misleading. These consolidated financial statements should be read in
conjunction with the consolidated financial statements and the notes thereto
included in our Annual Report on Form 10-K for the year ended December 31, 2004.
The preparation of financial statements in conformity with U.S. GAAP
requires management to make assumptions that affect the reported amounts of
assets and liabilities, disclosure of contingent assets and liabilities at the
date of the financial statements, and the reported amounts of revenues and
expenses during the reporting period. Actual results could differ from those
estimates.
We own a 70% general partner interest in Northern Border Pipeline Company.
Crestone Energy Ventures, L.L.C.; Bear Paw Energy, L.L.C.; Border Midstream
Services, Ltd.; Midwestern Gas Transmission Company; Viking Gas Transmission
Company; and Black Mesa Pipeline, Inc. are wholly-owned subsidiaries of the
Partnership. We also own a 49% common membership interest and a 100% preferred A
share interest in Bighorn Gas Gathering, L.L.C.; a 33% interest in Fort Union
Gas Gathering, L.L.C.; a 35% interest in Lost Creek Gathering, L.L.C.; and a 33%
interest in Guardian Pipeline, L.L.C.
2. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES
We use financial instruments in the management of our interest rate and
commodity price exposure. A control environment has been established which
includes policies and procedures for risk assessment as well as the approval,
reporting and monitoring of financial instrument activities.
On December 9, 2004, we entered into forward starting interest rate swap
agreements with a total notional amount of $100 million in anticipation of a
ten-year senior note issuance in the first half of 2005. At March 31, 2005, we
recorded a derivative financial instrument receivable of $1.5 million, the fair
value of the interest rate swap agreements, with a corresponding offset to
accumulated other comprehensive income.
8
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 1. FINANCIAL STATEMENTS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
We record in accumulated other comprehensive income amounts related to
terminated interest rate swap agreements for cash flow hedges with such amounts
amortized to interest expense over the term of the hedged debt. During the three
months ended March 31, 2005, we amortized approximately $0.5 million related to
the terminated interest rate swap agreements as a reduction to interest expense
from accumulated other comprehensive income and expect to amortize a comparable
amount in each of the remaining quarters of 2005.
We have outstanding interest rate swap agreements with notional amounts
totaling $150 million that expire in March 2011. Under the interest rate swap
agreements, we make payments to counterparties at variable rates based on the
London Interbank Offered Rate and in return receive payments based on a 7.10%
fixed rate. At March 31, 2005, the average effective interest rate on our
interest rate swap agreements was 5.80%. Our interest rate swap agreements have
been designated as fair value hedges as they hedge the fluctuations in the
market value of the senior notes issued by us in 2001. The accompanying
consolidated balance sheet at March 31, 2005, reflects derivative financial
instrument assets of approximately $0.3 million and derivative financial
instrument liabilities of $1.6 million with a corresponding decrease in
long-term debt related to our fair value hedges.
The Partnership and Northern Border Pipeline record in long-term debt
amounts received or paid related to terminated or amended interest rate swap
agreements for fair value hedges with such amounts amortized to interest expense
over the remaining life of the interest rate swap agreement. During the first
quarter of 2005, the Partnership and Northern Border Pipeline amortized
approximately $1.3 million as a reduction to interest expense and expect to
amortize a comparable amount in each of the remaining quarters of 2005.
Bear Paw Energy periodically enters into commodity derivative contracts
and fixed-price physical contracts. Bear Paw Energy primarily utilizes price
swaps and collars, which have been designated as cash flow hedges, to hedge its
exposure to gas and natural gas liquid price volatility. During the first
quarter of 2005, Bear Paw Energy recognized gains of $1.3 million from the
settlement of derivative contracts. At March 31, 2005, the consolidated balance
sheet reflected an unrealized loss of approximately $2.9 million in derivative
financial instrument liabilities with a corresponding decrease of $2.9 million
in accumulated other comprehensive income. For the remaining quarters in 2005,
if prices remain at current levels, Bear Paw Energy expects to reclassify
approximately $2.9 million from accumulated other comprehensive income as a
decrease to operating revenues. However, this decrease would be offset with
increased operating revenues due to the higher prices assumed.
3. BUSINESS SEGMENT INFORMATION
Our business is divided into three reportable segments, defined as
components of the enterprise, about which financial information is available and
evaluated regularly by our management and the Partnership Policy Committee. Our
reportable segments are strategic business units that offer different
9
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 1. FINANCIAL STATEMENTS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
services. Each segment is managed separately because each business requires a
different marketing strategy. These segments are as follows: the Interstate
Natural Gas Pipeline segment, which provides natural gas transmission services;
the Natural Gas Gathering and Processing segment, which provides services for
the gathering, treating, processing and compression of natural gas and the
fractionation of natural gas liquids; and the Coal Slurry Pipeline segment,
which transports crushed coal suspended in water. We evaluate performance based
on EBITDA, earnings before interest, taxes, depreciation and amortization less
the allowance for equity funds used during construction ("AFUDC"). Management
uses EBITDA to compare the financial performance of our segments and to
internally manage those business segments. Management believes that EBITDA
provides useful information to investors as a measure of comparability to peer
companies. EBITDA should not be considered an alternative to, or more meaningful
than, net income or cash flow as determined in accordance with U.S. GAAP. EBITDA
calculations may vary from company to company, therefore our computation of
EBITDA may not be comparable to a similarly titled measure of another company.
