UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549


FORM 10-K

[X] ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934

For the fiscal year ended December 31, 2004

[ ] 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
 incorporation or organization)                              Identification No.)

13710 FNB PARKWAY, OMAHA, NEBRASKA 68154-5200
(Address of principal executive offices) (Zip Code)

Registrant's telephone number, including area code: 402-492-7300


SECURITIES REGISTERED PURSUANT TO SECTION 12(b) OF THE ACT:

Title of each class                    Name of each exchange on which registered
-------------------                    -----------------------------------------
   Common Units                                 New York Stock Exchange

SECURITIES REGISTERED PURSUANT TO SECTION 12(g) OF THE ACT:
None

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 if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [X]


Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act). Yes [X] No [ ]

Aggregate market value of the Common Units held by non-affiliates of the registrant, based on closing prices in the daily composite list for transactions on the New York Stock Exchange on June 30, 2004, was approximately $1,832,811,558.

As of March 3, 2005, 46,397,214 Common Units were outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

None.

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NORTHERN BORDER PARTNERS, L.P.
TABLE OF CONTENTS

                                                                        PAGE NO.
                                                                        --------
                                     PART I

Item 1.    Business                                                         1
Item 2.    Properties                                                      20
Item 3.    Legal Proceedings                                               21
Item 4.    Submission of Matters to a Vote of Security Holders             21

                                     PART II

Item 5.    Market for Registrant's Common Equity, Related
              Stockholder Matters and Issuer Purchases of Equity
              Securities                                                   22
Item 6.    Selected Financial Data                                         24
Item 7.    Management's Discussion and Analysis of Financial
              Condition and Results of Operations                          26
Item 7A.   Quantitative and Qualitative Disclosures About Market
              Risk                                                         53
Item 8.    Financial Statements and Supplementary Data                     54
Item 9.    Changes in and Disagreements With Accountants on
              Accounting and Financial Disclosure                          54
Item 9A.   Controls and Procedures                                         57
Item 9B.   Other Information

                                    PART III

Item 10.   Directors and Executive Officers of the Registrant              58
Item 11.   Executive Compensation                                          66
Item 12.   Security Ownership of Certain Beneficial Owners
              and Management and Related Stockholder Matters               73
Item 13.   Certain Relationships and Related Transactions                  74
Item 14.   Principal Accounting Fees and Services                          76

                                     PART IV

Item 15.   Exhibits and Financial Statement Schedules                      78

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PART I

ITEM 1. BUSINESS.

GENERAL

We are a publicly-traded limited partnership formed in 1993 and a leading transporter of natural gas imported from Canada to the United States. Our business operations are comprised of the following segments:

- Interstate Natural Gas Pipeline

- Natural Gas Gathering and Processing

- Coal Slurry Pipeline

Our interstate natural gas pipelines segment includes companies that provide natural gas transmission services in the midwestern United States. The companies in this segment transport gas for shippers under tariffs regulated by the Federal Energy Regulatory Commission ("FERC"). The interstate pipelines' revenues are derived from agreements for the receipt and delivery of gas at points along the pipeline systems as specified in each shipper's individual transportation contract.

Our gas gathering and processing segment provides services for the gathering, treating, processing and compression of natural gas and the fractionation of natural gas liquids ("NGLs") for third parties. We do not explore for, or produce, crude oil or natural gas, and do not own crude oil or natural gas reserves. We have extensive natural gas gathering, processing and fractionation operations in the Williston Basin in Montana and North Dakota as well as gas gathering operations in the Powder River Basin and Wind River Basin in Wyoming. In December 2004, we sold our interest in the Gregg/Lake Obed Pipeline in Alberta, Canada.

Our coal slurry pipeline segment is comprised of our ownership of Black Mesa Pipeline, Inc. The 273-mile pipeline is the only coal slurry pipeline in operation in the United States. The coal slurry pipeline transports crushed coal suspended in water from a coal mine in Kayenta, Arizona to the Mohave Generating Station in Laughlin, Nevada.

We are managed under the direction of a partnership policy committee (similar to a board of directors). The partnership policy committee consists of three members, each of whom has been appointed by one of our general partners. Our general partners and the general partners of our subsidiary limited partnership, Northern Border Intermediate Limited Partnership, are Northern Plains Natural Gas Company, LLC ("Northern Plains") and Pan Border Gas Company, LLC, ("Pan Border") both subsidiaries of ONEOK, Inc. ("ONEOK"), and Northwest Border Pipeline Company, a subsidiary of TransCanada PipeLines Limited which is a subsidiary of TransCanada Corporation, collectively referred to as "TransCanada". In November 2004, ONEOK purchased Northern Plains, Pan Border and NBP Services, LLC from CCE Holdings, LLC ("CCE Holdings"). CCE Holdings, a joint venture between Southern Union Company and GE Commercial Finance Energy Financial purchased Northern Plains, Pan Border and NBP Services, LLC as part of its acquisition of CrossCountry Energy, LLC ("CrossCountry"). See Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - The Impact Of Enron's Chapter 11 Filing On Our Business."

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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.

Our general partners hold an aggregate 2% general partner interest in the Partnership. Northern Plains also owns common units representing a 1.06% limited partner interest. See Item 12. "Security Ownership of Certain Beneficial Owners and Management." The combined general and limited partner interests in the Partnership held by ONEOK and TransCanada are 2.71% and 0.35%, respectively.

NBP Services, LLC, a ONEOK subsidiary ("NBP Services"), provides administrative services for us and our subsidiaries and operating services for our natural gas gathering and processing segment. NBP Services has approximately 130 employees located in Denver, Colorado and at various locations at or near our gathering and processing facilities and also utilizes employees and information technology systems of its affiliates to provide these services. Northern Plains provides operating services to our interstate pipelines pursuant to operating agreements. Northern Plains employs approximately 310 individuals located at our headquarters in Omaha, Nebraska, and at various locations near the pipelines and also utilizes employees and information technology systems of its affiliates to provide these services. NBP Services' and Northern Plains' employees are not represented by any labor union and are not covered by any collective bargaining agreements.

For financial information about each of our business segments, see Note 16 to Consolidated Financial Statements included elsewhere in this report.

AVAILABLE INFORMATION

We make available free of charge, through our website, www.northernborderpartners.com, (a) our annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act as soon as reasonably practicable after we electronically file such material with, or furnish it to, the Securities and Exchange Commission ("SEC"), (b) our Governance Guidelines, (c) our Code of Conduct, (d) our Accounting and Financial Reporting Code of Ethics, (e) our Partnership Agreement and (f) the written charter of the Audit Committee. The Partnership's documents filed with, or furnished to, the SEC are also available at the SEC's website at www.sec.gov. Additionally, you can request a copy of these documents, excluding exhibits, at no cost, by contacting Investor Relations Department, Northern Border Partners, L.P., P.O. Box 542500, Omaha, NE 68154-8500.

INTERSTATE NATURAL GAS PIPELINE SEGMENT

Our interstate natural gas pipeline segment provides natural gas transmission services in the midwestern United States. Our interstate pipelines transport gas for shippers under tariffs regulated by the FERC. The tariffs specify the maximum and minimum transportation rates and the general terms and conditions of transportation service on the pipeline systems. Our interstate pipelines' revenues are derived from agreements for the receipt and delivery of gas at points along the pipeline systems as specified in each shipper's individual transportation contract. Generally, firm shippers are obligated to pay a monthly demand charge, regardless of the amount of natural gas they actually transport, for the term of their contracts. For our wholly-owned interstate pipelines, approximately 98% of the revenue generated is attributed to demand charges. The remaining 2% is attributed to commodity charges based on the volumes of gas actually transported. Our

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interstate pipelines do not own the gas that they transport for others and therefore do not assume natural gas commodity price risk for quantities transported. Any exposure to commodity risk for imbalances on the pipeline systems that may result from under or over deliveries to customers or interconnecting pipelines is either recovered through provisions in the tariffs or is immaterial. Our interstate pipelines own the line pack, which is the amount of gas necessary to maintain efficient operations of the pipeline. Shippers on each system are responsible to provide fuel gas necessary for the operation of the gas compressor stations on the pipelines. For Northern Border Pipeline Company and Viking Gas Transmission Company, the fuel gas collected from shippers is adjusted periodically to track the gas consumed. On Midwestern Gas Transmission Company, a fixed amount of fuel gas is collected. As a result, if the amount provided by shippers does not equal the amount consumed in its operations, Midwestern Gas Transmission is required to buy or sell natural gas. For 2004, Northern Border Pipeline Company, Midwestern Gas Transmission Company and Viking Gas Transmission Company accounted for 86%, 6% and 8%, respectively of the revenues in the interstate pipeline segment. Also reported in this segment is Guardian Pipeline, L.L.C. ("Guardian Pipeline") for which we own a one-third interest.

NORTHERN BORDER PIPELINE SYSTEM

We own a 70% general partnership interest in Northern Border Pipeline Company, a Texas general partnership ("Northern Border Pipeline"). Northern Border Pipeline owns a 1,249-mile interstate pipeline system that transports natural gas from the Montana-Saskatchewan border near Port of Morgan, Montana to natural gas markets in the midwestern United States. Construction of the pipeline was initially completed in 1982. The pipeline system was expanded and/or extended in 1991, 1992, 1998 and 2001. This pipeline system connects directly and through multiple pipelines to various natural gas markets in the United States. For the year ended December 31, 2004, we estimate that Northern Border Pipeline transported approximately 22% of the total amount of natural gas imported from Canada to the United States. Over the same period, approximately 88% of the natural gas transported by Northern Border Pipeline was produced in the western Canadian sedimentary basin located in the provinces of Alberta, British Columbia and Saskatchewan.

Our interest in Northern Border Pipeline represents the largest proportion of our assets, earnings and cash flows. The remaining 30% general partner interest in Northern Border Pipeline is owned by TC PipeLines Intermediate Limited Partnership, a subsidiary limited partnership of TC PipeLines, LP, a publicly-traded partnership ("TC PipeLines"). The general partner of TC PipeLines and its subsidiary limited partnership is TC PipeLines GP, Inc., which is a subsidiary of TransCanada.

Management of Northern Border Pipeline is overseen by the Northern Border Management Committee, which is comprised of three representatives from the Partnership (one designated by each of our general partners) and one representative from TC PipeLines. Voting power on the management committee is allocated among Northern Border Partners' three representatives in proportion to their general partner interests in Northern Border Partners. As a result, the 70% voting power of our three representatives on the management committee is allocated as follows: 35% to the representative designated by Northern Plains, 22.75% to the representative designated by Pan Border and 12.25% to the representative designated by Northwest Border. Therefore, ONEOK controls 57.75% of the voting power of the management committee and has the right to select two of its members. For a discussion of specific relationships with affiliates, refer to Item 13. "Certain Relationships and Related Transactions."

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The Northern Border Pipeline system consists of: (i) 822 miles of 42-inch diameter pipe from the Canadian border to Ventura, Iowa, capable of transporting on a summer design basis a total of 2,374 million cubic feet per day ("mmcfd");
(ii) 30-inch diameter pipe and 36-inch diameter pipe, each approximately 147 miles in length, capable of transporting 1,484 mmcfd in total from Ventura, Iowa to Harper, Iowa; (iii) 224 miles of 36-inch diameter pipe and 21 miles of 30-inch diameter pipe capable of transporting 844 mmcfd from Harper, Iowa to Manhattan, Illinois (Chicago area); and (iv) 35 miles of 30-inch diameter pipe capable of transporting 544 mmcfd from Manhattan, Illinois to a terminus near North Hayden, Indiana. A summer design basis pipeline is capable of transporting, at a minimum, the stated capacity at all times of the year. Along the pipeline there are 16 compressor stations with total rated horsepower of 499,000 and measurement facilities to support the receipt and delivery of gas at various points. Other facilities include four field offices and a microwave communication system with 50 tower sites.

The pipeline system has pipeline access to natural gas reserves in the western Canadian sedimentary basin in the provinces of Alberta, British Columbia and Saskatchewan in Canada, domestic natural gas produced within the Williston Basin and the Powder River Basin, and synthetic gas produced at the Dakota Gasification plant in North Dakota. In addition, the pipeline is capable of physically receiving natural gas at two locations near Chicago. For the year ended December 31, 2004, of the natural gas transported on the pipeline system, approximately 88% was produced in Canada, approximately 4% was produced by the Dakota Gasification plant, and approximately 8% was produced in the Williston Basin.

To access markets, the pipeline system interconnects with pipeline facilities of various interstate and intrastate pipeline companies and local distribution companies, as well as with end-users. The larger interconnections are:

- Northern Natural Gas Company at Ventura, Iowa as well as multiple smaller interconnections in South Dakota, Minnesota and Iowa;

- Natural Gas Pipeline Company of America at Harper, Iowa;

- MidAmerican Energy Company at Iowa City and Davenport, Iowa and Cordova, Illinois;

- Alliant Power Company at Prophetstown, Illinois;

- Northern Illinois Gas Company at Troy Grove and Minooka, Illinois;

- Midwestern Gas Transmission near Channahon, Illinois;

- ANR Pipeline Company near Manhattan, Illinois;

- Vector Pipeline L.P. in Will County, Illinois;

- Guardian Pipeline in Will County, Illinois;

- The Peoples Gas Light and Coke Company near Manhattan, Illinois; and

- Northern Indiana Public Service Company near North Hayden, Indiana at the terminus of the pipeline system.

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Several market centers, where natural gas transported on the pipeline system is sold, traded and received for transport to consuming markets in the Midwest and to interconnecting pipeline facilities, have developed on the pipeline system. The largest of these market centers is at Northern Border Pipeline's Ventura, Iowa interconnection with Northern Natural Gas Company. Two other market center locations are the Harper, Iowa connection with Natural Gas Pipeline Company of America and the multiple interconnects in the Chicago area that include connections with Northern Illinois Gas Company, The Peoples Gas Light and Coke Company and Northern Indiana Public Service Company, as well as four interstate pipelines.

All of Northern Border Pipeline's summer design capacity was under contract as of December 31, 2004 and, assuming no extensions of existing contracts or execution of new contracts, approximately 61% and 51% of summer design capacity is under contract as of December 31, 2005 and 2006, respectively. The pipeline system serves approximately 40 firm transportation shippers with diverse operating and financial profiles. Based upon shippers' contractual obligations, as of December 31, 2004, 92% of firm capacity contracted is with producers and marketers. The remaining firm capacity contracted primarily is with local distribution companies (7%) and end-users (1%). As of December 31, 2004, the termination dates of these contracts ranged from December 31, 2004 to December 21, 2013, and the weighted average contract life was approximately two and three-quarters years based upon contractual obligations and summer design capacity. See Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Overview - Interstate Natural Gas Pipeline Segment - Northern Border Pipeline Recontracting" for information regarding Northern Border Pipeline's recontracting.

Northern Border Pipeline's shippers may change throughout the year as a result of its shippers utilizing capacity release provisions that allow them to release all or part of their capacity, either permanently for the full term of their contract or temporarily. Under the terms of Northern Border Pipeline's tariff, a temporary capacity release does not relieve the originally contracted shipper from its payment obligations if the new shipper fails to pay.

At December 31, 2004, Nexen Marketing U.S.A. Inc., BP Canada Energy Marketing Corp. ("BP Canada"), EnCana Marketing U.S.A. Inc. and Cargill Incorporated were obligated for approximately 18%, 14%, 13% and 12%, respectively, of the summer design capacity. Contracts for approximately 63% of the capacity contracted by these shippers are due to expire by November 1, 2005. See Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Overview."

One of Northern Border Pipeline's shippers, ONEOK Energy Services Company, LP,("ONEOK Energy") a subsidiary of ONEOK, is affiliated with us. ONEOK Energy holds firm contracts representing 3% of summer design capacity. ONEOK Energy has also committed to be a shipper on the Chicago III Expansion project. See Item
13. "Certain Relationships and Related Transactions."

MIDWESTERN GAS TRANSMISSION SYSTEM

Midwestern Gas Transmission Company, our wholly-owned subsidiary ("Midwestern Gas Transmission"), owns a 350-mile pipeline system extending from an interconnection with Tennessee Gas Transmission near Portland, Tennessee to a point of interconnection with several interstate pipeline systems near Joliet, Illinois. Midwestern Gas Transmission serves markets in Chicago, Illinois, Kentucky, southern Illinois and Indiana.

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The Midwestern Gas Transmission system consists of 350 miles of 30-inch and 24-inch diameter pipe with a capacity of 650 mmcfd for volumes transported from Portland, Tennessee to the north. There are seven compressor stations with total rated horsepower of 65,570. The Midwestern Gas Transmission system is also capable of moving approximately 387 mmcfd southbound depending upon receipt and delivery point locations.

The Midwestern Gas Transmission system connects with multiple pipeline systems that provide its shippers access to various supply sources and markets. Because of its position in the natural gas pipeline grid, Midwestern Gas Transmission is designed to receive gas volumes at both ends of its system. On the north end, Midwestern Gas Transmission can physically receive gas from ANR Pipeline Company, Northern Border Pipeline, Natural Gas Pipeline Company of America, Alliance Pipeline, The Peoples Gas Light and Coke Company and Trunkline Gas Company. The significant receipt point on the southern end of the system is the interconnection with Tennessee Gas Transmission at Portland. Additionally, Midwestern Gas Transmission is capable of receiving gas at five other interconnections along its pipeline system. With respect to market access, Midwestern Gas Transmission is capable of delivering natural gas at points of interconnection with the interstate pipeline systems of ANR Pipeline Company, Guardian Pipeline, Natural Gas Pipeline Company of America, Northern Border Pipeline, Texas Eastern Transmission Company and Texas Gas Transmission Company. There are interconnections with local distribution companies such as Northern Illinois Gas Company, The Peoples Gas Light and Coke Company, Illinois Power, and Vectren Energy Delivery. In addition, a number of end-users and electric power generation facilities can be served by connections off the pipeline system.

The Midwestern Gas Transmission system serves approximately 25 firm transportation shippers. Based upon shipper firm contractual obligations as of December 31, 2004, approximately 68% of the contracted capacity is with local distribution companies, 30% with marketers and 2% with end-users.

As of December 31, 2004, Midwestern Gas Transmission's three largest shippers were Northern Illinois Gas Company, ProLiance Energy LLC and The Peoples Gas Light and Coke Company who were obligated for approximately 32%, 16% and 14%, respectively, of the system design capacity.

As of December 31, 2004, the termination dates of Midwestern Gas Transmission's firm transportation contracts ranged from December 31, 2004 to October 31, 2019. On December 31, 2004, approximately 91% of the northbound system design capacity and approximately 90% of southbound system design capacity was contracted on a firm basis and assuming no extensions of existing contracts or executions of new contracts approximately 75% and 20% of northbound design capacity and 48% and 11% of southbound design capacity is under contract as of December 31, 2005 and 2006, respectively. See Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Overview."

VIKING GAS TRANSMISSION SYSTEM

Our wholly-owned subsidiary, Viking Gas Transmission Company ("Viking Gas Transmission"), owns a pipeline system that extends from an interconnection with TransCanada near Emerson, Manitoba to an interconnection with ANR Pipeline Company near Marshfield, Wisconsin. Viking Gas Transmission's source of gas supply is the western Canadian sedimentary basin. Viking Gas Transmission also has interconnections with Northern Natural Gas Company and Great Lakes Gas Transmission to serve markets in Minnesota, Wisconsin and North Dakota.

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The Viking Gas Transmission system consists of: (i) 499 miles of 24-inch diameter mainline pipe with a summer design capacity of approximately 500 mmcfd at the origin near Emerson, Manitoba and 300 mmcfd at the terminus near Marshfield, Wisconsin, (ii) 95 miles of 24-inch mainline looping; and (iii) 79 miles of smaller diameter laterals. There are eight compressor stations with total horsepower of 68,650.

The Viking Gas Transmission system serves approximately 35 firm transportation shippers. Based upon shipper contractual obligations as of December 31, 2004, approximately 80% of the contracted firm capacity is with local distribution companies, 15% with marketers and 5% with end-users. As of December 31, 2004, Viking Gas Transmission's largest customers were Wisconsin Gas, LLC, CenterPoint Energy Minnegasco, Northern States Power Company-Minnesota, Michigan Consolidated Gas Company and Wisconsin Public Service Corporation, who were obligated for approximately 19%, 15%, 15%, 10% and 10%, respectively, of the summer design capacity.

As of December 31, 2004, the termination dates of Viking Gas Transmission's firm transportation contracts ranged from March 31, 2005 to October 31, 2014. On December 31, 2004, all of the summer design capacity at the origin of the pipeline near Emerson was contracted on a firm basis and assuming no extensions of existing contracts or execution of new contracts, approximately 85% and 83% of summer design capacity is under contract as of December 31, 2005 and 2006, respectively.

GUARDIAN PIPELINE SYSTEM

Viking Gas Transmission owns a 33-1/3% interest in Guardian Pipeline, which is a 141-mile interstate natural gas pipeline that was placed into service in December 2002. This system transports natural gas from Joliet, Illinois to a point west of Milwaukee, Wisconsin. Subsidiaries of Wisconsin Public Service and Wisconsin Energy Corporation hold the remaining interests in this system. Wisconsin Gas Company, a subsidiary of Wisconsin Energy Corporation, has contracted for 87% of the pipeline's 750 mmcfd capacity. Guardian Pipeline is currently operated by Northern Plains under an operating agreement that was effective July 1, 2004. Prior to that date, Trunkline Gas Company, which is part of Southern Union Company, was the operator. See Item 13. "Certain Relationships and Related Transactions."

DEMAND FOR INTERSTATE PIPELINE TRANSPORTATION CAPACITY

Recent developments have resulted in proposed expansions of our pipeline systems. In September 2004, Northern Border Pipeline announced it had received commitments from shippers sufficient to support a proposed expansion of the pipeline system into the Chicago market area. The "Chicago III Expansion" project, with an estimated 130 mmcfd of capacity, would involve construction of a new compressor station and minor modifications to two other compressor stations, and is estimated to cost approximately $21 million. The projected in-service date is April 1, 2006. FERC approval of this project is required and Northern Border Pipeline expects to file the required certificate application in March 2005.

Also, in August 2004, we announced that Midwestern Gas Transmission had finalized the necessary contractual commitment to proceed with its Eastern Extension Project. This project involves the construction of approximately 30 miles of 16-inch diameter pipeline, with a capacity of approximately 120 mmcfd, from Portland, Tennessee to planned interconnections with Columbia Gulf Transmission Company and East Tennessee Pipeline Company. The project is supported by a

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precedent agreement with Piedmont Natural Gas Company, a local distribution company, for approximately 120 mmcfd for a term of 15 years. Pending the receipt of regulatory and other required approvals, the proposed in-service date for the project is November 2006 and project costs are estimated at approximately $22 million to $25 million.

The long-term financial condition of our interstate natural gas pipeline segment is dependent on the continued availability of economic natural gas supplies, including western Canadian natural gas for import into the United States. Natural gas reserves may require significant capital expenditures by others for exploration and development drilling and the installation of production, gathering, storage, transportation and other facilities that permit natural gas to be produced and delivered to pipelines that interconnect with our interstate pipelines' systems. Prices for natural gas, the currency exchange rate between Canada and the United States, regulatory limitations or the lack of available capital for these projects could adversely affect the development of additional reserves and production, gathering, storage and pipeline transmission of natural gas supplies. Increased Canadian consumption related to the extraction process for oil sands projects as well as restrictions on gas production to protect oil sand reserves could also impact supplies of natural gas for export. Additional pipeline capacity from producing basins also could accelerate depletion of these reserves. Excess pipeline capacity could also affect the demand or value of the transport on our interstate pipelines.

Each of our interstate pipelines' business also depends on the level of demand for natural gas in the markets the pipeline system serves. The volumes of natural gas delivered to these markets from other sources affect the demand for both the natural gas supplies and the use of the pipeline systems. Demand for natural gas to serve other markets also influences the ability and willingness of shippers to use our pipeline systems to meet demand in the markets that our interstate pipelines serve.

A variety of factors could affect the demand for natural gas in the markets that our pipeline systems serve. These factors include:

- economic conditions;

- fuel conservation measures;

- alternative energy sources' requirements and prices;

- gas storage inventory levels;

- climatic conditions;

- government regulation; and

- technological advances in fuel economy and energy generation devices.

Our interstate pipelines' primary exposure to market risk occurs at the time existing transportation contracts expire and are subject to renegotiation. A key determinant of capacity value for shippers that have competitive pipeline alternatives is the basis differential or market price spread between two points on the pipeline. The difference in natural gas prices between the points along the pipeline where gas enters and where gas is delivered represents the gross margin that a shipper can expect to achieve from holding transportation capacity at any

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point in time. This margin and its variability become important factors in determining the rate customers are willing to pay when they renegotiate their transportation contracts. The basis differential between markets can be affected by trends in production, available pipeline capacity, storage inventories, weather and general market demand in the respective areas.

Throughput on our interstate pipelines may experience seasonal fluctuations depending upon the level of winter heating load demand, summer electric generation usage in the markets served by the pipeline systems and/or storage injection load. To the extent that capacity is contracted at maximum rates under firm transportation agreements, 98% of the expected charges are from demand charges that are not impacted materially by such seasonal throughput variations. However, as contracts terminate, renewals and replacements may be affected by seasonal fluctuations and historic usage patterns. See Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Overview."

We cannot predict whether these or other factors will have an adverse affect on demand for use of our interstate pipelines' systems or how significant that adverse affect could be.

INTERSTATE PIPELINE COMPETITION

Northern Border Pipeline and Viking Gas Transmission compete with other pipeline companies that transport natural gas from the western Canadian sedimentary basin or that transport natural gas to end-use markets in the midwestern United States. Their competitive positions are affected by the availability of Canadian natural gas for export, the availability of other sources of natural gas and demand for natural gas in the United States. Demand for transportation services on the systems is affected by natural gas prices, the relationship between export capacity and production in the western Canadian sedimentary basin, and natural gas shipped from producing areas in the United States. Shippers of natural gas produced in the western Canadian sedimentary basin also have other options to transport Canadian natural gas to the United States, including transportation on the Alliance Pipeline to the Chicago market area, on TransCanada's pipeline system through various interconnections with U.S. interstate pipelines in the upper Midwest and northeast markets and on the Westcoast Pipeline and TransCanada B.C. systems and through various interconnections with U.S. interstate pipelines serving northwest and west coast markets. In the near term, Northern Border Pipeline's short-term contracted capacity competes primarily with available and short-term capacity on the TransCanada and Westcoast pipelines. Alliance Pipeline is not a competitor in the short-term for Northern Border Pipeline, since substantially all of its capacity is contracted under long-term contracts.

In addition, Northern Border Pipeline competes in its markets with other interstate pipelines that provide access to other supply basins. Northern Border Pipeline's major deliveries into Northern Natural Gas at Ventura, Iowa compete with gas supplied from the Rockies and mid-continent regions. Northern Border Pipeline also competes with these supply basins at its delivery interconnect with Natural Gas Pipeline of America at Harper, Iowa. In the Chicago area, Northern Border Pipeline competes with many interstate pipelines that transport gas from the Gulf Coast, mid-continent, Rockies and western Canada. In December 2004, the Cheyenne Plains Pipeline system commenced service from the Cheyenne Hub in the Rocky Mountain area to the mid-continent area. The pipeline will provide additional supply and transportation competition in markets served by Northern Border Pipeline. The supply balance in the mid-continent area can impact the value of gas that is traded at Ventura, Iowa and Harper, Iowa delivery points and gas traded in

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the Chicago area. A change in trading value at these market centers will affect the corresponding transportation value of that portion of Northern Border Pipeline's system upstream and downstream of these trading centers.

Midwestern Gas Transmission can receive and deliver gas at either end of its system, which makes it a header pipeline system. Consequently, Midwestern Gas Transmission faces competition from multiple supply sources and interstate pipelines. In the Chicago market, Midwestern Gas Transmission's competition is from pipelines transporting gas from the gulf coast and mid-continent regions and gas sourced from Canada. In the Indiana and Western Kentucky markets, Midwestern Gas Transmission's competition is from pipelines transporting gas from the gulf coast and mid-continent regions.

Viking Gas Transmission directly serves markets in North Dakota, Minnesota and Wisconsin. Northern Natural Gas competes with Viking Gas Transmission in these states. In addition, Viking Gas Transmission indirectly serves Wisconsin and Michigan markets through deliveries into ANR Pipeline. The deliveries into ANR Pipeline compete with other supply sources on ANR Pipeline, which includes supply from the gulf coast and mid-continent regions and the Chicago market center.

In October 2004, FERC approved ANR Pipeline Company's application to expand its capacity in the north leg of its pipeline system by approximately 107 mmcfd per day to replace receipts from Viking Gas Transmission at the Marshfield, Wisconsin interconnection by November 2005. See Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Overview."

INTERSTATE PIPELINE REGULATION

Our interstate pipelines are subject to extensive regulation by the FERC, each as a "natural gas company" under the Natural Gas Act. Under the Natural Gas Act and the Natural Gas Policy Act, the FERC has jurisdiction with respect to virtually all aspects of this business segment, including:

- transportation of natural gas;

- rates and charges;

- terms of service including creditworthiness requirements;

- construction of new facilities;

- extension or abandonment of service and facilities;

- accounts and records;

- depreciation and amortization policies;

- the acquisition and disposition of facilities; and

- the initiation and discontinuation of services.

Where required, our interstate pipelines hold certificates of public convenience and necessity issued by the FERC covering the facilities, activities and services. Under Section 8 of the Natural Gas Act, the FERC has the power to prescribe the accounting treatment for items for regulatory purposes. Our interstate pipelines' books and records may be periodically audited by the FERC under Section 8.

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The FERC regulates the rates and charges for transportation in interstate commerce. Natural gas companies may not charge rates that have been determined not to be just and reasonable by the FERC. Generally, rates for interstate pipelines are based on the cost of service including recovery of and a return on the pipeline's actual prudent historical cost investment. In addition, the FERC prohibits natural gas companies from unduly preferring or unreasonably discriminating against any person with respect to pipeline rates or terms and conditions of service. Some types of rates may be discounted without further FERC authorization and rates may be negotiated subject to FERC approval. The rates and terms and conditions for service are found in each pipeline's FERC approved tariff.

Under its tariff, an interstate pipeline is allowed to charge for its services on the basis of stated transportation rates. Transportation rates are established in FERC proceedings known as rate cases. The tariff also allows the interstate pipeline to provide services under negotiated and discounted rates. Generally, firm shippers are obligated to pay a monthly demand charge, regardless of the amount of natural gas they actually transport, for the term of their contracts. For our wholly-owned interstate pipelines, approximately 98% of the revenue generated for a contract is attributed to demand charges. The remaining 2% is attributed to commodity charges based on the volumes of gas actually transported.

Our interstate pipelines also provide interruptible transportation service. Interruptible transportation service is transportation in circumstances when capacity is available after satisfying firm service requests. The maximum rate that may be charged to interruptible shippers is the sum of the firm transportation maximum demand and commodity charges.

Under the terms of settlement in Northern Border Pipeline's 1999 rate case, neither Northern Border Pipeline nor its existing shippers can seek rate changes to the settlement base rates until November 1, 2005, at which time Northern Border Pipeline must file a new rate case. Midwestern Gas Transmission and Viking Gas Transmission have no timing requirements or restriction in regard to future rate case filings. Under the terms of Guardian Pipeline's certificate of public convenience and necessity allowing for the construction of the Guardian pipeline system, Guardian Pipeline must file a revenue and cost study by December 7, 2005 to re-establish the recourse rates initially approved by the FERC. Prior to a future rate case, the interstate pipelines will not be permitted to increase rates if costs increase or if contract demand decreases, nor will they be required to reduce rates based on cost savings. As a result, the interstate pipelines' earnings and cash flow will depend on costs incurred, contracted capacity, the volumes of gas transported and their ability to recontract capacity at acceptable rates.

Until new depreciation rates are approved by the FERC, the interstate pipeline continues to depreciate its transmission plant at FERC approved depreciation rates. For our pipelines, the annual depreciation rates on transmission plant in service are 2.25% for Northern Border Pipeline, 1.9% for Midwestern Gas Transmission, 2.0% for Viking Gas Transmission and 3.3% for Guardian Pipeline. The effects of accumulated depreciation may be offset by acquiring or constructing assets that replace or add to existing pipeline facilities or transportation rates may be decreased.

In Northern Border Pipeline's 1995 rate case, the FERC addressed the issue of whether the federal income tax allowance included in Northern Border Pipeline's proposed cost of service was reasonable in light of previous FERC rulings. In those previous rulings, the FERC held that an interstate pipeline is not entitled

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to an income tax allowance for income attributable to limited partnership interests held by individuals. The settlement of Northern Border Pipeline's 1995 rate case provided that Northern Border Pipeline could continue to calculate the allowance for income taxes in the manner it had historically used for a period which ends in December 2005. In addition, a settlement adjustment mechanism was implemented, which effectively reduces the return on rate base. These provisions of the 1995 rate case were maintained in the settlement of Northern Border Pipeline's 1999 rate case.

On July 20, 2004, the D.C. Circuit Court of Appeals issued an opinion in BP West Coast Products, LLC v. FERC ("SFPP, L.P. Proceeding") that reversed the FERC decision that provided for an income tax allowance in the rates for SFPP, LP, a limited partnership. The D.C. Circuit Court remanded the case to the FERC for its determination regarding the proper income tax allowance. On December 2, 2004, the FERC initiated an inquiry open to all interested parties on whether the court's ruling applies only to the specific facts of the SFPP, L.P. Proceeding or if it extends to other capital structures involving partnerships and other forms of ownership. The inquiry did not propose a particular rule. The FERC inquired how the decision in the SFPP, L.P. Proceeding may impact investment in energy infrastructure and if there are other methods in providing an opportunity to earn an adequate return that are not dependent on the tax implications of a particular capital structure.

Approximately 50 separate comments were filed by trade associations, investor groups, producers, natural gas pipelines, electric utilities, oil pipelines, and customers in January 2005. A number of comments, including Northern Border Pipeline's, suggested that an income tax allowance is a proper element of a pipeline's cost of service for all jurisdictional entities regardless of legal structure. Some producers' and customers' comments argued against the inclusion of an income tax allowance for partnerships and other non-tax paying entities. It is not certain how, or when, the FERC may proceed with respect to its Request for Comments or the affect on our interstate natural gas pipelines, which are not corporations. In particular, Northern Border Pipeline is a general partnership whose rates include an allowance for income taxes. Northern Border Pipeline's specific circumstances regarding its tariff, deferred income tax treatment, FERC orders, past history and underlying agreements with shippers are different from those of SFPP, L.P. The issue of whether the inclusion of an income tax allowance in Northern Border Pipeline's rates is applicable, in light of the FERC and court rulings, may be addressed in Northern Border Pipeline's 2005 rate case.

Our interstate pipelines are subject to the requirements of FERC Order Nos. 497 and 566, which prohibit preferential treatment of transportation service providers' marketing affiliates and govern how information may be provided to those marketing affiliates. On November 25, 2003, the FERC issued a final rule, Order No. 2004, adopting new standards of conduct for transmission providers when dealing with their energy affiliates. Additional orders modifying Order No. 2004 were issued on April 16, August 2 and December 21, 2004. Transmission providers were required to comply with the standards of conduct by September 22, 2004. The standards of conduct are designed to prevent transmission providers from giving undue preferences to any of their energy affiliates. The final rule generally requires that transmission function employees operate independently of the marketing function employees and energy affiliates. As required of all transmission providers, each of our interstate pipelines posted its standards of conduct to its website on September 22, 2004. By definition, Bear Paw Energy, LLC and ONEOK Energy Services Company, L.P, as well as other subsidiaries of ONEOK, are energy affiliates. Prior to September 22, 2004, the operator of our interstate pipelines, Northern Plains, provided after hours and weekend gas control services

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for Bear Paw Energy, LLC and Crestone Energy Ventures that resulted in some cost savings to our interstate pipelines. Our interstate pipelines have requested a waiver, which is still pending at the FERC, to permit Northern Plains to resume after hours and weekend gas control services for Bear Paw Energy, LLC and Crestone Energy Ventures.

On July 17, 2002, the FERC issued a Notice of Inquiry Concerning Natural Gas Pipeline Negotiated Rate Policies and Practices. Subsequently, the FERC issued an order on July 25, 2003, modifying its prior policy on negotiated rates. The FERC ruled that it would no longer permit the pricing of negotiated rates based upon natural gas commodity price indices. Negotiated rates based upon such indices may continue until the end of the contract period for which such rates were negotiated, but such rates will not be prospectively approved by the FERC. The FERC also imposed certain requirements on other types of negotiated rate transactions to ensure that the agreements embodying such transactions do not materially differ from the terms and conditions set forth in the tariff of the pipeline entering into the transaction. This FERC ruling is not expected to have a material effect on our businesses.

Recent FERC orders in proceedings involving other natural gas pipelines have addressed certain aspects of a pipeline's creditworthiness provisions set forth in its tariff. In addition, industry groups, such as the North American Energy Standards Board ("NAESB"), have issued creditworthiness standards. On February 12, 2004, the FERC issued a Notice of Proposed Rulemaking to require interstate pipelines to follow standardized procedures for determining the creditworthiness of their shippers. The proposed rule would incorporate by reference ten consensus standards passed within NAESB and would adopt additional standards requiring, among other things, standardization of information shippers provide to establish credit, collateral requirements for service, procedures for suspension and termination for non-creditworthy shippers and procedures governing capacity release transactions. The enactment of some of these standards may have the effect of easing certain creditworthiness requirements and parameters currently reflected in our tariffs on existing transportation capacity. However, recent FERC orders, and this proposed rule, continue to allow more stringent collateral requirements for the construction of new facilities by a pipeline. However, we cannot predict the ultimate impact, if any, on our interstate pipelines of any resulting final rule.

In February 2004, the FERC adopted new quarterly financial reporting requirements and accelerated the filing date for the interstate pipeline's annual financial report. The quarterly reports include a basic set of financial statements and other selected data and are submitted electronically. There is no impact for complying with these requirements other than the time and additional expense for preparation of these reports.

In November 2004, the FERC issued a Notice of Proposed Accounting Release ("PAR") to provide guidance on the accounting for costs of pipeline assessment programs required under the Pipeline Safety Improvement Act of 2002 and regulations established thereunder. The PAR concluded that such costs should be treated as maintenance costs. Comments have been filed by the Interstate Natural Gas Association of America as well as individual pipelines setting forth the arguments that these costs should be capitalized.

In November 2004, the FERC issued a Notice of Inquiry on selective discounting particularly as it relates to allowing discount adjustments for contracts resulting from competition between interstate pipelines referred to as gas-on-gas competition. The FERC noted that in several proceedings, parties have objected to the FERC's current discounting policy, allowing selective discounting

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for gas-on-gas competition, on the grounds that it no longer benefits captive customers by allowing fixed costs to be spread over more units of service. These parties have argued that while benefits may still exist to the extent a discount is given to a customer who would otherwise use an alternative fuel and not ship gas at all, benefits do not exist in situations where discounts are given to meet competition from other gas pipelines. Although the FERC has not disallowed discount adjustments for gas-on-gas competition, the Notice of Inquiry seeks comments and responses to a series of questions that will allow the FERC to explore the potential impact of eliminating the discount adjustment for gas-on-gas competition and how the FERC should implement and monitor such a policy.

In August 2003, Northern Border Pipeline filed revised tariff sheets to clarify its procedures for the awarding of capacity. Several parties protested the filing. One party requested a show cause proceeding to examine past tariff practices alleging that Northern Border Pipeline violated its tariff by denying a request for service that would have involved transportation for a distance shorter than the available distance for less than a one-year term. Northern Border Pipeline's position is that selling capacity for shorter distances or on a shorter term basis may cause portions of its system to be "stranded" or not subject to firm transportation contracts on a consistent basis or may effectively constitute a discounted rate service. On September 10, 2003, the FERC rejected Northern Border Pipeline's tariff sheets based on the conclusion that certain aspects of the proposal were not in accordance with the FERC's policy. The FERC affirmed that, up to ninety days prior to the effective date, Northern Border Pipeline had the right not to sell capacity requested for shorter distances or on a short-term basis to shippers offering the maximum mileage-based transportation rate. Northern Border Pipeline filed a timely request for rehearing of the FERC's Order in October 2003, which is still pending. Northern Border Pipeline also filed responses to requests for further information on the award of capacity in the summer of 2003. Northern Border Pipeline filed its compliance tariff sheets in early December 2003 and is awaiting the FERC's decision on these tariff sheets. An order was issued on April 15, 2004, in which the FERC requested comments from interested parties on whether the FERC's current policy on awarding available capacity to a short-haul shipper appropriately balances the risks to the pipeline, prospective shippers and current shippers on the pipeline. Comments from Northern Border Pipeline and other interested parties were filed on June 15, 2004. The timing of the issuance of the FERC's order in this proceeding is not known.

NATURAL GAS GATHERING AND PROCESSING SEGMENT

Our gas gathering and processing segment provides services for the measurement, gathering, treating, compression and processing of natural gas and the fractionation of natural gas liquids (NGLs) for third parties and related field services. We do not explore for, or produce, crude oil or natural gas, and do not own crude oil or natural gas reserves.

Bear Paw Energy, LLC ("Bear Paw Energy"), our wholly-owned subsidiary, has extensive natural gas gathering, processing and fractionation operations in the Williston Basin in Montana and North Dakota as well as gas gathering operations in the Powder River Basin in Wyoming. In the Williston Basin, Bear Paw Energy has over 3,000 miles of gathering pipelines and five processing plants with 93 mmcfd of capacity. In the Powder River Basin, Bear Paw Energy has approximately 600 miles of high and low pressure gathering pipelines, approximately 65 compressor stations with approximately 140,000 installed horsepower and long-term volumetric contracts with producers covering approximately 390,000 acres of dedicated reserves in the

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Powder River Basin. Bear Paw Energy's revenues are primarily derived under fee-based gathering and percentage of proceeds agreements.

In addition, through our wholly-owned subsidiary, Crestone Energy Ventures, we own a 49% interest in Bighorn Gas Gathering, L.L.C. ("Bighorn"), a 33.33% interest in Fort Union Gas Gathering, L.L.C. ("Fort Union") and a 35% interest in Lost Creek Gathering, L.L.C. ("Lost Creek"), which collectively own over 300 miles of gas gathering facilities in the Powder River and Wind River Basins in Wyoming.

The Bighorn and Fort Union systems gather coalbed methane gas produced in the Powder River Basin in northeastern Wyoming. Under various agreements, the majority of which are long-term, producers have dedicated their gas reserves to Bighorn, giving Bighorn the right to gather natural gas produced in areas of Wyoming covering approximately 800,000 acres. Bighorn's system is capable of gathering more than 250 mmcfd of natural gas for delivery to the Fort Union gathering system. Fort Union has the capability of delivering more than 634 mmcfd of gas into the interstate pipeline grid. The Lost Creek system gathers natural gas produced from conventional gas wells in the Wind River Basin in central Wyoming and consists of 120 miles of gathering header. The system is capable of delivering more than 275 mmcfd of gas into the interstate pipeline grid.

Cantera Natural Gas, LLC (formerly CMS Field Services, Inc.)("Cantera Natural Gas") holds the remaining ownership interest in Bighorn and is the project manager and operator. The Bighorn system is managed through a management committee consisting of representatives of the owners. Cantera Natural Gas, CIG Resources Company, Western Gas Resources and Bargath, Inc. hold the remaining interests in Fort Union. Cantera Natural Gas is the managing member, Western Gas Resources is the field operator and CIG Resources Company is the administrative manager. Burlington Resources Trading, Inc. holds the remaining interest in Lost Creek and is the managing member. A subsidiary of Crestone Energy Ventures is the commercial and administrative manager. This system is operated by Elkhorn Field Services Company, an unaffiliated third party.