The following reconciles net income to EBITDA for each segment:
RECONCILIATION OF NET INCOME (LOSS) TO EBITDA
Natural
Interstate Gas
Natural Gathering Coal
Gas and Slurry
(In thousands) Pipeline Processing Pipeline Other(a) Total
- --------------------- ---------- ---------- -------- --------- -------
THREE MONTHS ENDED
MARCH 31, 2005
Net income (loss) $32,149 $13,690 $ 745 ($11,915) $34,669
Minority interest 12,189 -- -- -- 12,189
Interest expense, net 11,204 54 -- 9,908 21,166
Depreciation and
amortization 16,569 3,958 955 -- 21,482
Income tax 730 4 165 285 1,184
AFUDC (18) -- -- -- (18)
------- ------- ------ -------- -------
EBITDA $72,823 $17,706 $1,865 ($ 1,722) $90,672
======= ======= ====== ======== =======
THREE MONTHS ENDED
MARCH 31, 2004
Net income (loss) $34,250 $10,626 $ 674 ($ 8,935) $36,615
Minority interest 12,527 -- -- -- 12,527
Interest expense, net 10,882 106 9 7,571 18,568
Depreciation and
amortization 16,677 3,642 1,278 107 21,704
Income tax 1,547 7 9 373 1,936
AFUDC (44) -- -- -- (44)
------- ------- ------ -------- -------
EBITDA $75,839 $14,381 $1,970 ($ 884) $91,306
======= ======= ====== ======== =======
10
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 1. FINANCIAL STATEMENTS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
BUSINESS SEGMENT DATA
Natural
Interstate Gas
Natural Gathering Coal
Gas and Slurry
(In thousands) Pipeline Processing Pipeline Other (a) Total
- ----------------------- ---------- ---------- -------- --------- -----
THREE MONTHS ENDED
MARCH 31, 2005
Revenues from external
customers $96,645 $57,573 $6,161 $ -- $160,379
Operating income (loss) 55,638 9,502 926 (2,528) 63,538
THREE MONTHS ENDED
MARCH 31, 2004
Revenues from external
customers $97,626 $40,741 $5,406 $ -- $143,773
Operating income (loss) 58,574 4,810 694 (2,317) 61,761
Total assets by segment are as follows:
March 31, December 31,
(In thousands) 2005 2004
- ------------------------------------- ---------- ------------
Interstate Natural Gas Pipeline $1,891,074 $1,900,555
Natural Gas Gathering and Processing 573,070 570,101
Coal Slurry Pipeline 17,180 18,268
Other (a) 19,163 21,632
---------- ----------
Total Assets $2,500,487 $2,510,556
========== ==========
(a) Includes other items not allocable to segments.
4. NET INCOME PER UNIT
Net income per unit is computed by dividing net income, after deducting
the general partners' allocation, by the weighted average number of common units
outstanding. The general partners' allocation is equal to an amount based upon
their collective 2% general partner interest adjusted for incentive
distributions. The distribution to partners amount shown on the accompanying
consolidated statement of changes in partners' equity includes incentive
distributions to the general partners of approximately $2.0 million.
On April 19, 2005, we declared a cash distribution of $0.80 per unit
($3.20 per unit on an annualized basis) for the quarter ended March 31, 2005.
The distribution is payable May 13, 2005, to unitholders of record on April 29,
2005.
11
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 1. FINANCIAL STATEMENTS - (CONCLUDED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
5. COMMITMENTS AND CONTINGENCIES
Various legal actions that have arisen in the ordinary course of business
are pending. We believe that the resolution of these issues will not have a
material adverse impact on our results of operations or financial position.
6. ACCOUNTING PRONOUNCEMENTS
In March 2005, the Financial Accounting Standards Board ("FASB") issued
Interpretation ("FIN") No. 47, "Accounting for Conditional Asset Retirement
Obligations-an interpretation of FASB Statement No. 143." The statement
clarifies that the term conditional asset retirement obligation, as used in SFAS
No. 143, "Accounting for Asset Retirement Obligations," refers to a legal
obligation to perform an asset retirement activity in which the timing and (or)
method of settlement are conditional on a future event that may or may not be
within the control of the entity. This interpretation also clarifies when an
entity would have sufficient information to reasonably estimate the fair value
of an asset retirement obligation. The effective date of this interpretation is
no later than the end of the fiscal year ending after December 15, 2005. The
effect of adopting FIN 47 is not expected to be material to our results of
operations or financial position.
12
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
Our discussion and analysis of financial condition and results of
operations is based on our Consolidated Financial Statements. The Consolidated
Financial Statements are prepared in accordance with U.S. GAAP. You should read
the following discussion and analysis in conjunction with the Consolidated
Financial Statements included elsewhere in this report.
OVERVIEW
Our businesses fall into three major business segments:
- the interstate natural gas pipeline segment, which comprises
approximately 76% of our assets;
- the natural gas gathering and processing segment, which comprises
approximately 23% of our assets; and
- the coal slurry pipeline, which comprises approximately 1% of our
assets.
There are several major business drivers that have an impact on our
business. These factors are discussed in the "Overview" section of Management's
Discussion and Analysis of Financial Condition and Results of Operations in our
2004 Form 10-K.
Interstate Natural Gas Pipeline Segment
The interstate natural gas pipeline segment includes the operations of
Northern Border Pipeline Company, Midwestern Gas Transmission Company, Viking
Gas Transmission Company and our equity interest in Guardian Pipeline, L.L.C.
As previously disclosed in Item 7. "Management's Discussion and Analysis
of Financial Condition and Results of Operations-Overview" in our Form 10-K for
the year ended December 31, 2004, Northern Border Pipeline had approximately 800
million cubic feet per day ("mmcfd") or 28% of summer design capacity under
contracts that expired or are due to expire by May 31, 2005. Most of this
capacity is available from Port of Morgan, Montana to the Ventura, Iowa delivery
point. We previously disclosed a possible reduction to Northern Border
Pipeline's revenues of $7 million to $14 million ($5 million to $10 million net
to us) and that the impact could vary outside this range depending on actual
natural gas basis differentials. As a result of contracting activity to date, we
believe a greater reduction is now likely.
For the month of April, approximately 600 mmcfd of our firm transportation
capacity was available for contracting. This firm capacity was not contracted
for the month primarily due, we believe, to the unusually high summer to winter
price differentials causing greater than average natural gas storage injections
from Western Canadian supply sources. The impact to Northern Border Pipeline
revenues for the month of April is estimated to be a reduction of approximately
$6 million ($4 million net to us).
13
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
As of May 1, 2005, Northern Border Pipeline has 340 mmcfd that remains
available for contracting in May. We believe that the greatest risk of unsold
capacity exists during the second quarter but some weakness could continue
through the balance of the year based on weather conditions and mid-continent
pricing. Consequently, we now believe that the most likely range of impact on
Northern Border Pipeline revenues from unsold capacity in 2005 is $15 million to
$28 million ($11 million to $20 million net to us). Due to the difficulty in
predicting all of the variables that can affect the marketability of Northern
Border Pipeline's capacity, this estimate is subject to change.
Natural Gas Gathering and Processing Segment
The natural gas gathering and processing segment includes the operations
of Bear Paw Energy, L.L.C. and Crestone Energy Ventures, L.L.C. In addition, the
our equity interests in Bighorn Gas Gathering, L.L.C., Fort Union Gas Gathering,
L.L.C. and Lost Creek Gathering, L.L.C. are included in this segment.
In our wholly-owned gathering assets in the Powder River Basin, gathering
volumes for 2005 are expected to be down by approximately 10% when compared to
2004. The primary reason for this change is a reduction of 45 mmcfd under a low
margin gathering contract, offset by additional volumes from new wells. Bear Paw
Energy provides different levels of services in the Powder River Basin, namely,
low-pressure and high-pressure gathering. Low-pressure gathering involves
providing services from a central delivery point to a downstream pipeline.
High-pressure gathering is providing services after the gas has been aggregated
and compressed by producers. High-pressure service requires less capital and
expense and as a result, is lower margin service. For our wholly-owned
operations in the Powder River Basin, gathering volumes from high-pressure
gathering services represent 29% of the total volume gathered, but less than 11%
of our gathering revenues in the first quarter of 2005.
The increased drilling and development activities by Bear Paw Energy's
customers continue in the Williston Basin. Due to increased system throughput
and additional acreage being dedicated to our facilities, there are a number of
projects underway to increase capacity and optimize facilities.
Coal Slurry Pipeline Segment
This segment includes Black Mesa Pipeline Company. This pipeline has one
major customer, the coal supplier to the Mohave Generating Station, in Laughlin,
Nevada. This contract on Black Mesa Pipeline provides a steady, fee for service,
revenue stream through December 31, 2005. The interested parties are continuing
to work to resolve environmental, water supply, and recontracting issues
surrounding the resumption of operations of the Mohave Generating Station after
its planned shutdown in January 2006. We believe that successful resolution of
these issues should result in reconstruction of the coal slurry pipeline in 2008
and 2009.
14
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
Certain amounts included in or affecting our Consolidated Financial
Statements and related notes must be estimated, requiring us to make certain
assumptions with respect to values or conditions that cannot be known with
certainty at the time the financial statements are prepared. The preparation of
financial statements in conformity with U.S. GAAP requires management to make
estimates and assumptions that affect the reported amounts of assets and
liabilities, disclosure of contingent assets and liabilities at the date of the
financial statements, and the reported amounts of revenues and expenses during
the reporting period. Actual results could differ from those estimates. Key
estimates used by our management include: the economic useful lives of our
assets used to determine depreciation and amortization, the fair values used to
determine possible asset impairment charges, the fair values used to record
derivative assets and liabilities, expense accruals, and the fair values of
assets acquired. Any effects on our business, financial position or results of
operations resulting from revisions to these estimates are recorded in the
period in which the facts that give rise to the revision become known.
Our significant accounting policies are summarized in Note 2 - Notes to
Consolidated Financial Statements included in our Annual Report on Form 10-K for
the year ended December 31, 2004. Certain of our accounting policies are of more
significance in our financial statement preparation process than others.
The interstate natural gas pipelines' accounting policies conform to
Statement of Financial Accounting Standards ("SFAS") No. 71, "Accounting for the
Effects of Certain Types of Regulation." Accordingly, certain assets that result
from the regulated ratemaking process are recorded that would not be recorded
under U.S. GAAP for nonregulated entities. We continually assess whether the
future recovery of the regulatory assets is probable by considering such factors
as regulatory changes and the impact of competition. If future recovery ceases
to be probable, we would be required to write off the regulatory assets at that
time. At March 31, 2005, we have recorded regulatory assets of $12.6 million,
which are being recovered, or are expected to be recovered, from the pipelines'
shippers over varying time periods up to 44 years.
Our long-lived assets are stated at original cost. We must use estimates
in determining the economic useful lives of those assets. Useful lives are based
on historical experience and are adjusted when changes in planned use,
technological advances or other factors show that a different life would be more
appropriate. The depreciation rate used for utility property is an integral part
of the interstate natural gas pipelines' Federal Energy Regulatory Commission
("FERC") tariffs. Any revisions to the estimated economic useful lives of our
assets will change our depreciation and amortization expense prospectively. For
utility property, no retirement gain or loss is included in income except in the
case of retirements or sales of entire operating units. The original cost of
utility property retired is charged to accumulated depreciation and
amortization, net of salvage and cost of removal.
15
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
We review long-lived assets for impairment in accordance with SFAS No.
144, "Accounting for the Impairment or Disposal of Long-Lived Assets."
Long-lived assets are reviewed for impairment whenever events or changes in
circumstances indicate that the carrying amount of an asset may not be
recoverable. Recoverability of the carrying amount of assets is measured by a
comparison of the carrying amount of the asset to future net cash flows expected
to be generated by the asset. Estimates of future net cash flows include
anticipated future revenues, expected future operating costs and other
estimates. If such assets are considered to be impaired, the impairment to be
recognized is measured by the amount by which the carrying amount of the assets
exceeds the fair value of the assets.