Bear Paw Energy's facilities in the Powder River Basin are interconnected with the facilities of Bighorn, Fort Union, Thunder Creek Gas Gathering and Maverick Pipeline, LLC, and all the gathering facilities interconnect to the interstate gas pipeline grid serving gas markets in the Rocky Mountains, the Midwest and California.

Bear Paw Energy's Williston Basin gathering and processing facilities are located in eastern Montana and western North Dakota, with a small extension into Saskatchewan, Canada. The Williston Basin system consists of approximately 3,100 miles of polyethylene and steel pipeline and 31 compressor stations with a total rated horsepower of 31,000, in addition to plant compression of approximately 20,000 horsepower. Most of the wells connected to the facilities produce casinghead gas in association with crude oil. This gas is generally high in NGLs. The NGLs are separated from the gas at our processing plants and then fractionated into components and sold. The residue gas is sold into the interstate market. A substantial portion of Bear Paw Energy's gathering and processing contracts in the Williston Basin provide for the sale of the natural gas stream to Bear Paw Energy. Upon sale of the NGLs and the residue gas processed, Bear Paw Energy pays the producers based upon a percentage of the net proceeds realized.

For the year ended December 31, 2004, Bear Paw Energy's largest customers, Lodgepole Energy Marketing ("Lodgepole"), BP Canada and Montana Dakota Utilities ("Montana Dakota") accounted for 44%, 14% and 12%, respectively, of Bear Paw Energy's operating revenues. Lodgepole is the sole

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purchaser of natural gas liquids from our processing plants in the Williston Basin and the contract term extends until 2009. BP Canada and Montana Dakota are purchasers of residue gas from our processing plants in the Williston Basin under contracts whose terms are typically less than one year.

We no longer own an interest in gathering facilities in Canada. Our wholly-owned subsidiary, Border Midstream Services, Ltd. sold its undivided minority interest in the Gregg Lake/Obed Pipeline located in Alberta, Canada in December 2004 to KeySpan Energy Canada, Inc. for $14.0 million.

FUTURE DEMAND AND COMPETITION

Our gas gathering and processing segment competes with other natural gas gathering, processing and pipeline companies in the production areas in the Powder River, Wind River, and Williston Basins. Primary competitors in the Powder River Basin of Wyoming include both independent gathering companies and gathering companies affiliated with producers. Primary competitors affiliated with producers include affiliates of Western Gas Resources, Thunder Creek Gas Gathering, Bitter Creek Pipelines, LLC, Yates Petroleum and Anadarko Petroleum Corp. Primary non-producer affiliated competitors include Bighorn, Optigas, Inc. and Rimrock Pipeline, LLC. Competition for gathering and processing services in the Williston Basin includes Amerada Hess, PetroHunt Corporation and Hiland Resources in localized areas. Our competitive positions are affected by the pace of oil and gas drilling, gas production rates, gas reserves, natural gas and NGLs commodity prices, regulation and the demand for natural gas and NGLs in North America.

The pace of natural gas drilling may be impacted by, among other things, the ability of producers to obtain and maintain the necessary drilling and production permits in a timely and economic manner, reserve characteristics and performance, surface access and infrastructure issues as well as commodity prices. In addition, the regulation of discharge of the significant volumes of water produced in association with coalbed methane production can be a deterrent to producers in determining whether to drill or produce. The time period during which coalbed methane wells dewater before significant gas production becomes available may be unpredictable. Water quality may vary substantially, and disposal alternatives and associated costs may also affect producers' decisions to drill or produce. On January 17, 2003, the Bureau of Land Management ("BLM") released two final environmental impact statements ("EIS") regarding oil and natural gas development on Federal lands. One EIS pertains to oil and gas development on BLM-administered public lands and federal mineral leases within the Powder River Basin in northeastern Wyoming. The other EIS pertains to statewide oil and natural gas development in Montana. Lawsuits have been filed challenging the EIS in Wyoming and Montana. However, BLM's issuance of new drilling permits under the regulatory preconditions has continued, albeit at a slower rate than previous years. Approximately 65% of the Powder River Basin acreage is on federal lands.

In providing gas gathering, processing and other services, we may require acreage dedication, long term commitment and/or minimum volume commitments or demand charges from gas producers. Once a gathering and processing position is established, the term of the dedication, the likely economic reserve life and the cost of building duplicative facilities mitigate the level of competition in the vicinity. Development of future gas gathering and processing facilities will be staged to reflect the growth in number of wells and field production, economics, permitting considerations and other factors impacting producers' decisions to drill and produce. See Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Overview."

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We differentiate ourselves by the terms of services offered, our flexibility and additional value-added services provided. Our relationships with producers allow us to offer integrated services through all our gathering and processing facilities, as well. We also provide a variety of delivery choices, wide coverage area and operational efficiencies. We seek to improve operational profitability by increasing natural gas throughput through new connections, expansion, acquisitions, operational efficiencies and prudent deployment of capital.

COAL SLURRY PIPELINE SEGMENT

Black Mesa Pipeline, Inc., our wholly-owned subsidiary ("Black Mesa"), owns a 273-mile, 18-inch diameter coal slurry pipeline which originates at a coal mine in Kayenta, Arizona. The coal slurry pipeline transports crushed coal suspended in water. It traverses westward through northern Arizona to the 1,500 megawatt Mohave Generating Station located in Laughlin, Nevada. The coal slurry pipeline is the sole source of fuel for the Mohave Generating Station, which consumes an average of 4.8 million tons of coal annually. The capacity of the pipeline is fully contracted to Peabody Western Coal, the coal supplier for the Mohave Generating Station, through the year ending December 31, 2005.

The water used by the coal slurry pipeline is from an aquifer in The Navajo Nation and Hopi Tribe joint use area. The Navajo Nation and Hopi Tribe have not agreed to continued use of water from this aquifer after December 31, 2005. Under a consent decree, the Mohave Generating Station has agreed to install certain pollution control equipment by December 2005. With questions surrounding the water supply and renegotiation of the coal supply contracts, Southern California Edison ("SCE") a 56% owner of the Mohave Generating Station, filed a petition before the California Public Utility Commission ("CPUC") requesting that the CPUC either recognize the end of Mohave's coal-fired operations as of the end of 2005 with appropriate ratemaking accounts or authorize expenditures for pollution control activities required for future operation. On December 2, 2004, the CPUC issued its decision which authorizes SCE, among other things, to make the necessary and appropriate expenditures for critical path investments, including the new aquifer study and feasibility studies for alternatives to replace or compliment the power from the coal-fired plant, and directs the parties to continue working on resolution of the essential water and coal issues. With successful resolution of the issues, it is expected that the Mohave Generating Station, as well as the Black Mesa system, will be temporarily idled for at least a three-year period while pollution control equipment is installed at Mohave and the Black Mesa system is rebuilt. If efforts by the parties to resolve these issues are not successful and the Mohave Generating Station is permanently closed, it would be necessary to shut down Black Mesa in 2006, resulting in shut down costs of approximately $5 million to $7 million and a non-cash charge of approximately $12 million related to goodwill and the remaining undepreciated cost of the pipeline. See Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Overview."

Approximately 57 people are employed in the operations of Black Mesa, of which 28 are eligible to be represented by a labor union, the United Mine Workers of America ("UMWA"). Black Mesa's collective bargaining agreement with the UMWA was renewed in 2003 and is effective through December 31, 2005.

ENVIRONMENTAL AND SAFETY MATTERS

Our interstate pipeline, coal slurry pipeline and U.S. gathering and processing operations are subject to certain federal, state and local laws and

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regulations relating to safety and the protection of the environment, which include, as applicable, the Resource Conservation and Recovery Act, the Comprehensive Environmental Response, the Compensation and Liability Act of 1980, as amended, the Clean Air Act, as amended, the Clean Water Act, as amended, the Natural Gas Pipeline Safety Act of 1969, as amended, the Pipeline Safety Act of 1992 and the Pipeline Safety Improvement Act of 2002.

The Pipeline Safety Improvement Act of 2002 ("Act") was signed into law in December 2002, providing guidelines for interstate pipelines in the areas of risk analysis and integrity management, public education programs, verification of operator qualification programs and filings with the National Pipeline Mapping System. The Act requires pipeline companies to perform integrity assessments on pipeline segments that exist in high population density areas or near specifically identified sites that are designated as high consequence areas. Pipeline companies are required to perform the integrity assessments within ten years of the date of enactment and must perform subsequent integrity assessments on a seven-year cycle. At least 50% of the highest risk segments must be assessed within five years of the enactment date. In addition, within one year of enactment, the pipeline's operator qualification programs, in force since the mandatory compliance date of October 2002, must also conform to standards provided by the Department of Transportation. Rules on integrity management, direct assessment usage, and the operator qualification standards have been issued. We have made the required filings with the National Pipeline Mapping System and have reviewed and revised our public education program. Compliance with the Act is expected to increase our operating costs particularly related to integrity assessments for our interstate pipelines. As required, we have developed an overall plan for pipeline integrity management. Detailed analysis was performed to determine the priorities and costs for inspecting and testing our pipelines. However, the plan will be modified as a result of the findings noted and could result in additional assessment or remediation costs. Presently we expect our annual costs for integrity assessments to be approximately $1.0 million. We expect to include these costs in future rate case filings. How these costs may be classified for all interstate pipelines is the subject of the pending proceeding before the FERC. See "Interstate Natural Gas Pipeline Segment-Interstate Pipeline Regulation" above.

Black Mesa was subject to a judgment and Consent Decree entered in the United States District Court of Arizona in July 2001 through December 31, 2004. Under the Consent Decree, the United States Environmental Protection Agency ("EPA"), the Arizona Department of Environmental Quality ("ADEQ") and Black Mesa agreed to the payment of penalties for alleged violations of federal and state law due to unplanned discharges of coal slurry from Black Mesa's pipeline from December 1997 through July 1999. The Consent Decree also set forth certain preventative measures, reporting requirements and associated penalties for failure to comply with the provisions of the Consent Decree. Since the Consent Decree was entered, there have been several unplanned slurry discharges that have been reported to the EPA and ADEQ. Future unplanned spills, if any, may be subject to penalties for violations of federal and state laws.

Although we believe that our operations and facilities are in general compliance in all material respects with applicable environmental and safety regulations, risks of substantial costs and liabilities are inherent in pipeline and gas processing operations, and we cannot provide any assurances that we will not incur such costs and liabilities. Moreover, it is possible that other developments, such as enactment of increasingly strict environmental and safety laws, regulations and enforcement policies thereunder by Congress, the FERC, the Department of Transportation and other federal agencies, state regulatory bodies and the courts, and claims for damages to property or persons resulting from our

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operations, could result in substantial costs and liabilities to us. If we are unable to recover such resulting costs, earnings and cash distributions could be adversely affected.

ITEM 2. PROPERTIES.

See Item 1. "Business-Interstate Natural Gas Pipeline Segment," "Business-Natural Gas Gathering and Processing Segment" and "Business-Coal Slurry Pipeline Segment" for a brief description of the location and general characteristics of our important physical properties by segment.

INTERSTATE NATURAL GAS PIPELINE SEGMENT

Northern Border Pipeline, Midwestern Gas Transmission, Viking Gas Transmission and Guardian Pipeline hold the right, title and interest in their pipeline systems. With respect to real property, the pipeline systems fall into two basic categories: (a) parcels which are owned in fee, such as sites for compressor stations, meter stations, pipeline field offices, and microwave towers; and (b) parcels where the interest derives from leases, easements, rights-of-way, permits or licenses from landowners or governmental authorities permitting the use of such land for the construction and operation of the pipeline system. The right to construct and operate the pipeline systems across certain property was obtained through exercise of the power of eminent domain. The interstate pipeline systems continue to have the power of eminent domain in each of the states in which they operate, although Northern Border Pipeline may not have the power of eminent domain with respect to Native American tribal lands.

Approximately 90 miles of Northern Border Pipeline's system are located on fee, allotted and tribal lands within the exterior boundaries of the Fort Peck Indian Reservation in Montana. Tribal lands are lands owned in trust by the United States for the Fort Peck Tribes and allotted lands are lands owned in trust by the United States for an individual Indian or Indians. Northern Border Pipeline does have the right of eminent domain with respect to allotted lands.

In 1980, Northern Border Pipeline entered into a pipeline right-of-way lease with the Fort Peck Tribal Executive Board, for and on behalf of the Assiniboine and Sioux Tribes of the Fort Peck Indian Reservation ("Tribes"). This pipeline right-of-way lease, which was approved by the Department of the Interior, Bureau of Indian Affairs ("BIA") in 1981, granted to Northern Border Pipeline the right and privilege to construct and operate its pipeline on certain tribal lands. This pipeline right-of-way lease was scheduled to expire in 2011. Northern Border Pipeline has been granted options to renew the pipeline right-of-way lease to 2061. See Item 3. "Legal Proceedings."

In conjunction with obtaining a pipeline right-of-way lease across tribal lands located within the exterior boundaries of the Fort Peck Indian Reservation, Northern Border Pipeline also obtained a right-of-way across allotted lands located within the reservation boundaries. Most of the allotted lands are subject to a perpetual easement either granted by the BIA for and on behalf of individual Indian owners or obtained through condemnation. Several tracts are subject to a right-of-way grant that has a term of 15 years, expiring in 2015.

NATURAL GAS GATHERING AND PROCESSING SEGMENT

Bear Paw Energy, Bighorn, Lost Creek and Fort Union hold the right, title and interest in their gathering and processing facilities, which consist of low and high pressure gas gathering lines, compression and measurement installations and

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treating, processing and fractionation facilities. The real property rights for these facilities are derived through fee ownership, leases, easements, rights-of-way and permits.

COAL SLURRY PIPELINE SEGMENT

Black Mesa holds title to its pipeline and pump stations. The real property rights for Black Mesa facilities are derived through fee ownership, leases, easements, rights-of-way and permits. Black Mesa holds rights-of-way grants from private landowners as well as The Navajo Nation and the Hopi Tribe. These rights-of-way grants extend for terms at least through December 31, 2005, the date that Black Mesa's transportation contract with Peabody Western Coal is presently scheduled to end.

ITEM 3. LEGAL PROCEEDINGS.

On July 31, 2001, the Assiniboine and Sioux Tribes of the Fort Peck Indian Reservation ("Tribes") filed a lawsuit in Tribal Court against Northern Border Pipeline to collect more than $3 million in back taxes, together with interest and penalties. The lawsuit related to a utilities tax on certain of Northern Border Pipeline's properties within the Fort Peck Indian Reservation. The Tribes and Northern Border Pipeline, through a mediation process, reached a settlement with respect to pipeline right-of-way lease and taxation issues documented through an Option Agreement and Expanded Facilities Lease ("Agreement") executed in August 2004. Through the terms of the Agreement, the settlement grants to Northern Border Pipeline, among other things: (i) an option to renew the pipeline right-of-way lease upon agreed terms and conditions on or before April 1, 2011 for a term of 25 years with a renewal right for an additional 25 years;
(ii) a right to use additional tribal lands for expanded facilities; and (iii) release and satisfaction of all tribal taxes against Northern Border Pipeline. In consideration of this option and other benefits, Northern Border Pipeline paid a lump sum amount of $7.4 million during August 2004 and will make additional annual option payments of approximately $1.5 million thereafter through March 31, 2011. Northern Border Pipeline intends to seek regulatory recovery of the costs resulting from the settlement. See Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations - Risk Factors and Information Regarding Forward-Looking Statements."

See Item 1. "Business - Coal Slurry Pipeline Segment" for the discussion on the proceeding before the CPUC related to Black Mesa's continuation of service beyond 2005.

See Item 1. "Business - Interstate Pipeline Regulation" for the discussion on proceedings before the FERC.

We are not currently parties to any other legal proceedings that, individually or in the aggregate, would reasonably be expected to have a material adverse impact on our financial condition.

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.

There were no matters submitted to a vote of security holders during the fourth quarter of fiscal 2004.

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PART II

ITEM 5. MARKET FOR THE REGISTRANT'S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES.

Our common units are traded on the New York Stock Exchange. The following table sets forth, for the periods indicated, the high and low sale prices per common unit, as reported on the New York Stock Exchange Composite Tape, and the amount of cash distributions per common unit declared for each quarter:

                   Price Range
                 ---------------       Cash
2004              High      Low    Distribution
----             ------   ------   ------------
Fourth Quarter   $49.54   $44.60       $0.80
Third Quarter     45.81    38.61        0.80
Second Quarter    42.60    35.70        0.80
First Quarter     42.60    38.01        0.80

                   Price Range
                 ---------------       Cash
2003              High      Low    Distribution
----             ------   ------   ------------
Fourth Quarter   $43.70   $35.98       $0.80
Third Quarter     44.07    40.50        0.80
Second Quarter    42.33    38.10        0.80
First Quarter     39.00    36.57        0.80

As of March 8, 2005, there were approximately 1,200 record holders of common units and approximately 64,800 beneficial owners of the common units, including common units held in street name. On March 3, 2005, the last reported sale price of our common units on the New York Stock Exchange was $51.70 per common unit.

We currently have 46,397,214 common units outstanding, representing a 98% limited partner interest. The common units are the only outstanding limited partner interests. Thus, our equity consists of general partner interests representing in the aggregate a 2% interest and common units representing in the aggregate a 98% limited partner interest.

The general partners are entitled to 2% of all cash distributions, and the holders of common units are entitled to the remaining 98% of all cash distributions, except that the general partners are entitled to incentive distributions if the amount distributed with respect to any quarter exceeds $0.605 per common unit ($2.42 annualized). Under the incentive distribution provisions, the general partners are entitled to 15% of amounts distributed in excess of $0.605 per common unit ($2.42 annualized), 25% of amounts distributed in excess of $0.715 per common unit ($2.86 annualized) and 50% of amounts distributed in excess of $0.935 per common unit ($3.74 annualized). The amounts that trigger incentive distributions at various levels are subject to adjustment in certain events, as described in our partnership agreement.

EQUITY COMPENSATION PLAN INFORMATION

Effective November 1, 2001, Northern Plains and NBP Services adopted the Amended and Restated Northern Border Phantom Unit Plan as an incentive to attract and retain employees who are essential to the services provided to us and our

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subsidiaries. By its terms, the Amended and Restated Northern Border Phantom Unit Plan terminated on December 31, 2004. The Administrative Committee under the Plan, which are appointees of Northern Plains and NBP Services, will continue to administer the outstanding phantom units, which are based upon the general partner distribution rate. The Administrative Committee has complete authority to determine the time and provisions for settlement. During the duration of a grant, the participant's account is credited with distributions paid with respect to the underlying security. Upon settlement of the phantom units, the participant will receive common units or cash or a combination thereof, as determined by the Administrative Committee. The settlement value of the phantom units is determined by using a value derived from the general partner distribution rate and common unit distribution yield on the settlement date.

                            Number of securities
                              to be issued upon      Weighted average
                                 exercise of        Exercise price of      Number of units
                             outstanding phantom   outstanding phantom   remaining available
       Plan Category                units                 units          for future issuance
       -------------        --------------------   -------------------   -------------------
                                     (a)                   (b)                   (c)
                            --------------------   -------------------   -------------------
Equity compensation plans
   approved by the
   unitholders (1)                   --                     --                    --

Equity compensation plans
   not approved by the
   unitholders (1)                 37,602 (2)             $48.18 (2)           189,500 (3)

Total                              37,602                                      189,500

(1) Under our partnership agreement, our partnership policy committee has the sole authority, without the approval of the unitholders, to adopt employee benefit or incentive plans or issue common units pursuant to any employee benefit or incentive plan maintained or sponsored by a general partner or its affiliates.

(2) Based upon the closing price of the common units on December 31, 2004 and assumes that all outstanding phantom units were settled in common units as of December 31, 2004.

(3) The Plan limits the number of grants of phantom units and phantom LP units to an aggregate of 200,000. This assumes all grants are phantom LP units.

23

ITEM 6. SELECTED FINANCIAL DATA.
(in thousands, except per unit, other financial data and operating data)

The following table sets forth, for the periods and at the dates indicated, selected historical financial data for us. The selected consolidated financial information should be read in conjunction with the Consolidated Financial Statements and the Notes and Item 7. "Management's Discussion and Analysis of Financial Condition and Results of Operations," which are included elsewhere in this report.

                                                 YEAR ENDED DECEMBER 31,
                             --------------------------------------------------------------
                                2004       2003 (1)       2002       2001 (2)     2000 (3)
                             ----------   ----------   ----------   ----------   ----------
INCOME DATA:
Operating revenues, net      $  590,383   $  550,948   $  487,204   $  455,997   $  339,732
Product purchases               103,213       80,774       50,648       39,699           --
Operations and
   maintenance                  111,142      127,623      106,521       92,891       62,097
Depreciation and
   amortization (4)              86,431      299,791       74,672       75,424       60,699
Taxes other than income          36,212       35,443       32,194       27,863       28,634
                             ----------   ----------   ----------   ----------   ----------
   Operating income             253,385        7,317      223,169      220,120      188,302
Interest expense, net            76,943       78,980       82,898       89,908       81,495
Other income, net                19,648       23,679       15,170          258        8,410
Minority interests
   in net income                 50,033       44,460       42,816       42,138       38,119
Income taxes                      5,136        4,705        1,643          499          378
                             ----------   ----------   ----------   ----------   ----------
Income (loss) from
   continuing operations        140,921      (97,149)     110,982       87,833       76,720
Discontinued operations,
   net of tax (5)                 3,799        9,338        2,694          (47)          --
Cumulative effect of
   change in accounting
   principle, net of tax             --         (643)          --           --           --
                             ----------   ----------   ----------   ----------   ----------
Net income (loss) to
   partners                  $  144,720   $  (88,454)  $  113,676   $   87,786   $   76,720
                             ==========   ==========   ==========   ==========   ==========

Per unit income (loss)
   from continuing
   operations                $     2.81   $    (2.27)  $     2.38   $     2.12   $     2.50
                             ==========   ==========   ==========   ==========   ==========
Per unit net income (loss)   $     2.89   $    (2.08)  $     2.44   $     2.12   $     2.50
                             ==========   ==========   ==========   ==========   ==========
Number of units used
   in computation                46,397       45,370       42,709       38,538       29,665
                             ==========   ==========   ==========   ==========   ==========

CASH FLOW DATA:
Net cash provided by
   operating activities      $  244,658   $  224,660   $  244,006   $  233,948   $  169,615
Capital expenditures             43,477       30,282       50,738      126,414       19,721
Acquisition of businesses            --      123,194        1,561      345,074      229,505
Distribution per unit              3.20         3.20         3.20         2.99         2.65

BALANCE SHEET DATA
   (AT END OF YEAR):
Property, plant
   and equipment, net        $1,937,424   $1,992,104   $2,015,280   $2,040,099   $1,732,076
Total assets                  2,510,556    2,570,583    2,715,936    2,687,355    2,082,720
Long-term debt, including
   current maturities         1,330,358    1,415,986    1,403,743    1,423,227    1,171,962
Minority interests in
   partners' equity             290,142      240,731      242,931      250,078      248,098
Partners' equity                789,334      800,573      944,035      914,958      572,274

24

                                                YEAR ENDED DECEMBER 31,
                                 -----------------------------------------------------
                                    2004      2003 (1)     2002    2001 (2)   2000 (3)
                                 ---------   ---------   -------   --------   --------
OTHER FINANCIAL DATA:
Ratio of earnings to
   fixed charges (6)                   3.4         0.4       2.8        2.5        2.4

OPERATING DATA:
Interstate Natural Gas
   Pipeline Segment:
      Million cubic feet of
         gas delivered           1,130,634   1,110,969   935,654    891,935    852,674
      Average receipts (mmcfd)       3,166       3,147     2,636      2,605      2,400
Natural Gas Gathering and
   Processing Segment:
      Gathering (mmcfd)              1,022       1,037     1,052        754        397
      Processing (mmcfd)                55          52        55         54         --
Coal Slurry
   Pipeline Segment:
      Thousands of tons
         of coal shipped             4,652       4,451     4,639      4,932      4,711


(1) Includes results of operations for Viking Gas Transmission since date of acquisition in January 2003.

(2) Includes results of operations for Bear Paw Energy (March 2001), Midwestern Gas Transmission (May 2001) and Border Midstream Services (April 2001) since dates of acquisition.

(3) Includes results of operations for Crestone Energy Ventures and Crestone Gathering Services, L.L.C. since date of acquisition in September 2000.

(4) Includes goodwill and asset impairment charge of $219,080 in 2003 related to our natural gas gathering and processing business segment.

(5) In June 2003, Border Midstream Services sold its Gladys and Mazeppa processing plants and related gas gathering facilities. In December 2004, Border Midstream Services sold its undivided minority interest in the Gregg Lake/Obed Pipeline.

(6) "Earnings" means the sum of pre-tax income from continuing operations (before adjustment for minority interests in consolidated subsidiaries or income from equity investees), fixed charges, amortization of capitalized interest and distributions from equity investees, less capitalized interest and the minority interests in pre-tax income of subsidiaries that have not incurred fixed charges. "Fixed charges" means the sum of (a) interest expensed and capitalized; (b) amortized premiums, discounts and capitalized expenses related to indebtedness; and (c) an estimate of interest within rental expenses. The ratio of earnings to fixed charges for 2003 was lower than prior years' ratios due primarily to the goodwill and asset impairment charges booked in 2003. Excluding the impact of the impairment, the ratio would have been 3.1 for 2003.

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

Our discussion and analysis of our financial condition and operations are based on our Consolidated Financial Statements, which were prepared in accordance with U.S. generally accepted accounting principles. You should read the following discussion and analysis in conjunction with our Consolidated Financial Statements and the related notes included elsewhere in this report.

OVERVIEW

The Partnership's businesses fall into three major business segments:

- the interstate natural gas pipeline segment, which comprises 76% of our assets;

- the natural gas gathering and processing segment, which comprises 23% of our assets; and

- the coal slurry pipeline segment, which comprises 1% of our assets.

INTERSTATE NATURAL GAS PIPELINE SEGMENT

In the interstate natural gas pipeline segment, there are several major business drivers. First, a healthy long-term supply outlook for each pipeline is critical. Because the primary source of gas supply for two of our pipeline systems is in the western Canadian sedimentary basin, western Canadian supply trends are particularly important to this segment. With strong commodity prices, the current outlook for western Canadian supply looks flat for the foreseeable future, however, production has exceeded new reserve additions in recent years. To maintain an adequate gas supply/demand balance in western Canada, production will need to grow in the future to meet anticipated demand primarily driven by gas consumption in the extraction and processing associated with Canadian oil sands development. Canada holds substantial reserves of bitumen that is extracted from sand and can be upgraded to synthesized crude oil through several processes. The extraction and processing of bitumen require significant quantities of natural gas. We do not know how many of the announced oil sands development projects will be approved and constructed but the demand for transportation on our pipeline systems could be affected adversely by the additional competition for Canadian gas supply that would result. The supply outlook may be enhanced over time by developments in the northern frontier with new Mackenzie Delta supplies reaching the western Canadian pipeline grid potentially beginning by the end of this decade and Alaskan gas thereafter, although there is no assurance either project will be completed within that timeframe. Moreover, prices of western Canadian supply must be competitive with prices from other supply basins that serve our market areas. If prices are too high, other sources of supply may satisfy demand that otherwise could be met by us. Increased demand for western Canadian natural gas in markets other than those served by us may also cause a reduction of demand for service on us.

Natural gas markets are also critical to our long-term financial performance. Our pipeline systems serve natural gas markets in the upper midwestern area of the United States and access a major market hub in the Chicago area. Market growth has been steady with both heating load growth and direct end-user growth, such as power plants and ethanol plants for our pipelines.

26

We charge fees for transportation, which are primarily fixed and based on the amount of capacity reserved for each shipper. Contracting with shippers to reserve the available pipeline capacity as existing contracts expire is a critical factor in our success. Based on contracts in place at December 31, 2004, the percentage of summer design capacity contracted as of December 31, 2005 was 61% for Northern Border Pipeline, 85% for Viking Gas Transmission and 75% and 48% for northbound and southbound transportation, respectively, on Midwestern Gas Transmission.

Northern Border Pipeline Recontracting

During 2004, Northern Border Pipeline was successful in recontracting, at maximum rates, essentially all of the summer design capacity under contracts that expired on or before November 2004. However, most of those contracts were for terms of five to six months so Northern Border Pipeline has a significant amount of capacity, approximately 800 mmcfd or 28% of summer design capacity, under contracts that expire by May 31, 2005. Most of this capacity will become available on the pipeline system from Port of Morgan, Montana to the Ventura, Iowa delivery point.

Our objective for Northern Border Pipeline is to recontract the remaining pipeline capacity at maximum transportation rates for the longest terms possible. Because the forward natural gas basis differentials between Western Canada and Northern Border Pipeline's market centers continue to be less than the total transportation cost at maximum tariff rates, Northern Border Pipeline may again sell a significant portion of this capacity on a short-term basis. So long as we continue to provide economic value, gas likely will flow from western Canada over our system and Northern Border Pipeline will maintain its relatively high utilization levels. However, in any given month, current conditions of weather and storage in supply and market areas may affect the demand for capacity on Northern Border Pipeline. This could result in lower revenues in some months. Although, we believe a reduction in expected 2005 net income and cash flow of approximately $5 million to $10 million is possible, the impact on net income and cash flow may vary outside this range depending on actual natural gas basis differentials experienced during the year.

The composition of natural gas can affect the amount of energy that is transported through a pipeline system. Beginning in 2000, the energy content of natural gas that Northern Border Pipeline receives at the Canadian border has declined modestly from 1,023 British Thermal Units ("Btus") per cubic foot ("cf") to 1,005 Btus/cf. Northern Border Pipeline's transportation contracts in conjunction with its tariff define both the volume and equivalent Btu value of the gas to be transported. A reduction in the Btu level results in a higher volume of natural gas to be transported to meet an overall equivalent Btu value of the gas. This Btu decline that has been experienced was primarily the result of greater processing capacity in Alberta. The change caused Northern Border Pipeline to reduce its available capacity by almost 2 percent to maintain a high standard of system reliability for its customers. During 2004, the Btu level remained near the level of 1,005 Btus/cf and it is expected to remain at that level during 2005. This Btu variance will be addressed in the November 1, 2005 rate case filing.

Northern Border Pipeline Chicago III Expansion

27

In September 2004, Northern Border Pipeline announced sufficient customer support for a proposed expansion of the pipeline system into the Chicago market area. The Chicago III Expansion Project, with 130 mmcfd of incremental capacity, involves construction of a new 16,000 horsepower compressor station in Iowa and minor modifications to existing compressor facilities, in Iowa and Illinois. Capital costs are estimated to be approximately $21 million, and the target in-service date is April 1, 2006, subject to timely receipt of regulatory approval. We anticipate that approximately $15 million of the estimated $21 million capital budget will be expended in 2005, with the remaining $6 million to be spent in 2006.

Midwestern Gas Transmission Eastern Extension Project

We announced on August 17, 2004 that Midwestern Gas Transmission had finalized the necessary contractual commitment to proceed with the Eastern Extension Project. The project involves the construction of approximately 30 miles of 16-inch diameter pipeline, with a capacity of approximately 120 mmcfd, from Portland, Tennessee to planned interconnections with Columbia Gulf Transmission Company and East Tennessee Pipeline Company. The project is supported by a precedent agreement with Piedmont Natural Gas Company, a local distribution company, for approximately 120 mmcf/d for a term of 15 years. Midwestern Gas Transmission has pre-filed with the FERC under the National Environmental Policy Act process. A scoping meeting was held by the FERC in Tennessee on February 24, 2005. There is landowner opposition to the project, which is not unusual for pipeline construction. Midwestern Gas Transmission is working to keep the affected landowners, the FERC staff and other governmental agencies informed. Pending the receipt of regulatory and other required approvals, the proposed in-service date for the project is November 2006 and project costs are estimated at approximately $22 million to $25 million with approximately $8 million-$9 million to be expended in 2005.

Viking Gas Transmission Recontracting

During 2004, Viking Gas Transmission extended contracts of 49 mmcfd at maximum rates with existing shippers for terms ranging from 3 to 5 years, resulting in Viking Gas Transmission being fully contracted until November 2005. Viking Gas Transmission has been successful in recontracting 89% of the 154 mmcfd of the expiring capacity at the Marshfield, Wisconsin delivery point for 2 to 5 year terms at maximum rates in spite of potential competition with ANR Pipeline Company's North Leg Project scheduled to go into service in 2005. We expect other projects may be proposed to further compete for these markets. WE Energies, Wisconsin Power and Light Company and Wisconsin Public Service Corporation are jointly exploring the acquisition of firm natural gas pipeline capacity to accommodate growth and provide greater competition for deliveries to various points along a route from the greater Milwaukee area to Green Bay, Wisconsin.

Rate Case Filings and FERC Inquiry

Under the settlement agreement for Northern Border Pipeline's last rate case, it was agreed that Northern Border Pipeline must file a proceeding under section 4 of the Natural Gas Act to determine the just and reasonable rates to be charged for its transportation services. During the rate case process, the FERC staff and Northern Border Pipeline's customers will review the cost of service elements, (including allowed return on capital, operations and maintenance costs, depreciation and taxes) and contract

28

demand levels used to determine transportation rates. Also, as required under the order granting a certificate of public convenience and necessity, Guardian Pipeline must file a revenue and cost study by December 7, 2005.

As described more fully in Item 1. "Business-Interstate Pipeline Regulation", there is a FERC inquiry regarding the proper income tax allowance in rates for regulated entities other than corporations. In response, a number of comments, including ours, suggested that an income tax allowance is proper for all jurisdictional entities regardless of legal structure. Some producers' and customers' comments argued against the inclusion of an income tax allowance for partnerships and other non-tax paying entities. It is not certain how, or when, the FERC may proceed with respect to its Request for Comments or any impact on the rate methodology for our interstate natural gas pipelines which are not corporations. In particular, Northern Border Pipeline is a general partnership and one of the elements used to determine its cost of service, upon which its transportation rates are derived, is an allowance for income taxes. While we cannot predict the outcome of the FERC's inquiry, we do believe that Northern Border Pipeline's specific circumstances regarding its tariff, deferred income tax treatment, FERC orders, past history and underlying agreements with shippers are different from those of SFPP, L.P. The issue of whether Northern Border Pipeline's rates should include an income tax allowance, and if so the amount thereof, may be addressed in Northern Border Pipeline's 2005 rate case.

NATURAL GAS GATHERING AND PROCESSING SEGMENT

The gas gathering and processing segment accepts delivery of raw gas from natural gas wells at low pressure and gathers that wellhead production to central points where it is processed as necessary and compressed to high pressure for entry into the transmission pipeline grid. Key factors that have an impact on this segment are the pace of reserve development, the decline rate of existing wells, the composition of the raw gas stream being gathered, and the value of natural gas and natural gas liquids.

We charge a fee for this service in the Powder River Basin. In the Williston Basin, we buy the natural gas we gather and then resell the extracted natural gas liquids and residue, retaining a portion of the resale revenues in return for our gathering and processing services. In some cases, we charge a fee as well. The producers receive the balance of the proceeds from the resale.

Williston Basin Expansions

As a result of increased drilling and development by Bear Paw Energy's customers in the Williston Basin, Bear Paw Energy has selectively expanded its facilities and expects moderate growth in this area. The 5 mmcfd expansion of the Marmarth plant has been in full operation since February 2004. The project enables the plant to produce a higher grade of product by controlling the maximum ethane-propane mixture. Also, Bear Paw Energy has expanded the northwest portion of its system to accommodate additional volumes in the Bakken Oil Play. It is anticipated that as a result of placing these facilities into service in December 2004, an additional 3.8 mmcfd will be processed by Bear Paw Energy's Grasslands processing plant in 2005. Further expansion in the Bakken Oil Play is expected to bring additional volumes to our system.

29

Powder River Basin Developments

On our wholly-owned systems in the Powder River Basin, gathering volumes have increased 9% since reaching a low point in the first quarter 2004. For the full year 2004, average daily volumes gathered on our wholly-owned assets in the Powder River Basin were down 3% compared to 2003, in spite of modest growth in drilling activity and smaller than anticipated well production declines. Certain gathering contracts were renegotiated to mitigate volumetric risk and to reduce operation and maintenance expenses. In addition, certain non-strategic Powder River assets were sold during 2004, which resulted in gains totaling $3.3 million during 2004. Late in 2004, we also purchased a gathering system that gathers production from approximately 10,000 acres.

We hold minority interests in Bighorn and Fort Union, which are trunk gathering systems in the Powder River Basin. These businesses are also impacted by the pace of drilling, regulatory issues and declines in upstream areas, however, they are generally more stable in terms of throughput volumes and revenues because they gather gas from larger areas. Also, our ownership in Bighorn includes preferred A units, which effectively provide an incentive mechanism to Cantera Natural Gas tied to the number of wells connected to the system. Whether such targets have been met for 2004 is under discussion. We believe that a distribution for the preferred A units is due us for 2004. Our expected 2005 net income and cash flow includes approximately $2.6 million from this distribution.

Sale of Gregg Lake/Obed Pipeline Interest

Our wholly-owned subsidiary, Border Midstream Services sold its undivided minority interest in the Gregg Lake/Obed Pipeline located in Alberta, Canada in December 2004 for approximately $14.0 million. The sale resulted in a $3.6 million after-tax gain.

COAL SLURRY PIPELINE SEGMENT

Black Mesa Pipeline Company is our coal slurry pipeline. This pipeline has one major customer, the coal supplier to the Mohave Generating Station, in Laughlin, Nevada. This contract on Black Mesa provides a steady, fee for service, revenue stream through December 31, 2005. After that time, the future is uncertain. The Mohave Generating Station must complete some significant pollution control investments, and a new water supply for the coal slurry mixture must be established. In addition, new contracts for the coal supply, must be completed. We believe that we will be able to negotiate a new contract for Black Mesa's services, however, we cannot predict the timing or ultimate outcome. Should these issues be resolved, it appears likely that there would be a temporary shutdown of the Mohave Generating Station and the Black Mesa pipeline from 2006 to 2009. We anticipate that the capital expenditures for the Black Mesa refurbishment project will be in the range of $175 million to $200 million, which will be supported by revenues from a new transportation contract. Under certain circumstances upon the renewal of the transportation contract, we have a contingent obligation to issue common units to prior owners of an interest in Black Mesa Pipeline. If this obligation is triggered, approximately 70,000 to 75,000 common units would be issued. If efforts to resolve the issues surrounding the Mohave Generating Station are not successful and it is permanently closed, it would be necessary to shut down the Black Mesa

30

pipeline in 2006. In the event the Mohave Generating Station permanently closes, estimated shut down costs for Black Mesa could be in the range of $5 million to $7 million for such expenses as environmental reclamation, severance payments and pension plan funding. We would also be required to take a non-cash charge of approximately $12 million related to goodwill and the remaining undepreciated cost of the assets.

For all of our operations, we have continual focus on reliability for our shippers, safety for the public and our customers, and compliance with regulatory rules and regulations. In our businesses, these areas are essential.

STRATEGY

We are focused on growing our businesses, our income and cash flow and our distributions to unitholders. Our strategy involves three main components.

INTERSTATE NATURAL GAS PIPELINE SEGMENT

First, we will continue to focus on safe, efficient, and reliable operations and the further development of our regulated pipelines. We intend to maintain our position as a low cost transporter of Canadian gas to the midwestern U.S. and provide highly valued services to our customers. Any growth in our interstate pipelines would occur through incremental projects intended to access new markets or supply areas and would be supported by long-term contracts. For Northern Border Pipeline, the marketing of available capacity in a short-term contracting environment, filing for and receiving regulatory approvals for the Chicago III Expansion and filing the rate case will be priorities for 2005. In addition, Midwestern Gas Transmission will focus on receiving regulatory approvals for its Eastern Extension project and will continue pursuit of expanding existing and developing new interconnections with other interstate pipelines to access new markets.

NATURAL GAS GATHERING AND PROCESSING SEGMENT

Second, we also are developing our gas gathering and processing segment where we are building on our established business relationships with producers and marketers in the Rocky Mountain supply basins. We expect to see continued build-out of our gathering systems within the areas of acreage dedications we have secured, particularly in the Powder River Basin. Depending on the pace of reserve and production development, time associated with regulatory compliance including water-discharge permitting, and infrastructure development, we expect growth from new well connections to offset the decline from existing gas wells, resulting in approximately level aggregate gathered volumes on our Powder River systems during 2005. We are also continuing to pursue different approaches to conducting business in the Powder River Basin to reduce capital and operating expenditures, improve revenue, and reduce volume and capital recovery risks. We seek to build extensions to existing facilities on dedicated acreage using lower risk rate structures, expand our gathering network by securing additional acreage dedications, and encourage utilization of existing facilities.

We expect modest growth in gas volumes for our pipelines in the Williston Basin, reflecting prospects for drilling activity within the

31

Bakken Oil Play production area. In the Williston Basin, we seek to build extensions and expansions around our existing facilities and also pursue opportunities to reduce costs and streamline operations. In addition, we are pursuing new acreage dedications in the basin. The build-out of our existing, and the addition of new, acreage dedications should mitigate production declines and allow further improvement in cost efficiencies. We will also continue to seek opportunities to mitigate commodity price exposure on the Williston Basin production.

ACQUISITIONS

Finally, our objective is to continue to acquire profitable and complementary businesses. Our goal is approximately $200 to $250 million of capital expenditures annually in growth through acquisitions and internal development. We target businesses that leverage our core competencies of energy transportation, are conservative in terms of commodity price risk, are located in the U.S. and Canada, and provide immediate earnings and cash flow contribution. Our strategy is to focus on acquisitions of natural gas assets including interstate and intrastate natural gas pipelines, storage facilities and gathering and processing assets and natural gas liquids pipelines and storage facilities. We anticipate financing our capital expenditures and acquisitions conservatively through an appropriate mix of additional borrowings and equity issuances. Although we regularly evaluate various acquisition opportunities, we cannot provide assurance that we will reach our goal each year and would also expect that, depending on specific opportunities that develop, acquisitions in some years could significantly exceed our goal stated above. Our ability to maintain and grow our distributions to the unitholders is dependent upon the growth of our existing businesses and/or our acquisitions.

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 accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and 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 elsewhere in this report. 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

32

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 accounting principles generally accepted in the United States of America 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 December 31, 2004, we have recorded regulatory assets of $12.3 million, which are being recovered, or 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 pipelines' 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.

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.

As discussed in Note 5, Notes to Consolidated Financial Statements, effective January 1, 2003, we adopted SFAS No. 143, "Accounting for Asset Retirement Obligations." SFAS No. 143 requires entities to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred, if the liability can be reasonably estimated. We have, where possible, developed our estimate of the retirement obligations. The implementation of SFAS No. 143 resulted in an increase in net property, plant and equipment of $2.5 million, an increase in reserves and deferred credits of $3.1 million and a reduction to net income of $0.6 million for the net-of-tax cumulative effect of the change in accounting principle.

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.

33

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 December 31, 2004, the consolidated balance sheet included assets from derivative financial instruments of $4.6 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.

RESULTS OF OPERATIONS

The following table summarizes financial and other information by business segment for the years ended December 31, 2004, 2003 and 2002 (in thousands):

                                                Year Ended December 31,
                                            -------------------------------
                                              2004        2003        2002
                                            --------   ---------   --------
Operating revenues:
   Interstate Natural Gas Pipelines         $383,625   $ 375,256   $339,014
   Natural Gas Gathering and Processing      184,738     154,284    126,622
   Coal Slurry                                22,020      21,408     21,568
                                            --------   ---------   --------
      Total operating revenues               590,383     550,948    487,204
                                            --------   ---------   --------

Operating income (loss):
   Interstate Natural Gas Pipelines          231,027     212,841    200,584
   Natural Gas Gathering and Processing       28,278    (203,067)    23,278
   Coal Slurry                                 3,446       5,144      5,054
   Other                                      (9,366)     (7,601)    (5,747)
                                            --------   ---------   --------
      Total operating income (loss)          253,385       7,317    223,169
                                            --------   ---------   --------
Income (loss) from continuing operations:
   Interstate Natural Gas Pipelines          134,726     119,620    107,510
   Natural Gas Gathering and Processing       44,488    (183,016)    35,568
   Coal Slurry                                 3,088       4,092      4,136
   Other                                     (41,381)    (37,845)   (36,232)
                                            --------   ---------   --------
      Total income (loss) from continuing
         operations                          140,921     (97,149)   110,982
                                            --------   ---------   --------
Discontinued operations, net of tax            3,799       9,338      2,694
Cumulative effect of change in
   accounting principle, net of tax               --         643         --
                                            --------   ---------   --------
Net income (loss)                           $144,720   $ (88,454)  $113,676
                                            ========   =========   ========

Following is a detailed analysis of the results of operations for each of our operating segments.