Our accounting for goodwill is in accordance with SFAS No. 142, "Goodwill
and Other Intangible Assets." We have selected the fourth quarter for the
performance of our annual impairment testing.
Our accounting for financial instruments is in accordance with SFAS No.
133, "Accounting for Derivative Instruments and Hedging Activities," which
requires that every derivative instrument be recorded on the balance sheet as
either an asset or liability measured at its fair value. The statement requires
that changes in the derivative's fair value be recognized currently in earnings
unless specific hedge accounting criteria are met. Special accounting for
qualifying hedges allows a derivative's gains and losses to offset related
results on the hedged item in the income statement. At March 31, 2005, the
consolidated balance sheet included assets from derivative financial instruments
of $1.8 million and liabilities from derivative financial instruments of $4.5
million.
For our interstate natural gas pipelines, operating revenues are derived
from agreements for the receipt and delivery of gas at points along the pipeline
system as specified in each shipper's individual transportation contract.
Revenues are recognized based upon contracted capacity and actual volumes
transported under transportation service agreements. For our gas gathering and
processing businesses, operating revenue is recorded when gas is processed in or
transported through company facilities. For our coal slurry pipeline, operating
revenue is recognized based on a contracted demand payment, actual tons
transported and direct reimbursement of certain other expenses.
16
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
RESULTS OF OPERATIONS
Our income from continuing operations was $34.3 million in the first
quarter of 2005 or $0.68 per unit as compared to $35.9 million in the first
quarter of 2004 or $0.71 per unit. The $1.6 million decrease between 2004 and
2005 is primarily due to a $2.1 million decrease in income from the interstate
natural gas pipeline segment and a $2.3 million increase in interest expense not
allocated to our business segments, which was partially offset by a $3.1 million
increase in income from the natural gas gathering and processing segment.
The following table summarizes financial and other information by business
segment for the three months ended March 31, 2005 and 2004 (in thousands):
Three Months Ended
March 31,
--------------------------
2005 2004
--------- ---------
Operating revenues
Interstate Natural Gas Pipeline $ 96,645 $ 97,626
Natural Gas Gathering and Processing 57,573 40,741
Coal Slurry Pipeline 6,161 5,406
--------- ---------
Total operating revenues 160,379 143,773
--------- ---------
Operating income (loss):
Interstate Natural Gas Pipeline 55,638 58,574
Natural Gas Gathering and Processing 9,502 4,810
Coal Slurry Pipeline 926 694
Other (2,528) (2,317)
--------- ---------
Total operating income 63,538 61,761
--------- ---------
Income (loss) from continuing operations:
Interstate Natural Gas Pipeline 32,149 34,250
Natural Gas Gathering and Processing 13,690 10,626
Coal Slurry Pipeline 745 674
Other (12,305) (9,698)
--------- ---------
Total income from continuing operations 34,279 35,852
--------- ---------
Discontinued operations, net of tax 390 763
--------- ---------
Net income $ 34,669 $ 36,615
========= =========
Operating data (1):
Interstate Natural Gas Pipeline:
Million cubic feet of gas delivered 306,692 302,898
Average daily throughput (mmcfd) 3,501 3,409
Natural Gas Gathering and Processing:
Gathering (mmcfd) 1,049 975
Processing (mmcfd) 60 50
Coal Slurry Pipeline:
Thousands of tons of coal shipped 1,282 1,154
(1) Operating data includes 100% of the volumes for joint venture and equity
investments as well as for wholly-owned subsidiaries.
17
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
Below is a detailed analysis of the results of operations for each of our
operating segments.
INTERSTATE NATURAL GAS PIPELINE SEGMENT
The interstate natural gas pipeline segment reported income of $32.1
million in the first quarter of 2005 as compared to $34.3 million in the first
quarter of 2004. The decrease in income reflects a $0.8 million decrease in
Northern Border Pipeline's income and a $1.3 million decrease in Viking Gas
Transmission's income. The decrease in Northern Border Pipeline's income was
primarily due to a $0.5 million decrease in operating revenues and a $0.5
million increase in operations and maintenance expense (a combined $0.7 million
impact on continuing operations after minority interest). The decrease in Viking
Gas Transmission's income is primarily due to a $0.4 million decrease in
operating revenues and a $1.7 million increase in operations and maintenance
expense (a combined $1.2 million impact on continuing operations after income
taxes).
Operating revenues were $96.6 million in the first quarter of 2005 as
compared to $97.6 million in 2004. The decrease in operating revenues in 2005
over 2004 resulted from a $0.5 million decrease in Northern Border Pipeline's
revenues and a $0.4 million decrease in Viking Gas Transmission's revenues. The
primary cause for the decrease in Northern Border Pipeline's revenues was leap
year, which added an additional day of transportation in 2004 as compared to
2005. The decrease in Viking Gas Transmission revenues is primarily due to a
scheduled reduction in rates for certain services and elimination of certain
surcharges.
Operations and maintenance expense was $15.7 million in the first quarter
of 2005 as compared to $13.5 million in 2004. The increase in expense in 2005
over 2004 resulted from a $0.5 million increase from Northern Border Pipeline
and $1.7 million increase from Viking Gas Transmission. The increase in Northern
Border Pipeline's expenses was primarily due to an increase in salary and
benefit expenses. The increase in Viking Gas Transmission's expenses was due to
adjustments of $1.9 million for imbalances related to its system gas, which
represents volumes of gas maintained by the pipeline for operational purposes.
Income tax expense was $0.7 million in the first quarter of 2005 as
compared to $1.5 million in 2004. The decrease was primarily due to lower income
for Viking Gas Transmission.
NATURAL GAS GATHERING AND PROCESSING SEGMENT
The natural gas gathering and processing segment reported income of $13.7
million in the first quarter of 2005 as compared to $10.6 million in 2004. The
increase in income between 2004 and 2005 is primarily due to an increase in
revenues partially offset by an increase in product purchases and a decrease in
equity earnings from unconsolidated affiliates.
Operating revenues were $57.6 million in the first quarter of 2005 as
compared to $40.7 million in 2004. The increase in revenues reflects an
18
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
increase in volumes and realized prices for natural gas and natural gas liquids,
which accounted for $17.5 million of the increase, partially offset by lower
gathering rates in the Powder River Basin.
Product purchases were $32.5 million in the first quarter of 2005 as
compared to $21.4 million in 2004. Under certain gathering and processing
agreements in the Williston Basin, Bear Paw Energy purchases raw natural gas
from producers at a price tied to a percentage of the price for which it sells
extracted natural gas and natural gas liquids. Total revenues from the sale of
these products are included in operating revenues. Amounts paid to the producers
to purchase their raw natural gas are reflected in product purchases. The
increase in expenses is due to both an increase in volumes and prices received
for Williston products.
Equity earnings from unconsolidated affiliates were $4.0 million in the
first quarter of 2005 as compared to $5.9 million for 2004. The 2004 equity
earnings include $2.8 million from a special income allocation related to a cash
distribution from our preferred A interest in Bighorn Gas Gathering. This
distribution, determined in accordance with the joint venture agreement, was
based on the number of wells connected to the gathering system in the preceding
year. If certain well connect targets are not met, we receive a disproportionate
share of cash distributions and a related special income allocation. Whether
such targets have been met for 2004 is under review. The special income
allocation will not be recorded until an agreement is reached on preferred A
distributions for 2004. At this point, we expect to record another $2.6 million
special income allocation later in 2005. Partially offsetting this decrease was
an increase in equity earnings from Lost Creek Gathering due to higher
throughput volumes.
COAL SLURRY PIPELINE SEGMENT
The coal slurry pipeline segment reported income of $0.7 million in the
first quarter of 2005 on revenues of $6.2 million. In the first quarter of 2004,
the segment reported income of $0.7 million on revenues of $5.4 million. For the
first quarter of 2005, operations and maintenance expense increased $0.8 million
primarily due to an increase in electric power costs of $0.6 million. The
electric power costs are reimbursed by Black Mesa Pipeline's customer.
OTHER
Items not attributable to any segment include certain of our general and
administrative expenses, interest expense on our debt and other income and
expense items. The interest expense not allocated to any segment was $9.9
million in the first quarter of 2005 as compared to $7.6 million in 2004. The
increase in interest expense between 2004 and 2005 was primarily related to an
increase in average debt outstanding.
19
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
LIQUIDITY AND CAPITAL RESOURCES
OVERVIEW
We believe that we have adequate liquidity to fund future recurring
operating activities and investments. Short-term liquidity needs will be met by
our operating cash flows and our current or similar credit facilities discussed
below. Other liquidity needs are expected to be funded through the issuance of
long-term debt as well as additional limited partner interests. Our ability to
complete future debt and equity offerings and the timing of any such offerings
will depend on various factors, including prevailing market conditions, interest
rates, our financial condition and credit ratings at the time.
DEBT AND CREDIT FACILITIES
Our debt and credit facilities outstanding at March 31, 2005, are as
follows:
Payments Due by Period
---------------------------
Current Portion
(Less Than Long-Term
Total 1 Year) Portion
---------- --------------- ----------
(In Thousands)
Northern Border Pipeline
$175 million Pipeline Credit
Agreement, average 3.32%,
due 2005 (a) $ 5,000 $ 5,000 $ --
6.25% Senior Notes due 2007 150,000 -- 150,000
7.75% Senior Notes due 2009 200,000 -- 200,000
7.50% Senior Notes due 2021 250,000 -- 250,000
Viking Gas Transmission
Series A, B, C and D Senior
Notes, average 7.44%,
due 2008 to 2014 30,587 2,133 28,454
Northern Border Partners, L.P.
$275 million Partnership Credit
Agreement, average 3.48%,
due 2007 (a) 191,000 -- 191,000
8 7/8% Senior Notes due 2010 250,000 -- 250,000
7.10% Senior Notes due 2011 225,000 -- 225,000
---------- ---------- ----------
Total $1,301,587 $ 7,133 $1,294,454
========== ========== ==========
(a) Northern Border Partners, L.P. and Northern Border Pipeline each are
required to pay a facility fee of 0.15% and 0.125%, respectively, on the
principal commitment amount of their credit agreements.
20
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
Each of the Partnership and Northern Border Pipeline have entered into a
revolving credit facility, which is used for refinancing existing indebtedness,
funding capital expenditures and acquisitions, and for general business
purposes. We entered into a $275 million four-year revolving credit agreement
("2003 Partnership Credit Agreement") with certain financial institutions in
November 2003. Northern Border Pipeline entered into a $175 million three-year
credit agreement ("2002 Pipeline Credit Agreement") with certain financial
institutions in May 2002. The 2002 Pipeline Credit Agreement will expire in May
2005. Northern Border Pipeline has commenced discussions with financial
institutions and expects to have a credit agreement with similar terms and
conditions in place prior to expiration. At May 6, 2005, Northern Border
Pipeline has $32.0 million borrowed under the 2002 Pipeline Credit Agreement. We
have also commenced discussions with financial institutions to replace the 2003
Partnership Credit Agreement with a new five-year facility with more favorable
terms and total availability of $500 million. We expect to have this new
facility in place in the second quarter of 2005.