Our operating results for 2004 reflect the settlement or expected settlement of several outstanding issues related to our past relationship with Enron Corp. ("Enron"). Our potential obligation for costs related to the termination of Enron's cash balance plan was resolved late in 2004, which allowed us to reduce our expenses. Settlement was also reached with

34

Enron for certain administrative expenses for 2002 and 2003 that had been previously estimated, which also reduced our expenses. We also recorded income in 2004 for estimated recovery of bankruptcy claims against the Enron estate that we had previously fully reserved. In December 2004, Border Midstream sold its undivided minority interest in the Gregg Lake/Obed Pipeline. The operating results for Border Midstream are classified as discontinued operations. See Notes 3 and 19 - Notes to Consolidated Financial Statements.

Our operating results for 2003 reflected several significant events. Due to lower throughput volumes experienced and anticipated in our wholly-owned subsidiaries in our natural gas gathering and processing business segment, we recorded impairment charges related to goodwill and tangible assets for that segment. Effective January 17, 2003, we acquired all of the common stock of Viking Gas Transmission, including a one-third interest in Guardian Pipeline. In June 2003, we sold our Gladys and Mazeppa processing plants located in Alberta, Canada. The operating results for these plants are classified as discontinued operations. Finally, as a result of Enron's decision to terminate its cash balance plan, we recorded expenses for our expected charges related to the termination of that plan. See Notes 3, 4 and 18 - Notes to Consolidated Financial Statements.

Our income from continuing operations in 2004 was $140.9 million, $2.81 per unit, as compared to a loss from continuing operations of ($97.1) million in 2003, ($2.27) per unit, and income from continuing operations of $111.0 million in 2002, $2.38 per unit. Our loss in 2003 resulted from a $219.1 million goodwill and asset impairment recorded for our natural gas gathering and processing segment. Excluding the impairment charges, income from continuing operations increased $18.9 million in 2004 as compared to 2003. We were advised by Northern Plains and NBP Services, as a result of further evaluation and negotiation of Enron's proposed allocation of the termination costs, that no claim of reimbursement for the termination costs of Enron's cash balance plan will be made, resulting in a reduction to expense in 2004 of $6.2 million ($4.8 million, net of tax and minority interest). When compared to the impact of the charges recorded in 2003, this represents a $9.6 million change to income from continuing operations between 2003 and 2004. Income from continuing operations for 2004 also reflects an adjustment to our allowance for doubtful accounts for estimated recoveries of claims against the Enron estate of $3.3 million ($3.0 million, net of minority interest) and a gain on sale of two of Bear Paw Energy's gathering systems and other compressor equipment of $3.3 million. Excluding the impairment charges, income from continuing operations increased $11.0 million in 2003 as compared to 2002, which reflects income from Viking Gas Transmission of $7.1 million, lower interest expense for Northern Border Pipeline of $6.6 million ($4.6 million impact on continuing operations after minority interest) due to a decrease in average interest rates as well as a decrease in average debt outstanding, a $2.9 million special income allocation related to a cash distribution from our preferred A interest in Bighorn Gas Gathering and a $3.3 million payment received for a change in ownership of the other partner in Bighorn Gas Gathering. These increases to income were partially offset by charges associated with the termination of Enron's cash balance plan of $6.2 million ($4.8 million, net of tax and minority interest). The calculation of per unit income (loss) was also impacted by our issuance of additional partnership interests in May and June 2003.

Our consolidated income statement reflects income from discontinued

35

operations of $3.8 million in 2004, $9.3 million in 2003 and $2.7 million in 2002. Discontinued operations for 2004 include an after-tax gain of $3.6 million on the sale of the undivided interest in the Gregg Lake/Obed Pipeline. Discontinued operations for 2003 include an after-tax gain of $4.9 million on the sale of the Gladys and Mazeppa processing plants. The consolidated income statement also reflects a reduction to net income of $0.6 million due to a net-of-tax cumulative effect of change in accounting principle, which resulted from adopting SFAS No. 143, "Accounting for Asset Retirement Obligations."

INTERSTATE NATURAL GAS PIPELINE SEGMENT

Our interstate natural gas pipeline segment reported income of $134.7 million in 2004, $119.6 million in 2003 and $107.5 million in 2002. The increase in 2004 income from 2003 primarily relates to an increase in Northern Border Pipeline's revenues by $4.9 million ($3.4 million net impact to income after minority interests), a decrease in Northern Border Pipeline's operations and maintenance expense by $10.0 million ($7.0 million net impact to income after minority interests) and a decrease in Northern Border Pipeline's interest expense by $3.5 million ($2.5 million net impact to income after minority interests). The increase in 2003 income from 2002 primarily resulted from our acquisition of Viking Gas Transmission on January 17, 2003, and lower interest expense for Northern Border Pipeline. Viking Gas Transmission's income for 2003 totaled $7.1 million and Northern Border Pipeline's interest expense decreased by $6.6 million ($4.6 million net impact to income after minority interests).

Operating revenues for our interstate natural gas pipeline segment were $383.6 million in 2004, $375.2 million in 2003 and $339.1 million in 2002. The increase in operating revenues in 2004 over 2003 resulted from an increase in Northern Border Pipeline's revenues of $4.9 million, an increase in Viking Gas Transmission revenues of $2.1 million and an increase in Midwestern Gas Transmission revenues of $1.4 million. Due to the expiration of conditions under Northern Border Pipeline's previous rate case settlement, it was able to generate and retain approximately $2.0 million from the sale of short-term firm capacity and approximately $2.0 million due to no longer being required to share new service revenue with its shippers. The remaining increase of $0.9 million resulted from an additional day of transportation services due to leap year. Viking Gas Transmission's revenue was higher in 2004 primarily because 2003 does not reflect revenue prior to the January 17, 2003 acquisition date. Midwestern Gas Transmission's revenue increased primarily due to operational sales of gas. The increase in operating revenues in 2003 over 2002 resulted from Viking Gas Transmission revenues of $29.0 million, an increase in Midwestern Gas Transmission revenues of $4.0 million and an increase in Northern Border Pipeline's revenues of $3.1 million. Midwestern Gas Transmission's revenues in 2003 reflect an increase in contracted capacity as compared to the same period in 2002. Northern Border Pipeline's revenues for 2002 were affected by $1.8 million of uncollected revenues associated with the transportation capacity formerly held by ENA, which filed for Chapter 11 bankruptcy protection in December 2001 (see "The Impact Of Enron's Chapter 11 Filing On Our Business").

Operations and maintenance expenses for our interstate natural gas pipeline segment were $52.7 million in 2004, $63.6 million in 2003 and $48.3 million in 2002. The decrease in expenses from 2003 to 2004 primarily

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resulted from a decrease in Northern Border Pipeline's and Midwestern Gas Transmission's expense by $10.0 million and $1.1 million, respectively. In 2004, Northern Border Pipeline and Midwestern Gas Transmission reduced expenses by $4.2 million for adjustments to their accruals for estimated charges resulting from the termination of Enron's cash balance plan. Additionally in 2004, the interstate natural gas pipelines reduced their operations and maintenance expense by approximately $1.9 million related to the settlement of previously accrued charges for administrative services provided by Northern Plains, the pipelines' operator, and its affiliates. Also contributing to the decrease were adjustments made to our allowance for doubtful accounts of $1.1 million for estimated recoveries of claims against Enron. Expense was increased by $1.0 million related to costs incurred as part of our comprehensive effort to ensure compliance with Section 404 of the Sarbanes Oxley Act of 2002. The increase in expenses in 2003 over 2002 resulted from Viking Gas Transmission's expense of $10.8 million and an increase in Northern Border Pipeline's expense and Midwestern Gas Transmission's expense by a combined $4.5 million. This increase primarily related to the estimated charges for termination of Enron's cash balance plan of $4.2 million. Northern Border Pipeline's expenses in 2002 reflected a $10.0 million accrual for costs related to the treatment of previously collected quantities of natural gas used in utility operations to cover electric power costs (see Footnote 6 - Notes to Consolidated Financial Statements, included elsewhere in this report.) In February 2003, Northern Border Pipeline filed to amend its FERC tariff to clarify the definition of company use gas, which is gas supplied by its shippers for its operations. Northern Border Pipeline had included in its retention of company use gas, quantities that were equivalent to the cost of electric power at its electric-driven compressor stations during the period of June 2001 through January 2003. On March 27, 2003, the FERC issued an order rejecting Northern Border Pipeline's proposed tariff sheet revision and requiring refunds with interest within 90 days of the order. Northern Border Pipeline made refunds to its shippers of $10.3 million in May 2003.

Depreciation and amortization expenses for our interstate natural gas pipeline segment were $67.1 million in 2004, $65.9 million in 2003 and $61.0 million in 2002. The increase between 2004 and 2003 is primarily a result of assets that Viking Gas Transmission had placed in service in the fourth quarter of 2003. The increase between 2002 and 2003 is primarily due to the acquisition of Viking Gas Transmission in January 2003.

Taxes other than income for our interstate natural gas pipeline segment were $32.8 million in 2004, $32.9 million in 2003 and $29.2 million in 2002. The increase in 2003 from 2002 is primarily due to Viking Gas Transmission expenses of $2.5 million and a $1.2 million increase in Northern Border Pipeline's expense. Northern Border Pipeline's 2002 expense reflected a refund of use taxes previously paid on exempt purchases.

Interest expense for our interstate natural gas pipeline segment was $43.9 million in 2004, $47.6 million in 2003 and $51.5 million in 2002. The decrease in interest expense in 2004 from 2003 was primarily due to a decrease in average debt outstanding for Northern Border Pipeline partially offset by an increase in average interest rates. Northern Border Pipeline's interest expense decreased $6.6 million in 2003 from 2002 due to a decrease in average interest rates as well as a decrease in average debt outstanding. The 2003 expense included $2.7 million for Viking Gas Transmission.

Other income, net for our interstate natural gas pipeline segment was

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$0.8 million in 2004, $0.5 million in 2003 and $2.0 million in 2002. Significant items included in the $0.3 million increase between 2003 and 2004 are additional income of approximately $0.6 million for pipeline interconnections constructed partially offset by $0.5 million of bad debt expense. The decrease from 2002 to 2003 relates to a $0.6 million expense for Northern Border Pipeline's repayment of amounts received in 2002 for previously vacated microwave frequency bands.

Equity earnings from unconsolidated affiliates for our interstate natural gas pipeline segment were $1.6 million in 2004 and $2.0 million in 2003, which represents earnings from our one-third interest in Guardian Pipeline. The decrease in equity earnings was primarily due to higher depreciation expense as well as higher administrative expenses for Guardian Pipeline.

Minority interests in net income, which represent the 30% minority interest in Northern Border Pipeline, were $50.0 million for 2004, $44.5 million for 2003 and $42.8 million for 2002. The increases in 2004 and 2003 from prior year results were due to increased net income for Northern Border Pipeline.

Income tax expense for our interstate natural gas pipeline segment was $4.8 million in 2004 and $3.6 million in 2003 as compared to an income tax benefit of $0.7 million in 2002. The 2004 and 2003 amounts included Viking Gas Transmission income taxes of $2.6 million. The remaining income tax amounts relate to Midwestern Gas Transmission, which increased $1.2 million from 2003 to 2004 due to an increase in income before income taxes.

NATURAL GAS GATHERING AND PROCESSING SEGMENT

Our natural gas gathering and processing segment reported income from continuing operations of $44.5 million in 2004, a loss from continuing operations of ($183.0) million in 2003 and income from continuing operations of $35.6 million in 2002. The segment recorded impairment charges of $219.1 million in 2003 (see Note 4 - Notes to Consolidated Financial Statements, included elsewhere in this report). Excluding the effect of the impairment charges, the segment's income from continuing operations increased $8.4 million between 2003 and 2004 primarily due to a reduction to 2004 expense of $1.5 million for the adjustment to an accrual made in 2003 for estimated charges resulting from the termination of Enron's cash balance plan (resulting in a decrease between years of $2.9 million), a gain on sale of two gathering systems and other compressor equipment of $3.3 million and the adjustment to our allowance for doubtful accounts for estimated recoveries of claims against Enron of $2.3 million. Excluding the effect of the impairment charges, the segment's income from continuing operations for 2003 and 2002 was relatively unchanged.

Operating revenues for our natural gas gathering and processing segment were $184.7 million in 2004, $154.3 million in 2003 and $126.6 million in 2002. The increase in revenues in 2004 over 2003 reflects an increase in realized prices for natural gas and natural gas liquids and increased gathering and processing volumes in the Williston Basin, which accounted for $31.3 million of the revenue increase, partially offset by lower gathering volumes in the Powder River Basin, which decreased revenues by $3.3 million. The increase in 2003 over 2002 is due to an increase in natural gas and natural gas liquid prices, which accounted for $31.6 million of the overall increase, partially offset by lower volumes gathered in the

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Powder River Basin, which decreased revenues $3.9 million.

Product purchases for our natural gas gathering and processing segment were $103.2 million in 2004, $80.8 million in 2003 and $50.6 million in 2002. 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 liquids and residue gas. 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 product purchases in 2004 over 2003 is due to an increase in natural gas and natural gas liquid prices and increased gathering and processing volumes. The increase in 2003 over 2002 is due to an increase in natural gas and natural gas liquid prices.

Operations and maintenance expenses for our natural gas gathering and processing segment were $35.9 million in 2004, $42.8 million in 2003 and $38.2 million in 2002. The reduction in 2004 from 2003 was due to several factors. The 2004 amount includes a $3.3 million gain on sale of two gathering systems and other compressor equipment. In addition, the decrease in 2004 expense was due to the segment recording a $2.3 million estimated recovery of previously recorded bad debts. Expense for 2004 was also reduced by $1.5 million for the adjustment to the accrual made in 2003 for estimated charges resulting from the termination of Enron's cash balance plan. Partially offsetting these decreases to expense were higher fuel costs of $0.8 million and expenses incurred as a result of the Marmarth plant expansion, which went into service in 2004. Employee benefits expenses for 2003 increased $3.6 million as compared to 2002, which included $1.5 million of charges associated with the termination of Enron's cash balance plan.

For our natural gas gathering and processing segment, depreciation and amortization expenses, excluding the impairment charge recorded in 2003, were $14.8 million in 2004, $13.0 million in 2003 and $12.1 million in 2002. As a result of the goodwill and asset impairment analysis, we decided to shorten the useful life of our low-pressure gas gathering assets in the Powder River Basin from 30 to 15 years, which increased our depreciation expense by $0.6 million for this segment in 2003 and by $1.8 million in 2004.

Other income, net from our natural gas gathering and processing segment was $0.2 million in 2004, $3.9 million in 2003 and $0.1 million in 2002. The increase in other income for 2003 is primarily due a $3.3 million payment received for a change in ownership of the other partner in Bighorn Gas Gathering and a $0.5 million refund from an electric cooperative.

Equity earnings from our unconsolidated affiliates were $16.4 million in 2004, $16.8 million in 2003 and $13.0 million in 2002. The 2004 and 2003 equity earnings include $2.8 million and $2.9 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 targets are not met, we receive a disproportionate share of cash distributions.

COAL SLURRY PIPELINE SEGMENT

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Our coal slurry pipeline segment reported income from continuing operations of $3.1 million in 2004 on revenues of $22.0 million, income of $4.1 million in 2003 on revenues of $21.4 million and income of $4.1 million in 2002 on revenues of $21.6 million. The $1.0 million decrease in income from continuing operations between 2003 and 2004 was primarily due to higher depreciation expense of $2.6 million ($1.6 million impact after income taxes) partially offset by an increase in revenue by $0.6 million ($0.4 million impact after income taxes). Depreciation and amortization expense for the coal slurry pipeline was $4.5 million in 2004 as compared to $1.9 million in 2003 and $1.6 million in 2002. The Partnership determined it was appropriate to shorten the useful life of certain of its coal slurry assets to correspond with the expiration of the existing coal slurry transportation agreement in 2005. The increase in revenues in 2004 is primarily related to an increase in billing rates and an increase in tons of coal shipped.

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. Our general and administrative expenses not allocated to any segment were $9.4 million in 2004, $7.6 million in 2003 and $5.7 million in 2002. The increase in expense between 2003 and 2004 was primarily related to increased insurance costs of $1.1 million, $1.0 million of costs incurred as part of our comprehensive effort to ensure compliance with Section 404 of the Sarbanes Oxley Act of 2002 and $0.8 million of additional business development expenditures partially offset by a reduction to 2004 expense of $0.4 million for the adjustment to an accrual made in 2003 for estimated charges resulting from the termination of Enron's cash balance plan (resulting in a decrease between years of $0.8 million) and a $0.7 million reduction related to the settlement of previously accrued charges for administrative services provided by Northern Plains and its affiliates. The 2003 expense included $0.4 million for the termination of the Enron cash balance plan, an increase in insurance expense by $0.5 million due to an increase in liability premiums and additional business development expenditures of $0.4 million.

Interest expense on our debt was $32.7 million in 2004, $30.8 million in 2003 and $30.6 million in 2002. The increase in expense for 2004 from 2003 was primarily due to an increase in average debt outstanding partially offset by a decrease in average interest rates.

LIQUIDITY AND CAPITAL RESOURCES

The following table sets forth our contractual obligations as of December 31, 2004.

SUMMARY OF CERTAIN CONTRACTUAL OBLIGATIONS AND COMMERCIAL COMMITMENTS

                                            Payments Due by Period
                                       --------------------------------------------
                                       Less Than                             After
                             Total       1 Year    1-3 Years   4-5 Years    5 Years
                          ----------   ---------   ---------   ---------   --------
                                                (In Thousands)
2002 Pipeline Senior
   Notes due 2007         $  150,000    $    --     $150,000    $     --   $     --
1999 Pipeline Senior
   Notes due 2009            200,000         --           --     200,000         --
2000 Partnership Senior
   Notes due 2010            250,000         --           --          --    250,000

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2001 Partnership Senior
   Notes due 2011            225,000         --           --          --    225,000
2001 Pipeline Senior
   Notes due 2021            250,000         --           --          --    250,000
Viking Senior Notes
   due 2008 to 2014           31,120      2,133        4,266       1,779     22,942
2003 Partnership Credit
   Agreement due 2007        191,000         --      191,000          --         --
Capital Leases (a)             3,262      3,145          117          --         --
Operating Leases (b)          83,422      4,489        7,178       5,370     66,385
Other Long-Term
   Obligations (b)            61,260     11,624       23,247      22,710      3,679
                          ----------    -------     --------    --------   --------
Total                     $1,445,064    $21,391     $375,808    $229,859   $818,006
                          ==========    =======     ========    ========   ========

(a) See Note 8 - Notes to Consolidated Financial Statements.

(b) See Note 13 - Notes to Consolidated Financial Statements.

We have guaranteed the performance of certain of our unconsolidated affiliates in connection with their credit agreements that expire in March 2009 and September 2009. Collectively at December 31, 2004, the amount of both guarantees was $4.4 million.

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 new 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 and our financial condition and credit ratings at the time.

CREDIT FACILITIES

The Partnership and Northern Border Pipeline have entered into revolving credit facilities, which are used for refinancing existing indebtedness, capital expenditures, acquisitions and 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. At December 31, 2004, $191 million was outstanding under the 2003 Partnership Credit Agreement at an average interest rate of 3.20%. There were no amounts outstanding under the 2002 Pipeline Credit Agreement at December 31, 2004. With the 2002 Pipeline Credit Agreement due to expire in May 2005, Northern Border Pipeline has commenced discussions with financial institutions and expects to have a new credit agreement in place at terms and conditions similar to its current agreement.

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

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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 December 31, 2004, the Partnership and Northern Border Pipeline were in compliance with the covenants of our 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 LIBOR plus a spread that is based upon the long-term unsecured debt ratings in effect for us and for Northern Border Pipeline.

DEBT SECURITIES

In April 2002, Northern Border Pipeline completed a private offering of $225 million of 6.25% Senior Notes due 2007 ("2002 Pipeline Senior Notes"). The proceeds from the 2002 Pipeline Senior Notes were used to reduce indebtedness outstanding. In December 2004, Northern Border Pipeline redeemed $75 million of the 2002 Pipeline Senior Notes. The indentures under which the Pipeline Senior Notes were issued do not limit the amount of unsecured debt Northern Border Pipeline may incur, but they do contain material financial covenants, including restrictions on incurrence of secured indebtedness.

The indentures under which the Partnership Senior Notes were issued do not limit the amount of unsecured debt we may incur, but they do contain material financial covenants, including restrictions on incurrence, assumption or guarantee of secured indebtedness. The indentures also contain provisions that would require us to offer to repurchase the Partnership Senior Notes, if either Standard & Poor's Rating Services or Moody's Investor Services, Inc. rate the notes below investment grade and the investment grade rating is not reinstated for a period of 40 days.

At December 31, 2004, Viking Gas Transmission has four series of senior notes outstanding. In November 2004, Viking Gas Transmission amended the indenture on its senior notes. Prior to the amendment, Viking Gas Transmission made monthly principal and interest payments on the four series of notes. As a result of the amendment, three of the series of senior notes due between 2011 and 2014 require payment of interest quarterly and payment of principal at maturity. The senior notes due in 2008 continue to require monthly principal and interest payments. Under the previous indenture, Viking Gas Transmission's transportation contracts were pledged as security for payment, which has been replaced in the current indenture by a guarantee by the Partnership. In addition, Viking Gas Transmission is no longer required to maintain debt service funds on deposit. At December 31, 2003, the requirement for accumulation of debt service funds was $3.7 million.

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

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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 swaps and the issuance of the fixed rate debt. We expect to use the proceeds from the senior note issuance to repay amounts borrowed under the 2003 Partnership Credit Agreement.

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 the London Interbank Offered Rate and in return receive payments based on a 7.10% fixed rate. At December 31, 2004, the average effective interest rate on our interest rate swap agreements was 4.60%.

EQUITY ISSUANCES

In May and June 2003, we sold 2,250,000 and 337,500 common units, respectively. In July 2002, we sold 2,186,700 common units. In conjunction with the issuance of additional common units, our general partners are required to make capital contributions to maintain a 2% general partner interest in accordance with the partnership agreements. The net proceeds from the sale of common units and the general partners' capital contributions totaled approximately $102.2 million and $75.4 million in 2003 and 2002, respectively, and were primarily used to repay indebtedness outstanding.

CASH FLOWS FROM OPERATING ACTIVITIES

Cash flows provided by operating activities were $244.7 million in 2004, $224.7 million in 2003 and $244.0 million in 2002. The increase in operating revenues and lower interest expense in 2004 as compared to 2003 contributed to the increase in operating cash flow. These increases were partially offset by higher product purchases and a $2.3 million decrease in distributions received from unconsolidated affiliates. Other cash flows from operating activities for 2004 reflect Northern Border Pipeline's initial payment of $7.4 million to the Fort Peck Tribes, in accordance with the terms of the Agreement, and an inflow of $3.7 million for funds that Viking Gas Transmission was previously required to keep on deposit for debt service. The decrease from 2002 to 2003 is primarily due to Northern Border Pipeline's refund to its shippers for $10.3 million (see Note 6 - Notes to Consolidated Financial Statements, included elsewhere in this report). Operating cash flows were also decreased due to payments made to NBP Services and Northern Plains for administrative services provided prior to 2003 and due to a reduction in prepayments in 2003 that Northern Border Pipeline had required certain shippers make in 2002 for transportation service. Distributions received from unconsolidated affiliates increased $5.4 million to $16.3 million, primarily due to distributions received from Bighorn Gas Gathering related to our preferred A interest discussed previously.

CASH FLOWS FROM INVESTING ACTIVITIES

Cash used in investing activities was $20.9 million in 2004, $116.7 million in 2003 and $55.3 million in 2002. In 2003, we spent higher amounts primarily related to the acquisition of Viking Gas Transmission.

Our capital expenditures were $43.5 million in 2004, which included

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$25.6 million for natural gas gathering and processing facilities, $16.3 million for interstate natural gas pipeline facilities and $1.6 million for coal slurry pipeline facilities. Our capital expenditures were $30.3 million in 2003, which included $19.5 million for interstate natural gas pipeline facilities, $9.0 million for natural gas gathering and processing facilities and $1.8 million for coal slurry pipeline facilities. For 2002, our capital expenditures were $50.7 million, which included $33.7 million for natural gas gathering and processing facilities, $16.5 million for interstate natural gas pipelines facilities and $0.4 million for coal slurry pipeline facilities.

Our cash used in acquisitions was $123.2 million in 2003, as compared to $1.6 million in 2002. In January 2003, we acquired Viking Gas Transmission. We did not make any acquisitions in 2004.

Sale of assets were $22.7 million in 2004 due to the sale of our undivided minority interest in the Gregg Lake/Obed Pipeline for $14.0 million and the sale of two of Bear Paw Energy's gathering systems for $8.7 million. Sale of assets was $40.3 million in 2003 due to the sale of the Gladys and Mazeppa processing plants. No sale of assets occurred in 2002.

Our investments in unconsolidated affiliates were $0.1 million in 2004, $3.5 million in 2003 and $3.0 million in 2002. The 2003 amount primarily represents capital contributions to Guardian Pipeline while the 2002 amounts primarily reflect capital contributions to Bighorn Gas Gathering.

Total capital expenditures for 2005 are estimated to be $87 million. Capital expenditures for the interstate natural gas pipelines are estimated to be $57 million, including approximately $40 million for Northern Border Pipeline. Of the $57 million projected expenditures for the interstate natural gas pipelines, approximately $15 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 $25 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.

CASH FLOWS FROM FINANCING ACTIVITIES

Cash flows used in financing activities were $225.7 million for 2004, $106.7 million for 2003 and $170.8 million for 2002. Our cash distributions to our unitholders and our general partners in 2004, 2003 and 2002 were $159.6 million, $155.2 million and $147.0 million, respectively. The increase in distributions paid between years is due to an increase in the number of common units outstanding.

In 2004, Northern Border Pipeline received equity contributions from its general partners including $61.5 million from its minority interest holder. Northern Border Pipeline's distributions to its minority interest holder increased $15.5 million between 2003 and 2004. Effective January 1, 2004, Northern Border Pipeline changed its cash distribution policy. Cash

44

distributions will be equal to 100% of distributable cash flow as determined from Northern Border Pipeline's financial statements based upon earnings before interest, taxes, depreciation and amortization less interest expense and less maintenance capital expenditures.

In 2003 and 2002, we issued additional partnership interests of $102.2 million (2.6 million common units) and $75.4 million (2.2 million common units), respectively, which were primarily used to repay indebtedness outstanding.

For 2004, our borrowings on long-term debt totaled $259.0 million, which were primarily used to repay previously existing indebtedness. Issuances of long-term debt included borrowings under our credit agreement of $152.0 million and borrowings under Northern Border Pipeline's credit agreement of $107.0 million. Total repayments of debt were $327.5 million, which included the redemption of $75 million of the 2002 Pipeline Senior Notes. In connection with the redemption, Northern Border Pipeline was required to pay a premium of $4.8 million.

For 2003, our borrowings on long-term debt totaled $342.0 million, which were primarily used for our acquisition of Viking Gas Transmission and to repay previously existing indebtedness. Issuances of long-term debt included borrowings under our credit agreements of $200.0 million and borrowings under Northern Border Pipeline's credit agreement of $142.0 million. Total repayments of debt in 2003 were $361.1 million.

For 2002, our borrowings on long-term debt totaled $499.9 million, which were primarily used to repay previously existing indebtedness. Issuances of long-term debt included net proceeds from the 2002 Pipeline Senior Notes of approximately $223.5 million; borrowings under our prior credit agreement of $68.0 million; and borrowings under Northern Border Pipeline's credit agreements of $207.0 million. Total repayments of debt in 2002 were $567.5 million.

In November 2004, Northern Border Pipeline received $7.6 million from the termination of its interest rate swap agreements with a total notional amount of $225 million. In March 2003, the Partnership received $12.3 million from the termination of an interest rate swap agreement with a notional amount of $75 million. The proceeds were primarily used to repay existing indebtedness. In 2002, we agreed to an increase in the variable interest rate on two of our interest rate swap agreements with a total notional amount of $150 million. As consideration for the change to the variable interest rate, we received approximately $18.2 million, which represented the fair value of the financial instruments at the date of the adjustment. We used the proceeds to repay amounts borrowed under our prior credit agreement. Also, in 2002, Northern Border Pipeline received $2.4 million from the termination of forward starting interest rate swap agreements (see Note 9 - Notes to Consolidated Financial Statements).

THE IMPACT OF ENRON'S CHAPTER 11 FILING ON OUR BUSINESS

On December 2, 2001, Enron filed a voluntary petition for bankruptcy protection under Chapter 11 of the United States Bankruptcy Code. Certain wholly-owned Enron subsidiaries also filed for Chapter 11 bankruptcy protection on December 2, 2001 and thereafter. Until November 17, 2004, each of Northern Plains and Pan Border, two of our general partners, were

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subsidiaries of Enron. Northern Plains and Pan Border were not among the Enron companies who filed for Chapter 11 protection.

SALE OF ENRON ENTITIES

On March 31, 2004, Enron transferred its ownership interest in Northern Plains, Pan Border and NBP Services to CrossCountry Energy, LLC ("CrossCountry"). In addition, CrossCountry and Enron entered into a transition services agreement pursuant to which Enron would provide to CrossCountry, on an interim, transitional basis, various services, including but not limited to (i) information technology services, (ii) accounting system usage rights and administrative support and (iii) payroll, employee benefits and administrative services. In turn, these services are provided to us and our subsidiaries through Northern Plains and NBP Services.

On June 24, 2004, Enron announced that it had reached an agreement with a joint venture of Southern Union Company and GE Commercial Finance Energy Financial Services ("CCE Holdings") for the sale of CrossCountry. On September 1, 2004, Enron announced that it reached an amended agreement for the sale of CrossCountry to CCE Holdings ("CCE Holdings Agreement"). On September 10, 2004, the Bankruptcy Court issued an order (the "September 10 Order") approving the CCE Holdings Agreement.

On September 16, 2004, Southern Union Company and ONEOK, Inc. each announced that ONEOK had entered into an agreement ("ONEOK Agreement") to purchase Northern Plains, Pan Border and NBP Services (collectively the "Transfer Group Companies") from CCE Holdings. This acquisition closed on November 17, 2004. Under the CCE Holdings Agreement, Enron agreed to extend certain of the terms of the transition services agreement and transition services supplemental agreement between CrossCountry and Enron (together the "TSA") for a period of six months from the closing date.

As part of the closing, ONEOK and CCE Holdings entered a transition services agreement referred to as the "Northern Border Transition Services Agreement" covering certain transition services by and among ONEOK, CCE Holdings and Enron for a period of six months. Certain of the services previously provided by Enron are now being provided through ONEOK. As services are transitioned to Northern Plains, NBP Services or ONEOK, it is possible that additional costs for computer hardware, software and personnel may result. The costs estimated to date do not appear to be materially greater than the costs incurred in the past by Northern Plains and NBP Services from Enron and CrossCountry.

PENSION LIABILITY

On December 31, 2003, Enron filed a motion seeking approval of the Bankruptcy Court to provide additional funding to, and for authority to terminate, the Enron Corp. Cash Balance Plan ("Cash Balance Plan") and certain other defined benefit plans of Enron's affiliates (collectively the "Plans") in "standard terminations" within the meaning of Section 4041 of the Employee Retirement Income Security Act of 1974, as amended ("ERISA"). On January 30, 2004, the Bankruptcy Court entered an order authorizing the termination, additional funding and other actions necessary to effect the relief requested. Pursuant to the Bankruptcy Court order, any contributions to the Plans are subject to the prior receipt of a favorable determination by the Internal Revenue Service that the Plans are tax-qualified as of their respective dates of termination.

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On July 19, 2004, Enron was served with a complaint filed by the Pension Benefits Guaranty Corporation ("PBGC") in the District Court for the Southern District of Texas against Enron as the sponsor and/or administrator of the Plans
(the "Action"). By filing the Action, the PBGC is seeking an order (i)
terminating the Plans; (ii) appointing the PBGC the statutory trustee of the Plans; (iii) requiring transfer to the PBGC of all records, assets or other property of the Plans required to determine the benefits payable to the Plans' participants; and (iv) establishing June 2, 2004 as the termination date of the Plans. In the Bankruptcy Court September 10 Order, Enron was authorized to enter into an escrow agreement with CCE Holdings and PBGC. Upon closing, Enron deposited the amount of $321.8 million to an escrow account, which is intended to ensure that none of CCE Holdings or its affiliates are exposed to liability to the PBGC under Title IV of the Employee Retirement Income Security Act of 1974, as amended, for which CCE Holdings may otherwise be indemnified pursuant to the CCE Holdings Agreement. In addition, the form of escrow agreement approved pursuant to the September 10 Order provides that, under certain circumstances and upon approval by or notice to the parties to the escrow agreement, some or all of the funds placed in escrow may be paid directly in respect of the Cash Balance Plan to the PBGC. However, the September 10 Order also provides that PBGC retains any rights or claims it may have against the Transfer Group Companies.

Enron management previously informed Northern Plains and NBP Services that Enron would seek funding contributions from each member of its ERISA controlled group of corporations that employs, or employed, individuals who are, or were, covered under the Cash Balance Plan. Northern Plains and NBP Services are considered members of Enron's ERISA controlled group of corporations. As of December 31, 2003, the amount of approximately $6.2 million was estimated for Northern Plains' and NBP Services' proportionate share of the up to $200 million estimated termination costs for the Plans authorized by the Bankruptcy Court order. Since under the operating agreement with Northern Plains and the administrative agreement with NBP Services, these costs could be our responsibility, we accrued $6.2 million to satisfy claims of reimbursement for these termination costs.

As a result of further evaluation and negotiation of Enron's proposed allocation of the termination costs, Northern Plains and NBP Services advised us that no claim of reimbursement for the termination costs will be made, resulting in a reduction in reserves during 2004 of $6.2 million for the termination costs. Under the ONEOK Agreement, neither Northern Plains nor NBP Services nor the Partnership will be required to contribute to or otherwise be liable for any contributions to Enron in connection with the Cash Balance Plan. The purchase price under the agreements will be deemed to include all contributions which otherwise would have been allocable to Northern Plains and NBP Services.

CLAIMS FILED IN BANKRUPTCY

At the time of the filing of the bankruptcy petition, we had a number of contractual relationships with Enron and its subsidiaries.

On July 15, 2004, the Bankruptcy Court approved the amended joint Chapter 11 plan and related disclosure statement ("Chapter 11 Plan"). Under the approved Chapter 11 Plan, assuming the previously announced sale of

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Portland General Electric is consummated, Enron creditors, which should include subsidiaries of the Partnership as general unsecured creditors, will receive a combination of cash and equity of Prisma Energy International, Enron's international energy asset business. We have previously fully reserved our claims against Enron.

ENA, a wholly-owned subsidiary of Enron that is in bankruptcy, was a party to transportation contracts, which obligated ENA to pay for 3.5% of Northern Border Pipeline's capacity. Through the bankruptcy proceeding in 2002, ENA rejected and terminated all of its firm transportation contracts on Northern Border Pipeline. 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 between 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. The settlement agreement is expected to be presented to the Bankruptcy Court for approval in March 2005. Based upon this settlement between the parties, at December 31, 2004 Northern Border Pipeline adjusted its allowance for doubtful accounts to reflect an estimated recovery of $1.1 million for this claim.

ENA was also a party to a transportation contract for capacity on Midwestern Gas Transmission. ENA rejected and terminated this contract in November 2003. Midwestern Gas Transmission filed claims against ENA for breach of contract and other claims. However, this claim of approximately $150 thousand was denied.

In addition, Bear Paw Energy filed claims against ENA relating to terminated swap agreements. In accordance with SFAS No. 133 in 2001 Bear Paw Energy ceased to account for these swap agreements as hedge transactions. Bear Paw Energy had previously recorded approximately $6.7 million in accumulated other comprehensive income related to these agreements, which is being recorded into earnings in the same periods of the originally forecasted hedges. During the third quarter 2004, the Bankruptcy Court approved a settlement between Bear Paw Energy, Enron and certain of its wholly-owned subsidiaries of Bear Paw Energy's claim for commodity hedges. As a result, we adjusted our allowance for doubtful accounts to reflect an estimated $1.8 million recovery for this claim.

Also, Crestone Energy Ventures filed claims against ENA for unpaid gas gathering and administrative services fees in the amount of approximately $2.3 million. As a result of a settlement agreement between ENA and Crestone Energy Ventures, ENA has agreed to allow Crestone Energy Ventures' claim of approximately $2.3 million. The settlement agreement is expected to be presented to the Bankruptcy Court for approval in March 2005. Based upon this settlement between the parties, an adjustment of $0.5 million was made to our allowance for doubtful accounts.

We estimate that we could recognize, through future operating results, additional recoveries 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.

VEBA TRUST

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Enron is the grantor of the Enron Gas Pipeline Employee Benefit Trust (the "Trust"), which when taken together with the Enron Corp. Medical Plan for Inactive Participants (the "Medical Plan") constitutes a "voluntary employees' beneficiary association" or "VEBA" under Section 501(c)(9) of the Internal Revenue Code. In October 2002, Northern Plains was advised that Enron had notified the committee that has administrative and fiduciary oversight related to the Trust and the Medical Plan, that Enron had made the determination to begin necessary steps to partition the assets of the Trust and the related liabilities of the Medical Plan among all of the participating employers of the Trust. The Trust was established as a regulatory requirement for inclusion of certain costs for post-employment medical benefits in the rates established for the affected pipelines, including Northern Border Pipeline. Enron requested the enrolled actuary to prepare an analysis and recommendation for the allocation of the Trust's assets and associated liabilities among all the participating employers. On July 22, 2003, Enron sought approval of the Bankruptcy Court to terminate the Trust and to distribute its assets among certain identified pipeline companies, one being Northern Plains. If Enron's relief would have been granted as requested, Northern Plains would have assumed retiree benefit liabilities, estimated as of June 30, 2002, of $1.9 million with an asset allocation of $0.8 million. An objection to the motion was filed. An additional actuary has been engaged by Enron to review the analysis and recommendations for allocations. The results of that review have not been provided to Northern Plains. It is anticipated that a new motion will be filed and that the allocation of liabilities and assets will change from those set forth in the prior motion. We do not, however, believe that those changes will be material.

PUBLIC UTILITY HOLDING COMPANY ACT ("PUHCA") REGULATION

We were previously a subsidiary of a registered holding company. Upon consummation of the sale of Northern Plains and Pan Border to CCE Holdings and to ONEOK, we were no longer a subsidiary of a registered holding company.

RISK FACTORS AND INFORMATION REGARDING FORWARD-LOOKING STATEMENTS

Statements in this Annual 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. The future results of our 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 - The Impact Of Enron's Chapter 11 Filing On Our Business";

- the discussions in "Management's Discussion and Analysis of Financial Condition and Results of Operations -- Overview"; and

- the discussions in "Management's Discussion and Analysis of Financial Condition and Results of Operations -- Liquidity and

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Capital Resources."

Although we believe that our expectations regarding future events are based on reasonable assumptions within the bounds of our knowledge of our business, we cannot assure you that our goals will be achieved or that our expectations regarding future developments will be realized.

With this in mind, you should consider the following important factors that could cause actual results to differ materially from those in the forward-looking statements:

- Any customer's failure to perform its contractual obligations could adversely impact our cash flows and financial condition. Some of our shippers or their owners have experienced a deterioration of their financial condition. Should one or more file for bankruptcy protection, our ability to recover amounts owed or to resell the capacity would be impacted.

- Since Northern Plains, the interstate natural gas pipelines' operator, and NBP Services, administrator for us, are transitioning services from Enron and CrossCountry, Northern Plains and NBP Services may be unable to perform certain services under their agreements or may incur increases in costs to continue or replace the services.

- Contracts on our interstate pipelines will expire during the year 2005 with significant expirations in April and October. On Northern Border Pipeline, those contracts represent approximately 40% of its summer design capacity. The interstate pipelines' ability to recontract capacity as existing contracts terminate for maximum transportation rates will be subject to a number of factors including availability of natural gas supplies from the western Canadian sedimentary basin, the demand for natural gas in our market areas and the basis differential between the receipt and delivery points on our system. Northern Border Pipeline may have to contract for shorter terms or at less than maximum rates. See "Overview" above and Item 1. "Business - Interstate Pipelines - Demand For Transportation Capacity."

- Our interstate pipelines are subject to extensive regulation by the FERC governing all aspects of our business, including our transportation rates. Under Northern Border Pipeline's 1999 rate case settlement, neither Northern Border Pipeline nor its existing customers can seek rate changes to its settlement base rates until November 2005, at which time Northern Border Pipeline is obligated to file a rate case. We cannot predict what challenges our interstate pipelines may have to their rates in the future. See Item 1. "Business
- Interstate Pipelines - FERC Regulation."

- In the event that the FERC ultimately determines that interstate natural gas pipelines that are partnerships are not entitled to an allowance for income tax in their rates and Northern Border Pipeline is unsuccessful in its arguments regarding its facts and circumstances, the disallowance of this component of cost of service for rates in Northern Border Pipeline could be materially adverse to us. See Item 1. "Business - Interstate Pipelines - FERC Regulation."

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- In a rate case proceeding setting the maximum rates that may be charged, our interstate pipeline systems are generally allowed the opportunity to collect from their customers a return on their assets or "rate base" as reflected in their financial records as well as recover that rate base through depreciation. The amount they may collect from customers, as a result of a subsequent rate case, decreases as the rate base declines as a result of, depreciation and amortization. In order to avoid a reduction in the level of cash available for distributions to its owners, in the event of a future rate case, each of these pipelines must maintain or increase its rate base through projects that maintain or add to existing pipeline facilities or increase its rate of return.

- Conflicts of interest may arise between our general partners and their affiliates on one hand, and us on the other hand. As a result of these conflicts, the general partners may favor their own interests and the interests of their affiliates over the interests of our limited partners.

- We face competition from third parties in our natural gas transportation, gathering and processing businesses. See Item 1. "Business - Interstate Pipeline Competition" and "Business - Interstate Pipelines-Future Demand and Competition."

- Our operations are subject to federal and state agencies for environmental protection and operational safety. We may incur substantial costs and liabilities in the future as a result of stricter environmental and safety laws, regulations and enforcement policies. See Item 1. "Business - Environmental and Safety Matters."

- Northern Border Pipeline expects to seek rate recovery of its costs associated with the settlement of pipeline right-of-way lease and taxation issues with the Fort Peck Tribes. If Northern Border Pipeline is unable to recover these settlement costs in rates, it will be required to expense costs previously deferred as regulatory assets.

See Item 3. "Legal Proceedings."

- Black Mesa's contract to transport coal slurry terminates in December 2005. If Black Mesa is unable to extend or enter into a new arrangement for transportation of coal slurry, Black Mesa could incur costs and expenses for employee related matters, a write-off of recorded goodwill and removal of certain facilities. See Item 1. "Business - Coal Slurry Pipeline" and "Overview" above.