Each of the 2003 Partnership Credit Agreement and the 2002 Pipeline Credit
Agreement requires the Partnership and Northern Border Pipeline to maintain
compliance with certain financial, operational and legal covenants. The 2003
Partnership Credit Agreement and 2002 Pipeline Credit Agreement require the
Partnership and Northern Border Pipeline to maintain ratios of EBITDA (net
income plus minority interests in net income, interest expense, income taxes and
depreciation and amortization) to interest expense of greater than 3 to 1. The
credit agreements also require the maintenance of the ratio of indebtedness to
adjusted EBITDA (EBITDA adjusted for pro forma operating results of acquisitions
made during the year) of no more than 4.5 to 1. Under the 2003 Partnership
Credit Agreement, if we consummate one or more acquisitions in which the
aggregate purchase price is $25 million or more, the allowable ratio of
indebtedness to adjusted EBITDA is temporarily increased to 5 to 1. At March 31,
2005, the Partnership and Northern Border Pipeline were in compliance with the
covenants of their credit agreements. The interest rate applied to amounts
outstanding under these agreements may, as selected by us and by Northern Border
Pipeline, be either the lender's base rate or the London Interbank Offered Rate
("LIBOR") plus a spread that is based upon the long-term unsecured debt ratings
in effect for us and for Northern Border Pipeline.
HEDGING ACTIVITY
In 2004, we entered into forward starting interest rate swap agreements
with a total notional amount of $100 million in anticipation of a ten-year fixed
rate senior notes issuance to be placed in the first half of 2005. The interest
rate swap agreements have been designated as cash flow hedges as they hedge the
fluctuations in Treasury rates and spreads between the execution date of the
swap agreements and the issuance of the fixed rate debt.
We currently have outstanding interest rate swap agreements with notional
amounts totaling $150 million that expire in March 2011. Under the interest rate
swap agreements, we make payments to counterparties at variable rates based on
LIBOR and in return receive payments based on a 7.10% fixed rate. At March 31,
2005, the average effective interest rate on our interest rate swap agreements
was 5.80%.
21
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
CASH FLOWS FROM OPERATING ACTIVITIES
Cash flows provided by operating activities were $67.1 million in the
first quarter of 2005 as compared to $73.3 million in 2004. The decrease in
operating cash flows is primarily due to a $3.1 million decrease in
distributions received from unconsolidated affiliates. In 2004, we received a
distribution from our common and preferred A interests in Bighorn Gas Gathering.
We have not received any distribution from Bighorn Gas Gathering in 2005. In
addition, working capital changes increased operating cash flows by $3.7 million
in 2005 as compared to $6.4 million in 2004.
CASH FLOWS FROM INVESTING ACTIVITIES
Cash used in investing activities was $11.3 million in the first quarter
of 2005 as compared to $2.1 million in 2004. Our investments in unconsolidated
affiliates totaled $1.5 million in the first quarter of 2005, which represents
contributions made to Bighorn Gas Gathering for its capital expenditures.
Capital expenditures were $9.8 million in the first quarter of 2005, which
included $5.4 million for the interstate natural gas pipeline segment and $3.9
million for the natural gas gathering and processing segment. Capital
expenditures were $2.1 million in the first quarter of 2004, which included $0.5
million for the interstate natural gas pipeline segment and $1.5 million for the
natural gas gathering and processing segment. For the interstate natural gas
pipeline segment, the capital expenditures for 2005 and 2004 were primarily
related to renewals and replacements of existing facilities. For the natural gas
gathering and processing segment, the capital expenditures for 2005 and 2004
were primarily related to growth capital expenditures. We classify expenditures
that are expected to generate additional revenues or significant operating
efficiencies as growth capital expenditures.
Total capital expenditures for 2005 are estimated to be $82 million.
Capital expenditures for the interstate natural gas pipelines are estimated to
be $54 million, including approximately $39 million for Northern Border
Pipeline. Of the $54 million projected expenditures for the interstate natural
gas pipelines, approximately $14 million relates to Northern Border Pipeline's
Chicago III Expansion Project and $8 million to $9 million relates to Midwestern
Gas Transmission's Eastern Extension Project. Northern Border Pipeline currently
anticipates funding its 2005 capital expenditures primarily by borrowing on its
credit facility and using operating cash flows. Capital expenditures for natural
gas gathering and processing facilities are estimated to be $23 million for
2005. The remaining $5 million estimated to be spent in 2005 primarily relates
to information technology systems. Funds required to meet the capital
requirements for 2005 are anticipated to be provided from our credit facility
and operating cash flows.
22
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONTINUED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
CASH FLOWS FROM FINANCING ACTIVITIES
Cash flows used in financing activities were $52.4 million in the first
quarter of 2005 as compared to $43.8 million in 2004. In January 2004, Northern
Border Pipeline received equity contributions from its general partners
including $19.5 million from its minority interest holder.
For the first quarter of 2005, borrowings on long-term debt totaled $13.0
million. For the first quarter of 2004, borrowings on long-term debt totaled
$50.0 million, which were primarily used for our equity contribution to Northern
Border Pipeline. Total debt repayments in the first quarter of 2005 and 2004
were $9.3 million and $58.9 million, respectively. The 2004 amount includes
repayments made by Northern Border Pipeline on its credit agreement of $57.0
million.
THE IMPACT OF ENRON'S CHAPTER 11 FILING ON OUR BUSINESS
Please read our Form 10-K for the year ended December 31, 2004, for the
full discussion of impacts of Enron's Chapter 11 Filing on our business.
Enron North America Corp.("ENA"), a wholly-owned subsidiary of Enron that
is in bankruptcy, was a party to transportation contracts on Northern Border
Pipeline, which ENA rejected and terminated in the bankruptcy proceedings. Since
Enron guaranteed the obligations of ENA under those contracts, Northern Border
Pipeline filed claims against both ENA and Enron for damages in the bankruptcy
proceedings. As a result of a settlement agreement, approved by the Bankruptcy
Court in March 2005, among ENA, Enron and Northern Border Pipeline, each of ENA
and Enron have agreed to allow Northern Border Pipeline's claim of approximately
$20.6 million. Based upon this settlement among the parties, at December 31,
2004, Northern Border Pipeline adjusted its allowance for doubtful accounts to
reflect a $1.1 million estimated recovery for previously billed amounts under
the transportation contracts.
In addition, Bear Paw Energy filed claims against ENA relating to
terminated swap agreements. During the third quarter 2004, the Bankruptcy Court
approved a settlement among Bear Paw Energy, Enron and certain of Enron's
wholly-owned subsidiaries of Bear Paw Energy's claim for the terminated swap
agreements. As a result, at December 31, 2004, we adjusted our allowance for
doubtful accounts to reflect an estimated $1.8 million recovery for this claim.
Crestone Energy Ventures filed claims against ENA for unpaid gas gathering
and administrative services fees in the amount of approximately $2.3 million.
ENA allowed Crestone Energy Ventures' claim of approximately $2.3 million and at
December 31, 2004, an adjustment was made to our allowance for doubtful accounts
to reflect an estimated recovery of $0.5 million for this claim.
We estimate that we could recognize additional net income through future
operating results of $4 million to $7 million for the claims in the Enron
bankruptcy proceedings. However, there can be no assurances on the amounts
actually recovered or timing of distributions under the Chapter 11 Plan.
23
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS - (CONCLUDED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
INFORMATION REGARDING FORWARD-LOOKING STATEMENTS
The statements in this Quarterly Report that are not historical
information are 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. These forward-looking statements are identified as any statement that does
not relate strictly to historical or current facts. Forward-looking statements
are not guarantees of performance. They involve risks, uncertainties and
assumptions. Our future results of operations may differ materially from those
expressed in these forward-looking statements. Such forward-looking statements
include the discussions in "Management's Discussion and Analysis of Financial
Condition and Results of Operations - Overview" and "Liquidity and Capital
Resources - Overview" regarding contracting on Northern Border Pipeline and our
estimated capital expenditures in 2005. Although we believe that our
expectations regarding future events are based on reasonable assumptions within
the bounds of our knowledge of our business, we can give no assurance that our
goals will be achieved or that our expectations regarding future developments
will be realized. Important factors that could cause actual results to differ
materially from those in the forward-looking statements herein include:
developments in the December 2, 2001, filing by Enron of a voluntary petition
for bankruptcy protection under Chapter 11 of the United States Bankruptcy Code;
industry results; future demand for natural gas; availability of supplies of
Canadian natural gas; availability of additional storage capacity; weather
conditions; the ability to recover costs of the settlement with the Fort Peck
Tribes on rights-of-way and tax issues in our rates; the rate of development,
gas quality, and competitive conditions in gas fields near the Partnership's
natural gas gathering systems in the Powder River and Williston Basins and its
investments in the Powder River and Wind River Basins; regulatory actions and
receipt of expected regulatory clearances; renewal of the coal slurry
transportation contract under favorable terms and preparation for a possible
temporary shutdown of the coal slurry pipeline; any costs related to changes in
the systems and services currently provided to us by Enron Corp. and
CrossCountry Energy and their affiliates and costs related to replacing these
systems and services or transitioning them to ONEOK; competitive conditions in
the overall natural gas and electricity markets; the ability to market pipeline
capacity on favorable terms; performance of contractual obligations by the
shippers; prices of natural gas and natural gas liquids; the impact of unsold
capacity on Northern Border Pipeline or our other pipelines being greater than
expected; actions by rating agencies; the ability to negotiate gathering
contracts with producers on favorable terms; successful resolution of the
special income allocation related to a cash distribution on preferred A interest
in Bighorn Gas Gathering; political and regulatory developments that impact FERC
proceedings involving interstate pipelines and the interstate pipelines' success
in sustaining their positions in such proceedings; regulatory actions relative
to rate recovery of income tax allowances for partnerships; timely receipt of
right-of-way, regulatory clearances and approval for the expansion projects; the
ability to control operating costs; competitive developments by Canadian and
U.S. natural gas transmission peers; our ability to complete acquisitions or
growth projects and their future performance; and conditions in the capital
markets and the ability to access the capital markets.
24
PART I. FINANCIAL INFORMATION - (CONTINUED)
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
We may be exposed to market risk through changes in commodity prices and
interest rates as discussed below. A control environment has been established
which includes policies and procedures for risk assessment and the approval,
reporting and monitoring of financial instrument activities.
We have utilized and expect to continue utilizing financial instruments in
the management of interest rate risks and our natural gas and natural gas
liquids marketing activities to achieve more predictable cash flows by reducing
our exposure to interest rate and price fluctuations. We do not use these
instruments for trading purposes.
INTEREST RATE RISK
Our interest rate exposure results from variable rate borrowings from
commercial banks. To mitigate potential fluctuations in interest rates, we
attempt to maintain a significant portion of our consolidated debt portfolio in
fixed rate debt. We also use interest rate swap agreements as a means to manage
interest expense by converting a portion of fixed rate debt to variable rate
debt. At March 31, 2005, we had $346.0 million of variable rate debt
outstanding, $150.0 million of which was previously fixed rate debt that had
been converted to variable rate debt through the use of interest rate swap
agreements. As of March 31, 2005, approximately 74% of our debt portfolio was in
fixed rate debt.
If average interest rates change by one percent compared to rates in
effect as of March 31, 2005, consolidated annual interest expense would change
by approximately $3.5 million. This amount has been determined by considering
the impact of the hypothetical interest rates on our variable rate borrowings
outstanding as of March 31, 2005.