- Part of our business strategy is to expand existing assets and acquire additional assets and businesses that will allow us to increase our cash flow and distributions to unitholders. Unexpected costs or challenges may arise whenever we acquire new assets or businesses. Successful acquisitions require management and other personnel to devote significant amounts of time to new businesses or integrating the acquired assets with existing businesses.

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- Our ability to maintain and/or expand our midstream gas gathering business will depend in large part on the pace of drilling and production activity in the Powder River, Wind River and Williston Basins. Drilling and production activity will be impacted by a number of factors beyond our control, including demand for and prices of natural gas and refinery grade crude oil, producer response to the EIS, reserve performance, the ability of producers to obtain necessary permits and capacity constraints on natural gas transmission pipelines that transport gas from the producing areas. See Item 1. "Business - Natural Gas Gathering and Processing Segment - Future Demand and Competition."

- Our financial performance will depend on our ability to successfully manage business operations to further reduce operating expenditures and volume and capital recovery risks in the Powder River Basin operations.

- Initiatives by states to regulate the rates that we charge for our gathering and processing of natural gas and/or to assess taxes on certain aspects of our gas gathering and processing and interstate pipeline businesses may adversely impact us.

- The impact of changing quality of natural gas received into our gathering and processing facilities may adversely affect our revenues and operations. In particular, the energy content of our gathered Powder River Basin production during 2004 was approximately 940 Btus/cf. Most natural gas quality standards of interstate pipelines require a minimum of 950 Btus/cf. If we are unable to blend customers' gas, additional treatment may be necessary to avoid curtailment of certain volumes.

- Although our business strategy is to pursue fee-based and fixed-rate contracts, some of our gas processing facilities are subject to certain contracts that give us quantities of natural gas liquids and residue gas as payment of our processing services. The income and cash flow from these contracts will be impacted directly by changes in these commodity prices. See Item 7A. "Quantitative and Qualitative Disclosures About Market Risk" below.

- We may need new capital to finance future acquisitions and expansions. If our access to capital is limited, this will impair our ability to execute our growth strategy. As we acquire new businesses and make additional investments in existing businesses, we may need to increase borrowings and issue additional equity in order to maintain an appropriate capital structure. This may be dilutive to our unitholders and impact the market value of our common units. See "Liquidity and Capital Resources - Debt and Credit Facilities and Issuance of Common Units" above.

- Our indentures contain provisions that would require us to offer to repurchase our Senior Notes if Moodys or Standard & Poor's rating services rate our notes below investment grade. See "Liquidity and Capital Resources-Debt and Credit Facilities and Issuance of Common Units" above.

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- We may be adversely impacted by the potential enactment of legislation in various states to modify existing provisions for income tax withholding on partners' distributions.

- Under current law, we are treated as a partnership for federal income tax purposes and do not pay any income tax at the entity level. In order to qualify for this treatment, we must derive more than 90% of our annual gross income from specified investments and activities. While we believe that we currently do qualify and intend to meet this income requirement, if we should fail, we would be treated as if we were a newly formed corporation and the income we generate from the date of such failure would be subject to corporate income tax. Because the tax would be imposed on us, the cash available for distribution to our unitholders would be substantially reduced. In addition, the entire amount of cash received by each unitholder would generally be taxed as a corporate dividend when received.

- In addition, because of widespread state budget deficits, several states are evaluating ways to subject partnerships to entity-level taxation through the imposition of state income, use, franchise or other forms of taxation. If any state were to impose a tax upon us as an entity, the cash available to pay distributions would be reduced. The partnership agreement provides that, if a law is enacted or existing law is modified or interpreted in a manner that subjects us to taxation as a corporation or otherwise subjects us to entity-level taxation for federal, state or local income tax purposes, then the minimum quarterly distribution and the target distribution levels will be decreased to reflect that impact on us.

Additional risks and uncertainties not currently known to us, or risks that we currently deem immaterial may impair our business operations. Any of the risk factors described above could significantly and adversely impair our operating results.

NEW ACCOUNTING PRONOUNCEMENTS

The FASB issued SFAS No. 153, "Exchanges of Nonmonetary Assets" in December 2004. See Note 15 - Notes to Consolidated Financial Statements for a discussion of this new accounting pronouncement.

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

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 to utilize financial instruments in the management of interest rate risks and our natural gas and natural gas liquids marketing activities to achieve a more predictable cash flow by reducing our exposure to interest rate and price fluctuations. We do not use these instruments for trading purposes.

INTEREST RATE RISK

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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 swaps as a means to manage interest expense by converting a portion of fixed rate debt to variable rate debt to take advantage of declining interest rates. At December 31, 2004, we had $341.0 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 swaps. As of December 31, 2004, approximately 74% of our debt portfolio was in fixed rate debt. See Notes 8 and 9 - Notes to Consolidated Financial Statements.

If average interest rates change by one percent compared to rates in effect as of December 31, 2004, consolidated annual interest expense would change by approximately $3.4 million. This amount has been determined by considering the impact of the hypothetical interest rates on our variable rate borrowings outstanding as of December 31, 2004.

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 $0.3 million. 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 42% of our commodity price risk in 2005.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.

The information required hereunder is included in this report as set forth in the "Index to Financial Statements" on page F-1.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.

None.

ITEM 9A. CONTROLS AND PROCEDURES.

CONCLUSION REGARDING THE EFFECTIVENESS OF DISCLOSURE CONTROLS AND

PROCEDURES

The Partnership's principal executive officer and principal financial officer have evaluated the effectiveness of the Partnership's "disclosure controls and procedures," (as such term is defined in Exchange Act Rule 13a-15(e) or 15d-15(e)) as of the end of the period covered by this report. Based upon their evaluation, the principal executive officer and principal financial officer concluded that the Partnership's disclosure controls and procedures are effective.

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MANAGEMENT'S ANNUAL REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING

The Partnership's principal executive officer and principal financial officer are responsible for establishing and maintaining adequate internal control over financial reporting for the Partnership. The Partnership's internal control system was designed to provide reasonable assurance to the Partnership's management and members of the Partnership's Policy Committee and Audit Committee regarding the fair presentation of published financial statements. All internal control systems, no matter how well designed, have inherent limitations. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.

The Partnership's management assessed the effectiveness of the Partnership's internal control over financial reporting as of December 31, 2004. In making this assessment, it used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission ("COSO") in Internal Control-Integrated Framework. Based on the assessment, the Partnership's management believes that, as of December 31, 2004, the Partnership's internal control over financial reporting is effective based on those criteria.

The Partnership's independent registered public accounting firm has issued an attestation report on management's assessment of the Partnership's internal control over financial reporting. This report appears in the Report of Independent Registered Public Accounting Firm below.

/s/ WILLIAM R. CORDES
----------------------------------------
William R. Cordes
Chief Executive Officer


/s/ JERRY L. PETERS
----------------------------------------
Jerry L. Peters
Chief Financial and Accounting Officer

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Report of Independent Registered Public Accounting Firm

Northern Border Partners, L.P.:

We have audited management's assessment, included in the accompanying Management's Report on Internal Control over Financial Reporting, that Northern Border Partners, L.P. maintained effective internal control over financial reporting as of December 31, 2004, based on criteria established in Internal Control--Integrated Framework, issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). The Company's management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting. Our responsibility is to express an opinion on management's assessment and an opinion on the effectiveness of the Company's internal control over financial reporting based on our audit.

We conducted our audit in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, evaluating management's assessment, testing and evaluating the design and operating effectiveness of internal control, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

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In our opinion, management's assessment that Northern Border Partners, L.P. maintained effective internal control over financial reporting as of December 31, 2004, is fairly stated, in all material respects, based on COSO. Also, in our opinion, Northern Border Partners, L.P. maintained, in all material respects, effective internal control over financial reporting as of December 31, 2004, based on COSO.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheets of Northern Border Partners, L.P. and subsidiaries as of December 31, 2004 and 2003, and the related consolidated statements of income, comprehensive income, cash flows, and changes in partners' equity, for each of the years in the three-year period ended December 31, 2004, and our report dated March 2, 2005, expressed an unqualified opinion on those consolidated financial statements.

/s/ KPMG LLP

Omaha, Nebraska
March 2, 2005

CHANGES IN INTERNAL CONTROL OVER FINANCIAL REPORTING.

There were no changes in our internal control over financial reporting that occurred during our last fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. However, in the quarter ending December 31, 2004, the payroll system used for the employees of Northern Plains and NBP Services, was transitioned to ONEOK's payroll system.

The Partnership relied on certain systems owned or services provided by Enron and CrossCountry that support our financial accounting and reporting. Since the sale of Northern Plains and NBP Services on November 17, 2004, the Partnership has begun the transition of these systems to systems owned by us or provided by ONEOK.

The Partnership's transition from the Enron and CrossCountry systems and services should be completed in May 2005. This activity has and will cause changes to the Partnership's internal control over financial reporting.

ITEM 9B. OTHER INFORMATION

The following information is being provided in lieu of filing an Item 5.02 Form 8-K.

On March 8, 2005, Gil J. Van Lunsen was appointed by the Partnership Policy Committee as a member of the Audit Committee, effective upon Mr. Whitty's retirement. Mr. Van Lunsen replaces Mr. Whitty who is retiring from the Audit Committee effective March 15, 2005. See Item 10. "Partnership Management" for biographical and other information regarding Mr. Van Lunsen and our Audit Committee.

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PART III

ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT.

We are managed under the direction of the Partnership Policy Committee consisting of three members, each of which has been appointed by one of our general partners. The members appointed by Northern Plains, Pan Border and Northwest Border have 50%, 32.5% and 17.5%, respectively, of the voting power.

We also have an audit committee comprised of individuals who are neither officers nor employees of any general partner nor any affiliate of a general partner, to serve as a committee of the Partnership (the "Audit Committee"). The Audit Committee members are not members of, and do not vote on matters, submitted to the Partnership Policy Committee. The Partnership Policy Committee has delegated to the Audit Committee oversight responsibility with respect to the integrity of our financial statements, the performance of our internal audit function, the independent auditor's qualification and independence and compliance with legal and regulatory requirements. The Audit Committee directly appoints, retains, evaluates and may terminate our independent auditors. The Audit Committee reviews the annual financial statements and resolves, if necessary, any significant disputes between management and the independent auditor that arise in connection with the preparation of the financial statements. The Audit Committee also has the authority to review, at the request of a general partner, specific matters as to which a general partner believes there may be a conflict of interest in order to determine if the resolution of such conflict proposed by the Partnership Policy Committee is fair and reasonable to us. The Audit Committee has all other responsibilities required by the New York Listing Standards and SEC rules.

Because we are a limited partnership, the listing standards of the New York Stock Exchange do not require us to have a majority of independent directors or a nominating/corporate governance or compensation committee. None of our Policy Committee Members are independent.

As is commonly the case with publicly-traded partnerships, we do not directly employ any of the persons responsible for managing or operating the Partnership or for providing it with services relating to its day-to-day business affairs. We have entered into an Administrative Services Agreement with NBP Services, a wholly-owned subsidiary of ONEOK, pursuant to which NBP Services provides tax, accounting, legal, cash management, investor relations, operating and other services for the Partnership. NBP Services has approximately 130 employees. It also uses employees of its affiliates who have duties and responsibilities other than those relating to the Administrative Services Agreement. Also, Northern Plains, one of our general partners and a wholly-owned subsidiary of ONEOK, provides operating services to our interstate pipelines pursuant to operating agreements. Northern Plains employs approximately 310 individuals located at our headquarters in Omaha, Nebraska, and at various locations near the pipelines and also utilizes employees and information technology systems of its affiliates to provide its services. In consideration for their services under the Administrative Services Agreement and the operating agreements, NBP Services and Northern Plains are reimbursed for their direct and indirect costs and expenses, including an allocated portion of employee time and overhead costs. See Item 13. "Certain Relationships and Related Transactions."

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Set forth below is certain information concerning the members of the Partnership Policy Committee, our representatives on the Northern Border Management Committee and the persons designated by the Partnership Policy Committee as our executive officers and as Audit Committee members. All members of the Partnership Policy Committee and our representatives on the Northern Border Management Committee serve at the discretion of the general partner that appointed them. The persons designated as executive officers serve in that capacity at the discretion of the Partnership Policy Committee. The members of the Partnership Policy Committee receive no management fee or other remuneration for serving on this committee. The Audit Committee members are elected, and may be removed, by the Partnership Policy Committee. Daniel P. Whitty, who has been a member of the audit committee since 1993, has tendered his resignation to be effective March 15, 2005. On March 8, 2005, the Partnership Policy Committee appointed Gil J. Van Lunsen to be a member of the Audit Committee effective March 15, 2005. The Chairman of the Audit Committee receives an annual fee of $50,000 and other Audit Committee members receive an annual fee of $40,000 and each is paid $1,500 for each meeting attended.

As noted above, the members of our Partnership Policy Committee and Audit Committee are not elected by unitholders. Accordingly, we do not have a procedure by which security holders may recommend nominees to our Partnership Policy Committee or Audit Committee.

Effective with the purchase and sale of Northern Plains and Pan Border on November 17, 2004, Stanley C. Horton resigned as a member of the Partnership Policy Committee and as a member of the Management Committee of Northern Border Pipeline Company. Effective November 17, 2004, David L. Kyle was appointed by Northern Plains as its member and the Chairman of the Partnership Policy Committee. Mr. Kyle has also been appointed by Pan Border as its member to the Management Committee of Northern Border Pipeline Company. There are no family relationships between any of our executive officers or members of the Partnership Policy Committee and the Audit Committee.

              NAME                AGE                  POSITIONS
              ----                ---                  ---------
Executive Officers:
      William R. Cordes            56   Chief Executive Officer
      Jerry L. Peters              47   Chief Financial and Accounting Officer

Members of Partnership Policy
   Committee and Partnership's
   representatives on Northern
   Border Management Committee:

      David L. Kyle                52   Chairman
      William R. Cordes            56   Member
      Paul E. Miller               46   Member

Members of Audit Committee:
      Gerald B. Smith              54   Chairman
      Daniel P. Whitty             73   Member
      Gary N. Petersen             53   Member
      Gil J. Van Lunsen            62   Nominee

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David L. Kyle was named Chairman of the Policy Committee in November 2004. Mr. Kyle is Chairman and Chief Executive Officer of Northern Plains, Pan Border and NBP Services. Besides Chairman of the Policy Committee of Northern Border Partners, Mr. Kyle is the Chairman of the Board, President, and Chief Executive Officer of ONEOK, Inc. He was employed by Oklahoma Natural Gas Company in 1974 as an engineer trainee. He served in a number of positions prior to being elected Vice President of Gas Supply September 1, 1986, and Executive Vice President May 17, 1990 of Oklahoma Natural Gas Company. He was elected President of Oklahoma Natural Gas Company on September 1, 1994. He was elected President of ONEOK, Inc. effective September 1, 1997, and was elected Chairman of the Board and appointed the Chief Executive Officer of ONEOK, Inc. August 28, 2000. Mr. Kyle is a member of the boards of directors of Bank of Oklahoma Financial Corporation and Blue Cross and Blue Shield of Oklahoma.

William R. Cordes was named Chief Executive Officer of the Partnership and appointed to the Partnership Policy Committee in October 2000. He served as Chairman of the Partnership Policy Committee from October 2000 until November 17, 2004. Mr. Cordes is the President of Northern Plains, Pan Border and NBP Services, ONEOK subsidiaries, having been appointed to that position on October 1, 2000 for Northern Plains and Pan Border and November 17, 2004 for NBP Services. Mr. Cordes was named Chairman of the Northern Border Management Committee October 1, 2000. In 1970, he started his career with Northern Natural Gas Company, an Enron subsidiary until February 2002, where he worked in several management positions. From June of 1993 until September of 2000, he was President of Northern Natural Gas Company and from May of 1996 until September of 2000, he was also President of Transwestern Pipeline, a subsidiary of Enron.

Paul E. Miller was designated by TransCanada as its member on the Partnership Policy Committee in September 2003. Mr. Miller is also a representative on the Northern Border Management Committee. Additionally, Mr. Miller serves as Director Corporate Development of TransCanada, a position he has held since February 2003. From July 1998 to January 2003, Mr. Miller was Director Finance of TransCanada. Prior to July 1998, Mr. Miller was Manager, Finance of TransCanada.

Jerry L. Peters was named Chief Financial and Accounting Officer in July 1994. Mr. Peters has held several management positions with Northern Plains since 1985 and was elected Vice President of Finance in July 1994, and Treasurer in October 1998. Mr. Peters was also elected Vice President of Finance for NBP Services in November 2004. Mr. Peters was also Vice President, Finance of the following former affiliates of Northern Plains: Florida Gas Transmission Company from February 2001 to May 2002; Transportation Trading Services Company from September 2001 to July 2002; Citrus Corp. from October 2001 to July 2002; and Transwestern Pipeline Company from November 2001 to May 2002. Prior to joining Northern Plains in 1985, Mr. Peters was employed as a Certified Public Accountant by KPMG LLP.

Gerald B. Smith was appointed to the Audit Committee in April 1994. He is Chairman and Chief Executive Officer and co-founder of Smith, Graham & Company Investment Advisors, a global investment management firm, which was founded in 1990. He is a member of the Board of Trustees of Charles Schwab Family of Fund; and a director and member of the audit committee of Cooper Industries. He is a former director of the Fund Management Board of Robeco Group, Rorento N.V. (Netherlands).

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Daniel P. Whitty was appointed to the Audit Committee in December 1993. Mr. Whitty is an independent financial consultant. He has served as a member of the Board of Directors of Methodist Retirement Communities Inc., and a Trustee of the Methodist Retirement Trust. Mr. Whitty was a partner at Arthur Andersen LLP ("Andersen") until his retirement on January 31, 1988. At Andersen, he had firm wide responsibility for the natural gas transmission industry for many years. Until his resignation in December 2001, Mr. Whitty served as a director of EOTT Energy Corp., a subsidiary of Enron and the general partner of EOTT Energy Partners, L.P. EOTT Energy Corp. filed for bankruptcy protection on October 21, 2002.

Gary N. Petersen was appointed to the Audit Committee on March 19, 2002. Since 1998, he has provided consulting services related to strategic and financial planning. Additionally, he is currently the President of Endres Processing LLC. From 1977 to 1998, Mr. Petersen was employed by Reliant Energy-Minnegasco. He served as Reliant Energy-Minnegasco's President and Chief Operating Officer from 1991 to 1998. Prior to his employment at Minnegasco, he was a senior auditor with Andersen. He currently serves on the boards of the YMCA of Metropolitan Minneapolis and the Dunwoody Institute.

Gil J. Van Lunsen was appointed to the Audit Committee on March 8, 2005. Prior to his retirement in June 2000, Mr. Van Lunsen was a Managing Partner of KPMG LLP and led the firm's Tulsa, Oklahoma office. He began his career with KPMG in 1968. He is currently a director and audit committee chairman of Array Biopharma in Boulder, Colorado and Sirenza Microdevices in Broomfield, Colorado.

At the meeting of the Partnership Policy Committee on March 3, 2005, the following persons were deemed to be officers of the Partnership for purposes of
Section 16 of the Securities Exchange Act of 1934. Some of these individuals are officers at certain subsidiaries of the Partnership:

        NAME          AGE                POSITIONS
        ----          ---                ---------
Christopher R Skoog    41   Executive Vice President

Paul F. Miller         38   Vice President and General
                            Manager for Northern Border
                            Pipeline

Michel E. Nelson       57   Vice President, Operations,
                            Interstate Pipelines

Raymond D. Neppl       60   Vice President, Regulatory Affairs
                            and Market Services, Interstate
                            Pipelines

Pierce H. Norton       45   President, Bear Paw Energy

Janet K. Place         55   Vice President, General Counsel
                            and Secretary

Fred G. Rimington      54   Vice President, Administration and
                            President of Black Mesa Pipeline

Gaye Lynn Schaffart    45   Vice President and General
                            Manager, Interstates

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Christopher R Skoog was appointed executive vice president of Northern Plains and NBP Services effective February 1, 2005. Mr. Skoog is responsible for all commercial, operational and regulatory functions of the Partnership's natural gas businesses and will coordinate the Partnership's business development initiatives. From 1999 to January 31, 2005, Mr. Skoog served as President of ONEOK Energy Services Company, II. From 1995 to 1999, he was Vice President, ONEOK Gas Marketing Company.

Paul F. Miller is Vice President and General Manager for Northern Border Pipeline of Northern Plains, having been elected in January 2005. From March 2002 until January 2005, Mr. Miller was Vice President of Marketing for Northern Plains. Mr. Miller was previously Account Executive, Marketing from December 1998 until August 2000, when he was promoted to Director, Marketing. Mr. Miller joined Northern Plains in 1990.

Michel E. Nelson is Vice President, Operations for Northern Plains, having been elected in November 2004. Mr. Nelson was previously Vice President of Operations and Support Services for CrossCountry Energy, LLC, an Enron subsidiary, from 2002 to November 2004. From 1997 to 2002, Mr. Nelson held various positions for Enron Transportation Services with responsibility for pipeline operations. Mr. Nelson started his pipeline operations career with Northern Natural Gas Company in 1968. CrossCountry Energy, Enron Transportation Services and Northern Natural Gas Company were formerly affiliated with Northern Plains.

Raymond D. Neppl is Vice President, Regulatory Affairs and Market Services, a position he has held since July 1994. Mr. Neppl was previously Vice President of Regulatory Affairs from 1991 to 1994. Mr. Neppl joined Northern Natural Gas Company, formerly affiliated with Northern Plains, in 1975 and transferred to Northern Plains in 1980.

Pierce H. Norton is President of Bear Paw Energy, a subsidiary of the Partnership, having been appointed in February 2003. Mr. Norton is Vice President and General Manager for midstream businesses for NBP Services, having been appointed in 2003. Mr. Norton, from 2001 to 2003 served as Vice President, Business Development for Bear Paw. Prior to the Partnership's purchase of Bear Paw, Mr. Norton was Vice President--Business Development for Bear Paw Energy and its predecessor from 1999 to 2001 where he was responsible for managing contracts and asset acquisitions.

Janet K. Place is Vice President, General Counsel and Secretary of Northern Plains, having been elected in August 1994 as Vice President and November 2004 as Secretary. She was also elected Vice President, General Counsel and Secretary of NBP Services in November 2004. In 1993, Ms. Place was named General Counsel. Ms. Place joined Northern Plains in 1980 as an Attorney.

Gaye Lynn Schaffart is Vice President and General Manager, Interstates of Northern Plains, having been elected February 2005. Ms. Schaffart was previously Director, Business Development and Planning from 1993 to 2004 when she was promoted to Vice President, Business Development and Strategic Planning in March 2004. Ms. Schaffart joined Northern Plains in 1982.

Fred G. Rimington is Vice President, Administration of Northern Plains and NBP Services, having been elected in February 2005. He is also the President of Black Mesa Pipeline, Inc., having been appointed in January

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2000. Mr. Rimington was Director, Business Development from 1994 to 1999 for Northern Plains. Mr. Rimington joined Northern Plains in 1980.

AUDIT COMMITTEE MATTERS

INDEPENDENCE AND FINANCIAL EXPERT

The Partnership has a separately-designated standing Audit Committee in accordance with Section 3(a)(58)(A) of the Exchange Act. The members of our Audit Committee are Mr. Gerald B. Smith, Daniel P. Whitty and Gary N. Petersen. Additionally, Mr. Gil J. Van Lunsen was appointed to the Audit Committee on March 8, 2005 and replaces Mr. Whitty who is retiring on March 15, 2005. The Partnership's guidelines for determining independence are included in the Partnership's Governance Guidelines, which, along with the Audit Committee charter, is available on the "Governance" section of the Partnership's website at www.northernborderpartners.com. Copies of the Governance Guidelines as well as the Audit Committee charter are available in print to any security holder who requests them by sending a written request to Investor Relations Department, Northern Border Partners, L.P., P.O. Box 542500, Omaha, NE 68154-8500. Our Governance Guidelines contain independence standards for our Audit Committee members. The Governance Guidelines provide that the members of the Audit Committee shall at all times qualify as independent members under the independence standards of the New York Stock Exchange, including Section 10A(m)(3) of the Securities Exchange Act of 1934, the rules and regulations of the Securities and Exchange Commission and other applicable laws. At least annually the Partnership Policy Committee reviews the relationships that each Audit Committee member has with the Partnership to affirmatively determine the independence of each member. The Policy Committee has affirmatively determined that Messrs. Petersen, Smith, Whitty, and Mr. Van Lunsen meet the standards for independence set forth in the Governance Guidelines and are independent from management.

Annually, the Partnership Policy Committee determines the financial expertise of the members of the audit committee. On March 3, 2005, the Policy Committee determined that Messrs. Petersen, Smith and Whitty were "audit committee financial experts" and each is independent, as noted above.

SEPARATE SESSIONS OF NON-MANAGEMENT COMMITTEE MEMBERS

The Partnership Policy Committee has documented its governance practices in the Governance Guidelines, a copy of which is available on the "Governance" section of the Partnership's website at www.northernborderpartners.com. The Chairman of the Audit Committee, Mr. Gerald Smith, presides at these sessions of non-management committee members, which include the members of the Audit Committee and Messrs. Kyle and Miller of the Partnership Policy Committee. The first meeting occurred at the November 2, 2004 meeting. In the future, meetings of the non-management committee members are scheduled quarterly or as requested by any non-management committee member.

Interested parties desiring to communicate with the presiding member, the non-management members of the Partnership Policy Committee as a group or the Audit Committee members as a group regarding the Partnership may directly contact such member(s) by utilizing the Partnership Ethics and Compliance Hotline which is posted on the "Governance-Contact Information" section of our website at www.northernborderpartners.com.

SERVICE ON OTHER AUDIT COMMITTEES

Mr. Smith, the Chairman of our Audit Committee, and Mr. Van Lunsen, our newly appointed Audit Committee member, also serve on the audit committees of two other public companies. The Partnership Policy Committee has determined

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that Mr. Smith and Mr. Van Lunsen's service on these other audit committees does not impair their ability to effectively serve on the Partnership's Audit Committee.

SECTION 16(a) BENEFICIAL OWNERSHIP REPORTING COMPLIANCE

Section 16(a) of the Securities Exchange Act of 1934 requires executive officers, members of the Partnership Policy Committee and persons who own more than ten percent of a registered class of the equity securities issued by us to file reports of ownership and changes in ownership with the SEC and the New York Stock Exchange and to furnish the Partnership with copies of all Section 16(a) forms they file. Based solely on our review of the copies of such reports received by us, or written representations from certain reporting persons that no Form 5's were required for those persons, we believe that during 2004 our reporting persons complied with all applicable filing requirements in a timely manner.

CODE OF ETHICS AND CODE OF CONDUCT

We have adopted an Accounting and Financial Reporting Code of Ethics applicable to the Partnership's chief executive officer and chief financial and accounting officer. A copy of the Accounting and Financial Reporting Code of Ethics is posted on the "Governance" section of our website, www.northernborderpartners.com, and we intend to post on our website any amendments to, or waivers from, any provision of our Accounting and Financial Reporting Code of Ethics that applies to our chief executive officer and chief financial and accounting officer within four business days following such amendment or waiver.

We have also adopted a Code of Conduct applicable to the members of the Partnership Policy Committee and Audit Committee, our officers and the deemed executive officers and the employees of Northern Plains and NBP Services. The Code of Conduct is intended to meet the requirements of a "code of business conduct and ethics" under Section 303A.10 of the New York Stock Exchange Listed Company Manual. A copy of the Code of Conduct is posted on the "Governance" section of our website at www.northernborderpartners.com and is available in print to any security holder who requests it by writing to Investor Relations Department, Northern Border Partners, L.P., P.O. Box 542500, Omaha, NE 68154-8500. We intend to promptly post on our website any amendments to, or waivers from (including any implicit waivers), any provision of our Code of Conduct in accordance with the rules of the New York Stock Exchange ("NYSE").

CERTIFICATION

Certifications

As required by New York Stock Exchange ("NYSE") listing standards, William R. Cordes, our Chief Executive Officer, certified on November 15, 2004 that he was not aware of any violation by the Partnership of NYSE corporate governance listing standards. The certifications required by Section 302 of the Sarbanes-Oxley Act are attached as exhibits 31.1 and 31.2 to this Annual Report on Form 10-K.

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ITEM 11. EXECUTIVE COMPENSATION.

We are managed by a three member policy committee, with one member appointed by each general partner. The Partnership Policy Committee has designated two executive officers who serve as officers of the Partnership at the discretion of the Partnership Policy Committee. In addition, certain officers of the general partners and certain officers of subsidiaries of the partnership were deemed to be executive officers of the Partnership by the Partnership Policy Committee.

The following table sets forth a summary of compensation paid for the last three years of the chief executive officer of the Partnership and the other four most highly compensated executive officers of the Partnership during 2004, which we collectively refer to as the "Named Officers." For the years 2002, 2003 and through November 17, 2004, compensation plans were administered by Enron. Beginning November 18, 2004, compensation plans are administered by ONEOK.

SUMMARY COMPENSATION TABLE

                                                                               Long-Term Compensation
                                              Annual Compensation              ----------------------     All Other
                                  ------------------------------------------         Restricted         Compensation
    Name & Principal                                          Other Annual          Stock Awards        ------------
        Position           Year   Salary $   Bonus $ (1)    Compensation (2)         ($) (3) (4)           ($) (5)
    ----------------       ----   --------   ------------   ----------------        ------------           -------
William R. Cordes          2004   $325,000     $175,000            --                 $     --             $ 4,908
Chief Executive Officer    2003   $324,583     $200,000            --                 $ 99,972             $ 3,000
                           2002   $319,333     $240,000            --                 $100,051             $ 1,031

Jerry L. Peters            2004   $171,380     $110,000            --                       --             $ 5,658
Chief Financial and        2003   $163,324     $107,500            --                       --             $76,386
Accounting Officer         2002   $159,285     $110,000            --                       --             $23,950

Janet K. Place             2004   $182,552     $115,000            --                       --             $ 8,675
Vice President & General   2003   $177,592     $110,000            --                       --             $ 6,233
Counsel and Secretary      2002   $171,500     $110,000            --                       --             $ 7,266
NPNG

Pierce H. Norton           2004   $183,834     $105,000            --                       --             $ 2,520
Vice President & General   2003   $178,842     $ 80,000            --                       --             $ 1,295
Manager - NBP Services     2002   $166,688     $ 57,250            --                       --             $ 1,580
Corp

Paul F. Miller             2004   $153,298     $118,000            --                       --             $ 5,335
Vice President & General   2003   $148,958     $111,000            --                       --             $90,325
Manager for Northern       2002   $139,850     $ 92,000            --                       --             $ 4,721
Border Pipeline

(1) For bonus amounts for 2004, there was an early payout of an amount equal to 10/12ths in October 2004 and the remaining 2/12s was paid in March 2005.

(2) No Named Officer received perquisites or other personal benefits, securities or property in an amount in excess of the lesser of either $50,000 or 10% of the total of salary and bonus reported for such officer in the two preceding columns.

(3) The aggregate total of shares in unreleased Enron restricted stock holdings and their values as of December 31, 2003, for each of the Named Officers is: Mr. Cordes, 4,295 shares valued at $0, Mr. Peters, 1,701 shares valued at $0 and Ms. Place, 1,832 at $0. Dividend equivalents for all restricted stock awards accrue from date of grant and are paid upon vesting. Any dividends on Enron Corp. stock accrued and unreleased as of the date of Enron Corp.'s filing for bankruptcy protection will only be released in accordance with applicable bankruptcy law.

(4) Mr. Cordes' employment agreement, as executed in September 2001, provided for a grant of 882 Northern Border Phantom Units. On June 1, 2002 and 2003, grants of 697 and 669 Northern Border Phantom Units valued at $143.5456 and $149.4346 per unit,

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respectively, were made in accordance with his employment agreement. The phantom units vest on the fifth anniversary of the date of each grant.

(5) The amounts shown include the matching contributions to employees' Enron Corp. Savings Plan and to the Thrift Plan for employees of ONEOK, and imputed income on life insurance benefits. For Mr. Cordes and Mr. Peters, the amount shown for 2004 was for matching contributions. For Ms. Place, the amount shown for 2004 for matching contributions was $6,050 and for imputed income was $2,625. For Mr. Norton, the amount shown for 2004 for matching contributions was $2,520. For Mr. Miller, the amount shown for matching contributions was $5,080 for 2004 and the amount for imputed income was $255. Mr. Peters' employment agreement, as executed in April 2002, provided for a "stay" bonus in which $23,950 of the amount was paid six months following the implementation of the agreement. The remaining amount of $71,853 was paid in March 2003 upon completion of the term of the agreement. Mr. Miller's employment agreement, as executed in October 2002, provided for a "stay" bonus in which 25% was to be paid six months following the implementation of the agreement and the remainder upon completion of the term of the agreement. The entire bonus of $85,470 was distributed in 2003.

For 1999, 2000 and 2001, employees of Northern Plains were able to elect to receive Northern Border phantom units, Enron Corp. phantom stock, and/or Enron Corp. stock options in lieu of all or a portion of an annual bonus payment. Mr. Cordes, Mr. Peters, Ms. Place and Mr. Miller elected to receive Northern Border phantom units under the Northern Border Phantom Unit Plan in lieu of a portion of the cash bonus payment. As a result of this deferral, Mr. Cordes received 1,914 units in 2001; Mr. Peters received 1,532 units in 1999, 1,450 units in 2000 and 842 units in 2001; Ms. Place received 901 units in 1999 and 240 units in 2001; and Mr. Miller received 137 units in 1999, 123 units in 2000 and 230 units in 2001. In each case, units will be released based upon the holding period selected by the participant. For the release in January 2004, Mr. Peters received 4,727 common units. For the release in January 2003, Ms. Place received 1,091 common units and for the release in 2004, she elected a redemption payment in cash of $83,232.28. For the release in January 2002, Mr. Miller received 333 common units; for the release in 2003, he received 329 common units and for the release in 2004, he elected a redemption payment in cash of $25,283.42.

On January 20, 2005, the Board of Directors of ONEOK granted restricted stock incentive units and performance share units to the named executive officers as follows: Mr. Cordes, 6,000 restricted stock incentive units and 10,500 performance share units; Mr. Peters, 3,000 restricted stock incentive units and 4,500 performance share units; Ms. Place 2,000 restricted stock incentive units and 3,500 performance share units; Mr. Norton 2,500 restricted stock incentive units and 4,000 performance share units; and Mr. Miller 2,500 restricted stock incentive units and 4,000 performance share units. The restricted stock incentive units vest three years from the date of grant at which time the grantee is entitled to receive two-thirds of the grant in shares of ONEOK common stock and one-third of the grant in cash. The performance share units granted vest three years from the date of grant at which time the holder is entitled to receive a percentage (0% to 200%) of the performance shares granted based on ONEOK's total shareholder return over the period January 20, 2005, to January 20, 2008, compared to the total shareholder return of a peer group of 20 other companies, payable two-thirds of the grant in shares of ONEOK common stock and one-third of the grant in cash.

STOCK OPTION GRANTS IN 2004

Due to the bankruptcy filing by Enron on December 2, 2001, there were no grants of stock options pursuant to Enron's stock plans to the Named

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Officers reflected in the Summary Compensation Table. No stock appreciation rights were granted during 2004.

AGGREGATED OPTION/SAR EXERCISES IN 2004 AND 2004 YEAR-END OPTION/SAR VALUES

The following table sets forth information with respect to the Named Officers concerning the exercise of Enron SARs and options during the last fiscal year and unexercised Enron options and SARs held as of December 31, 2005:

                                                  Number of Securities
                                                 Underlying Unexercised         Value of Unexercised
                                                    Options/SARs at          In-the-Money Options/SARs
                       Shares                      December 31, 2004           December 31, 2004 (1)
                     Acquired on     Value    ---------------------------   ---------------------------
       Name         Exercise (#)   Realized   Exercisable   Unexercisable   Exercisable   Unexercisable
       ----         ------------   --------   -----------   -------------   -----------   -------------
William R. Cordes        --           $--       182,270          650            $--            $--
Jerry L. Peters          --           $--        62,850          305            $--            $--
Janet K. Place           --           $--        37,383          332            $--            $--
Pierce H. Norton         --           $--            --          525            $--            $--
Paul F. Miller           --           $--        20,684          218            $--            $--

(1) Due to Enron's bankruptcy filing there is no dollar value assignable to Enron Corp. stock options.

TERMINATION AGREEMENT

Effective January 5, 2005, ONEOK, Inc. entered into termination agreements with Messrs. Cordes, Peters, Norton and Miller and Ms. Place.

Each termination agreement has an initial term from January 5, 2005 until January 1, 2007 and is automatically extended in one-year increments after the expiration of the initial term unless ONEOK provides notice to the officer or the officer provides notice to ONEOK at least 90 days before January 1 preceding the initial or any subsequent termination date of the agreement that the party providing notice does not wish to extend the term. If a "change in control" of ONEOK occurs, the term of each termination agreement will not expire for at least three years after the change in control.

Under the termination agreements, severance payments and benefits are payable if the officer's employment is terminated by ONEOK without "just cause" or by the officer for "good reason" at any time during the three years after a change in control. In general, severance payments and benefits include a lump sum payment in an amount equal to (1) two times (three times, in the case of William Cordes) the officer's annual compensation and (2) a prorated portion of the officer's targeted short-term incentive compensation. The officer would also be entitled to accelerated vesting of retirement and other benefits under the Supplemental Executive Retirement Plan (discussed below) and continuation of welfare benefits for 24 months (36 months in case of Mr. Cordes). Severance payments will be reduced if the net after-tax benefit to such officer exceeds the net after-tax benefit if such reduction were not made. Gross up payments will be made to such officers only if the severance payments, as reduced, are subsequently deemed to constitute excess parachute payments.

For purposes of these agreements, a "change in control" generally means any of the following events:

- an acquisition of voting securities of ONEOK by any person that results in the person having beneficial ownership of 20% or more of

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the combined voting power of ONEOK's outstanding voting securities, other than an acquisition directly from ONEOK;

- the current members of ONEOK's Board of Directors, and any new director approved by a vote of at least two-thirds of ONEOK's Board of Directors, cease for any reason to constitute at least a majority of ONEOK's Board of Directors, other than in connection with an actual or threatened proxy contest (collectively, the "Incumbent Board");

- a merger, consolidation or reorganization with ONEOK or in which ONEOK issues securities, unless (a) ONEOK's shareholders immediately before the transaction do not, as a result of the transaction, own, directly or indirectly, at least 50% of the combined voting power of the voting securities of the company resulting from the transaction, (b) members of ONEOK's Incumbent Board after the execution of the transaction agreement do not constitute at least a majority of the members of the Board of the company resulting from the transaction, or (c) no person other than persons who, immediately before the transaction owned 30% or more of ONEOK's outstanding voting securities, has beneficial ownership of 30% or more of the outstanding voting securities of the company resulting from the transaction; or

- ONEOK's complete liquidation or dissolution or the sale or other disposition of all or substantially all of our assets.

RETIREMENT PLANS-ENRON

Enron maintains the Enron Corp. Cash Balance Plan (the "Cash Balance Plan"), which is a noncontributory defined benefit pension plan to provide retirement income for employees of Enron and its subsidiaries. Through December 31, 1994, participants in the Cash Balance Plan with five years or more of service were entitled to retirement benefits in the form of an annuity based on a formula that uses a percentage of final average pay and years of service. In 1995, Enron's Board of Directors adopted an amendment to and restatement of the Cash Balance Plan changing the plan's name from the Enron Corp. Retirement Plan to the Enron Corp. Cash Balance Plan. In connection with a change to the retirement benefit formula, all employees became fully vested in retirement benefits earned through December 31, 1994. The formula in place prior to January 1, 1995 was suspended and replaced with a benefit accrual in the form of a cash balance of 5% of eligible annual base pay beginning January 1, 1996. Effective January 1, 2003 Enron suspended future 5% benefit accruals under the Cash Balance Plan. Each employee's accrued benefit will continue to be credited with interest based on ten-year Treasury Bond yields.

Enron maintained a noncontributory employee stock ownership plan ("ESOP"), which was merged into the Enron Corp. Savings Plan effective August 30, 2002 and covered all eligible employees. Allocations to individual employees' retirement accounts within the ESOP offset a portion of benefits earned under the Cash Balance Plan prior to December 31, 1994. December 31, 1993 was the final date on which ESOP allocations were made to employees' retirement accounts.

The following table sets forth the estimated annual benefits payable under the Cash Balance Plan at normal retirement at age 65, assuming only interest credits based on ten-year Treasury Bond yields and no future 5%

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benefit accruals after January 1, 2003, with to the Named Officers under the provisions of the foregoing retirement plans.

                        ESTIMATED
              CURRENT    CREDITED      CURRENT        ESTIMATED
             CREDITED    YEARS OF   COMPENSATION   ANNUAL BENEFIT
             YEARS OF    SERVICE       COVERED      PAYABLE UPON
              SERVICE   AT AGE 65     BY PLANS       RETIREMENT
             --------   ---------   ------------   --------------
Mr. Cordes     34.4        34.4          $0            $73,979
Mr. Peters     19.1        19.1          $0            $22,933
Ms. Place      24.1        24.1          $0            $30,096
Mr. Norton      3.9         3.9          $0            $ 3,132
Mr. Miller     14.7        14.7          $0            $13,028

NOTE: The estimated annual benefits payable are based on the straight life annuity form without adjustment for any offset applicable to a participant's retirement subaccount in Enron's ESOP.

PENSION PLAN-ONEOK

ONEOK's retirement plan is a tax-qualified, defined-benefit pension plan under both the Internal Revenue Code of 1986, as amended, and the Employee Retirement Income Security Act of 1974, as amended. The following table sets forth the estimated annual retirement benefits payable to a non-bargaining unit plan participant based upon the final average pay formulas under ONEOK's retirement plan for employees in the compensation and years-of-service classifications specified. The estimates assume that benefits are received in the form of a single life annuity.

PENSION PLAN TABLE

                                 YEARS OF SERVICE
               ----------------------------------------------------
REMUNERATION   15 YEARS   20 YEARS   25 YEARS   30 YEARS   35 YEARS
------------   --------   --------   --------   --------   --------
125,000        $ 33,091   $ 44,122   $ 55,152   $ 66,182   $ 77,213
150,000        $ 40,404   $ 53,872   $ 67,340   $ 80,807   $ 94,275
175,000        $ 47,716   $ 63,622   $ 79,527   $ 95,432   $111,338
200,000        $ 55,029   $ 73,372   $ 91,715   $110,057   $128,400
225,000        $ 62,341   $ 83,122   $103,902   $124,682   $145,463
250,000        $ 69,654   $ 92,872   $116,090   $139,307   $162,525
300,000        $ 84,279   $112,372   $140,465   $168,557   $196,650
400,000        $113,529   $151,372   $189,215   $227,057   $264,900
450,000        $128,154   $170,872   $213,590   $256,307   $299,025
500,000        $142,779   $190,372   $237,965   $285,557   $333,150

Benefits under the ONEOK retirement plan become vested and non-forfeitable after completion of five years of continuous employment. A vested participant receives the monthly retirement benefit at normal retirement age under the retirement plan, unless an early retirement benefit is elected under the plan, in which case the retirement benefit is actuarially reduced for early commencement. Benefits are calculated at retirement date based on a participant's credited service, limited to a maximum of 35 years, and final average earnings. Credited years of service under this plan for the named executive officers as of December 31, 2004 is 1/12 years.

For purposes of the table, the annual social security covered compensation benefit $46,284 was used in the excess benefit calculation.

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Benefits payable under ONEOK's retirement plan are not offset by social security benefits.

Under the Internal Revenue Code, the annual compensation of each employee to be taken into account under ONEOK's retirement plan for 2004 cannot exceed $205,000.

Amounts shown in the table are estimates only and are subject to adjustment based on rules and regulations applicable to the method of distribution and survivor benefit options selected by the retiree.