COMMODITY PRICE RISK
Bear Paw Energy is subject to certain contracts that give it quantities of
natural gas and natural gas liquids as partial consideration for processing
services. The income and cash flows from these contracts will be impacted by
changes in prices for these commodities. Considering the effects of any hedging,
for each $0.10 per million British thermal unit change in natural gas prices or
for each $0.01 per gallon change in natural gas liquid prices, our annual net
income would change by approximately $0.2 million and $0.1 million,
respectively. This amount has been determined by considering the impact of the
hypothetical commodity prices on our projected gathering and processing volumes
for 2005. The sensitivity could be impacted by changes to our projected
throughput volumes. We have hedged approximately 56% of our commodity price risk
for the remainder of 2005 based on our projected volumes.
25
PART I. FINANCIAL INFORMATION - (CONCLUDED)
ITEM 4. CONTROLS AND PROCEDURES
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
Evaluation of Disclosure Controls and Procedures.
As of the end of the period covered by this report, we carried out an
evaluation, under the supervision and with the participation of our Chief
Executive Officer and our Chief Financial and Accounting Officer, of the
effectiveness of disclosure controls and procedures as defined in Rules
13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended.
Based on such evaluation, our Chief Executive Officer and our Chief Financial
and Accounting Officer have concluded that as of the end of the period covered
by this report, our disclosure controls and procedures were effective in
recording, processing, summarizing and reporting information, and timely
alerting them to material information relating to us (including our consolidated
subsidiaries) required to be included in our periodic filings with the
Securities and Exchange Commission.
Changes in Internal Control over Financial Reporting.
During the most recently completed fiscal quarter, we continued to
implement changes to our internal control over financial reporting related to
the transition from Enron systems to ONEOK systems or our systems ("Transition
Project"). As of January 1, 2005, most of our financial and accounting systems
had been transitioned from Enron systems to ONEOK systems. The Transition
Project is anticipated to be completed by mid-May 2005. We anticipate that there
will be additional changes in internal control over financial reporting as a
result of the Transition Project.
As part of the transition process, we evaluate the impact of these changes
on our internal control over financial reporting and have determined that these
changes have not materially affected, or are not reasonably likely to materially
affect, our internal control over financial reporting.
26
PART II. OTHER INFORMATION
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
ISSUER PURCHASE OF EQUITY SECURITIES
Total number of units Maximum number of
purchased as part of units that may
Total number Average publicly announced yet be purchased
of units price paid repurchase plan or under the plan or
Month purchases per unit program(1) programs
- -------------- ------------ ---------- --------------------- -----------------
(a) (b) (c) (d)
January 1-31,
2005 10,000 $ 48.8493 10,000 0
February 1-28,
2005 0 -- 0 0
March 1-31,
2005 0 -- 0 0
------ --------- ------ --
Total 10,000 10,000 0
====== ========= ====== ==
(1) On January 4, 2005, we announced a repurchase program by Northern Plains
Natural Gas Company, LLC, one of our general partners, to purchase in the open
market up to 10,000 common units to satisfy obligations in January 2005 under
the Amended and Restated Northern Border Phantom Unit Plan. Those units were
purchased on January 12 and 13, 2005.
ITEM 5. OTHER INFORMATION
On May 4, 2005, the FERC issued a policy statement as a result of its
request for comments on the proper tax allowance treatment for capital
structures involving partnerships and other forms of ownership. Under the new
policy, an income tax allowance would be permitted on all partnership interests
if the owner of that interest has an actual or potential income tax liability on
that income. As previously disclosed, Northern Border Pipeline's tariff
provides for an income tax allowance. We believe that the policy statement
generally is a positive development regarding income tax allowances in the
derivation of rates for pipelines. In the event the policy statement is
applied to our interstate natural gas pipelines, the issue of whether a
particular owner has an actual or potential income tax liability and related
matters may be resolved in individual rate proceedings.
27
PART II. OTHER INFORMATION (CONCLUDED)
NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
ITEM 6. EXHIBITS
3.1 Amended and Restated Agreement of Limited Partnership of Northern
Border Intermediate Limited Partnership dated as of October 1, 1993.
10.1 Form of Termination Agreement dated as of January 5, 2005,
incorporated by reference to Exhibit 99.1 to the registrant's Form
8-K filed on January 11, 2005.
10.2 ONEOK, Inc. 2005 Supplemental Executive Retirement Plan filed as
Exhibit 99.2 to registrant's Form 8-K filed on January 11, 2005.
31.1 Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer.
31.2 Rule 13a-14(a)/15d-14(a) Certification of Chief Financial and
Accounting Officer.
32.1 Section 1350 Certification of Chief Executive Officer.
32.2 Section 1350 Certification of Chief Financial and Accounting Officer.
28
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the
Registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
NORTHERN BORDER PARTNERS, L.P.
(A Delaware Limited Partnership)
Date: May 9, 2005 By: /s/ Jerry L. Peters
----------------------------------
Jerry L. Peters
Chief Financial and Accounting
Officer
29
Index to Exhibits
Exhibit No Description
- ---------- ---------------------------------------------------------------------------------
3.1 Amended and Restated Agreement of Limited Partnership of Northern Border
Intermediate Limited Partnership
10.1 Form of Termination Agreement dated as of January 5, 2005, incorporated by
reference to Exhibit 99.1 to the registrant's Form 8-K filed on January 11, 2005.
10.2 ONEOK, Inc. 2005 Supplemental Executive Retirement Plan filed as Exhibit 99.2 to
registrant's Form 8-K filed on January 11, 2005.
31.1 Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer.
31.2 Rule 13a-14(a)/15d-14(a) Certification of Chief Financial and Accounting Officer.
32.1 Section 1350 Certification of Chief Executive Officer.
32.2 Section 1350 Certification of Chief Financial and Accounting Officer.