The compensation covered by the retirement plan benefit formula for non-bargaining unit employees is the base salary and bonus paid to an employee within the employee's final average earnings. Final average earnings means the employee's highest earnings during any 60 consecutive months during the last 120 months of employment. For any named executive officer who retires with vested benefits under the plan, the compensation shown as "Salary" and "Bonus" in the Summary Compensation Table could be considered covered compensation in determining benefits, except that the plan benefit formula takes into account only a fixed percentage of final average earnings which is uniformly applied to all employees. The amount of covered compensation that may be considered in calculating retirement benefits is also subject to limitations in the Internal Revenue Code of 1986, as amended, applicable to the plan.

SUPPLEMENTAL EXECUTIVE RETIREMENT

ONEOK maintains a Supplemental Executive Retirement Plan ("SERP" for certain of its elected or appointed officers, and certain other employees in a select group of management and highly compensated employees. Participants are selected by ONEOK's Chief Executive Officer, or, in the case of ONEOK's Chief Executive Officer, by the Board of Directors. Effective January 5, 2005, Messrs. Cordes, Peters, Miller and Norton and Ms. Place were named participants.

Benefits payable under the SERP are based upon a specified percentage (reduced for early retirement) of the highest 36 consecutive months' compensation of the employee's last 60 months of service. The SERP will, in any case, pay a benefit at least equal to the benefit which would be payable to the participant under ONEOK's retirement plan if limitations imposed by the Internal Revenue Code were not applicable, less the benefit payable under ONEOK's retirement plan with such limitations. Benefits under the SERP are paid concurrently with the payment of benefits under ONEOK's retirement plan or as ONEOK's administrative committee may determine. SERP benefits are offset by benefits payable under our retirement plan, but are not offset by social security benefits

ONEOK'S EMPLOYEE NON-QUALIFIED DEFERRED COMPENSATION PLAN

The Named Officers are also eligible to participate in ONEOK's Non-Qualified Deferred Compensation Plan. ONEOK's Non-Qualified Deferred Compensation Plan provides select employees, as approved by the Board of Directors, with the option to defer portions of their compensation and provides non-qualified deferred compensation benefits which are not otherwise available due to limitations on employer and employee contributions to qualified defined contribution plans under the federal tax laws. Under the plan, participants have the option to defer their salary and/or bonus

70

compensation to a short-term deferral account, which pays out a minimum of five years from commencement, or to a long-term deferral account, which pays out at retirement or termination of the employment of the participant. Participants are immediately 100 percent vested. Short-term deferral accounts are credited with a deemed investment return based on the five year Treasury Bond fund. Long-term deferral accounts are credited with a deemed investment return based on various investment options, which do not include an option to invest in ONEOK common stock. At the distribution date, cash is distributed to participants based on the fair market value of the deemed investment of the participant at that date.

SEVERANCE PLANS

Northern Plains' and NBP Services' Severance Pay Plans provide for the payment of benefits to employees who are terminated for failing to meet performance objectives or standards or who are terminated due to reorganization or similar business circumstances. The amount of benefits payable for performance related terminations is based on length of service and may not exceed eight weeks' pay. For those terminated as the result of reorganization or similar business circumstances, the benefit is based on length of service and amount of pay up to a maximum payment of 52 weeks of base pay. The employee must sign a Waiver and Release of Claims Agreement in order to receive any severance benefit. As part of the sale and purchase agreement between ONEOK and CCE Holdings, for a period of twelve months, neither Northern Plains nor NBP Services may take any action that would change the Severance Pay Plans that would have an adverse impact on the employees of Northern Plains or NBP Services.

See Item 10. "Directors and Executive Officers of the Registrant" for information on compensation paid to the members of the Partnership Policy Committee and our Audit Committee.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS.

The following table sets forth the beneficial ownership of the voting securities of the Partnership as of March 3, 2005 by our executive officers, members of the Partnership Policy Committee and the Audit Committee who own units and by certain beneficial owners. Other than as set forth below, no person is known by the general partners to own beneficially more than 5% of the voting securities.

                                            Amount and Nature of Beneficial Ownership
                                            -----------------------------------------
                                                           Common Units
                                                       -------------------
                                                        Number     Percent
                                                       of Units   of Class
                                                       --------   --------
William R. Cordes                                         1,000      *
   13710 FNB Parkway
   Omaha, NE 68154-5200

Jerry L. Peters (1/)                                      7,734      *
   13710 FNB Parkway
   Omaha, NE 68154-5200

Pierce H. Norton (2/)                                     6,778      *
   1400 16th Street, Suite 310
   Denver, CO 80202

Janet K. Place (3/)                                       1,691      *
   13710 FNB Parkway
   Omaha, NE 68154-5200

Gary N. Petersen                                          5,854      *
   3520 Wedgewood Ln. N
   Plymouth, MN 55441-2262

ONEOK, Inc. (4/)                                        501,603     1.06
   100 West Fifth Street
   Tulsa, OK74103-4298

All Policy Committee Members, Audit                      24,001      *
Committee Members, nominees and executive
officers as a group (16 persons)


* Less than 1%.

(1/) Includes 1000 units held by immediate family members for which Mr. Peters has shared voting or investment power.

(2/) These units are held in trust for which Mr. Norton has sole voting or investment power.

(3/) Includes 500 units held by immediate family members for which Ms. Place has shared voting or investment power.

(4/) Indirect ownership through its subsidiaries. Northern Plains is the beneficial owner of 501,603 Common Units which includes 1,603 common units to satisfy obligations under the Amended and Restated Northern Border Phantom Unit Plan.

For information on equity compensation plans of the Partnership, see Item
5. "Market for Registrant's Common Equity, Related Stockholder Matters

72

and Issuer Purchases of Equity Securities".

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.

On December 2, 2001, Enron and certain of its subsidiaries filed voluntary petitions for Chapter 11 reorganization under the Bankruptcy Code. During 2004, we had a number of relationships with Enron and its subsidiaries. In November 2004, ONEOK purchased Northern Plains, Pan Border and NBP Services, LLC from CCE Holdings, LLC. CCE Holdings, a joint venture between Southern Union Company and GE Commercial Finance Energy Financial purchased Northern Plains, Pan Border and NBP Services as part of its acquisition of CrossCountry. Through ONEOK's ownership of two of our general partners, ONEOK is able to elect members with a majority of the voting power on the Partnership Policy Committee and Northern Border Pipeline Management Committee. Such other relationships include the following:

- With the sale of Northern Plains and NBP Services from CCE Holdings to ONEOK, CCE Holdings and ONEOK entered into a transition services agreement. This transition services agreement provides for the continued use by Northern Plains and NBP Services of certain services, data applications, systems and infrastructure relied on by Northern Plains and NBP Services to perform under the Operating Agreements and Administrative Services Agreement with us or our subsidiaries, as more fully described below. The term of the transition services agreement is until May 16, 2005; the parties may agree to extend any transition service beyond the term. The cost of the transition services is estimated to be $3.9 million for the full term of the agreement.

- Northern Plains, a subsidiary of ONEOK, provides certain administrative, operating and management services to the Partnership through Operating Agreements with Northern Border Pipeline, Midwestern Gas Transmission and Viking Gas Transmission. NBP Services, a subsidiary of ONEOK, provides the Partnership services in connection with the operation and management of the Partnership and operating services for Crestone Energy Ventures and Bear Paw Energy pursuant to the terms of an Administrative Services Agreement between the Partnership and NBP Services. For the year ended December 31, 2004, the aggregate amount charged by Northern Plains and NBP Services for their services was approximately $45.8 million.

- ONEOK holds contracts for firm transportation on Northern Border Pipeline with expiration dates from December 31, 2004 to March 31, 2009. Revenues from ONEOK for the period from the date of affiliation to December 31, 2004, were $1.1 million. Also, ONEOK has entered into a precedent agreement for capacity on Northern Border Pipeline's Chicago III Expansion Project.

- Commencing on July 1, 2004, Northern Plains, was selected on a fixed fee and cost reimbursement basis to provide certain administrative, operating and management services through an Operating Agreement with Guardian Pipeline, of which we own a one third interest. The annual amount of the fixed fee to be charged by Northern Plains for its services is $3.6 million. Guardian Pipeline has agreed to reimburse up to $800,000 of certain of Northern Plains' costs associated with the transition of the role of operator of Guardian Pipeline from Trunkline Gas Company to Northern Plains and has agreed to compensate Northern Plains for any services provided to Guardian Pipeline prior to July 1, 2004.

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- In conjunction with the selection of Northern Plains as operator of Guardian Pipeline, we agreed to contract with Northern Plains to assume the financial risks and benefits resulting from and arising out of Northern Plains' responsibilities and obligations as operator of Guardian Pipeline.

The Partnership Policy Committee, whose members are designated by our three general partners, establishes the business policies of the Partnership. We have three representatives on the Northern Border Management Committee, each of whom votes a portion of our 70% interest on the Northern Border Management Committee, with the other 30% interest being voted by a representative of TC PipeLines, which is an affiliate of one of our general partners.

Our general partners (subsidiaries of ONEOK and a subsidiary of TransCanada) and their respective affiliates, currently actively engage or may engage in the businesses in which we engage or in which we may engage in the future. As a result, conflicts of interest may arise between our general partners and their affiliates on the one hand, and the Partnership on the other hand. In such case the members of the Partnership Policy Committee will generally have a fiduciary duty to resolve such conflicts in a manner that is in our best interest.

TC PipeLines (a 30% owner of Northern Border Pipeline whose general partner is an affiliate of one of our general partners) and its affiliates are also actively engaged in interstate pipeline transportation of natural gas in the United States separate from their interests in Northern Border Pipeline. As a result, conflicts also may arise between TransCanada and its affiliates or TC PipeLines and its affiliates, on the one hand, and the Northern Border Pipeline on the other hand. If such conflicts arise, the representatives on the Northern Border Pipeline Management Committee will generally have a fiduciary duty to resolve such conflicts in a manner that is in the best interest of Northern Border Pipeline.

Unless otherwise provided for in a partnership agreement, the laws of Delaware and Texas generally require a general partner of a partnership to adhere to fiduciary duty standards under which it owes its partners the highest duties of good faith, fairness and loyalty. Similar rules apply to persons serving on the Partnership Policy Committee or the Northern Border Management Committee. Because of the competing interests identified above, our Partnership Agreement and the partnership agreement for Northern Border Pipeline contain provisions that modify certain of these fiduciary duties. For example:

- Our Partnership Agreement states that our general partners, their affiliates and their officers and directors will not be liable for damages to us, our limited partners or their assignees for errors of judgment or for any acts or omissions if the general partners and such other persons acted in good faith.

- Our Partnership Agreement allows our general partners and our Partnership Policy Committee to take into account the interests of parties in addition to our interest in resolving conflicts of interest.

- Our Partnership Agreement provides that the general partners will not be in breach of their obligations under

74

our Partnership Agreement or their duties to us or our unitholders if the resolution of a conflict is fair and reasonable to us. The latitude given in our Partnership Agreement in connection with resolving conflicts of interest may significantly limit the ability of a unitholder to challenge what might otherwise be a breach of fiduciary duty.

- Our Partnership Agreement provides that a purchaser of Common Units is deemed to have consented to certain conflicts of interest and actions of the general partners and their affiliates that might otherwise be prohibited and to have agreed that such conflicts of interest and actions do not constitute a breach by the general partners of any duty stated or implied by law or equity.

- Our Audit Committee will, at the request of a general partner or a member of the Partnership Policy Committee, review conflicts of interest that may arise between a general partner and its affiliates (or the member of the Partnership Policy Committee designated by it), on the one hand, and the unitholders or us, on the other. Any resolution of a conflict approved by the Audit Committee is conclusively deemed fair and reasonable to us.

- The partnership agreement of Northern Border Pipeline that relieves us and TC PipeLines, their affiliates and their transferees from any duty to offer business opportunities to Northern Border Pipeline, subject to specified exceptions.

We are required to indemnify the members of the Partnership Policy Committee and general partners, their affiliates and their respective officers, directors, employees, agents and trustees to the fullest extent permitted by law against liabilities, costs and expenses incurred by any such person who acted in good faith and in a manner reasonably believed to be in, or (in the case of a person other than one of the general partners) not opposed to, our best interests and with respect to any criminal proceedings, had no reasonable cause to believe the conduct was unlawful.

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES

The following sets forth fees billed for the audit and other services provided by KPMG LLP, the Partnership's principal accountant, for the fiscal years ended December 31, 2004 and December 31, 2003:

                         Year Ended December 31,
                         -----------------------
                             2004       2003
                           --------   --------
Audit fees (1)             $895,250   $431,045
Audit-related fees               --         --
Tax Fees (2)                     --        855
All Other Fees                   --         --
                           --------   --------
Total                      $895,250   $431,900

(1) Includes fees for the audit of annual financial statements and internal control over financial reporting, reviews of the related quarterly financial statements and related consents and comfort letters for documents filed with the Securities and Exchange Commission.

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(2) Includes fees related to professional services for tax compliance and consultation.

The Audit Committee has considered whether the provision of the non-audit services described above is compatible with maintaining the independence of KPMG LLP and determined that the provision of such services was compatible with maintaining such independence.

AUDIT COMMITTEE POLICIES AND PROCEDURES FOR PRE-APPROVAL OF AUDIT AND NON-AUDIT SERVICES

Consistent with SEC policies regarding auditor independence, the audit committee is responsible for pre-approving all audit and non-audit services performed by the independent auditor. In addition to its approval of the audit engagement, the audit committee takes action at least annually to authorize the performance by the independent auditor of several specific types of services within the categories of audit services, audit-related services, tax services and all other services. Audit services include assurance and related services that are reasonably related to the performance of the audit or review of the financial statements, attestations pursuant to Section 404 of the Sarbanes-Oxley Act, quarterly reviews comfort letters, consents, review of registration statements, accounting research from completed transactions and tax assistance related to the audit services. Audit-related services include due diligence related to potential business acquisitions/dispositions, accounting research and other audit or attest services. Authorized tax services include compliance-related services such as services involving tax filings, as well as consulting services such as tax planning, transaction analysis and opinions. All other services include special investigations to assist the Audit Committee or its counsel and assistance with regulatory activities. Services are subject to pre-approval of the specific engagement if they are outside the specific types of services included in the periodic approvals covering service categories or if they are in excess of specified fee limitations. The Audit Committee has delegated pre-approval authority to the Audit Committee Chairman. The tax fees for 2003 were pre-approved.

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PART IV

ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES.

(a)(1) and (2) Financial Statements and Financial Statement Schedules

See "Index to Financial Statements" set forth on page F-1.

(A)(3) EXHIBITS

 3.1   Northern Border Partners, L.P. Certificate of Limited Partnership,
       Certificate of Amendment dated February 16, 2001, and Certificate of
       Amendment dated May 20, 2003.

 3.2   Amended and Restated Agreement of Limited Partnership of Northern
       Border Partners, L.P. dated October 1, 1993.

 3.3   Northern Border Intermediate Limited Partnership Certificate of
       Limited Partnership, Certificate of Amendment dated February 16, 2001,
       and Certificate of Amendment dated May 20, 2003.

*3.4   Form of Amended and Restated Agreement of Limited Partnership for
       Northern Border Intermediate Limited Partnership (incorporated by
       reference to Exhibit 10.1 to Form S-1 Registration Statement,
       Registration No. 33-66158 ("Form S-1")).

*4.1   Indenture, dated as of June 2, 2000, between Northern Border Partners,
       L.P. and Northern Border Intermediate Limited Partnership and Bank One
       Trust Company, N.A. (incorporated by reference to Exhibit 4.1 to the
       Partnership's Quarterly Report on Form 10-Q for the quarterly period
       ended June 30, 2000 (File No. 1-12202) ("June 2000 10-Q")).

*4.2   First Supplemental Indenture, dated as of September 14, 2000, between
       Northern Border Partners, L.P., Northern Border Intermediate Limited
       Partnership and Bank One Trust Company, N.A. (incorporated by
       reference to Exhibit 4.2 to the Partnership's Form S-4 Registration
       Statement, Registration No. 333-46212 ("NBP Form S-4")).

*4.3   Indenture, dated as of March 21, 2001, between Northern Border
       Partners, L.P. and Northern Border Intermediate Limited Partnership
       and Bank One Trust Company, N.A., Trustee (incorporated by reference
       to Exhibit 4.3 to the Partnership's Form 10-K for the year ended
       December 31, 2001 (File No. 1-12202)).

*4.4   Indenture, dated as of August 17, 1999, between Northern Border
       Pipeline Company and Bank One Trust Company, NA, successor to The
       First National Bank of Chicago, as trustee. (incorporated by reference
       to Exhibit No. 4.1 to Northern Border Pipeline Company's Form S-4
       Registration Statement filed on October 7, 1999, Registration No.
       333-88577 ("NB Form S-4")).

*4.5   Indenture, dated as of September 17, 2001, between Northern Border
       Pipeline Company and Bank Trust Company, N.A. (incorporated by
       reference to Exhibit 4.2 to Northern Border Pipeline Company's
       Registration Statement on Form S-4 filed on November 13, 2001,
       Registration No. 333-73282 ("2001 NB Form S-4")).

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  *4.6   Indenture, dated as of April 29, 2002, between Northern Border
         Pipeline Company and Bank One Trust Company, N.A. (incorporated by
         reference to Exhibit 4.1 to Northern Border Pipeline Company's Form
         10-Q for the quarter ended March 31, 2002 (File No. 333-88577)).

 *10.1   Northern Border Pipeline Company General Partnership Agreement between
         Northern Plains Natural Gas Company, Northwest Border Pipeline
         Company, Pan Border Gas Company, TransCanada Border Pipeline Ltd. and
         TransCan Northern Ltd., effective March 9, 1978, as amended
         (incorporated by reference to Exhibit 10.2 to Form S-1).

 *10.2   Form of Seventh Supplement Amending Northern Border Pipeline Company
         General Partnership Agreement (incorporated by reference to Exhibit
         10.15 to Form S-1).

 *10.3   Eighth Supplement Amending Northern Border Pipeline Company General
         Partnership Agreement (incorporated by reference to Exhibit 10.15 to
         NB Form S-4).

 *10.4   Ninth Supplement Amending Northern Border Pipeline Company General
         Partnership Agreement (incorporated by reference to Exhibit 10.37 to
         2001 NB Form S-4).

 *10.5   Tenth Supplement Amending Northern Border Pipeline Company General
         Partnership Agreement dated March 2, 2005 (incorporated by reference
         to Exhibit 3.5 to Northern Border Pipeline's Form 10-K filed on March
         11, 2005 (File No. 333-88577)).

 *10.6   Operating Agreement between Northern Border Pipeline Company and
         Northern Plains Natural Gas Company, dated February 28, 1980
         (incorporated by reference to Exhibit 10.3 to Form S-1).

 *10.7   Administrative Services Agreement between NBP Services Corporation,
         Northern Border Partners, L.P. and Northern Border Intermediate
         Limited Partnership (incorporated by reference to Exhibit 10.4 to Form
         S-1).

 *10.8   Revolving Credit Agreement, dated as of November 24, 2003, among
         Northern Border Partners, L.P., SunTrust Bank, Harris Nesbitt Corp.,
         Wachovia Bank, National Association, Citigroup, N.A., SunTrust Capital
         Markets, Inc., and the Lenders (as named therein) (incorporated by
         reference to Exhibit 10.7 to the Partnership's Form 10-K for the year
         ended December 31, 2003 (File No. 1-12202)).

 *10.9   First Amendment to the Revolving Credit Agreement dated as of April 9,
         2004 between Northern Border Partners, L.P., SUNTRUST BANK and the
         lenders named therein (incorporated by reference to Exhibit 10.1 to
         the Partnership's Form 10-Q for the quarter ended March 31, 2004 (File
         No. 1-12202)).

*10.10   Second Amendment entered into as of October 25, 2004 to Northern
         Border Partners' Revolving Credit Agreement dated as of November 24,
         2003 (incorporated by reference to Exhibit 99.1 to the Partnership's
         Form 8-K filed on November 5, 2004 (File No. 1-12202)).

*10.11   Revolving Credit Agreement, dated as of May 16, 2002, among Northern
         Border Pipeline Company, Bank One, NA, Citibank, N.A., Bank of
         Montreal, SunTrust Bank, Wachovia Bank, National Association, Banc One
         Capital Markets, Inc, and Lenders (as defined therein) (incorporated
         by reference to Exhibit 10.1 to the Partnership's Current Report on
         Form 8-K dated June 26, 2002 (File No. 1-12202)).

*10.12   First Amendment to the Revolving Credit Agreement dated as of April 9,
         2004 between Northern Border Pipeline Company, Bank One, NA and the
         lenders named therein. (incorporated by reference to Exhibit No. 10.1
         to Northern Border Pipeline

78

          Company's Quarterly Report on Form 10-Q for the quarterly period ended
          March 31, 2004 (File No. 333-88577)).

 *10.13   Agreement between Northern Plains and Northern Border Intermediate
          Limited Partnership regarding the costs, expenses and expenditures
          arising under the operating agreement between Northern Plains and
          Guardian Pipeline, LLC (incorporated by reference to Exhibit 10.3 to
          the Partnership's Form 10-Q for the quarter ended March 31, 2004 (File
          No. 1-12202)).

+*10.14   Form of Termination Agreement with ONEOK dated as of January 5, 2005
          (incorporated by reference to Exhibit 99.1 to the Partnership's Form
          8-K filed on January 11, 2005 (File No. 1-12202)).

+*10.15   ONEOK, Inc. 2005 Supplemental Executive Retirement Plan. (incorporated
          by reference to Exhibit 99.1 to the Partnership's Form 8-K filed on
          January 11, 2005(File No. 1-12202)).

+*10.16   ONEOK, Inc. Long-Term Incentive Plan (incorporated by reference from
          Exhibit 10(a) to ONEOK's Form 10-K for the year ended December 31,
          2001 (File No. 1-13643)).

+*10.17   ONEOK, Inc. Form of Restricted Stock Incentive Award (incorporated by
          reference from Exhibit 10.4 to ONEOK's Form 10-Q for the quarterly
          period ended September 30, 2004 (File No. 1-13643)).

+*10.18   ONEOK, Inc. Form of Performance Shares Award (incorporated by
          reference from Exhibit 10.5 to ONEOK's Form 10-Q for the quarterly
          period ended September 30, 2004 (File No. 1-13643)).

+*10.19   ONEOK, Inc. Employee Non-Qualified Deferred Compensation Plan, as
          amended, dated February 2001 (incorporated by reference to Exhibit
          10(g) to ONEOK's Form 10-K for the year ended December 31, 2001(File
          No. 1-13643)).

+*10.20   ONEOK, Inc. Annual Officer Incentive Plan (incorporated by reference
          to Exhibit 10(f) to ONEOK's Form 10-K for the year ended December 31,
          2001 (File No. 1-13643)).

 *10.21   Operating Agreement between Midwestern Gas Transmission Company and
          Northern Plains Natural Gas Company dated as of April 1, 2001
          (incorporated by reference to Exhibit 10.38 to the Partnership's Form
          10-K for the year ended December 31, 2001 (File No. 1-12202)).

 *10.22   Operating Agreement between Viking Gas Transmission Company and
          Northern Plains Natural Gas Company dated as of January 17, 2003
          (incorporated by reference to Exhibit 10.18 to the Partnership's Form
          10-K for the year ended December 31, 2002 (File No. 1-12202)).

 *10.23   Northern Border Pipeline Company Agreement among Northern Plains
          Natural Gas Company, Pan Border Gas Company, Northwest Border Pipeline
          Company, TransCanada Border PipeLine Ltd., TransCan Northern Ltd.,
          Northern Border Intermediate Limited Partnership, Northern Border
          Partners, L.P., and the Management Committee of Northern Border
          Pipeline, dated as of March 17, 1999 (incorporated by reference to
          Exhibit 10.21 to the Partnership's Form 10-K/A for the year ended
          December 31, 1998 (File No. 1-12202) ("1998 10-K")).

79

 10.24   Northern Border Transition Services Agreement dated November 17, 2004,
         by and between ONEOK, Inc. and CCE Holdings, LLC.

  12.1   Statement re computation of ratios.

    21   List of subsidiaries.

  23.1   Consent of KPMG LLP.

  31.1   Rule 13a-14(a)/15d-14(a) certification of principal executive officer.

  31.2   Rule 13a-14(a)/15d-14(a) Certification of principal financial officer.

  32.1   Section 1350 certification of principal executive officer.

  32.2   Section 1350 certification of principal financial officer.

+*99.1   Northern Border Phantom Unit Plan (incorporated by reference to
         Exhibit 99.1 to Amendment No. 1 to the Partnership's Form S-8,
         Registration No. 333-66949 and Exhibit 99.1 to Northern Border
         Partners, L.P.'s Registration No. 333-72696).

* Indicates exhibits incorporated by reference as indicated; all other exhibits are filed herewith.

+ Management contract, compensatory plan or arrangement.

The total amount of securities of the Partnership authorized under any instrument with respect to long-term debt not filed as an exhibit does not exceed 10% of the total assets of the Partnership and its subsidiaries on a consolidated basis. The Partnership agrees, upon request of the Securities and Exchange Commission, to furnish copies of any or all of such instruments to the Securities and Exchange Commission.

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SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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 on this 11th day of March, 2005.

NORTHERN BORDER PARTNERS, L.P.
(A Delaware Limited Partnership)

By: WILLIAM R. CORDES

William R. Cordes Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons in the capacities and on the dates indicated.

           Signature                          Title                    Date
           ---------                          -----                    ----


/s/ WILLIAM R. CORDES             Chief Executive Officer and     March 11, 2005
-------------------------------   Member of Partnership Policy
    William R. Cordes             Committee
                                  (Principal Executive Officer)


/s/ DAVID L. KYLE                 Chairman of the Partnership
-------------------------------   Policy Committee                March 11, 2005
    David L. Kyle


/s/ PAUL E. MILLER                Member of Partnership Policy    March 11, 2005
-------------------------------   Committee
    Paul E. Miller


/s/ JERRY L. PETERS               Chief Financial and             March 11, 2005
-------------------------------   Accounting Officer
    Jerry L. Peters               (Principal Financial
                                  and Accounting Officer)

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NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
INDEX TO FINANCIAL STATEMENTS

                                                                      PAGE NO.
                                                                     -----------
Consolidated Financial Statements

   Report of Independent Registered Public Accounting Firm           F-2
   Consolidated Balance Sheet - December 31, 2004 and 2003           F-3
   Consolidated Statement of Income - Years Ended                    F-4
      December 31, 2004, 2003 and 2002
   Consolidated Statement of Comprehensive Income - Years Ended      F-5
      December 31, 2004, 2003 and 2002
   Consolidated Statement of Cash Flows - Years Ended                F-6
      December 31, 2004, 2003 and 2002
   Consolidated Statement of Changes in Partners' Equity -           F-7
      Years Ended December 31, 2004, 2003 and 2002
   Notes to Consolidated Financial Statements                        F-8 through
                                                                     F-35

Financial Statements Schedule

   Report of Independent Registered Public Accounting Firm
      on Schedule                                                    S-1
   Schedule II - Valuation and Qualifying Accounts                   S-2

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

Northern Border Partners, L.P.:

We have audited the accompanying consolidated balance sheets of Northern Border Partners, L.P. and subsidiaries as of December 31, 2004 and 2003, and the related consolidated statements of income, comprehensive income, cash flows, and changes in partners' equity for each of the years in the three-year period ended December 31, 2004. These consolidated financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Northern Border Partners, L.P. and subsidiaries as of December 31, 2004 and 2003, and the results of their operations and their cash flows for each of the years in the three-year period ended December 31, 2004, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the effectiveness of Northern Border Partners, L.P.'s internal control over financial reporting as of December 31, 2004, based on criteria established in Internal Control--Integrated Framework, issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated March 2, 2005 expressed an unqualified opinion on management's assessment of, and the effective operation of, internal control over financial reporting.

/s/ KPMG LLP

Omaha, Nebraska
March 2, 2005

F-2

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(IN THOUSANDS)

                                                               DECEMBER 31,
                                                         -----------------------
                                                            2004         2003
                                                         ----------   ----------
ASSETS

CURRENT ASSETS
   Cash and cash equivalents                             $   33,980   $   35,895
   Accounts receivable (net of allowance for doubtful
      accounts of $9,175 in 2004)                            68,930       61,503
   Related party receivables (net of allowance
      for doubtful accounts of $11,988 in 2003)               1,077           --
   Materials and supplies, at cost                            5,654        7,826
   Prepaid expenses                                           4,642        6,726
   Derivative financial instruments                           1,996           --
   Other                                                      1,008        2,245
                                                         ----------   ----------
      Total current assets                                  117,287      114,195
                                                         ----------   ----------

PROPERTY, PLANT AND EQUIPMENT
   Interstate Natural Gas Pipelines                       2,626,579    2,612,241
   Gas Gathering and Processing                             265,484      253,903
   Coal Slurry                                               47,402       45,911
                                                         ----------   ----------

Total property, plant and equipment                       2,939,465    2,912,055
   Less: Accumulated provision for depreciation
      and amortization                                    1,002,041      919,951
                                                         ----------   ----------
      Property, plant and equipment, net                  1,937,424    1,992,104
                                                         ----------   ----------

INVESTMENTS AND OTHER ASSETS
   Investment in unconsolidated affiliates                  273,202      268,166
   Goodwill                                                 152,782      152,782
   Derivative financial instruments                           2,555       19,553
   Other                                                     27,306       23,783
                                                         ----------   ----------
      Total investments and other assets                    455,845      464,284
                                                         ----------   ----------
      Total assets                                       $2,510,556   $2,570,583
                                                         ==========   ==========

LIABILITIES AND PARTNERS' EQUITY

CURRENT LIABILITIES
   Current maturities of long-term debt                  $    5,126   $    7,740
   Accounts payable                                          28,802       20,834
   Related party payables                                     6,293       25,698
   Accrued taxes other than income                           32,563       33,708
   Accrued interest                                          16,530       13,206
   Derivative financial instruments                              --        5,736
                                                         ----------   ----------
      Total current liabilities                              89,314      106,922
                                                         ----------   ----------
LONG-TERM DEBT, net of current maturities                 1,325,232    1,408,246
                                                         ----------   ----------
MINORITY INTERESTS IN PARTNERS' EQUITY                      290,142      240,731
                                                         ----------   ----------

RESERVES AND DEFERRED CREDITS
   Deferred income taxes                                      7,186        2,898
   Other                                                      9,348       11,213
                                                         ----------   ----------
      Total reserves and deferred credits                    16,534       14,111
                                                         ----------   ----------

COMMITMENTS AND CONTINGENCIES (NOTE 13)

PARTNERS' EQUITY
   General partners                                          15,603       15,902
   Common units (46,397,214 units issued and
      outstanding at December 31, 2004 and 2003)            764,550      779,195
   Accumulated other comprehensive income                     9,181        5,476
                                                         ----------   ----------
      Total partners' equity                                789,334      800,573
                                                         ----------   ----------
      Total liabilities and partners' equity             $2,510,556   $2,570,583
                                                         ==========   ==========

The accompanying notes are an integral part of these consolidated financial statements.

F-3

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF INCOME

(IN THOUSANDS, EXCEPT PER UNIT AMOUNTS)

                                                     YEAR ENDED DECEMBER 31,
                                                 ------------------------------
                                                   2004       2003       2002
                                                 --------   --------   --------
OPERATING REVENUES                               $590,383   $550,948   $487,204
                                                 --------   --------   --------
OPERATING EXPENSES
   Product purchases                              103,213     80,774     50,648
   Operations and maintenance                     111,142    127,623    106,521
   Depreciation and amortization, including
      impairment charges of $219,080 in 2003       86,431    299,791     74,672
   Taxes other than income                         36,212     35,443     32,194
                                                 --------   --------   --------
      Operating expenses                          336,998    543,631    264,035
                                                 --------   --------   --------
OPERATING INCOME                                  253,385      7,317    223,169
                                                 --------   --------   --------
INTEREST EXPENSE
   Interest expense                                77,346     79,159     83,227
   Interest expense capitalized                      (403)      (179)      (329)
                                                 --------   --------   --------
      Interest expense, net                        76,943     78,980     82,898
                                                 --------   --------   --------
OTHER INCOME (EXPENSE)
   Allowance for equity funds used during
      construction                                    117        331        248
   Equity earnings of unconsolidated
      affiliates                                   18,015     18,815     12,983
   Other income                                     3,654      5,992      2,740
   Other expense                                   (2,138)    (1,459)      (801)
                                                 --------   --------   --------
        Other income, net                          19,648     23,679     15,170
                                                 --------   --------   --------
MINORITY INTERESTS IN NET INCOME                   50,033     44,460     42,816
                                                 --------   --------   --------
INCOME (LOSS) FROM CONTINUING OPERATIONS
   BEFORE INCOME TAXES                            146,057    (92,444)   112,625

INCOME TAXES                                        5,136      4,705      1,643
                                                 --------   --------   --------
INCOME (LOSS) FROM CONTINUING OPERATIONS          140,921    (97,149)   110,982

DISCONTINUED OPERATIONS, NET OF TAX                 3,799      9,338      2,694

CUMULATIVE EFFECT OF CHANGE IN
   ACCOUNTING PRINCIPLE, NET OF TAX                    --       (643)        --
                                                 --------   --------   --------
NET INCOME (LOSS) TO PARTNERS                    $144,720   $(88,454)  $113,676
                                                 ========   ========   ========

CALCULATION OF LIMITED PARTNERS' INTEREST
   IN NET INCOME (LOSS):
Net income (loss) to partners                    $144,720   $(88,454)  $113,676
Less: general partners' interest in
   net income (loss)                               10,854      5,969      9,602
                                                 --------   --------   --------
Limited partners' interest in
   net income (loss)                             $133,866   $(94,423)  $104,074
                                                 ========   ========   ========

LIMITED PARTNERS' PER UNIT NET INCOME (LOSS):
   Income (loss) from continuing operations      $   2.81   $  (2.27)  $   2.38
   Discontinued operations, net of tax               0.08       0.20       0.06
   Cumulative effect of change in
      accounting principle, net of tax                 --      (0.01)        --
                                                 --------   --------   --------
   Net income (loss)                             $   2.89   $  (2.08)  $   2.44
                                                 ========   ========   ========
NUMBER OF UNITS USED IN COMPUTATION                46,397     45,370     42,709
                                                 ========   ========   ========

The accompanying notes are an integral part of these consolidated financial statements.

F-4

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

(IN THOUSANDS)

                                                     YEAR ENDED DECEMBER 31,
                                                 ------------------------------
                                                   2004       2003       2002
                                                 --------   --------   --------
Net income (loss) to partners                    $144,720   $(88,454)  $113,676
Other comprehensive income:
   Change associated with current period
      hedging transactions                          5,263     (4,383)   (13,490)
   Change associated with current
      period foreign currency translation          (1,558)     2,345        475
                                                 --------   --------   --------
Total comprehensive income (loss)                $148,425   $(90,492)  $100,661
                                                 ========   ========   ========

The accompanying notes are an integral part of these consolidated financial statements.

F-5

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CASH FLOWS

(IN THOUSANDS)

                                                                   YEAR ENDED DECEMBER 31,
                                                              ---------------------------------
                                                                 2004        2003        2002
                                                              ---------   ---------   ---------
CASH FLOWS FROM OPERATING ACTIVITIES:
   Net income (loss) to partners                              $ 144,720   $ (88,454)  $ 113,676
                                                              ---------   ---------   ---------
   Adjustments to reconcile net income (loss) to
   partners to net cash provided by operating activities:
      Depreciation and amortization, including
         impairment charges of $219,080 in 2003                  87,203     301,977      76,239
      Minority interests in net income                           50,033      44,460      42,816
      Non-cash gains from risk management activities               (460)       (209)     (4,509)
      Provision for regulatory refunds                               --         261      10,000
      Regulatory refunds paid                                        --     (10,261)         --
      Cumulative effect of change in accounting principle            --         643          --
      Gain on sale of gathering and processing assets            (6,621)     (4,872)         --
      Equity earnings in unconsolidated affiliates              (18,015)    (18,928)    (14,570)
      Distributions received from unconsolidated affiliates      13,946      16,262      10,820
      Allowance for equity funds used during construction          (117)       (331)       (248)
      Reserves and deferred credits                              (2,747)      4,472         (24)
      Changes in components of working capital                  (19,243)    (18,592)      9,670
      Other                                                      (4,041)     (1,768)        136
                                                              ---------   ---------   ---------
         Total adjustments                                       99,938     313,114     130,330
                                                              ---------   ---------   ---------
      Net cash provided by operating activities                 244,658     224,660     244,006
                                                              ---------   ---------   ---------

CASH FLOWS FROM INVESTING ACTIVITIES:
   Capital expenditures for property, plant
      and equipment, net                                        (43,477)    (30,282)    (50,738)
   Acquisition of businesses                                         --    (123,194)     (1,561)
   Sale of gathering and processing assets                       22,685      40,250          --
   Investments in unconsolidated affiliates and other               (84)     (3,514)     (2,972)
                                                              ---------   ---------   ---------
      Net cash used in investing activities                     (20,876)   (116,740)    (55,271)
                                                              ---------   ---------   ---------

CASH FLOWS FROM FINANCING ACTIVITIES:
   Cash distributions
      General and limited partners                             (159,624)   (155,173)   (146,960)
      Minority Interests                                        (61,690)    (46,194)    (49,238)
   Equity contributions from Minority Interests                  61,500          --          --
   Issuance of partnership interests, net                           (40)    102,203      75,376
   Issuance of long-term debt, net                              259,000     342,000     499,894
   Retirement of long-term debt                                (327,521)   (361,129)   (567,540)
   Proceeds upon termination of derivatives                       7,575      12,250      20,551
   Debt reacquisition costs                                      (4,897)         --          --
   Long-term debt financing costs                                    --        (671)     (2,884)
                                                              ---------   ---------   ---------
      Net cash used in financing activities                    (225,697)   (106,714)   (170,801)
                                                              ---------   ---------   ---------

NET CHANGE IN CASH AND CASH EQUIVALENTS                          (1,915)      1,206      17,934
Cash and cash equivalents-beginning of year                      35,895      34,689      16,755
                                                              ---------   ---------   ---------
Cash and cash equivalents-end of year                         $  33,980   $  35,895   $  34,689
                                                              =========   =========   =========
Changes in components of working capital:
   Accounts receivable                                        $ (12,992)  $  (3,135)  $   4,303
   Materials and supplies, prepaid expenses and other             3,355      (3,833)     (2,573)
   Accounts payable                                             (10,065)     (8,525)      9,370
   Accrued taxes other than income                               (1,145)        437       2,378
   Accrued interest                                               1,604      (3,536)     (3,808)
                                                              ---------   ---------   ---------
   Total                                                      $ (19,243)  $ (18,592)  $   9,670
                                                              =========   =========   =========

The accompanying notes are an integral part of these consolidated financial statements.

F-6

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CHANGES IN PARTNERS' EQUITY

(IN THOUSANDS)

                                                                 ACCUMULATED
                                                                    OTHER         TOTAL
                                          GENERAL    COMMON     COMPREHENSIVE   PARTNERS'
                                         PARTNERS     UNITS        INCOME        EQUITY
                                         --------   ---------   -------------   ---------
Partners' Equity at December 31, 2001    $ 17,889   $ 876,540     $ 20,529      $ 914,958
Net income to partners                      9,602     104,074           --        113,676
Change associated with current
   period hedging transactions                 --          --      (13,490)       (13,490)
Change associated with current
   period foreign currency translation         --          --          475            475
Issuance of partnership interests, net
   (2,186,700 common units)                 1,507      73,869           --         75,376
Distributions paid                        (10,268)   (136,692)          --       (146,960)
                                         --------   ---------      -------      ---------
Partners' Equity at December 31, 2002      18,730     917,791        7,514        944,035
Net income (loss) to partners               5,969     (94,423)          --        (88,454)
Change associated with current
   period hedging transactions                 --          --       (4,383)        (4,383)
Change associated with current
   period foreign currency translation         --          --        2,345          2,345
Issuance of partnership interests, net
   (2,587,500 common units)                 2,044     100,159           --        102,203
Distributions paid                        (10,841)   (144,332)          --       (155,173)
                                         --------   ---------      -------      ---------
Partners' Equity at December 31, 2003      15,902     779,195        5,476        800,573
Net income to partners                     10,854     133,866           --        144,720
Change associated with current
   period hedging transactions                 --          --        5,263          5,263
Change associated with current
   period foreign currency translation         --          --       (1,558)        (1,558)
Issuance of partnership interests, net         (1)        (39)          --            (40)
Distributions paid                        (11,152)   (148,472)          --       (159,624)
                                         --------   ---------     --------      ---------
Partners' Equity at December 31, 2004    $ 15,603   $ 764,550     $  9,181      $ 789,334
                                         ========   =========     ========      =========

The accompanying notes are an integral part of these consolidated financial statements.

F-7

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. ORGANIZATION AND MANAGEMENT

Northern Border Partners, L.P., through a subsidiary limited partnership, Northern Border Intermediate Limited Partnership, both Delaware limited partnerships, collectively referred to herein as the Partnership, owns a 70% general partner interest in Northern Border Pipeline Company (Northern Border Pipeline). The remaining 30% general partner interest in Northern Border Pipeline is owned by TC PipeLines Intermediate Limited Partnership (TC PipeLines). Crestone Energy Ventures, L.L.C. (Crestone Energy Ventures); Bear Paw Energy, L.L.C. (Bear Paw Energy); Border Midstream Services, Ltd. (Border Midstream); Midwestern Gas Transmission Company (Midwestern Gas Transmission); Viking Gas Transmission Company (Viking Gas Transmission) and Black Mesa Pipeline, Inc. (Black Mesa) are wholly-owned subsidiaries of the Partnership. As discussed in Note 3, the Partnership acquired all of the common stock of Viking Gas Transmission on January 17, 2003.

Northern Plains Natural Gas Company, LLC (Northern Plains), a wholly-owned subsidiary of ONEOK, Inc. (ONEOK), Pan Border Gas Company, LLC (Pan Border), a wholly-owned subsidiary of Northern Plains, and Northwest Border Pipeline Company (Northwest Border), a wholly-owned subsidiary of TransCanada PipeLines Limited, which is a subsidiary of TransCanada Corporation, and affiliate of TC PipeLines, serve as the General Partners of the Partnership and collectively own a 2% general partner interest in the Partnership. Northern Plains and Pan Border hold an aggregate 1.65% general partner interest and Northwest Border holds a 0.35% general partner interest. Northern Plains also owns common units representing a 1.1% limited partner interest.

The Partnership is managed under the direction of the Partnership Policy Committee consisting of one person appointed by each General Partner. The members appointed by Northern Plains, Pan Border and Northwest Border have 50%, 32.5% and 17.5%, respectively, of the voting interest on the Partnership Policy Committee.

In November 2004, ONEOK purchased Northern Plains, Pan Border and NBP Services LLC (NBP Services) from CCE Holdings, LLC (CCE Holdings). CCE Holdings, a joint venture between Southern Union Company and GE Commercial Finance Energy Financial purchased Northern Plains, Pan Border and NBP Services as part of its acquisition of CrossCountry Energy, LLC (CrossCountry).

On March 31, 2004, Enron Corp. (Enron) transferred its ownership interest in Northern Plains, Pan Border, and NBP Services to CrossCountry. In addition, CrossCountry and Enron entered into a transition services agreement pursuant to which Enron would provide to CrossCountry, on an interim, transitional basis, various services, including but not limited to
(i) information technology services, (ii) accounting system usage rights and administrative support and (iii) payroll, employee benefits and administrative services. In turn, these services are provided to the Partnership through Northern Plains and NBP Services.

F-8

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. ORGANIZATION AND MANAGEMENT (continued)

As part of the closing, ONEOK and CCE Holdings entered into a transition services agreement referred to as the "Northern Border Transition Services Agreement" covering certain transition services by and among ONEOK, CCE Holdings and Enron for a period of six months. Certain of the services previously provided by Enron are now being provided through ONEOK.

The Partnership has entered into an administrative services agreement with NBP Services, a wholly-owned subsidiary of ONEOK. NBP Services provides certain administrative, operating and management services for the Partnership and its gas gathering and processing and coal slurry businesses and is reimbursed for its direct and indirect costs and expenses. The day-to-day management of Northern Border Pipeline's, Midwestern Gas Transmission's and Viking Gas Transmission's affairs is the responsibility of Northern Plains, as defined by their respective operating agreements with Northern Plains. Northern Border Pipeline, Midwestern Gas Transmission and Viking Gas Transmission are charged for the salaries, benefits and expenses of Northern Plains. Northern Plains and NBP Services also utilize their current and former affiliates for management services including those provided through the Northern Border Transition Services Agreement. For the years ended December 31, 2004, 2003 and 2002, charges from NBP Services, Northern Plains and their current and former affiliates totaled approximately $45.8 million, $57.6 million and $45.3 million, respectively. See Note 18 for a discussion of the Partnership's previous relationships with Enron and developments involving Enron.

Northern Border Pipeline is a Texas general partnership formed in 1978. Northern Border Pipeline owns a 1,249-mile natural gas transmission pipeline system extending from the United States-Canadian border near Port of Morgan, Montana, to a terminus near North Hayden, Indiana.

Northern Border Pipeline is managed by a Management Committee that includes three representatives from the Partnership (one representative appointed by each of the General Partners of the Partnership) and one representative from TC PipeLines. The Partnership's representatives selected by Northern Plains, Pan Border and Northwest Border have 35%, 22.75% and 12.25%, respectively, of the voting interest on the Northern Border Pipeline Management Committee. The representative designated by TC PipeLines votes the remaining 30% interest.

Midwestern Gas Transmission system consists of a 350-mile interstate natural gas pipeline extending from Portland, Tennessee to Joliet, Illinois. Midwestern Gas Transmission's pipeline system connects with multiple pipeline systems, including Northern Border Pipeline.

On January 17, 2003, the Partnership acquired Viking Gas Transmission (see Note 3). The Viking Gas Transmission system is a 578-mile interstate natural gas pipeline extending from the United States-Canadian border near Emerson, Manitoba to Marshfield, Wisconsin. Viking Gas Transmission connects with multiple pipeline systems.

Bear Paw Energy has extensive natural gas gathering, processing and fractionation operations in the Williston Basin in Montana, North Dakota and Saskatchewan as well as gas gathering operations in the Powder River Basin

F-9

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. ORGANIZATION AND MANAGEMENT (continued)

in Wyoming. In the Williston Basin, Bear Paw Energy has over 3,000 miles of gathering pipelines and five processing plants with 93 million cubic feet per day of capacity. Bear Paw Energy has approximately 600 miles of high and low pressure gathering pipelines and approximately 390,000 acres of dedicated reserves in the Powder River Basin.

Border Midstream previously owned the Mazeppa and Gladys gas processing plants, gas gathering systems and an undivided minority interest in the Gregg Lake/Obed Pipeline. In June 2003, the Partnership sold its Gladys and Mazeppa processing plants and related gas gathering facilities. Effective December 1, 2004, the Partnership sold its undivided minority interest in the Gregg Lake/Obed Pipeline (see Note 3).

The Partnership owns a 49% common membership interest and a 100% preferred A share interest in Bighorn Gas Gathering, L.L.C. (Bighorn); a 33% interest in Fort Union Gas Gathering, L.L.C. (Fort Union); a 35% interest in Lost Creek Gathering, L.L.C. (Lost Creek); and a 33% interest in Guardian Pipeline, L.L.C. (Guardian Pipeline). The Partnership acquired its interest in Guardian Pipeline in January 2003 (see Note 3).

Collectively, Bighorn, Fort Union and Lost Creek own over 300 miles of gas gathering facilities in Wyoming. The gathering facilities interconnect to the interstate gas pipeline grid serving gas markets in the Rocky Mountains, the Midwest and California. Guardian Pipeline is a 141-mile interstate natural gas pipeline system that went into service on December 7, 2002. This system transports natural gas from Joliet, Illinois to a point west of Milwaukee, Wisconsin.

Black Mesa owns a 273-mile, 18-inch diameter coal slurry pipeline that originates at a coal mine in Kayenta, Arizona and ends at the 1,500 megawatt Mohave Generating Station located in Laughlin, Nevada.

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(A) Principles of Consolidation and Use of Estimates

The consolidated financial statements include the assets, liabilities and results of operations of the Partnership and its majority-owned subsidiaries. The Partnership operates through a subsidiary limited partnership of which the Partnership is the sole limited partner and the General Partners are the sole general partners. The 30% ownership of Northern Border Pipeline by TC PipeLines is accounted for as a minority interest. All significant intercompany balances and transactions have been eliminated in consolidation.

The preparation of financial statements in conformity with U.S. generally accepted accounting principles (GAAP) requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and 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.

F-10

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

(B) Government Regulation

Northern Border Pipeline, Midwestern Gas Transmission, Viking Gas Transmission and Guardian Pipeline are subject to regulation by the Federal Energy Regulatory Commission (FERC). Northern Border Pipeline's and Viking Gas Transmission's 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 accounting principles generally accepted in the United States of America for nonregulated entities. Northern Border Pipeline and Viking Gas Transmission continually assess whether the recovery of the regulatory assets are probable by such factors as regulatory changes and the impact of competition. Northern Border Pipeline and Viking Gas Transmission believe the recovery of the existing regulatory assets is probable. If future recovery ceases to be probable, Northern Border Pipeline and Viking Gas Transmission would be required to write off the regulatory assets at that time. At December 31, 2004 and 2003, Northern Border Pipeline and Viking Gas Transmission have reflected regulatory assets, which are currently being recovered or are expected to be recovered from their shippers, of approximately $12.3 million and $8.9 million, respectively, on the consolidated balance sheet. Northern Border Pipeline is recovering the regulatory assets from its shippers over varying time periods, which range from five to 44 years. Viking Gas Transmission is recovering the regulatory assets from its shippers over five years.

Although Northern Border Pipeline is a general partnership, Northern Border Pipeline's tariff establishes the method of accounting for and calculating income taxes and requires Northern Border Pipeline to reflect in its financial records the income taxes, which would have been paid or accrued if Northern Border Pipeline were organized during the period as a corporation. As a result, for purposes of determining transportation rates in calculating the return allowed by the FERC, partners' capital and rate base are reduced by the amount equivalent to the net accumulated deferred income taxes. Such amounts were approximately $355 million and $350 million at December 31, 2004 and 2003, respectively, and are primarily related to accelerated depreciation and other plant-related differences.

(C) Cash and Cash Equivalents

Cash equivalents consist of highly liquid investments with original maturities of three months or less. The carrying amount of cash and cash equivalents approximates fair value because of the short maturity of these investments.

(D) Revenue Recognition

Northern Border Pipeline, Midwestern Gas Transmission and Viking Gas Transmission transport gas for shippers under tariffs regulated by the FERC. The tariffs specify the calculation of amounts to be paid by shippers and the general terms and conditions of transportation service

F-11

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

(D) Revenue Recognition (continued)

on the respective pipeline systems. 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 for the natural gas pipelines are recognized based upon contracted capacity and actual volumes transported under transportation service agreements. Northern Border Pipeline, Midwestern Gas Transmission and Viking Gas Transmission do not own the gas that they transport, and therefore do not assume the related natural gas commodity risk.

For the gas gathering and processing businesses, operating revenue is recorded when gas is processed in or transported through company facilities. The gas gathering and processing businesses also receive certain cash payments from customers in advance for gathering services to be provided in the future. These cash payments are deferred and recognized into operating revenues by using a percentage based on the depletion of natural gas reserves associated with the gathering system.

Black Mesa's operating revenue is derived from a pipeline transportation agreement. Black Mesa's revenue is recognized based on a monthly demand payment, actual tons transported and direct reimbursement of certain other expenses.

Accounts receivable from customers are reviewed regularly for collectibility. An allowance for doubtful accounts is recorded in situations where collectibility is not reasonably assured.

(E) Income Taxes

The Partnership is not a taxable entity for federal income tax purposes. As such, the Partnership does not directly pay federal income tax. The Partnership's taxable income or loss, which may vary substantially from the net income or loss reported in the consolidated statement of income, is includable in the federal income tax returns of each partner. The aggregate difference in the basis of the Partnership's net assets for financial and income tax purposes cannot be readily determined as the Partnership does not have access to information about each partner's tax attributes related to the Partnership.

The Partnership's corporate subsidiaries are required to pay federal and state income taxes. Income taxes are accounted for under the asset and liability method. Deferred income tax assets and liabilities are recognized by these entities for the future tax consequences attributable to differences between the financial statement carrying amount of existing assets and liabilities and their respective tax bases and operating loss carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.

F-12

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

(F) Property, Plant and Equipment and Related Depreciation and Amortization

Property, plant and equipment is stated at original cost. During periods of construction, utilities are permitted to capitalize an allowance for funds used during construction, which represents the estimated costs of funds used for construction purposes. Property, plant and equipment on the consolidated balance sheet includes construction work in progress of $13.8 million and $17.5 million at December 31, 2004 and 2003, respectively.

The original cost of utility property retired is charged to accumulated depreciation and amortization, net of salvage and cost of removal. For utility property, no retirement gain or loss is included in income except in the case of retirements or sales of entire operating units. Maintenance and repairs are charged to operations in the period incurred.

For utility property, the provision for depreciation and amortization is an integral part of the interstate pipelines' FERC tariffs. The effective depreciation rate applied to Northern Border Pipeline's, Midwestern Gas Transmission's and Viking Gas Transmission's transmission plant was 2.25%, 1.9% and 2.0%, respectively. Composite rates are applied to all other functional groups of utility property having similar economic characteristics. The effective depreciation rate applied to natural gas gathering and processing assets ranges from 5% to 20%. The effective depreciation rate applied to coal slurry assets ranges from 4% to 20%.

The Partnership evaluates impairment of long-lived assets 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. 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.

(G) Foreign Currency Translation

For the Partnership's Canadian subsidiary, Border Midstream, asset and liability accounts are translated from its functional currency (the Canadian dollar) at year-end rates of exchange and revenue and expenses are translated at average exchange rates prevailing during the year. Translation adjustments are included as a separate component of other comprehensive income and partners' equity. Currency transaction gains and losses, which result when Border Midstream pays Canadian dollars to the Partnership, are recorded in other income (expense) and discontinued operations on the consolidated statement of income. During the years ended December 31, 2004 and 2003, the Partnership recorded currency transaction gains of $2.2 million and $6.0 million, respectively. Currency transaction gains were insignificant in 2002.

F-13

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

(H) Goodwill

The excess of cost over fair value of the net assets acquired in business acquisitions is accounted for as goodwill. The Partnership's accounting for goodwill is in accordance with SFAS No. 142, "Goodwill and Other Intangible Assets." Among other things, SFAS No. 142 requires entities to perform annual impairment tests by applying a fair-value-based analysis on the goodwill in each reporting segment.

(I) Equity Method of Accounting

The Partnership accounts for its investments, which it does not control, by the equity method of accounting. Under this method, an investment is carried at its acquisition cost, plus the equity in undistributed earnings or losses since acquisition.

(J) Risk Management

The Partnership uses financial instruments in the management of its interest rate and commodity price exposure. A control environment has been established which includes policies and procedures for risk assessment and the approval, reporting and monitoring of financial instrument activities. The Partnership does not use these instruments for trading purposes. SFAS No. 133, "Accounting for Derivative Instruments and Hedging Activities," as amended by SFAS No. 137 and SFAS No. 138, requires that every derivative instrument (including certain derivative instruments embedded in other contracts) 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, and requires that a company formally document, designate and assess the effectiveness of transactions that receive hedge accounting. See Note 9 for a discussion of the Partnership's derivative instruments and hedging activities.

(K) Reclassifications

Certain reclassifications have been made to the consolidated financial statements for prior years to conform with the current year presentation.

3. BUSINESS ACQUISITIONS AND DISPOSITIONS

On January 17, 2003, the Partnership acquired all of the common stock of Viking Gas Transmission including a one-third interest in Guardian Pipeline for approximately $162 million, which included the assumption of $40 million of debt.

The Partnership has accounted for the acquisition using the purchase method of accounting and accordingly, operations of Viking Gas Transmission have been included since the date of acquisition. The purchase price has been

F-14

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

3. BUSINESS ACQUISITIONS AND DISPOSITIONS (continued)

allocated based upon the estimated fair value of the assets and liabilities acquired as of the acquisition date. The investment in Guardian Pipeline is reflected in investments in unconsolidated affiliates on the consolidated balance sheet.

The following is a summary of the effects of the acquisition on the Partnership's consolidated financial position as of December 31, 2003 (amounts in thousands):

Current assets                                 $  8,804
Property, plant and equipment                   127,619
Investments in unconsolidated affiliates         27,600
Goodwill and other assets                         5,035
Current liabilities                              (5,559)
Long-term debt, including current maturities    (40,025)
Other liabilities                                  (280)
                                               --------
                                               $123,194
                                               ========

Border Midstream sold its undivided minority interest in the Gregg Lake/Obed Pipeline (Gregg Lake/Obed) for $14.0 million, effective December 1, 2004. In June 2003, the Partnership sold its Gladys and Mazeppa processing plants and related gas gathering facilities located in Alberta, Canada for approximately $40.3 million. Operating revenues, operating expenses and other income and expense for 2003 and 2002 have been reclassified for amounts related to the discontinued operations. Operating revenues for discontinued operations for the years ended December 31, 2004, 2003 and 2002, were $3.0 million, $9.9 million and $8.1 million, respectively. Discontinued operations on the accompanying consolidated statement of income consists of the following:

                                                        December 31,
                                                 -------------------------
(in thousands)                                     2004     2003      2002
-------------                                    -------   ------   ------
Operating income                                 $ 2,248   $3,259   $1,650
Other income (expense)                              (540)   1,747    1,587
Gain on sale of assets                             5,026    4,056       --
Income tax (expense) benefit                      (2,935)     276     (543)
                                                 -------   ------   ------
Income from discontinued operations              $ 3,799   $9,338   $2,694
                                                 =======   ======   ======

4. GOODWILL AND ASSET IMPAIRMENT

At December 31, 2004 and 2003, the Partnership's balance sheet included goodwill of approximately $334 million. Of the total goodwill, approximately $182 million was recorded in the Partnership's investment in unconsolidated affiliates at December 31, 2004 and 2003. The Partnership has selected the fourth quarter to perform its annual impairment testing. If testing indicates an impairment of goodwill exists in a reporting segment, the carrying value of tangible assets in that segment are also tested for impairment under SFAS No. 144.

During 2003, due to lower throughput volumes experienced and anticipated in its wholly owned subsidiaries in its natural gas gathering and processing business segment, the Partnership accelerated its annual impairment test

F-15

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

4. GOODWILL AND ASSET IMPAIRMENT (continued)

under SFAS No. 142 from the fourth quarter to the third quarter for this segment. For the Partnership's remaining reporting segments, the annual impairment testing was performed in the fourth quarter. In future years, unless conditions indicate earlier testing is needed, the annual impairment testing for all business segments will occur in the fourth quarter.

The Partnership engaged the services of an outside independent consultant to assist in the determination of fair value, as defined by SFAS No. 142, for purposes of computing the amount of the goodwill impairment. Upon the determination of the existence of a goodwill impairment, the Partnership further analyzed, under SFAS No. 144, the carrying value of the tangible assets in its wholly owned subsidiaries in its natural gas gathering and processing business segment to determine the impairment attributed to the tangible assets. The Partnership recorded total impairment charges of $219.1 million in the third quarter of 2003. This was comprised of $76.0 million related to the tangible assets in the Powder River Basin and $143.1 million for the goodwill related to the natural gas gathering and processing business segment. Beginning October 1, 2003, the estimated depreciable life of the Partnership's assets in the Powder River Basin was reduced from 30 years to 15 years to reflect the results of the analysis performed.

Changes in the carrying amount of goodwill for the years ended December 31, 2004 and 2003, are summarized as follows:

                               Interstate    Gas Gathering
                               Natural Gas        and         Coal
(In thousands)                  Pipelines     Processing     Slurry     Total
--------------                 -----------   -------------   ------   ---------
Balance at December 31, 2002     $68,872       $ 398,633     $8,378   $ 475,883
Goodwill acquired                  1,527              --                  1,527
Impairment losses                     --        (143,066)        --    (143,066)
                                 -------       ---------     ------   ---------
Balance at December 31, 2003      70,399         255,567      8,378     334,344
Impairment losses                     --              --         --          --
                                 -------       ---------     ------   ---------
Balance at December 31, 2004     $70,399       $ 255,567     $8,378   $ 334,344
                                 =======       =========     ======   =========

5. ASSET RETIREMENT OBLIGATIONS

In 2001, the Financial Accounting Standards Board (FASB) issued SFAS No. 143, "Accounting for Asset Retirement Obligations." SFAS No. 143 requires entities to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred, if the liability can be reasonably estimated. When the liability is initially recorded, the carrying amount of the related asset is increased by the same amount. Over time, the liability is accreted to its future value and the accretion is recorded to expense. The initial adjustment to the asset is depreciated over its useful life. Upon settlement of the liability, an entity either settles the obligation for its recorded amount or incurs a gain or loss. In some instances, the Partnership's subsidiaries are obligated by contractual terms or regulatory requirements to remove facilities or perform other remediation upon retirement. The Partnership has, where possible, developed its estimate of the retirement obligations.

F-16

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

5. ASSET RETIREMENT OBLIGATIONS (continued)

Effective January 1, 2003, the Partnership adopted SFAS No. 143. The implementation of SFAS No. 143 resulted in an increase in net property, plant and equipment of $2.5 million, an increase in reserves and deferred credits of $3.1 million and a reduction to net income of $0.6 million for the net-of-tax cumulative effect of change in accounting principle. The impact of SFAS No. 143 on prior periods' results of operations is immaterial. A reconciliation of the beginning and ending aggregate carrying amount of the Partnership's asset retirement obligations for the years ended December 31, 2004 and 2003, is as follows (in thousands):

Balance at December 31, 2002                 $    --
Cumulative effect of transition adjustment     3,496
Accretion expense                                159
Liabilities transferred with asset sales      (2,016)
                                             -------
Balance at December 31, 2003                   1,639
Accretion expense                                102
                                             -------
Balance at December 31, 2004                 $ 1,741
                                             =======

6. RATES AND REGULATORY ISSUES

The FERC regulates the rates and charges for transportation on the Partnership's interstate natural gas pipelines. Interstate natural gas pipeline companies may not charge rates that have been determined not to be just and reasonable by the FERC. Generally, rates for interstate pipelines are based on the cost of service including recovery of and a return on the pipeline's actual prudent historical cost investment. The rates and terms and conditions for service are found in each pipeline's FERC approved tariff. Under its tariff, an interstate pipeline is allowed to charge for its services on the basis of stated transportation rates. Transportation rates are established periodically in FERC proceedings known as rate cases. The tariff also allows the interstate pipeline to provide services under negotiated and discounted rates. Under the terms of settlement in Northern Border Pipeline's 1999 rate case, neither Northern Border Pipeline nor its existing shippers can seek rate changes to the settlement base rates until November 1, 2005, at which time Northern Border Pipeline must file a new rate case. Midwestern Gas Transmission and Viking Gas Transmission have no timing requirements or restriction in regard to future rate case filings.

In February 2003, Northern Border Pipeline filed to amend its FERC tariff to clarify the definition of company use gas, which is gas supplied by its shippers for its operations. Northern Border Pipeline had included in its retention of company use gas, quantities that were equivalent to the cost of electric power at its electric-driven compressor stations during the period of June 2001 through January 2003. On March 27, 2003, the FERC issued an order rejecting Northern Border Pipeline's proposed tariff sheet revision and requiring refunds with interest within 90 days of the order. Northern Border Pipeline made refunds to its shippers of $10.3 million in May 2003.

7. TRANSPORTATION, GATHERING AND PROCESSING AGREEMENTS

Northern Border Pipeline's, Midwestern Gas Transmission's and Viking Gas Transmission's operating revenues are collected pursuant to their FERC tariffs through transportation service agreements. Northern Border Pipeline's firm service agreements extend for various terms with

F-17

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

7. TRANSPORTATION, GATHERING AND PROCESSING AGREEMENTS

termination dates that range from December 2004 to December 2013. The termination dates for Midwestern Gas Transmission's firm service agreements range from December 2004 to October 2019. The termination dates for Viking Gas Transmission's firm service agreements range from March 2005 to October 2014. Northern Border Pipeline, Midwestern Gas Transmission and Viking Gas Transmission also have interruptible transportation service agreements and other transportation service agreements with numerous shippers.

Under the capacity release provisions of Northern Border Pipeline's, Midwestern Gas Transmission's and Viking Gas Transmission's FERC tariffs, shippers are allowed to release all or part of their capacity either permanently for the full term of the contract or temporarily. A temporary capacity release does not relieve the original contract shipper from its payment obligations if the replacement shipper fails to pay for the capacity temporarily released to it.

For the interstate natural gas pipeline segment, Northern Border Pipeline's revenues represented approximately 86%, 86% and 95% of the segment's revenues in 2004, 2003 and 2002, respectively. At December 31, 2004, Northern Border Pipeline's largest shippers, Nexen Marketing, U.S.A. Inc (Nexen), BP Canada Energy Marketing Corp. (BP Canada), EnCana Marketing U.S.A. Inc. (EnCana) and Cargill Incorporated (Cargill), were obligated for approximately 18%, 14%, 13% and 12% of the summer design capacity, respectively. The Nexen, BP Canada, Encana and Cargill firm service agreements extend for various terms with termination dates from March 2005 to December 2013, December 2004 to February 2012, October 2005 to June 2009 and March 2005 to December 2008, respectively. For the year ending December 31, 2004, shippers providing significant operating revenues were BP Canada and Encana with revenues of $65.6 million and $56.3 million, respectively. For the year ended December 31, 2003, Northern Border Pipeline's significant shippers were BP Canada, EnCana, and Pan-Alberta Gas (U.S) Inc. (Pan Alberta) with operating revenues of $54.7 million, $32.9 million and $45.5 million, respectively. For the year ended December 31, 2002, Northern Border Pipeline's largest shippers were Pan-Alberta and Mirant Americas Energy Marketing, LP with combined operating revenues of $105.5 million.

At December 31, 2004, Northern Border Pipeline had contracted firm capacity held by one shipper affiliated with its general partners. ONEOK Energy Services Company L.P. (ONEOK Energy Services), a subsidiary of ONEOK, holds firm service agreements representing 3% of summer design capacity. The firm service agreements with ONEOK Energy Services extend for various terms with termination dates that range from March 2005 to March 2009. ONEOK Energy Services became affiliated with Northern Border Pipeline on November 17, 2004 in connection with ONEOK's purchase of Northern Plains. Revenues from ONEOK Energy Services for the period from the date of affiliation to December 31, 2004 were $1.1 million. At December 31, 2004, Northern Border Pipeline had an outstanding receivable from ONEOK Energy Services of $0.8 million. In 2003, there were no operating revenues from affiliates. In 2002, one of Northern Border Pipeline's shippers was affiliated with its general partners. Operating revenues from affiliates were $1.4 million for the year ended December 31, 2002.

F-18

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

7. TRANSPORTATION, GATHERING AND PROCESSING AGREEMENTS (continued)

The gas gathering and processing businesses provide services for gathering, treating, processing and compression of natural gas and the fractionation of natural gas liquids. For the year ended December 31, 2004, Bear Paw Energy's largest customers, Lodgepole Energy Marketing (Lodgepole), BP Canada Energy Marketing Corp. (BP Canada) and Montana Dakota Utilities accounted for $82.0 million (44%), $26.7 million (14%) and $21.7 million (12%), respectively of Bear Paw Energy's operating revenues. For the year ended December 31, 2003, Bear Paw Energy's largest customers, Lodgepole, Tenaska Marketing Ventures (Tenaska) and BP Canada accounted for $62.4 million (40%), $27.3 million (18%) and $16.6 million (11%), respectively, of Bear Paw Energy's operating revenue. For the year ended December 31, 2002, Bear Paw Energy's largest customers, Lodgepole and Tenaska accounted for $44.2 million (35%) and $20.2 million (16%), respectively, of Bear Paw Energy's operating revenue. Crestone Energy Venture's revenues from affiliates totaled $0.2 million, $0.1 million and $0.2 million in 2004, 2003 and 2002, respectively.

Black Mesa's operating revenue is derived from a transportation agreement with Peabody Western Coal, the coal supplier for the Mohave Generating Station that expires in December 2005. The coal slurry pipeline is the sole source of fuel for the Mohave plant. Operating revenues under the agreement totaled $22.0 million, $21.4 million and $21.5 million for the years ended December 31, 2004, 2003, and 2002, respectively.

8. CREDIT FACILITIES, LONG-TERM DEBT AND CAPITAL LEASES

Detailed information on long-term debt is as follows:

                                                               December 31,
                                                         -----------------------
(In thousands)                                              2004         2003
--------------                                           ----------   ----------
Northern Border Pipeline
   2002 Pipeline Credit Agreement - average
      1.95% at December 31, 2003, due 2005               $       --   $  131,000
   1999 Pipeline Senior Notes - 7.75%, due 2009             200,000      200,000
   2001 Pipeline Senior Notes - 7.50%, due 2021             250,000      250,000
   2002 Pipeline Senior Notes - 6.25%, due 2007             150,000      225,000
Viking Gas Transmission
   Senior Notes (Series A) - 6.65%, due 2008                  8,178       10,311
   Senior Notes (Series B) - 7.10%, due 2011                  2,520        2,850
   Senior Notes (Series C) - 7.31%, due 2012                  7,311        8,167
   Senior Notes (Series D) - 8.04%, due 2014                 13,111       14,333
Northern Border Partners, L.P.
   2003 Partnership Credit Agreement -
      average 3.20% and 2.67% at December 31, 2004
      and 2003, respectively, due 2007                      191,000       46,000
   2000 Partnership Senior Notes - 8 7/8%, due 2010         250,000      250,000
   2001 Partnership Senior Notes - 7.10%, due 2011          225,000      225,000
Bear Paw Energy Capital Leases                                3,110        6,090
Fair value adjustment for interest rate swaps (Note 9)        2,555       19,553
Unamortized debt premium                                     27,573       27,682
                                                         ----------   ----------
Total                                                     1,330,358    1,415,986
Less: Current maturities of long-term debt                    5,126        7,740
                                                         ----------   ----------
Long-term debt                                           $1,325,232   $1,408,246
                                                         ==========   ==========

F-19

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

8. CREDIT FACILITIES, LONG-TERM DEBT AND CAPITAL LEASES (continued)

The Partnership and Northern Border Pipeline have entered into revolving credit facilities, which are used for capital expenditures, acquisitions and general business purposes and for refinancing existing indebtedness. Northern Border Pipeline entered into a $175 million three-year credit agreement (2002 Pipeline Credit Agreement) with certain financial institutions in May 2002. The Partnership entered into a $275 million four-year credit agreement (2003 Partnership Credit Agreement) with certain financial institutions in November 2003. Both of the revolving credit facilities permit the Partnership and Northern Border Pipeline to choose among various interest rate options, to specify the portion of the borrowings to be covered by specific interest rate options and to specify the interest rate period. Both the Partnership and Northern Border Pipeline are required to pay a fee on the principal commitment amounts.

In April 2002, Northern Border Pipeline completed a private offering of $225 million of 6.25% Senior Notes due 2007 (2002 Pipeline Senior Notes). The 2002 Pipeline Senior Notes were subsequently exchanged in registered offerings for notes with substantially identical terms. The proceeds from the senior notes were used to reduce indebtedness outstanding.

On December 1, 2004, Northern Border Pipeline redeemed $75 million of the 2002 Pipeline Senior Notes. In connection with the redemption, Northern Border Pipeline was required to pay a premium of $4.8 million and received $2.5 million from the termination of interest rate swaps associated with the debt (see Note 9). The net loss from the redemption, including unamortized debt costs and discounts associated with the debt, is recorded as a loss on reacquired debt and amortized to interest expense over the remaining life of the 2002 Pipeline Senior Notes. At December 31, 2004, the unamortized loss on reacquired debt was $2.6 million and is included in other assets on the consolidated balance sheet.

Interest paid, net of amounts capitalized, during the years ended December 31, 2004, 2003 and 2002 was $77.7 million, $86.7 million and $88.2 million, respectively.

Aggregate repayments of long-term debt required for the next five years, excluding payments required under Bear Paw Energy's capital leases, are as follows: $2 million, $2 million, $343 million, $2 million and $200 million for 2005, 2006, 2007, 2008 and 2009, respectively.

The indentures under which the 1999, 2001 and 2002 Pipeline Senior Notes were issued do not limit the amount of indebtedness or other obligations that Northern Border Pipeline may incur, but do contain material financial covenants, including restrictions on the incurrence of secured indebtedness. The 2002 Pipeline Credit Agreement requires the maintenance of a ratio of EBITDA (net income plus interest expense, income taxes and depreciation and amortization) to interest expense to be greater than 3 to
1. The 2002 Pipeline Credit Agreement also requires the maintenance of the ratio of indebtedness to EBITDA of no more than 4.5 to 1. At December 31, 2004, Northern Border Pipeline was in compliance with its financial covenants.

At December 31, 2004, Viking Gas Transmission has four series of senior notes outstanding. In November 2004, Viking Gas Transmission amended the indenture on its senior notes. Prior to the amendment, Viking Gas Transmission made monthly principal and interest payments on the four series

F-20

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

8. CREDIT FACILITIES, LONG-TERM DEBT AND CAPITAL LEASES (continued)

of notes. As a result of the amendment, three of the series of senior notes due between 2011 and 2014 require payment of interest quarterly and payment of principal at maturity. The senior notes due in 2008 continue to require monthly principal and interest payments. Under the previous indenture, Viking Gas Transmission's transportation contracts were pledged as security for payment, which has been replaced in the current indenture by a guarantee by the Partnership. In addition, Viking Gas Transmission is no longer required to maintain debt service funds on deposit in an amount equal to all scheduled payments of principal and interest for the 180-day period following the current month end. At December 31, 2003, the requirement for accumulation of debt service funds was $3.7 million. The senior notes contain certain financial covenants and at December 31, 2004, Viking Gas Transmission was in compliance with its financial covenants.

The indentures under which the 2001 and 2000 Partnership Senior Notes were issued do not limit the amount of indebtedness or other obligations that the Partnership may incur, but do contain material financial covenants, including restrictions on the incurrence of secured indebtedness. The indentures also contain a provision that would require the Partnership to offer to repurchase the 2001 and 2000 Partnership Senior Notes if either Standard & Poor's Rating Services or Moody's Investor Service, Inc. rate the notes below investment grade and the investment grade rating is not reinstated for a period of 40 days. The 2003 Partnership Credit Agreement requires the maintenance of a ratio of consolidated EBITDA (consolidated net income plus minority interests in net income, consolidated interest expense, income taxes, depreciation and amortization and all other non-cash charges) to consolidated interest expense of greater than 3 to 1. The 2003 Partnership Credit Agreement also requires the maintenance of the ratio of consolidated total debt to adjusted consolidated EBITDA (EBITDA adjusted for pro forma operating results of acquisitions made during the year) of no more than 4.5 to 1. If the Partnership consummates one or more acquisitions in which the aggregate purchase price is $25 million or more, the allowable ratio of consolidated total debt to adjusted consolidated EBITDA temporarily increases to 5 to 1. At December 31, 2004, the Partnership was in compliance with these covenants.

Bear Paw Energy has entered into non-cancelable capital leases on compressors. The capital leases incorporate annual interest rates ranging from 7.10% to 8.85% and are for a term of five years, after which Bear Paw Energy receives ownership of the equipment. Future minimum payments under Bear Paw Energy's capital leases are as follows (in thousands):

   Years ending December 31,
           2005                     $3,145
           2006                        117
                                    ------
                                    $3,262
Less amount representing interest      152
                                    ------
Present value of lease payments      3,110
Less: current portion                2,993
                                    ------
Long-term portion                   $  117
                                    ======

The following estimated fair values of financial instruments represent the amount at which each instrument could be exchanged in a current transaction between willing parties. Based on quoted market prices for similar issues

F-21

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

8. CREDIT FACILITIES, LONG-TERM DEBT AND CAPITAL LEASES (continued)

with similar terms and remaining maturities, the estimated fair value of the aggregate of the 1999 Pipeline Senior Notes, 2000 Partnership Senior Notes, 2001 Partnership Senior Notes, 2001 Pipeline Senior Notes, 2002 Pipeline Senior Notes and Viking Gas Transmission Senior Notes was approximately $1,205 million and $1,306 million at December 31, 2004 and 2003, respectively. The Partnership presently intends to maintain the current schedule of maturities for the 1999 Pipeline Senior Notes, 2000 Partnership Senior Notes, 2001 Partnership Senior Notes, 2001 Pipeline Senior Notes, 2002 Pipeline Senior Notes and Viking Gas Transmission Senior Notes, which will result in no gains or losses on their respective repayment. The fair value of the 2003 Partnership Credit Agreement and the 2002 Pipeline Credit Agreement approximates the carrying value since the interest rates are periodically adjusted to reflect current market conditions.

9. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

The Partnership reflects in consolidated accumulated other comprehensive income its 70% share of Northern Border Pipeline's accumulated other comprehensive income. The remaining 30% is reflected as an adjustment to minority interests in partners' equity. The Partnership also reflects in consolidated accumulated other comprehensive income its ownership share of accumulated other comprehensive income of its unconsolidated affiliates (see Note 10).

Prior to the anticipated issuance of fixed rate debt, both the Partnership and Northern Border Pipeline have entered into forward starting interest rate swap agreements. 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. The notional amount of the interest rate swap agreements does not exceed the expected principal amount of fixed rate debt to be issued. Upon issuance of the fixed rate debt, the swap agreements were terminated and the proceeds received or amounts paid to terminate the swap agreements were recorded in accumulated other comprehensive income and amortized to interest expense over the term of the hedged debt. The Partnership also recorded an adjustment to minority interests in partners' equity for Northern Border Pipeline's terminated swap agreements.

On December 9, 2004, the Partnership 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 note issuance to be placed in the first half of 2005. At December 31, 2004, the Partnership has recorded a derivative instrument liability of $0.8 million, the fair value of the interest rate swap agreements, with a corresponding offset to accumulated other comprehensive income.

For the year ended December 31, 2002, Northern Border Pipeline received $2.4 million from terminated interest rate swap agreements that had been designated as cash flow hedges, of which $1.6 million was recorded in accumulated other comprehensive income and $0.8 million was recorded as an adjustment to minority interests in partners' equity.

F-22

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

9. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (continued)

During the years ended December 31, 2004, 2003 and 2002, the Partnership and Northern Border Pipeline amortized approximately $2.1 million, $2.2 million and $2.1 million, respectively, related to the terminated interest rate swap agreements, as a reduction to interest expense from accumulated other comprehensive income. A comparable amount is expected to be amortized in 2005.

At December 31, 2004 and 2003, the Partnership had outstanding interest rate swaps with notional amounts totaling $150 million. Under the interest rate swap agreements, the Partnership makes payments to counterparties at variable rates based on the London Interbank Offered Rate and in return receives payments based on a 7.10% fixed rate. At December 31, 2004 and 2003, the average effective interest rate on the Partnership's interest rate swap agreements was 4.60% and 3.72%, respectively.

Northern Border Pipeline entered into interest rate swap agreements with notional amounts totaling $225 million in May 2002. Under the interest rate swap agreements, Northern Border Pipeline makes payments to counterparties at variable rates based on the London Interbank Offered Rate and in return receives payments based on a 6.25% fixed rate. At December 31, 2003 the average effective interest rate on Northern Border Pipeline's interest rate swap agreements was 2.31%.

In November 2004, Northern Border Pipeline terminated its interest rate swap agreements with notional amounts totaling $225 million and received $7.5 million. Of the total proceeds, $2.5 million related to the redemption of $75 million of the 2002 Pipeline Senior Notes (see note 8). In October 2002, the Partnership agreed to an increase in the variable interest rate on two of its interest rate swap agreements with notional amounts totaling $150 million. As consideration for the change to the variable interest rate, the Partnership received approximately $18.2 million, which represented the fair value of the financial instruments at the date of the adjustment. In March 2003, the Partnership terminated one of its interest rate swap agreements with a notional amount of $75 million and received $12.3 million. The Partnership used the proceeds to repay amounts borrowed under its credit facility.

The Partnership and Northern Border Pipeline records 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 years ended December 31, 2004, 2003 and 2002, the Partnership and Northern Border Pipeline amortized approximately $3.3 million, $3.4 million and $0.5 million, respectively, as a reduction to interest expense. The Partnership and Northern Border Pipeline expect to amortize approximately $5.2 million as a reduction to interest expense in 2005 for these agreements.

Both the Partnership's and Northern Border Pipeline's 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 the Partnership in 2001 and by Northern Border Pipeline in 2002.

F-23

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

9. DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (continued)

The accompanying consolidated balance sheet at December 31, 2004 and 2003, reflects an unrealized gain of approximately $2.6 million and $19.6 million, respectively, in derivative financial instruments with a corresponding increase in long-term debt.

Bear Paw Energy periodically enters into commodity derivatives 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 years ended December 31, 2004, 2003 and 2002, respectively, Bear Paw Energy recognized losses of $9.4 million, $8.5 million and $2.8 million from the settlement of derivative contracts. At December 31, 2004, the consolidated balance sheet reflected an unrealized gain of approximately $2.0 million in derivative financial instruments with a corresponding increase of $2.0 million in accumulated other comprehensive income. At December 31, 2003, the consolidated balance sheet reflected an unrealized loss of approximately $5.7 million in derivative financial instruments with a corresponding reduction of $5.5 million in accumulated other comprehensive income. For 2005, if prices remain at current levels, Bear Paw Energy expects to reclassify approximately $2.0 million from accumulated other comprehensive income as an increase to operating revenues. However, this increase would be offset with decreased operating revenues due to the lower prices assumed.

At September 30, 2001, Bear Paw Energy had outstanding commodity price swap arrangements with ENA, which had been accounted for as cash flow hedges, and resulted in Bear Paw Energy recording a non-cash gain of approximately $6.7 million in accumulated other comprehensive income. During the fourth quarter of 2001, the Partnership determined that ENA was no longer likely to honor the obligations it had to Bear Paw Energy for these derivatives and terminated the swap arrangements (see Note 18). In accordance with SFAS No. 133, Bear Paw Energy ceased to account for these derivatives as hedges. The gain previously recorded in accumulated other comprehensive income is reflected in earnings in the same periods during which the hedged forecasted transactions will affect earnings. During the years ended December 31, 2004, 2003 and 2002, the Partnership recorded approximately $0.2 million, $0.3 million and $4.6 million, respectively, in earnings and expects to record approximately $0.1 million in earnings in 2005.

10. UNCONSOLIDATED AFFILIATES

The Partnership's investments in unconsolidated affiliates which are accounted for by the equity method is as follows:

                                             Net          December 31,
                                          Ownership   ---------------------
(In thousands)                            Interest      2004         2003
--------------                            ---------   --------     --------
Bighorn                                      (a)      $ 92,350     $ 94,153
Fort Union                                   33%        71,710       70,278
Lost Creek                                   35%        74,935       71,177
Guardian Pipeline                            33%        34,207       32,558
                                                      --------     --------
                                                      $273,202(b)  $268,166
                                                      ========     ========

F-24

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

10. UNCONSOLIDATED AFFILIATES (continued)

(a) The Partnership held a 49% common membership interest in Bighorn and 100% of the non-voting preferred A shares of Bighorn at December 31, 2004 and 2003. Bighorn's ownership structure consists of common membership interests and non-voting preferred A and B shares. Both of the non-voting classes of shares are subject to certain distribution preferences and limitations based on the cumulative number of wells connected to the Bighorn system at the end of each calendar year. These shares will receive an income allocation equal to the cash distributions received and are not entitled to any other allocations of income or distributions of cash. Ownership of these shares does not affect the amount of capital contributions that may be required to be made to the operations of Bighorn by the owners of the common membership interests.

(b) The unamortized excess of the Partnership's investments in unconsolidated affiliates over the underlying fair value of the net assets accounted for under the equity method was $181.6 million at December 31, 2004 and 2003.

The Partnership's equity earnings of unconsolidated affiliates is as follows:

(In thousands)                                    2004      2003      2002
--------------                                  -------   -------   -------
Bighorn                                         $ 5,832   $ 6,467   $ 3,764
Fort Union                                        5,357     5,953     5,540
Lost Creek                                        5,176     4,403     3,679
Guardian Pipeline                                 1,650     1,992        --
                                                -------   -------   -------
                                                $18,015   $18,815   $12,983
                                                =======   =======   =======

Summarized combined financial information of the Partnership's unconsolidated affiliates is presented below:

                                                           December 31,
                                                       --------------------
(In thousands)                                           2004       2003
--------------                                         --------   --------
Balance sheet
   Current assets                                      $ 37,651   $ 34,101
   Property, plant and equipment, net                   466,775    470,840
   Other noncurrent assets                                3,224      3,260
   Current liabilities                                   39,936     44,013
   Long-term debt                                       224,965    243,620
   Other noncurrent liabilities                           2,605      4,958
   Accumulated other comprehensive income                (2,605)    (4,958)
   Owners' equity                                       242,749    220,568

(In thousands)                                    2004      2003      2002
--------------                                  -------   -------   -------
Income statement
   Operating revenues                           $92,402   $94,318   $57,364
   Operating expenses                            34,160    31,927    17,976
   Net income                                    39,736    42,583    33,065
Distributions paid to the Partnership           $13,946   $16,262   $10,820

F-25

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

11. PARTNERS' EQUITY

At December 31, 2004 and 2003, partners' equity consisted of 46,397,214 common units representing an effective 98% limited partner interest in the Partnership and a 2% general partner interest. At December 31, 2004 and 2003, approximately 1.1% of the limited partner interest was held by Northern Plains. Sundance Assets, L.P. (Sundance), an indirect subsidiary of Enron) held approximately 5.8% of the limited partnership interest at December 31, 2003. Sundance sold its limited partner interest during 2004. The Partnership did not receive any proceeds from the sale.

In conjunction with the issuance of additional common units, the Partnership's general partners are required to make equity contributions to the Partnership to maintain a 2% general partner interest in accordance with the partnership agreements.

In May and June 2003, the Partnership sold 2,250,000 and 337,500 common units, respectively. In July 2002, the Partnership sold 2,186,700 common units. The net proceeds from the sale of common units and the general partners' contributions totaled approximately $102.2 million in 2003 and $75.4 million in 2002 and were primarily used to repay indebtedness outstanding.

Under the partnership agreement, the Partnership will make distributions to its partners with respect to each calendar quarter in an amount equal to 100% of its Available Cash. "Available Cash" generally consists of all of the cash receipts of the Partnership adjusted for its cash disbursements and net changes to cash reserves. Available Cash will generally be distributed 98% to the Unitholders and 2% to the General Partners. As an incentive, the General Partners' percentage interest in quarterly distributions is increased after certain specified target levels are met. Under the incentive distribution provisions, the General Partners receive 15% of amounts distributed in excess of $0.605 per common unit, 25% of amounts distributed in excess of $0.715 per unit and 50% of amounts distributed in excess of $0.935 per unit. Partnership income is allocated to the General Partners and the limited partners in accordance with their respective partnership percentages, after giving effect to any priority income allocations for incentive distributions that are allocated to the General Partners. For the years ended December 31, 2004, 2003 and 2002, incentive distributions to the General Partners totaled $8.0 million, $7.7 million and $7.3 million, respectively.

12. NORTHERN BORDER PIPELINE CASH DISTRIBUTION POLICY

The Northern Border Pipeline partnership agreement provides that distributions to Northern Border Pipeline's partners are to be made on a pro rata basis according to each partner's capital account balance. The Northern Border Pipeline Management Committee determines the amount and timing of such distributions. Any changes to, or suspension of, the cash distribution policy of Northern Border Pipeline requires the unanimous approval of the Northern Border Pipeline Management Committee. In December 2003, Northern Border Pipeline's Management Committee voted to (i) issue equity cash calls to its partners in the total amount of $130 million in early 2004 and $90 million in 2007; (ii) fund future growth capital

F-26

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

12. NORTHERN BORDER PIPELINE CASH DISTRIBUTION POLICY (continued)

expenditures with 50% equity capital contributions from its partners; and
(iii) change the cash distribution policy of Northern Border Pipeline. Effective January 1, 2004, cash distributions are equal to 100% of distributable cash flow as determined from Northern Border Pipeline's financial statements based upon earnings before interest, taxes, depreciation and amortization less interest expense and maintenance capital expenditures. Effective January 1, 2008, the cash distribution policy will be adjusted to maintain a consistent capital structure. On November 30, 2004, Northern Border Pipeline issued an equity cash call to its partners in the total amount of $75 million, which was utilized to repay existing bank debt. This equity contribution will reduce the previously approved 2007 equity cash call from $90 million to $15 million.

13. COMMITMENTS AND CONTINGENCIES

Firm Transportation Obligations and Other Commitments

Crestone Energy Ventures has firm transportation agreements with Fort Union and Lost Creek. Under these agreements, Crestone Energy Ventures must make specified minimum payments each month. Crestone Energy Ventures recorded expenses of $11.8 million, $11.7 million and $ 11.4 million for the years ended December 31, 2004, 2003 and 2002, respectively, related to these agreements. At December 31, 2004, the estimated aggregate amounts of such required future payments were $11.6 million annually for 2005 through 2008, $11.1 million for 2009 and $3.7 million for later years.

At December 31, 2004, the Partnership has guaranteed the performance of certain of its unconsolidated affiliates in connection with credit agreements that expire in March 2009 and September 2009. Collectively, at December 31, 2004, the amount of both guarantees was $4.4 million.

Operating Leases

Future minimum lease payments under non-cancelable operating leases on office space, pipeline equipment, rights-of-way and vehicles are as follows (in thousands):

Year ending December 31,
          2005             $ 4,489
          2006               4,024
          2007               3,154
          2008               2,978
          2009               2,392
          Thereafter        66,385
                           -------
                           $83,422
                           =======

Expenses incurred related to these lease obligations for the years ended December 31, 2004, 2003 and 2002, were $3.8 million, $3.7 million and $2.0 million, respectively.

F-27

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

13. COMMITMENTS AND CONTINGENCIES (continued)

Cash Balance Plan

As further discussed in Note 18, on December 31, 2003, Enron filed a motion seeking approval of the Bankruptcy Court to provide additional funding to, and for authority to, terminate the Enron Corp. Cash Balance Plan and certain other defined benefit plans. The Partnership recorded charges associated with the termination of the cash balance plan of $6.2 million in 2003. In 2004, the Partnership reduced its expense by $6.2 million, since it determined it is no longer liable for terminations costs of the Cash Balance Plan.

Capital Expenditures

Total capital expenditures for 2005 are estimated to be $87 million. This includes approximately $57 million for interstate natural gas pipeline facilities, $25 million for natural gas gathering and processing facilities and $5 million for information technology systems. Funds required to meet the capital requirements for 2005 are anticipated to be provided from credit facilities and operating cash flows.

Environmental Matters

The Partnership is not aware of any material contingent liabilities with respect to compliance with applicable environmental laws and regulations.

Other

On July 31, 2001, the Assiniboine and Sioux Tribes of the Fort Peck Indian Reservation (Tribes) filed a lawsuit in Tribal Court against Northern Border Pipeline to collect more than $3 million in back taxes, together with interest and penalties. The lawsuit related to a utilities tax on certain of Northern Border Pipeline's properties within the Fort Peck Indian Reservation. The Tribes and Northern Border Pipeline, through a mediation process, reached a settlement with respect to pipeline right-of-way lease and taxation issues documented through an Option Agreement and Expanded Facilities Lease (Agreement) executed in August 2004. Through the terms of the Agreement, the settlement grants to Northern Border Pipeline, among other things: (i) an option to renew the pipeline right-of-way lease upon agreed terms and conditions on or before April 1, 2011 for a term of 25 years with a renewal right for an additional 25 years; (ii) a right to use additional tribal lands for expanded facilities; and (iii) release and satisfaction of all tribal taxes against Northern Border Pipeline. In consideration of this option and other benefits, Northern Border Pipeline paid a lump sum amount of $7.4 million and will make additional annual option payments of approximately $1.5 million thereafter through March 31, 2011. Of the amount paid in 2004, $1.0 million was determined to be a settlement of previously accrued property taxes. The remainder has been recorded in other assets on the balance sheet. Northern Border Pipeline intends to seek regulatory recovery from the settlement in its upcoming rate case.

Various legal actions that have arisen in the ordinary course of business are pending. The Partnership believes that the resolution of these issues will not have a material adverse impact on the Partnership's results of operations or financial position.

F-28

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

14. INCOME TAXES

Components of the income tax provision applicable to continuing operations and income taxes paid by the Partnership's corporate subsidiaries are as follows (in thousands):

                                                    Year Ended December 31,
                                                   ------------------------
                                                    2004     2003     2002
                                                   ------   ------   ------
Taxes currently payable:
   Federal                                         $1,346   $  900   $  453
   State                                              289      311       87
                                                   ------   ------   ------
      Total                                         1,635    1,211      540
                                                   ------   ------   ------
Taxes deferred:
   Federal                                          2,789    2,842      934
   State                                              712      652      169
                                                   ------   ------   ------
      Total                                         3,501    3,494    1,103
                                                   ------   ------   ------
Total tax provision                                $5,136   $4,705   $1,643
                                                   ======   ======   ======
Income taxes paid                                  $5,346   $1,544   $   32
                                                   ======   ======   ======

The difference between the statutory federal income tax rate and the Partnership's effective income tax rate is summarized as follows:

                                                    Year Ended December 31,
                                                    -----------------------
                                                     2004    2003     2002
                                                    -----   -----    -----
Federal income tax rate                              35.0%   35.0%    35.0%
Increase (decrease) as a result of:
   Partnership earnings not subject to tax          (35.0)  (35.0)   (35.0)
   Corporate subsidiary earnings subject to tax       2.8    (4.1)     1.3
   State taxes                                        0.7    (1.0)     0.2
                                                    -----   -----    -----
Effective tax rate                                    3.5%   (5.1)%    1.5%
                                                    =====   =====    =====

Deferred tax assets and liabilities result from the following (in thousands):

                                                             December 31,
                                                          -----------------
                                                            2004      2003
                                                          -------   -------
Deferred tax assets:
   Net operating loss                                     $ 6,606   $ 6,379
   Plant related differences                                2,333       670
   Joint venture income                                        --       675
   Other                                                      410       816
                                                          -------   -------
Total deferred tax assets                                 $ 9,349   $ 8,540
                                                          -------   -------
Deferred tax liabilities:
   Goodwill                                               $ 5,458   $ 4,383
   Accelerated depreciation and other plant
      related differences                                   3,514     3,829
   Partnership income                                       7,563     3,226
                                                          -------   -------
Total deferred tax liabilities                            $16,535   $11,438
                                                          -------   -------
Net deferred tax liabilities                              $ 7,186   $ 2,898
                                                          =======   =======

F-29

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

14. INCOME TAXES (continued)

The Partnership had available, at December 31, 2004, approximately $6.6 million of tax benefits related to net operating loss carryforwards, which will expire between the years 2008 and 2024. The Partnership believes that it is more likely than not that the tax benefits of the net operating loss carryforwards will be utilized prior to their expiration; therefore, no valuation allowance is necessary.

15. ACCOUNTING PRONOUNCEMENTS

In December 2003, the FASB issued Interpretation No. (FIN) 46 (revised December 2003), "Consolidation of Variable Interest Entities," which addresses how a business enterprise should evaluate whether it has a controlling financial interest in an entity through means other than voting rights and accordingly should consolidate the entity; such entities are known as variable interest entities. The Partnership adopted FIN 46 as of January 1, 2004. In connection with the adoption of FIN 46, the Partnership evaluated its investments in Bighorn, Fort Union, Lost Creek and Guardian Pipeline and determined that these entities are appropriately accounted for as equity method investments. The adoption of FIN 46 did not have an effect on the Partnership's financial position, results of operations or cash flows.

In December 2004, the FASB issued SFAS No. 153, "Exchanges of Nonmonetary Assets." This Statement amends the guidance in APB Opinion No. 29, "Accounting for Nonmonetary Transactions." APB 29 provided an exception to the basic measurement principle (fair value) for exchanges of similar assets, requiring that some nonmonetary exchanges be recorded on a carryover basis. SFAS 153 eliminates the exception to fair value for exchanges of similar productive assets and replaces it with a general exception for exchange transactions that do not have commercial substance, that is, transactions that are not expected to result in significant changes in the cash flows of the reporting entity. The provisions of SFAS 153 are effective for exchanges of nonmonetary assets occurring in fiscal periods beginning after June 15, 2005. The Partnership believes that SFAS 153 will not have a significant effect on the financial position, results of operations, and cash flows of the Partnership.

16. BUSINESS SEGMENT INFORMATION

The Partnership's business is divided into three reportable segments, defined as components of the enterprise about which financial information is available and evaluated regularly by the Partnership's executive management and the Partnership Policy Committee in deciding how to allocate resources to an individual segment and in assessing performance of the segment.

The Partnership's reportable segments are strategic business units that offer different services. Each are managed separately because each business requires different marketing strategies. These segments are as follows: the Interstate Natural Gas Pipeline segment provides natural gas transmission services; the Natural Gas Gathering and Processing segment 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 transports crushed coal suspended in water. The accounting policies of the segments are the same as those described in the summary of significant accounting policies in Note 2.

F-30

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

16. BUSINESS SEGMENT INFORMATION (continued)

The Partnership evaluates 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 its segments and to internally manage those business segments and believes that EBITDA is a good indicator of each segment's performance. EBITDA should not be considered an alternative to, or more meaningful than, net income or cash flow as determined in accordance with GAAP. EBITDA calculations may vary from company to company, so the Partnership's computation of EBITDA may not be comparable to a similarly titled measure of another company. The following table shows how EBITDA is calculated:

RECONCILIATION OF NET INCOME (LOSS) TO EBITDA

                                                              Natural
                                               Interstate       Gas
                                                 Natural     Gathering
                                                   Gas          and        Coal
(In thousands)                                  Pipelines   Processing    Slurry    Other(a)     Total
--------------                                 ----------   ----------   --------   --------   ---------
2004
Net income (loss)                              $ 134,726     $  44,488    $ 3,088   ($37,582)  $ 144,720
Minority interest                                 50,033            --         --         --      50,033
Interest expense, net                             43,882           369         11     32,681      76,943
Depreciation and amortization                     67,487        14,851      4,465        400      87,203
Income tax                                         4,783            26        327      2,935       8,071
AFUDC                                               (117)           --         --         --        (117)
                                               ---------     ---------    -------   --------   ---------
EBITDA                                         $ 300,794     $  59,734    $ 7,891   ($ 1,566)  $ 366,853
                                               =========     =========    =======   ========   =========

2003
Net income (loss)                              $ 119,620     ($183,016)   $ 3,658   ($28,716)  ($ 88,454)
Cumulative effect of change in accounting
 principle, net of tax                                --            --        434        209         643
Minority interest                                 44,460            --         --         --      44,460
Interest expense, net                             47,577           591         33     30,779      78,980
Depreciation and amortization                     66,245       232,777      1,848      1,107     301,977
Income tax                                         3,629            --      1,076       (276)      4,429
AFUDC                                               (331)           --         --         --        (331)
                                               ---------     ---------    -------   --------   ---------
EBITDA                                         $ 281,200     $  50,352    $ 7,049   $  3,103   $ 341,704
                                               =========     =========    =======   ========   =========

2002
Net income (loss)                              $ 107,510     $  35,568    $ 4,136   ($33,538)  $ 113,676
Minority interest                                 42,816            --         --         --      42,816
Interest expense, net                             51,525           794         33     30,546      82,898
Depreciation and amortization                     61,002        12,102      1,568      1,202      75,874
Income tax                                           730            --        913        543       2,186
AFUDC                                               (248)           --         --         --        (248)
                                               ---------     ---------    -------   --------   ---------
EBITDA                                         $ 263,335     $  48,464    $ 6,650   ($ 1,247)  $ 317,202
                                               =========     =========    =======   ========   =========

BUSINESS SEGMENT DATA

                                                              Natural
                                               Interstate       Gas
                                                 Natural     Gathering     Coal
                                                   Gas          and       Slurry
(In thousands)                                  Pipelines   Processing   Pipeline   Other(a)      Total
--------------                                 ----------   ----------   --------   --------   ----------
2004
Revenues from external customers               $  383,625   $ 184,738    $22,020    $    --    $  590,383
Depreciation and amortization                      67,115      14,851      4,465         --        86,431
Operating income (loss)                           231,027      28,278      3,446     (9,366)      253,385
Interest expense, net                              43,882         369         11     32,681        76,943
Equity earnings of unconsolidated affiliates        1,649      16,366         --         --        18,015
Other income (expense), net                           748         239        (20)       666         1,633
Income tax expense                                  4,783          26        327         --         5,136
Capital expenditures                               16,258      25,646      1,573         --        43,477
Identifiable assets                             1,866,348     337,502     18,268     15,236     2,237,354
Investments in unconsolidated affiliates           34,207     238,995         --         --       273,202
Total assets                                   $1,900,555   $ 576,497    $18,268    $15,236    $2,510,556

2003
Revenues from external customers               $  375,256   $ 154,284    $21,408    $    --    $  550,948
Depreciation and amortization (b)                  65,881     232,063      1,847         --       299,791
Operating income (loss)                           212,841    (203,067)     5,144     (7,601)        7,317
Interest expense, net                              47,577         591         33     30,779        78,980
Equity earnings unconsolidated affiliates           1,992      16,823         --         --        18,815
Other income (expense), net                           453       3,819         57        535         4,864
Income tax expense                                  3,629          --      1,076         --         4,705
Capital expenditures                               19,497       8,981      1,804         --        30,282
Identifiable assets                             1,938,249     317,182     21,319     25,667     2,302,417
Investments in unconsolidated affiliates           32,558     235,608         --         --       268,166
Total assets                                   $1,970,807   $ 552,790    $21,319    $25,667    $2,570,583

F-31

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

16. BUSINESS SEGMENT INFORMATION (continued)

                                              Natural
                                            Interstate       Gas
                                              Natural     Gathering     Coal
                                                Gas          and       Slurry
(In thousands)                               Pipelines   Processing   Pipeline   Other(a)      Total
--------------                              ----------   ----------   --------   --------   ----------
2002
Revenues from external customers            $  339,014    $126,622     $21,568   $    --    $  487,204
Depreciation and amortization                   61,002      12,102       1,568        --        74,672
Operating income (loss)                        200,584      23,278       5,054    (5,747)      223,169
Interest expense, net                           51,525         794          33    30,546        82,898
Equity earnings unconsolidated affiliates           --      12,983          --        --        12,983
Other income (expense), net                      1,997         101          28        61         2,187
Income tax expense                                 730          --         913        --         1,643
Capital expenditures                            16,579      33,718         441        --        50,738
Identifiable assets                          1,848,960     536,937      20,206    75,448     2,481,551
Investments in unconsolidated affiliates            --     234,385          --        --       234,385
Total assets                                $1,848,960    $771,322     $20,206   $75,448    $2,715,936

(a) Includes other items not allocable to segments.

(b) Natural gas gathering and processing results includes goodwill and asset impairment charges of $219,080 (see Note 4).

17. OTHER INCOME (EXPENSE)

Other income (expense) on the consolidated statement of income includes such items as investment income, nonoperating revenues and expenses, foreign currency gains and losses, and nonrecurring other income and expense items. For the year ended December 31, 2003, other income also included a $3.3 million payment received for a change in ownership of the other partner in Bighorn.

F-32

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

18. QUARTERLY FINANCIAL DATA (Unaudited)

                                                  Income       Per Unit
                                                  (Loss)     Income (Loss)
                                    Operating      From           From
(In thousands, except   Operating     Income    Continuing     Continuing
  per unit amounts)      Revenues     (Loss)    Operations     Operations
---------------------   ---------   ---------   ----------   -------------
2004
   First Quarter         $143,773   $  61,761   $  35,852       $ 0.71
   Second Quarter         142,476      60,595      32,872         0.65
   Third Quarter          147,355      62,093      34,400         0.68
   Fourth Quarter         156,779      68,936      37,797         0.76

2003
   First Quarter         $138,175   $  58,731   $  32,520       $ 0.68
   Second Quarter         134,362      56,767      27,170         0.55
   Third Quarter          138,008    (160,795)   (183,976)       (3.93)
   Fourth Quarter         140,403      52,614      27,137         0.53

19. RELATIONSHIPS WITH ENRON

In December 2001, Enron and certain of its subsidiaries filed a voluntary petition for bankruptcy protection under Chapter 11 of the United States Bankruptcy Code. Until November 17, 2004, each of Northern Plains, Pan Border and NBP Services were subsidiaries of Enron. Northern Plains, Pan Border and NBP Services were not among the Enron companies filing for Chapter 11 protection.

Enron North America (ENA), a wholly owned subsidiary of Enron that is in bankruptcy, was a party to transportation contracts which obligated ENA to pay for 3.5% of Northern Border Pipeline's capacity. Through the bankruptcy proceeding in 2002, ENA rejected and terminated all of its firm transportation contracts on Northern Border Pipeline. Northern Border Pipeline had previously fully reserved for amounts invoiced to ENA. 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 between 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. The settlement agreement is expected to be presented to the Bankruptcy Court for approval in March 2005. Based upon this settlement between the parties, at December 31, 2004, Northern Border Pipeline adjusted its allowance for doubtful accounts to reflect an estimated recovery of $1.1 million for these claims.

ENA was also a party to a transportation contract for capacity on Midwestern Gas Transmission. ENA rejected and terminated this contract in November 2003. Midwestern Gas Transmission filed claims against ENA for breach of contract and other claims. However, this claim of approximately $150,000 was denied.

In addition, Bear Paw Energy filed claims against ENA relating to terminated swap agreements. In accordance with SFAS No. 133, Bear Paw Energy ceased to account for these swap agreements as hedge transactions. Bear Paw Energy had previously recorded approximately $6.7 million in accumulated other comprehensive income related to these agreements, which is being recorded into earnings in the same periods of the originally forecasted

F-33

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

19. RELATIONSHIPS WITH ENRON (continued)

hedges. During the third quarter 2004, the Bankruptcy Court approved a settlement between Bear Paw Energy, Enron and certain of its wholly-owned subsidiaries of Bear Paw Energy's claim for commodity hedges. As a result, the Partnership adjusted its allowance for doubtful accounts to reflect an estimated $1.8 million recovery for its claim.

Also, Crestone Energy Ventures filed claims against ENA for unpaid gas gathering and administrative services fees in the amount of $2.3 million. As a result of a settlement agreement between ENA and Crestone Energy Ventures, ENA has agreed to allow Crestone Energy Ventures' claim of approximately $2.3 million. The settlement agreement is expected to be presented to the Bankruptcy Court for approval in March 2005. Based upon this settlement between the parties, the Partnership adjusted its allowance for doubtful accounts to reflect an estimated $0.5 million recovery for its claim.

The Partnership estimates that it could recognize, through future operating results, additional recoveries 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.

On December 31, 2003, Enron filed a motion seeking approval of the Bankruptcy Court to provide additional funding to, and for authority to terminate the Enron Corp. Cash Balance Plan (Plan) and certain other defined benefit plans of Enron's affiliates in 'standard terminations' within the meaning of Section 4041 of the Employee Retirement Income Security Act of 1974, as amended (ERISA). Such standard terminations would satisfy all of the obligations of Enron and its affiliates with respect to funding liabilities under the Plan. In addition, a standard termination would eliminate the contingent claims of Pension Benefit Guaranty Corporation (PBGC) against Enron and its affiliates with respect to funding liabilities under the Plan. On January 30, 2004, the Bankruptcy Court entered an order authorizing termination, additional funding and other actions necessary to effect the relief requested. Pursuant to the Bankruptcy Court order, any contributions to the Plan are subject to the prior receipt of a favorable determination by the Internal Revenue Service that the Plan is tax-qualified as of the date of termination.

On July 19, 2004, Enron was served with a complaint filed by the PBGC in the District Court for the Southern District of Texas against Enron as the sponsor and/or administrator of the Plans (the Action). By filing the Action, the PBGC is seeking an order (i) terminating the Plans; (ii) appointing the PBGC the statutory trustee of the Plans; (iii) requiring transfer to the PBGC of all records, assets or other property of the Plans required to determine the benefits payable to the Plans' participants; and
(iv) establishing June 2, 2004 as the termination date of the Plans. In the Bankruptcy Court September 10 Order, Enron was authorized to enter into an escrow agreement with CCE Holdings and PBGC. Upon closing, Enron deposited the amount of $321.8 million to an escrow account, which is intended to ensure that none of CCE Holdings or its affiliates are exposed

F-34

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

19. RELATIONSHIPS WITH ENRON (continued)

to liability to the PBGC under Title IV of the Employee Retirement Income Security Act of 1974, as amended, for which CCE Holdings may otherwise be indemnified pursuant to the CCE Holdings Agreement. In addition, the form of escrow agreement approved pursuant to the September 10 Order provides that, under certain circumstances and upon approval by or notice to the parties to the escrow agreement, some or all of the funds placed in escrow may be paid directly in respect of the Cash Balance Plan or to the PBGC. However, the September 10 Order also provides that PBGC retains any rights or claims it may have against the Transfer Group Companies.

Enron management previously informed Northern Plains and NBP Services that Enron would seek funding contributions from each member of its ERISA controlled group of corporations that employs, or employed, individuals who are, or were, covered under the Cash Balance Plan. Northern Plains and NBP Services are considered members of Enron's ERISA controlled group of corporations. As of December 31, 2003, the amount of approximately $6.2 million was estimated for Northern Plains' and NBP Services' proportionate share of the up to $200 million estimated termination costs for the Plans authorized by the Bankruptcy Court order. Since under the operating agreement with Northern Plains and the administrative agreement with NBP Services, these costs could be the Partnership's responsibility, the Partnership accrued $6.2 million to satisfy claims of reimbursement for these termination costs. As a result of further evaluation and negotiation of Enron's proposed allocation of the termination costs, Northern Plains and NBP Services advised the Partnership that no claim of reimbursement for the termination costs will be made, resulting in a reduction in reserves during 2004 of $6.2 million for the termination costs. Under the ONEOK Agreement, neither Northern Plains nor NBP Services nor the Partnership will be required to contribute to or otherwise be liable for any contributions to Enron in connection with the Cash Balance Plan. The purchase price under the agreements will be deemed to include all contributions which otherwise would have been allocable to Northern Plains and NBP Services.

Management continues to monitor developments at Enron, to assess the impact on the Partnership of its existing agreements and relationships with Enron and to take appropriate action to protect the interests of the Partnership.

20. SUBSEQUENT EVENTS

On January 21, 2005, the Partnership declared a cash distribution of $0.80 per unit ($3.20 per unit on an annualized basis) for the quarter ended December 31, 2004. The distribution was paid February 14, 2005, to unitholders of record at January 31, 2005.

F-35

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM ON SCHEDULE

Northern Border Partners, L.P.:

We have audited in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated financial statements of Northern Border Partners, L.P. and Subsidiaries as of December 31, 2004 and 2003 and for each of the years in the three-year period ended December 31, 2004 included in this Form 10-K, and have issued our report thereon dated March 2, 2005.

Our audits were made for the purpose of forming an opinion on the basic financial statements taken as a whole. The schedule of Northern Border Partners, L.P. and Subsidiaries listed in Item 15 of Part IV of this Form 10-K is the responsibility of the Company's management and is presented for purposes of complying with the Securities and Exchange Commission's rules and is not part of the basic financial statements. This schedule has been subjected to the auditing procedures applied in the audits of the basic financial statements and, in our opinion, fairly states in all material respects, the financial data required to be set forth therein in relation to the basic financial statements taken as a whole.

/s/ KPMG LLP

Omaha, Nebraska
March 2, 2005

S-1

SCHEDULE II

NORTHERN BORDER PARTNERS, L.P. AND SUBSIDIARIES
SCHEDULE II - VALUATION AND QUALIFYING ACCOUNTS
FOR THE YEARS ENDED DECEMBER 31, 2004, 2003 AND 2002
(IN THOUSANDS)

Column A                           Column B           Column C             Column D        Column E
-----------                       ----------   ---------------------   ---------------   -----------
                                                     Additions
                                               ---------------------     Deductions
                                  Balance at   Charged to    Charged   For Purpose For
                                   Beginning    Costs and   to Other   Which Reserves    Balance at
Description                         of Year     Expenses    Accounts    Were Created     End of Year
-----------                       ----------   ----------   --------   ---------------   -----------
Reserve for regulatory issues
   2004                             $ 7,644      $  640        $--         $ 6,329         $ 1,955
   2003                             $12,294      $5,611        $--         $10,261         $ 7,644
   2002                             $ 2,531      $9,763        $--         $    --         $12,294

Allowance for doubtful accounts
   2004                             $11,988      $  569        $--         $ 3,382         $ 9,175
   2003                             $11,936      $   52        $--         $    --         $11,988
   2002                             $10,287      $3,463        $52         $ 1,866         $11,936

S-2

Index to Exhibits

EXHIBITS          DESCRIPTION
---------------   -----------
            3.1   Northern Border Partners, L.P. Certificate of Limited
                  Partnership, Certificate of Amendment dated February 16, 2001,
                  and Certificate of Amendment dated May 20, 2003.

            3.2   Amended and Restated Agreement of Limited Partnership of
                  Northern Border Partners, L.P. dated October 1, 1993.

            3.3   Northern Border Intermediate Limited Partnership Certificate
                  of Limited Partnership, Certificate of Amendment dated
                  February 16, 2001, and Certificate of Amendment dated May 20,
                  2003.

           *3.4   Form of Amended and Restated Agreement of Limited Partnership
                  for Northern Border Intermediate Limited Partnership
                  (incorporated by reference to Exhibit 10.1 to Form S-1
                  Registration Statement, Registration No. 33-66158 ("Form
                  S-1")).

           *4.1   Indenture, dated as of June 2, 2000, between Northern Border
                  Partners, L.P. and Northern Border Intermediate Limited
                  Partnership and Bank One Trust Company, N.A. (incorporated by
                  reference to Exhibit 4.1 to the Partnership's Quarterly Report
                  on Form 10-Q for the quarterly period ended June 30, 2000
                  (File No. 1-12202) ("June 2000 10-Q")).

           *4.2   First Supplemental Indenture, dated as of September 14, 2000,
                  between Northern Border Partners, L.P., Northern Border
                  Intermediate Limited Partnership and Bank One Trust Company,
                  N.A. (incorporated by reference to Exhibit 4.2 to the
                  Partnership's Form S-4 Registration Statement, Registration
                  No. 333-46212 ("NBP Form S-4")).

           *4.3   Indenture, dated as of March 21, 2001, between Northern Border
                  Partners, L.P. and Northern Border Intermediate Limited
                  Partnership and Bank One Trust Company, N.A., Trustee
                  (incorporated by reference to Exhibit 4.3 to the Partnership's
                  Form 10-K for the year ended December 31, 2001 (File No.
                  1-12202)).

           *4.4   Indenture, dated as of August 17, 1999, between Northern
                  Border Pipeline Company and Bank One Trust Company, NA,
                  successor to The First National Bank of Chicago, as trustee.
                  (incorporated by reference to Exhibit No. 4.1 to Northern
                  Border Pipeline Company's Form S-4 Registration Statement
                  filed on October 7, 1999, Registration No. 333-88577 ("NB Form
                  S-4")).

           *4.5   Indenture, dated as of September 17, 2001, between Northern
                  Border Pipeline Company and Bank Trust Company, N.A.
                  (incorporated by reference to Exhibit 4.2 to Northern Border
                  Pipeline Company's Registration Statement on Form S-4 filed on
                  November 13, 2001, Registration No. 333-73282 ("2001 NB Form
                  S-4")).


  *4.6   Indenture, dated as of April 29, 2002, between Northern Border
         Pipeline Company and Bank One Trust Company, N.A.
         (incorporated by reference to Exhibit 4.1 to Northern Border
         Pipeline Company's Form 10-Q for the quarter ended March 31,
         2002 (File No. 333-88577)).

 *10.1   Northern Border Pipeline Company General Partnership Agreement
         between Northern Plains Natural Gas Company, Northwest Border
         Pipeline Company, Pan Border Gas Company, TransCanada Border
         Pipeline Ltd. and TransCan Northern Ltd., effective March 9,
         1978, as amended (incorporated by reference to Exhibit 10.2 to
         Form S-1).

 *10.2   Form of Seventh Supplement Amending Northern Border Pipeline
         Company General Partnership Agreement (incorporated by
         reference to Exhibit 10.15 to Form S-1).

 *10.3   Eighth Supplement Amending Northern Border Pipeline Company
         General Partnership Agreement (incorporated by reference to
         Exhibit 10.15 to NB Form S-4).

 *10.4   Ninth Supplement Amending Northern Border Pipeline Company
         General Partnership Agreement (incorporated by reference to
         Exhibit 10.37 to 2001 NB Form S-4).

 *10.5   Tenth Supplement Amending Northern Border Pipeline Company
         General Partnership Agreement dated March 2, 2005
         (incorporated by reference to Exhibit 3.5 to Northern Border
         Pipeline's Form 10-K filed on March 11, 2005 (File No.
         333-88577)).

 *10.6   Operating Agreement between Northern Border Pipeline Company
         and Northern Plains Natural Gas Company, dated February 28,
         1980 (incorporated by reference to Exhibit 10.3 to Form S-1).

 *10.7   Administrative Services Agreement between NBP Services
         Corporation, Northern Border Partners, L.P. and Northern
         Border Intermediate Limited Partnership (incorporated by
         reference to Exhibit 10.4 to Form S-1).

 *10.8   Revolving Credit Agreement, dated as of November 24, 2003,
         among Northern Border Partners, L.P., SunTrust Bank, Harris
         Nesbitt Corp., Wachovia Bank, National Association, Citigroup,
         N.A., SunTrust Capital Markets, Inc., and the Lenders (as
         named therein) (incorporated by reference to Exhibit 10.7 to
         the Partnership's Form 10-K for the year ended December 31,
         2003 (File No. 1-12202)).

 *10.9   First Amendment to the Revolving Credit Agreement dated as of
         April 9, 2004 between Northern Border Partners, L.P., SUNTRUST
         BANK and the lenders named therein (incorporated by reference
         to Exhibit 10.1 to the Partnership's Form 10-Q for the quarter
         ended March 31, 2004 (File No. 1-12202)).

*10.10   Second Amendment entered into as of October 25, 2004 to
         Northern Border Partners' Revolving Credit Agreement dated as
         of November 24, 2003 (incorporated by reference to Exhibit
         99.1 to the Partnership's Form 8-K filed on November 5, 2004
         (File No. 1-12202)).

*10.11   Revolving Credit Agreement, dated as of May 16, 2002, among
         Northern Border Pipeline Company, Bank One, NA, Citibank,
         N.A., Bank of Montreal, SunTrust Bank, Wachovia Bank, National
         Association, Banc One Capital Markets, Inc, and Lenders (as
         defined therein) (incorporated by reference to Exhibit 10.1 to
         the Partnership's Current Report on Form 8-K dated June 26,
         2002 (File No. 1-12202)).

*10.12   First Amendment to the Revolving Credit Agreement dated as of
         April 9, 2004 between Northern Border Pipeline Company, Bank
         One, NA and the lenders named therein. (incorporated by
         reference to Exhibit No. 10.1 to Northern Border Pipeline


          Company's Quarterly Report on Form 10-Q for the quarterly
          period ended March 31, 2004 (File No. 333-88577).

 *10.13   Agreement between Northern Plains and Northern Border
          Intermediate Limited Partnership regarding the costs, expenses
          and expenditures arising under the operating agreement between
          Northern Plains and Guardian Pipeline, LLC (incorporated by
          reference to Exhibit 10.3 to the Partnership's Form 10-Q for
          the quarter ended March 31, 2004 (File No. 1-12202)).

+*10.14   Form of Termination Agreement with ONEOK dated as of January
          5, 2005 (incorporated by reference to Exhibit 99.1 to the
          Partnership's Form 8-K filed on January 11, 2005 (File No.
          1-12202)).

+*10.15   ONEOK, Inc. 2005 Supplemental Executive Retirement Plan.
          (incorporated by reference to Exhibit 99.1 to the
          Partnership's Form 8-K filed on January 11, 2005(File No.
          1-12202)).

+*10.16   ONEOK, Inc. Long-Term Incentive Plan (incorporated by
          reference from Exhibit 10(a) to ONEOK's Form 10-K for the year
          ended December 31, 2001 (File No. 1-13643)).

+*10.17   ONEOK, Inc. Form of Restricted Stock Incentive Award
          (incorporated by reference from Exhibit 10.4 to ONEOK's Form
          10-Q for the quarterly period ended September 30, 2004 (File
          No. 1-13643)).

+*10.18   ONEOK, Inc. Form of Performance Shares Award (incorporated by
          reference from Exhibit 10.5 to ONEOK's Form 10-Q for the
          quarterly period ended September 30, 2004 (File No. 1-13643)).

+*10.19   ONEOK, Inc. Employee Non-Qualified Deferred Compensation Plan,
          as amended, dated February 2001 (incorporated by reference to
          Exhibit 10(g) to ONEOK's Form 10-K for the year ended December
          31, 2001 (File No. 1-13643)).

+*10.20   ONEOK, Inc. Annual Officer Incentive Plan (incorporated by
          reference to Exhibit 10(f) to ONEOK's Form 10-K for the year
          ended December 31, 2001 (File No. 1-13643)).

 *10.21   Operating Agreement between Midwestern Gas Transmission
          Company and Northern Plains Natural Gas Company dated as of
          April 1, 2001 (incorporated by reference to Exhibit 10.38 to
          the Partnership's Form 10-K for the year ended December 31,
          2001 (File No. 1-12202)).

 *10.22   Operating Agreement between Viking Gas Transmission Company
          and Northern Plains Natural Gas Company dated as of January
          17, 2003 (incorporated by reference to Exhibit 10.18 to the
          Partnership's Form 10-K for the year ended December 31, 2002
          (File No. 1-12202)).

 *10.23   Northern Border Pipeline Company Agreement among Northern
          Plains Natural Gas Company, Pan Border Gas Company, Northwest
          Border Pipeline Company, TransCanada Border PipeLine Ltd.,
          TransCan Northern Ltd., Northern Border Intermediate Limited
          Partnership, Northern Border Partners, L.P., and the
          Management Committee of Northern Border Pipeline, dated as of
          March 17, 1999 (incorporated by reference to Exhibit 10.21 to
          the Partnership's Form 10-K/A for the year ended December 31,
          1998 (File No. 1-12202) ("1998 10-K")).


 10.24   Northern Border Transition Services Agreement dated November
         17, 2004, by and between ONEOK, Inc. and CCE Holdings, LLC.

  12.1   Statement re computation of ratios.

    21   List of subsidiaries.

  23.1   Consent of KPMG LLP.

  31.1   Rule 13a-14(a)/15d-14(a) certification of principal executive
         officer.

  31.2   Rule 13a-14(a)/15d-14(a) Certification of principal financial
         officer.

  32.1   Section 1350 certification of principal executive officer.

  32.2   Section 1350 certification of principal financial officer.

+*99.1   Northern Border Phantom Unit Plan (incorporated by reference
         to Exhibit 99.1 to Amendment No. 1 to the Partnership's Form
         S-8, Registration No. 333-66949 and Exhibit 99.1 to Northern
         Border Partners, L.P.'s Registration No. 333-72696).

* Indicates exhibits incorporated by reference as indicated; all other exhibits are filed herewith.

+ Management contract, compensatory plan or arrangement.

The total amount of securities of the Partnership authorized under any instrument with respect to long-term debt not filed as an exhibit does not exceed 10% of the total assets of the Partnership and its subsidiaries on a consolidated basis. The Partnership agrees, upon request of the Securities and Exchange Commission, to furnish copies of any or all of such instruments to the

Securities and Exchange Commission.


EXHIBIT 3.1

CERTIFICATE OF LIMITED PARTNERSHIP
OF
NORTHERN BORDER PARTNERS, L.P.

This Certificate of Limited Partnership has been duly executed, is being filed pursuant to 6 Del. C. Section 17-201, and shall be effective immediately upon filing.

1. The name of this limited partnership is "Northern Border Partners, L.P."

2. The address of the registered office is:

Corporation Trust Company
1209 Orange Street
Wilmington, New Castle County, Delaware 19801

The name and address of the registered agent for service of process are:

The Corporation Trust Company Corporation Trust Center
1209 Orange Street
Wilmington, New Castle County, Delaware 19801

3. The name and the business address of each general partner are:

Northern Plains Natural                      Pan Border Gas
Gas Company                                  Company
1111 South 103 Street                        5400 Westheimer Court
Omaha, Nebraska 68124                        Houston, Texas 77056

Northwest Border Pipeline Company
One Williams Center
East Second Street
Tulsa, Oklahoma 74172

                                           NORTHERN PLAINS NATURAL
                                           GAS COMPANY
                                           General Partner

                                           By: /s/ Gary A. McConnell
                                               ---------------------
                                               Gary A. McConnell
                                               Vice President

                                           PAN BORDER GAS COMPANY
                                           General Partner

                                           By: /s/ George L.Mazanec
                                               ---------------------
                                               George L.Mazanec
                                               Vice President

                                           NORTHWEST BORDER PIPELINE
                                           COMPANY
                                           General Partner

                                           By: /s/ G. L. Best
                                               ---------------------
                                               G. L. Best
                                               Vice President

                                           Date: July 12, 1993

                                               STATE OF DELAWARE
                                              SECRETARY OF STATE
                                           DIVISION OF CORPORATIONS
                                           FILED 09:00 AM 02/27/2001
                                              010101868 - 234348O

CERTIFICATE OF AMENDMENT

TO

CERTIFICATE OF LIMITED PARTNERSHIP

OF

NORTHERN BORDER PARTNERS, L.P.

Northern Border Partners, L.P. (hereinafter called the "partnership"), a limited partnership organized under the Delaware Revised Uniform Limited Partnership Act (the "Act"), for the purpose of amending Certificate of Limited Partnership filed with the office of the Secretary of State of Delaware on July 13,1993, hereby certifies that:

1. The name of the limited partnership is Northern Border Partners, L.P.

2. Pursuant to the provisions of Section 17-202, Title 6, Delaware Code, the amendment to the Certificate of Limited partnership effected by this Certificate of Amendment is to change the address of the registered office of the partnership in the State of Delaware to 9 East Loockerman Street, Dover, Delaware 19901, and to change the name of the registered agent of the partnership in the State of Delaware at the said address to National Registered Agents, Inc.

The undersigned, a general partner of the partnership, executes this Certificate of Amendment on February 16, 2001.

Northern Plains Natural Gas Company General Partner

/s/ Geneva K. Holland
--------------------------------------
Geneva K. Holland, Assistant Secretary


CERTIFICATE OF AMENDMENT

TO

CERTIFICATE OF LIMITED PARTNERSHIP

OF

NORTHERN BORDER PARTNERS, LP.

NORTHERN BORDER PARTNERS, LP. (hereinafter called the "partnership"), a limited partnership organized under the Delaware Revised Uniform Limited Partnership Act (the "Act"), for the purpose of amending the Certificate of Limited Partnership filed with the office of the Secretary of State of Delaware on July 13, 1993, hereby certifies that:

1. The name of the limited partnership is Northern Border Partners, LP.

2. Pursuant to provisions of Section 17-202, Title 6, Delaware Code, the Certificate of Limited Partnership is amended as follows:

The name and business address of each general partner are:

Northern Plains Natural Gas Company 13710 FNB Parkway
Omaha, NE 68154-5200

Northwest Border Pipeline Company c/o TransCanada PipeLines Limited 450 - 1st Street S.W.

Calgary, Alberta
T2P 5H1

Pan Border Gas Company
13710 FNB Parkway
Omaha, NE 68154-5200

The undersigned, an authorized officer of a general partner of the partnership, executed this Certificate of Amendment on May 20, 2003.

NORTHERN PLAINS NATURAL GAS
COMPANY, General Partner

/s/ Lori Pinder-Metz
-------------------------------------
Lori Pinder-Metz, Assistant Secretary


EXHIBIT 3.2

AMENDED AND RESTATED AGREEMENT

OF

LIMITED PARTNERSHIP

OF

NORTHERN BORDER PARTNERS, L.P.


TABLE OF CONTENTS

                        ARTICLE I
              ORGANIZATIONAL MATTERS..........          1
1.1 Formation and Continuation................          1
1.2 Name......................................          1
1.3 Registered Office; Principal Office.......          1
1.4 Power of Attorney.........................          2
1.5 Term......................................          3
1.6 Possible Restrictions on Transfer.........          3

                       ARTICLE II
             DEFINITIONS......................          3
"Additional Limited Partner"..................          3
"Adjusted Capital Account"....................          4
"Adjusted Property"...........................          4
"Administrative Services Agreement"...........          4
"Affiliate"...................................          4
"Agreed Allocation"...........................          4
"Agreed Value"................................          4
"Agreement"...................................          5
"Arbitrator"..................................          5
"Assignee"....................................          5
"Audit Committee".............................          5
"Authorized Officer"..........................          5
"Available Cash"..............................          5
"Book-Tax Disparity"..........................          6
"Business Day"................................          6
"Buyout Price"................................          6
"Buyout Event"................................          6
"Capital Account".............................          7
"Capital Additions and Improvements"..........          7
"Capital Contribution"........................          7
"Carrying Value"..............................          7
"Cash from Interim Capital Transactions"......          7
"Cash from Operations"........................          7
"Cause".......................................          9
"Certificate".................................          9
"Certificate of Limited Partnership"..........          9
"Citizenship Certification"...................          9
"Closing Date"................................          9
"Closing Price"...............................          9
"Code"........................................          9
"Combined Interest"...........................          9
"Commission"..................................          9
"Common Unit".................................          9
"Common Unit Arrearage".......................          9
"Contributed Property"........................         10
"Conveyance Agreement"........................         10
"Credit Agreement"............................         10

ii

"Cumulative Common Unit Arrearage"......................    10
"Curative Allocation"...................................    10
"Current Market Price"..................................    10
"Delaware Act"..........................................    10
"Departing Partner".....................................    10
"Economic Risk of Loss".................................    10
"Eligible Citizen"......................................    10
"Enron".................................................    10
"Event of Withdrawal"...................................    10
"First Liquidation Target Amount".......................    11
"First Target Distribution".............................    11
"General Partners"......................................    11
"General Partner Percentage Interest"...................    11
"Gross General Partner Percentage Interest".............    11
"Group".................................................    11
"Hypothetical Equity Value".............................    11
"Incentive Distribution"................................    11
"Indemnified Persons"...................................    12
"Indemnitee"............................................    12
"Indemnity Agreement"...................................    12
"Initial Common Units"..................................    12
"Initial Limited Partners"..............................    12
"Initial Offering"......................................    12
"Initial Unit Price"....................................    12
"Interim Capital Transactions"..........................    12
"Intermediate Partnership"..............................    12
"Intermediate Partnership Agreement"....................    13
"Issue Price"...........................................    13
"Limited Partner".......................................    13
"Liquidation Date"......................................    13
"Liquidator"............................................    13
"Maintenance Capital Expenditures"......................    13
"Merger Agreement"......................................    13
"Minimum Quarterly Distribution"........................    13
"National Securities Exchange"..........................    13
"Net Agreed Value"......................................    14
"Net Income"............................................    14
"Net Loss"..............................................    14
"Net Termination Gain"..................................    14
"Net Termination Loss"..................................    14
"Non-citizen Assignee"..................................    15
"Nonrecourse Built-in Gain".............................    15
"Nonrecourse Deductions"................................    15
"Nonrecourse Liability".................................    15
"Northern Border Interim Capital Transactions"..........    15
"Northern Border Pipeline"..............................    15
"Northern Border Pipeline Partnership Agreement"........    15
"Northern Border Termination Capital Transactions"......    15
"Northern Plains".......................................    15
"Northwest Border"......................................    15

iii

"Notice of Election to Purchase" .............    15
"Opinion of Counsel" .........................    16
"Organizational Limited Partner" .............    16
"Outstanding" ................................    16
"Overallotment Option" .......................    16
"Pan Border" .................................    16
"Panhandle" ..................................    16
"Partner Nonrecourse Debt" ...................    16
"Partner Non-recourse Debt Minimum Gain"......    16
"Partner Non-recourse Deductions" ............    16
"Partners" ...................................    16
"Partnership" ................................    16
"Partnership Interest" .......................    16
"Partnership Minimum Gain" ...................    16
"Partnership Policy Committee" ...............    17
"Partnership Securities" .....................    17
"Per Unit Capital Amount" ....................    17
"Percentage Interest" ........................    17
"Person" .....................................    17
"Pipeline System" ............................    17
"Purchase Date" ..............................    17
"Recapture Income" ...........................    17
"Record Date" ................................    17
"Record Holder" ..............................    17
"Redeemable Units" ...........................    17
"Registration Statement" .....................    17
"Required Allocations" .......................    18
"Residual Gain" ..............................    18
"Residual Loss" ..............................    18
"Second Liquidation Target Amount" ...........    18
"Second Target Distribution" .................    18
"Securities Act" .............................    18
"Special Approval" ...........................    18
"Subordinated Unit" ..........................    18
"Subordination Period" .......................    18
"Substituted Limited Partner" ................    19
"Surviving Business Entity" ..................    19
"Termination Capital Transactions" ...........    19
"Third Target Distribution" ..................    19
"Trading Day" ................................    19
"Transfer Agent" .............................    19
"Transfer Application" .......................    19
"Underwriter" ................................    20
"Underwriting Agreement" .....................    20
"Unit" .......................................    20
"Unpaid MQD" .................................    20
"Unrealized Gain" ............................    20
"Unrealized Loss" ............................    20
"Unrecovered Initial Unit Price" .............    20
"Unrecovered Subordinated Unit Capital" ......    20

iv

"Williams".................................................................    21
"Withdrawal Opinion of Counsel"............................................    21

                                   ARTICLE III
                                    PURPOSE................................    21
3.1 Purpose and Business...................................................    21
3.2 Powers.................................................................    21

                                   ARTICLE IV
                            CAPITAL CONTRIBUTIONS..........................    21
4.1 Contributions by the General Partners..................................    21
4.2 Issuances of Additional Units and Other Securities.....................    22
4.3 Limited Preemptive Rights..............................................    23
4.4 Capital Accounts.......................................................    23
4.5 Interest...............................................................    26
4.6 No Withdrawal..........................................................    26
4.7 Loans from Partners....................................................    26
4.8 No Fractional Units....................................................    26
4.9 Splits and Combinations................................................    26

                                    ARTICLE V
                        ALLOCATIONS AND DISTRIBUTIONS......................    27
5.1 Allocations for Capital Account Purposes...............................    27
    (a) Net Income.........................................................    27
    (b) Net Losses.........................................................    28
    (c) Net Termination Gains and Losses...................................    28
    (d) Special Allocations................................................    30
        (i)   Partnership Minimum Gain Chargeback..........................    30
        (ii)  Chargeback of Partner Nonrecourse Debt Minimum Gain..........    30
        (iii) Priority Allocations.........................................    31
        (iv)  Qualified Income Offset......................................    31
        (v)   Gross Income Allocations.....................................    31
        (vi)  Nonrecourse Deductions.......................................    31
        (vii) Partner Nonrecourse Deductions...............................    32
        (viii)Nonrecourse Liabilities......................................    32
        (ix)  Code Section 754 Adjustments.................................    32
        (x)   Economic Uniformity..........................................    32
        (xi)  Curative Allocation..........................................    33
5.2 Allocations for Tax Purposes...........................................    33
5.3 Requirement and Characterization of Distributions......................    35
5.4 Distributions of Cash from Operations..................................    36
5.5 Distributions of Cash from Interim Capital Transactions................    37
5.6 Adjustment of Minimum Quarterly Distribution and Target Distribution
    Levels.................................................................    37
5.7 Special Provisions Relating to the Subordinated Units..................    37

                                   ARTICLE VI
                       MANAGEMENT AND OPERATION OF BUSINESS................    38
6.1 Partnership Policy Committee...........................................    38
6.2 Management.............................................................    41

v

6.3  Certificate of Limited Partnership.........................................    42
6.4  Restrictions on the Partnership Policy Committee's Authority...............    43
6.5  Reimbursement of the General Partners and the Partnership Policy
     Committee..................................................................    44
6.6  Outside Activities.........................................................    44
6.7  Loans to and from the General Partners; Contracts with Affiliates..........    45
6.8  Indemnification............................................................    47
6.9  Liability of Indemnitees...................................................    48
6.10 Resolution of Conflicts of Interest........................................    49
6.11 Other Matters Concerning the General Partners and the Partnership Policy
     Committee..................................................................    50
6.12 Title to Partnership Assets................................................    51
6.13 Purchase or Sale of Units..................................................    51
6.14 Registration Rights of Certain Persons.....................................    51
6.15 Reliance by Third Parties..................................................    54

                                   ARTICLE VII
                RIGHTS AND OBLIGATIONS OF LIMITED PARTNERS......................    55
7.1  Limitation of Liability....................................................    55
7.2  Management of Business.....................................................    55
7.3  Outside Activities.........................................................    55
7.4  Return of Capital..........................................................    55
7.5  Rights of Limited Partners Relating to the Partnership.....................    55

                                  ARTICLE VIII
                     BOOKS, RECORDS, ACCOUNTING AND REPORTS.....................    56
8.1  Records and Accounting.....................................................    56
8.2  Fiscal Year................................................................    57
8.3  Reports....................................................................    57

                                   ARTICLE IX
                                  TAX MATTERS...................................    57
9.1  Preparation of Tax Returns.................................................    57
9.2  Tax Elections..............................................................    57
9.3  Tax Controversies..........................................................    57
9.4  Organizational Expenses....................................................    58
9.5  Withholding................................................................    58
9.6  Entity Level-Taxation......................................................    58
9.7  Entity Level-Arrearage Collections.........................................    58
9.8  Opinions of Counsel........................................................    59

                                    ARTICLE X
                                   CERTIFICATES.................................    59
10.1 Certificates...............................................................    59
10.2 Registration, Registration of Transfer and Exchange........................    59
10.3 Mutilated, Destroyed, Lost or Stolen Certificates..........................    60
10.4 Record Holder..............................................................    60

                                   ARTICLE XI
                             TRANSFER OF INTERESTS..............................    61

vi

11.1  Transfer............................................................    61
11.2  Transfer of a General Partner's Partnership Interest................    61
11.3  Transfer of Units...................................................    62
11.4  Restrictions on Transfers...........................................    62
11.5  Citizenship Certificates; Non-citizen Assignees.....................    62
11.6  Redemption of interests.............................................    63
11.7  Right to Make Offer; Preferential Purchase Right; Buyout Right......    64

                                   ARTICLE XII
                             ADMISSION OF PARTNERS........................    65
12.1  Admission of General Partners and Underwriters as Limited Partners..    65
12.2  Admission of Substituted Limited Partners...........................    65
12.3  Admission of Successor General Partner..............................    66
12.4  Admission of Additional Limited Partners............................    66
12.5  Amendment of Agreement and Certificate of Limited Partnership.......    66

                                  ARTICLE XIII
                       WITHDRAWAL OR REMOVAL OF PARTNERS..................    66
13.1  Withdrawal of a General Partner.....................................    66
13.2  Removal of a General Partner........................................    68
13.3  Interest of Departing Partner and Successor General Partner.........    68
13.4  Withdrawal of Limited Partners......................................    69

                                   ARTICLE XIV
                           DISSOLUTION AND LIQUIDATION....................    70
14.1  Dissolution.........................................................    70
14.2  Continuation of the Business of the Partnership after Dissolution...    70
14.3  Liquidation.........................................................    71
14.4  Distributions in Kind...............................................    72
14.5  Cancellation of Certificate of Limited Partnership..................    72
14.6  Reasonable Time for Winding Up......................................    72
14.7  Return of Capital...................................................    73
14.8  No Capital Account Restoration......................................    73
14.9  Waiver of Partition.................................................    73

                                   ARTICLE XV
                       AMENDMENT OF PARTNERSHIP AGREEMENT;
                             MEETINGS; RECORD DATE........................    73
15.1  Amendment to be Adopted Solely by Partnership Policy Committee......    73
15.2  Amendment Procedures................................................    74
15.3  Amendment Requirements..............................................    74
15.4  Meetings............................................................    75
15.5  Notice of a Meeting.................................................    75
15.6  Record Date.........................................................    75
15.7  Adjournment.........................................................    76
15.8  Waiver of Notice; Approval of Meeting; Approval of Minutes..........    76
15.9  Quorum..............................................................    76
15.10 Conduct of Meeting..................................................    76
15.11 Action Without a Meeting............................................    77
15.12 Voting and Other Rights.............................................    77

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                                  ARTICLE XVI
                                    MERGER.....................    78
16.1  Authority................................................    78
16.2  Procedure for Merger or Consolidation....................    78
16.3  Approval by Limited Partners of Merger or Consolidation..    79
16.4  Certificate of Merger....................................    79
16.5  Effect of Merger.........................................    79

                                  ARTICLE XVII
                             RIGHT TO ACQUIRE UNITS............    80
17.1 Right to Acquire Units....................................    80

                                 ARTICLE XVIII
                               GENERAL PROVISIONS..............    81
18.1  Addresses and Notices....................................    81
18.2  References...............................................    82
18.3  Pronouns and Plurals.....................................    82
18.4  Further Action...........................................    82
18.5  Binding Effect...........................................    82
18.6  Integration..............................................    82
18.7  Creditors................................................    82
18.8  Waiver...................................................    82
18.9  Counterparts.............................................    82
18.10 Applicable Law...........................................    82
18.11 Invalidity of Provisions.................................    83

Exhibit A - Form of Certificate Evidencing Common Units

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AMENDED AND RESTATED AGREEMENT OF LIMITED PARTNERSHIP OF
NORTHERN BORDER PARTNERS, L.P.

THIS AMENDED AND RESTATED AGREEMENT OF LIMITED PARTNERSHIP OF NORTHERN BORDER PARTNERS, L.P., dated as of October 1, 1993, is entered into by and among Northern Plains Natural Gas Company, a Delaware corporation, Pan Border Gas Company, a Delaware corporation, and Northwest Border Pipeline Company, a Delaware corporation, each in its capacity as a General Partner, and Northwest Border Pipeline Company, a Delaware corporation, in its capacity as the Organizational Limited Partner, together with any other Persons who become Partners in the Partnership or parties hereto as provided herein. In consideration of the covenants, conditions and agreements contained herein, the parties hereto hereby agree as follows:

ARTICLE I
ORGANIZATIONAL MATTERS

1.1 FORMATION AND CONTINUATION. (a) The General Partners and the Organizational Limited Partner have previously formed the Partnership as a limited partnership pursuant to the provisions of the Delaware Act and hereby amend and restate the original Agreement of Limited Partnership of Northern Border Partners, L.P., as previously amended, in its entirety. Subject to the provisions of this Agreement, the General Partners and the Organizational Limited Partner hereby continue the Partnership as a limited partnership pursuant to the provisions of the Delaware Act. Except as expressly provided to the contrary in this Agreement, the rights and obligations of the Partners and the administration, dissolution and termination of the Partnership shall be governed by the Delaware Act. All Partnership Interests shall constitute personal property of the owner thereof for all purposes.

(b) In connection with the formation of the Partnership, Northern Plains, Pan Border and Northwest Border have been admitted as general partners of the Partnership (each owning a general partner interest in the Partnership equal to its General Partner Percentage Interest), and the Organizational Limited Partner has been admitted as a limited partner of the Partnership. As of the Closing Date, after giving effect to the transactions contemplated by Section 4.1, the interest in the Partnership of the Organizational Limited Partner shall be terminated and the Organizational Limited Partner shall withdraw as a limited partner of the Partnership.

1.2 NAME. The name of the Partnership shall be "Northern Border Partners, L.P." The Partnership's business may be conducted under any other name or names deemed necessary or appropriate by the Partnership Policy Committee. The words "Limited Partnership," "L.P.," "Ltd." or similar words or letters shall be included in the Partnership's name where necessary for the purposes of complying with the laws of any jurisdiction that so requires. The Partnership Policy Committee in its sole discretion may change the name of the Partnership at any time and from time to time and shall notify the Limited Partners of such change in the next regular communication to Limited Partners.

1.3 REGISTERED OFFICE; PRINCIPAL OFFICE. Unless and until changed by the Partnership Policy Committee, the registered office of the Partnership in the State of Delaware shall be located at The Corporation Trust Center, 1209 Orange Street, New Castle County, Wilmington, Delaware 19801, and the registered agent for service of process on the Partnership in the State of Delaware

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at such registered office shall be The Corporation Trust Company. The principal office of the Partnership shall be located at 1400 Smith Street, Houston, Texas 77002, or such other place as the Partnership Policy Committee may from time to time designate by notice to the Limited Partners. The Partnership may maintain offices at such other place or places within or outside the State of Delaware as the Partnership Policy Committee deems necessary or appropriate.

1.4 POWER OF ATTORNEY. (a) Each Limited Partner and each Assignee hereby constitutes and appoints each Authorized Officer and, if a Liquidator shall have been selected pursuant to Section 14.3, the Liquidator severally (and any successor to the Liquidator by merger, transfer, assignment, election or otherwise) and each authorized officer and attorney-in-fact of the Liquidator, with full power of substitution, as his true and lawful agent and attorney-in-fact, with full power and authority in his name, place and stead, to:

(i) execute, swear to, acknowledge, deliver, file and record in the appropriate public offices (A) all certificates, documents and other instruments (including, without limitation, this Agreement and the Certificate of Limited Partnership and all amendments or restatements thereof) that the Partnership Policy Committee or the Liquidator deems necessary or appropriate to form, qualify or continue the existence or qualification of the Partnership as a limited partnership (or a partnership in which the limited partners have limited liability) in the State of Delaware and in all other jurisdictions in which the Partnership may conduct business or own property; (B) all certificates, documents and other instruments that the Partnership Policy Committee or the Liquidator deems necessary or appropriate to reflect, in accordance with its terms, any amendment, change, modification or restatement of this Agreement; (C) all certificates, documents and other instruments (including, without limitation, conveyances and a certificate of cancellation) that the Partnership Policy Committee or the Liquidator deems necessary or appropriate to reflect the dissolution and liquidation of the Partnership pursuant to the terms of this Agreement; (D) all certificates, documents and other instruments relating to the admission, withdrawal, removal or substitution of any Partner pursuant to, or other events described in, Article XI, XII, XIII or XIV or the Capital Contribution of any Partner; (E) all certificates, documents and other instruments relating to the determination of the rights, preferences and privileges of any class or series of Units or other Partnership Securities issued pursuant to Section 4.2; and (F) all certificates, documents and other instruments (including, without limitation, agreements and a certificate of merger) relating to a merger or consolidation of the Partnership pursuant to Article XVI; and

(ii) execute, swear to, acknowledge, deliver, file and record all ballots, consents, approvals, waivers, certificates, documents and other instruments necessary or appropriate, in the sole discretion of the Partnership Policy Committee or the Liquidator, to make, evidence, give, confirm or ratify any vote, consent, approval, agreement or other action that is made or given by the Partners hereunder or is consistent with the terms of this Agreement or is necessary or appropriate, in the sole discretion of the Partnership Policy Committee or the Liquidator, to effectuate the terms or intent of this Agreement; provided, that when required by Section 15.3 or any other provision of this Agreement that establishes a percentage of the Limited Partners or of the Limited Partners of any class or series required to take any action, the Partnership Policy Committee or the Liquidator may exercise the power of attorney made in this Section 1.4(a)(ii) only after the necessary vote, consent or approval of the Limited Partners or of the Limited Partners of such class or series, as applicable.

Nothing contained in this Section 1.4(a) shall be construed as authorizing the Partnership Policy Committee to amend this Agreement except in accordance with Article XV or as may be otherwise expressly provided for in this Agreement.

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(b) The foregoing power of attorney is hereby declared to be irrevocable and a power coupled with an interest, and it shall survive and not be affected by the subsequent death, incompetency, disability, incapacity, dissolution, bankruptcy or termination of any Limited Partner or Assignee and the transfer of all or any portion of such Limited Partner's or Assignee's Partnership Interest and shall extend to such Limited Partner's or Assignee's heirs, successors, assigns and personal representatives. Each such Limited Partner or Assignee hereby agrees to be bound by any representation made by the Partnership Policy Committee or the Liquidator acting in good faith pursuant to such power of attorney; and each such Limited Partner or Assignee hereby waives any and all defenses that may be available to contest, negate or disaffirm the action of the Partnership Policy Committee or the Liquidator taken in good faith under such power of attorney. Each Limited Partner or Assignee shall execute and deliver to the Partnership Policy Committee or the Liquidator, within 15 days after receipt of the Partnership Policy Committee's or the Liquidator's request therefor, such further designation, powers of attorney and other instruments as the Partnership Policy Committee or the Liquidator deems necessary to effectuate this Agreement and the purposes of the Partnership.

1.5 TERM. The Partnership commenced upon the filing of the Certificate of Limited Partnership in accordance with the Delaware Act and shall continue in existence until the close of Partnership business on December 31, 2083, or until the earlier termination of the Partnership in accordance with the provisions of Article XIV.

1.6 POSSIBLE RESTRICTIONS ON TRANSFER. Notwithstanding anything to the contrary contained in this Agreement, in the event of (a) the enactment (or imminent enactment) of any legislation, (b) the publication of any temporary or final regulation by the Treasury Department, (c) any ruling by the Internal Revenue Service or (d) any judicial decision, that, in any such case, in the Opinion of Counsel, would result in the taxation of the Partnership, the Intermediate Partnership or Northern Border Pipeline as an association taxable as a corporation or would otherwise result in the Partnership, the Intermediate Partnership or Northern Border Pipeline being taxed as an entity for federal income tax purposes, then, the Partnership Policy Committee may impose such restrictions on the transfer of Units or Partnership Interests as may be required, in the Opinion of Counsel, to prevent the Partnership, the Intermediate Partnership or Northern Border Pipeline from being taxed as an association taxable as a corporation or otherwise as an entity for federal income tax purposes, including, without limitation, making such amendments to this Agreement as the Partnership Policy Committee in its sole discretion may determine to be necessary or appropriate to impose such restrictions, provided, that any such amendment to this Agreement that would result in the delisting or suspension of trading of any class of Units on any National Securities Exchange on which such class of Units is then traded must be approved by the holders of at least two-thirds of the Outstanding Units of such class (excluding the vote in respect of Units held by the General Partners and their Affiliates).

ARTICLE II
DEFINITIONS

The following definitions shall be for all purposes, unless otherwise clearly indicated to the contrary, applied to the terms used in this Agreement.

"ADDITIONAL LIMITED PARTNER" means a Person admitted to the Partnership as a Limited Partner pursuant to Section 12.4 and who is shown as such on the books and records of the Partnership.

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"ADJUSTED CAPITAL ACCOUNT" means the Capital Account maintained for each Partner as of the end of each fiscal year of the Partnership, (a) increased by any amounts that such Partner is obligated to restore under the standards set by Treasury Regulation Section 1.704-1 (b)(2)(ii)(c) (or is deemed obligated to restore under Treasury Regulation Sections 1.704-2(g) and 1.704-2(i)(5)) and (b) decreased by (i) the amount of all losses and deductions that, as of the end of such fiscal year, are reasonably expected to be allocated to such Partner in subsequent years under Sections 704(e)(2) and 706(d) of the Code and Treasury Regulation Section 1.751-1 (b)(2)(ii), and (ii) the amount of all distributions that, as of the end of such fiscal year, are reasonably expected to be made to such Partner in subsequent years in accordance with the terms of this Agreement or otherwise to the extent they exceed offsetting increases to such Partner's Capital Account that are reasonably expected to occur during (or prior to) the year in which such distributions are reasonably expected to be made (other than increases as a result of a minimum gain chargeback pursuant to Section 5.1
(d)(i) or 5.1 (d)(ii)). The foregoing definition of Adjusted Capital Account is intended to comply with the provisions of Treasury Regulation Section 1.704-1
(b)(2)(ii)(d) and shall be interpreted consistently therewith. The "Adjusted Capital Account" in respect of a Common Unit, a Subordinated Unit or any other specified interest in the Partnership shall be the amount which such Adjusted Capital Account would be if such Common Unit, Subordinated Unit or other interest in the Partnership was the only interest in the Partnership held by a Limited Partner.

"ADJUSTED PROPERTY" means any property the Carrying Value of which has been adjusted pursuant to Section 4.4(d)(i) or 4.4(d)(ii). Once an Adjusted Property is deemed distributed by, and recontributed to, the Partnership for federal income tax purposes upon a termination thereof pursuant to Section 708 of the Code, such property shall thereafter constitute a Contributed Property until the Carrying Value of such property is subsequently adjusted pursuant to
Section 4.4(d)(i) or 4.4(d)(ii).

"ADMINISTRATIVE SERVICES AGREEMENT" means that certain Administrative Services Agreement, dated the Closing Date, among NBP Services Corporation, a Delaware corporation, the Intermediate Partnership and the Partnership.

"AFFILIATE" means, with respect to any Person, any other Person that directly or indirectly controls, is controlled by or is under common control with, the Person in question. As used herein, the term "control" means the possession, directly or indirectly, of the power to direct or cause the direction of the management and policies of a Person, whether through ownership of voting securities, by contract or otherwise.

"AGREED ALLOCATION" means any allocation, other than a Required Allocation, of an item of income, gain, loss or deduction pursuant to the provisions of Section 5.1, including, without limitation, a Curative Allocation (if appropriate to the context in which the term "Agreed Allocation" is used).

"AGREED VALUE" of any Contributed Property means the fair market value of such property or other consideration at the time of contribution as determined by the Partnership Policy Committee using such reasonable method of valuation as it may adopt; provided, however, that the Agreed Value of any property deemed contributed to the Partnership for federal income tax purposes upon termination and reconstitution thereof pursuant to Section 708 of the Code shall be determined in accordance with Section 4.4(c)(i). Subject to Section 4.4(c)(i), the Partnership Policy Committee shall, in its sole discretion, use such method as it deems reasonable and appropriate to allocate the aggregate Agreed Value of

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Contributed Properties contributed to the Partnership in a single or integrated transaction among each separate property on a basis proportional to the fair market value of each Contributed Property.

"AGREEMENT" means this Amended and Restated Agreement of Limited Partnership of Northern Border Partners, L.P., as it may be amended, supplemented or restated from time to time.

"ARBITRATOR" has the meaning assigned to such term in Section 6.1(b)(iii)(A).

"ASSIGNEE" means a Non-citizen Assignee or a Person to whom one or more Units have been transferred in a manner permitted under this Agreement and who has executed and delivered a Transfer Application as required by this Agreement, but who has not become a Substituted Limited Partner.

"AUDIT COMMITTEE" means a committee consisting of two persons appointed by the Partnership Policy Committee who are neither officers nor employees of any General Partner or any of their Affiliates.

"AUTHORIZED OFFICER" means the Chief Executive Officer and the Chief Financial and Accounting Officer and such other officers as may be authorized from time to time by the Partnership Policy Committee to execute contracts, certificates and other instruments on behalf of the Partnership.

"AVAILABLE CASH" means, with respect to any calendar quarter and without duplication:

(a) the sum of:

(i) all cash receipts of the Partnership during such quarter from all sources (including, without limitation, distributions of cash received from the Intermediate Partnership (other than any such distributions that constitute distributions received by the Intermediate Partnership in respect of Northern Border Termination Capital Transactions) and cash proceeds from Interim Capital Transactions, but excluding cash proceeds from Termination Capital Transactions), plus, in the case of the calendar quarter ending December 31, 1993, the cash balance of the Partnership and the Intermediate Partnership as of the close of business on the Closing Date; and

(ii) any reduction in a reserve with respect to such quarter from the level of such reserve at the end of the prior quarter;

(b) less the sum of:

(i) all cash disbursements of the Partnership during such quarter, including, without limitation, disbursements for operating expenses, taxes, if any, debt service (including, without limitation, the payment of principal, premium and interest), capital expenditures and contributions, if any, to the Intermediate Partnership (but excluding all cash distributions to Partners and any cash disbursements with respect to which, and to the extent that, a reserve was established in a prior quarter); and

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(ii) any reserves established with respect to such quarter, and any increase in reserves established with respect to prior quarters, in such amounts as the Partnership Policy Committee determines in its reasonable discretion to be necessary or appropriate (x) to provide for the proper conduct of the business of the Partnership or the Intermediate Partnership, (y) to provide funds for distributions with respect to Units in respect of any one or more of the next four calendar quarters or (z) because the distribution of such amounts would be prohibited by applicable law or by any loan agreement, security agreement, mortgage, debt instrument or other agreement or obligation to which the Partnership or the Intermediate Partnership is a party or by which it is bound or its assets are subject.

Notwithstanding the foregoing, "Available Cash" with respect to any calendar quarter (A) shall not include any cash receipts or reductions in reserves or take into account any disbursements made or reserves established after the Liquidation Date and (B) shall include any distributions of cash (to the extent such distributions are attributable to transactions and operations during such quarter) received by the Partnership from the Intermediate Partnership after the end of such quarter but on or before the date on which the Partnership makes its distribution of Available Cash in respect of such quarter pursuant to Section
5.3. Taxes paid by the Partnership on behalf of, or amounts withheld with respect to, all or less than all of the Partners shall not be considered cash disbursements of the Partnership that reduce Available Cash, but the payment or withholding thereof shall be deemed to be a distribution of Available Cash to such Partners. Alternatively, in the discretion of the Partnership Policy Committee, such taxes (if pertaining to all Partners) may be considered to be cash disbursements of the Partnership which reduce Available Cash, but the payment or withholding thereof shall not be deemed to be a distribution of Available Cash to such Partners (and thus shall not be considered for purposes of determining whether the Partnership has distributed an amount equal to the Minimum Quarterly Distribution for the applicable quarter).

"BOOK-TAX DISPARITY" means with respect to any item of Contributed Property or Adjusted Property, as of the date of any determination, the difference between the Carrying Value of such Contributed Property or Adjusted Property and the adjusted basis thereof for federal income tax purposes as of such date. A Partner's share of the Partnership's Book-Tax Disparities in all of its Contributed Property and Adjusted Property will be reflected by the difference between such Partner's Capital Account balance as maintained pursuant to Section 4.4 and the hypothetical balance of such Partner's Capital Account computed as if it had been maintained strictly in accordance with federal income tax accounting principles.

"BUSINESS DAY" means Monday through Friday of each week, except that a legal holiday recognized as such by the government of the United States or the states of New York or Texas shall not be regarded as a Business Day.

"BUYOUT PRICE" means, as of the date of determination, an amount equal to 110% of the sum of (a) the fair market value of the Combined Interest of the affected General Partner as determined in accordance with the second paragraph of Section 13.3(a), and (b) the product of (i) the number of Subordinated Units owned by the affected General Partner and (ii) the then Current Market Price of a Common Unit.

"BUYOUT EVENT" has the meaning assigned to such term in Section 11.7(c).

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"CAPITAL ACCOUNT" means the capital account maintained for a Partner pursuant to Section 4.4.

"CAPITAL ADDITIONS AND IMPROVEMENTS" Means additions or improvements (whether by acquisition or new construction) to the Pipeline System (as same existed on the Closing Date) or a newly acquired or constructed pipeline system (in each case, including, without limitation, related facilities such as those that increase the throughput, deliverable capacity or storage capacity of the Pipeline System from the throughput, deliverable capacity or storage thereof immediately prior to the making or acquisition of such additions or improvements), irrespective of whether such additions or improvements serve the same or different geographic markets than are served by the Pipeline System immediately prior to the making or acquisition of such additions or improvements.

"CAPITAL CONTRIBUTION" means any cash, cash equivalents or the Net Agreed Value of Contributed Property that a Partner contributes to the Partnership pursuant to the Conveyance Agreement or Sections 4.1, 4.2, 4.4(c)(i) or 13.3(c).

"CARRYING VALUE" means (a) with respect to a Contributed Property, the Agreed Value of such property reduced (but not below zero) by all depreciation, amortization and cost recovery deductions charged to the Partners' and Assignees' Capital Accounts in respect of such Contributed Property, and (b) with respect to any other Partnership property, the adjusted basis of such property for federal income tax purposes, all as of the time of determination. The Carrying Value of any property shall be adjusted from time to time in accordance with Sections 4.4(d)(i) and 4.4(d)(ii) and to reflect changes, additions or other adjustments to the Carrying Value for dispositions and acquisitions of Partnership properties, as deemed appropriate by the Partnership Policy Committee.

"CASH FROM INTERIM CAPITAL TRANSACTIONS" means, at any date, the sum of such amounts of Available Cash as (i) are deemed to be Cash from Interim Capital Transactions pursuant to Section 5.3 and (ii) constitute distributions received by the Intermediate Partnership from Northern Border Pipeline in respect of Northern Border Interim Capital Transactions.

"CASH FROM OPERATIONS" means, at the close of any calendar quarter but prior to the Liquidation Date, on a cumulative basis and without duplication,

(a) the sum of all cash receipts of the Partnership and the Intermediate Partnership during the period since the Closing Date through such date (including, without limitation, (i) the cash balance of the Partnership as of the close of business on the Closing Date, and (ii) cash distributions received by the Intermediate Partnership from Northern Border Pipeline (other than any such distributions in respect of Northern Border Interim Capital Transactions or Northern Border Termination Capital Transactions), but in each case excluding any cash proceeds from any Interim Capital Transactions (except to the extent specified in Section 5.3) and Termination Capital Transactions),

(b) less the sum of:

(i) all cash operating expenditures of the Partnership and the Intermediate Partnership during such period, including, without limitation, taxes, if any, and the Partnership's share of capital contributions made by the

7

Intermediate Partnership to Northern Border Pipeline in respect of the Intermediate Partnership's share of similar expenditures of Northern Border Pipeline,

(ii) all cash debt service payments of the Partnership and the Intermediate Partnership during such period (other than payments or prepayments of principal and premium required by reason of loan agreements (including, without limitation, covenants and default provisions therein) or by lenders, in each case in connection with sales or other dispositions of assets or made in connection with refinancings or refundings of indebtedness, provided, that any payment or prepayment of principal, whether or not then due, shall be deemed, at the election and in the discretion of the Partnership Policy Committee, to be refunded or refinanced by any indebtedness incurred or to be incurred by the Partnership or the Intermediate Partnership simultaneously with or within 180 days prior to or after such payment or prepayment to the extent of the principal amount of such indebtedness so incurred) and the Partnership's share of capital contributions made by the Intermediate Partnership to Northern Border Pipeline in respect of the Intermediate Partnership's share of any such payments made by Northern Border Pipeline,

(iii) all cash capital expenditures of the Partnership and the Intermediate Partnership during such period, and the Partnership's share of any capital contributions made by the Intermediate Partnership to Northern Border Pipeline in respect of the Intermediate Partnership's share of any cash capital expenditures of Northern Border Pipeline during such period, including, without limitation, cash capital expenditures made, or the Partnership's share of capital contributions to Northern Border Pipeline, in respect of Maintenance Capital Expenditures, but excluding (A) cash capital expenditures made, or the Partnership's share of capital contributions to Northern Border Pipeline, in respect of Capital Additions and Improvements and (B) cash expenditures made in payment of transaction expenses relating to Interim Capital Transactions,

(iv) an amount equal to revenues, if any, collected by the Intermediate Partnership (or by Northern Border Pipeline to the extent same are distributed to the Intermediate Partnership) as a result of transportation rate increases that are subject to possible refund,

(v) any reserves outstanding as of such date that the Partnership Policy Committee deems in its reasonable discretion to be necessary or appropriate to provide for the future cash payment of, or future capital contributions to Northern Border Pipeline with respect to, items of the type referred to in clauses (i) through
(iv) of this sentence, and

(vi) any reserves that the Partnership Policy Committee deems in its reasonable discretion to be necessary or appropriate to provide funds for distributions with respect to Units in respect of any one or more of the next four calendar quarters,

all as determined on a consolidated basis and after taking into account the interest of each of the General Partners therein attributable to their general partner interest in the Intermediate

8

Partnership. Where cash capital expenditures, or capital contributions by the Intermediate Partnership, are made in part in respect of Capital Additions and Improvements and in part for other purposes, the Partnership Policy Committee's good faith allocation thereof between the portion made for Capital Additions and Improvements and the portion made for other purposes shall be conclusive.

"CAUSE" means a court of competent jurisdiction has entered a final, non-appealable judgment finding a General Partner liable for actual fraud, gross negligence or willful or wanton misconduct in its capacity as general partner of the Partnership.

"CERTIFICATE" means a certificate, substantially in the form of Exhibit A to this Agreement or in such other forms as may be adopted by the Partnership Policy Committee in its sole discretion, issued by the Partnership evidencing ownership of one or more Common Units, or a certificate, in such form as may be adopted by the Partnership Policy Committee in its sole discretion, issued by the Partnership evidencing ownership of one or more other Units.

"CERTIFICATE OF LIMITED PARTNERSHIP" means the Certificate of Limited Partnership filed with the Secretary of State of the State of Delaware as referenced in Section 6.3, as such Certificate of Limited Partnership may be amended, supplemented or restated from time to time.

"CITIZENSHIP CERTIFICATION" means a properly completed certificate in such form as may be specified by the Partnership Policy Committee by which an Assignee or a Limited Partner certifies that he (and if he is a nominee holding for the account of another Person, that to the best of his knowledge such other Person) is an Eligible Citizen.

"CLOSING DATE" means the first date on which Common Units are sold by Northern Plains and Pan Border to the Underwriters pursuant to the provisions of the Underwriting Agreement.

"CLOSING PRICE" has the meaning assigned to such term in Section 17.1(a).

"CODE" means the Internal Revenue Code of 1986, as amended and in effect from time to time, as interpreted by the applicable regulations thereunder. Any reference herein to a specific section or sections of the Code shall be deemed to include a reference to any corresponding provision of future law.

"COMBINED INTEREST" has the meaning assigned to such term in Section 13.3(a).

"COMMISSION" means the Securities and Exchange Commission.

"COMMON UNIT" means a Unit representing a fractional part of the Partnership Interests of all Limited Partners and Assignees and having the rights and obligations specified with respect to Common Units in this Agreement.

"COMMON UNIT ARREARAGE" means, with respect to any Common Unit, whenever issued, and as to any calendar quarter within the Subordination Period, the excess, if any, of (a) the Minimum Quarterly Distribution with respect to such Common Unit over (b) the sum of all Available Cash distributed with respect to such Common Unit in respect of such quarter pursuant to Section 5.4(a).

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"CONTRIBUTED PROPERTY" means each property or other asset, in such form as may be permitted by the Delaware Act, but excluding cash, contributed to the Partnership (or deemed contributed to the Partnership on termination and reconstitution thereof pursuant to Section 708 of the Code). Once the Carrying Value of a Contributed Property is adjusted pursuant to Section 4.4(d), such property shall no longer constitute a Contributed Property, but shall be deemed an Adjusted Property.

"CONVEYANCE AGREEMENT" means the Conveyance, Contribution and Assumption Agreement dated as of the Closing Date, among the Partnership, the Intermediate Partnership, Northern Plains, Pan Border and Northwest Border.

"CREDIT AGREEMENT" means the Credit Agreement dated as of October 1, 1993, among the Intermediate Partnership, as Borrower, Northern Plains, Pan Border and Northwest Border, as Lenders, and NB Services Corporation, as agent for the Lenders.

"CUMULATIVE COMMON UNIT ARREARAGE" means, with respect to any Common Unit, whenever issued, and as of the end of any calendar quarter, the excess, if any, of (a) the sum resulting from adding together the Common Unit Arrearage as to such Common Unit for each of the quarters within the Subordination Period ending on or before the last day of such quarter over (b) the sum of any distributions theretofore made pursuant to Section 5.4(b) with respect to such Common Unit (including any distributions to be made in respect of the last of such quarters).

"CURATIVE ALLOCATION" means any allocation of an item of income, gain, deduction, loss or credit pursuant to the provisions of Section 5.1(d)(xi).

"CURRENT MARKET PRICE" has the meaning assigned to such term in Section 17.1(a).

"DELAWARE ACT" means the Delaware Revised Uniform Limited Partnership Act, 6 Del C. Section 17-101, et seq., as amended, supplemented or restated from time to time, and any successor to such statute.

"DEPARTING PARTNER" means a General Partner with respect to which an Event of Withdrawal of the type described in Section 13.1 has occurred.

"ECONOMIC RISK OF LOSS" has the meaning set forth in Treasury Regulation
Section 1.752-2(a).

"ELIGIBLE CITIZEN" means a Person qualified to own interests in real property in jurisdictions in which the Partnership, the Intermediate Partnership or Northern Border Pipeline does business or proposes to do business from time to time, and whose status as a Limited Partner or Assignee does not or would not subject the Partnership, the Intermediate Partnership or Northern Border Pipeline to a substantial risk of cancellation or forfeiture of any of its properties or any interest therein.

"ENRON" means Enron Corp., a Delaware corporation.

"EVENT OF WITHDRAWAL" has the meaning assigned to such term in Section 13.1(a).

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"FIRST LIQUIDATION TARGET AMOUNT" has the meaning assigned to such term in
Section 5.1(c)(i)(D).

"FIRST TARGET DISTRIBUTION" means $0.605 per Unit (or, with respect to the period commencing on the Closing Date and ending on December 31,1993, the product of $0.605 multiplied by a fraction of which the numerator is the number of days in such period and of which the denominator is 92), subject to adjustment in accordance with Sections 5.6 and 9.6.

"GENERAL PARTNERS" means Northern Plains, Pan Border and Northwest Border, as the initial general partners of the Partnership, and any Person or Persons that either (i) acquires the general partner interest of such Person in the Partnership pursuant to and in accordance with the terms of Section 11.2 or (ii) is approved as a successor General Partner pursuant to Section 13.1 or 13.2 and, in either case, is admitted to the Partnership as a general partner in accordance with the terms of Section 12.3.

"GENERAL PARTNER PERCENTAGE INTEREST" means (a) as to Northern Plains and its permitted successors and assigns, 0.50%, (b) as to Pan Border and its permitted successors and assigns, 0.325%, and (c) as to Northwest Border and its permitted successors and assigns, 0.175%.

"GROSS GENERAL PARTNER PERCENTAGE INTEREST" means, with respect to a Departing Partner, an amount equal to the sum of (a) the product of such Departing Partner's General Partner Percentage Interest (expressed as a decimal) and .9899 and (b) such Departing Partner's general partner percentage interest in the Intermediate Partnership. By way of example, if Northern Plains were the Departing Partner, its Gross General Partner Percentage Interest would be equal to .01 ((.005 x .9899) + .0050505).

"GROUP" means a "group" of Persons as defined in Section 13(d)(3) of the Securities Exchange Act of 1934, as amended, and the rules and regulations of the Commission promulgated thereunder.

"HYPOTHETICAL EQUITY VALUE" means, as of the date of determination, an amount equal to the product obtained from the following formula:

1.0101 x [TCUO] x [1/PCU] x CMP

where such symbols have the following meanings as of the date of determination:
(a) "TCUO" means the total number of Common Units Outstanding, (b) "PCU" means the product, expressed as a decimal, of (i) the total number of Common Units Outstanding divided by the total number of Units Outstanding and (ii) .9899 and
(c) CMP means the Current Market Price as of such date (as such term is defined in Section 17.1 (a)). By way of example, if the Current Market Price is $22.50 and the Overallotment Option is not exercised, then the Hypothetical Equity Value is equal to $601,529,396.91 (1.0101 x 17,200,000 x (1/(17,200,000/26,200,000 X .9899)) X $22.50.

"INCENTIVE DISTRIBUTION" means any amount of cash distributed to the General Partners, in their capacity as general partners of the Partnership, pursuant to Sections 5.4(e), 5.4(f) or 5.4(g) that exceeds that amount equal to 1% of the aggregate amount of cash then being distributed pursuant to such provisions.

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"INDEMNIFIED PERSONS" has the meaning assigned to such term in Section 6.14(h).

"INDEMNITEE" means any General Partner, any member of the Partnership Policy Committee, any Departing Partner, any Person who is or was an Affiliate of any General Partner or any Departing Partner, any Person who is or was an officer, director, employee, partner, agent or trustee of any General Partner, the Partnership or any Departing Partner or any such Affiliate, or any Person who is or was serving at the request of any General Partner, the Partnership Policy Committee or any Departing Partner or any such Affiliate as a director, officer, employee, partner, agent or trustee of another Person.

"INDEMNITY AGREEMENT" means the Indemnity Agreement dated as of September 23, 1993 among Northern Plains, Pan Border and Northwest Border.

"INITIAL COMMON UNITS" means any Common Units received by Northwest Border on the Closing Date pursuant to Section 4.1 or in connection with the exercise by the Underwriters of the Overallotment Option pursuant to Section 5.7.

"INITIAL LIMITED PARTNERS" means the General Partners (with respect to the Common Units and Subordinated Units received by them pursuant to Section 4.1) and the Underwriters, in each case upon being admitted to the Partnership in accordance with Section 12.1.

"INITIAL OFFERING" means the initial offering and sale of Common Units to the public, as described in the Registration Statement.

"INITIAL UNIT PRICE" means the initial price per Common Unit at which the Underwriters offered the Common Units to the public for sale as set forth on the cover page of the prospectus first issued at or after the time the Registration Statement first became effective and, with respect to any other class or series of Units, the price per unit at which such class or series of Units is initially sold by the Partnership, as determined by the Partnership Policy Committee, in each case adjusted as the Partnership Policy Committee determines to be appropriate to give effect to any distribution, subdivision or combination of Units.

"INTERIM CAPITAL TRANSACTIONS" means (a) borrowings, refinancings or refundings of indebtedness and sales of debt securities (other than for working capital purposes and other than for items purchased on open account in the ordinary course of business) by the Partnership or the Intermediate Partnership,
(b) sales of equity interests (other than sales of Common Units by the Underwriters pursuant to the exercise of the Overallotment Option) by the Partnership or the Intermediate Partnership and (c) sales or other voluntary or involuntary dispositions of any assets of the Partnership or the Intermediate Partnership (other than (x) sales or other dispositions of inventory in the ordinary course of business, (y) sales or other dispositions of other current assets including, without limitation, receivables and accounts and (z) sales or other dispositions of assets as a part of normal retirements or replacements), in each case prior to the commencement of the dissolution and liquidation of the Partnership.

"INTERMEDIATE PARTNERSHIP" means Northern Border Intermediate Limited Partnership, a Delaware limited partnership continued pursuant to the Intermediate Partnership Agreement.

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"INTERMEDIATE PARTNERSHIP AGREEMENT" means the Amended and Restated Agreement of Limited Partnership of Northern Border Intermediate Limited Partnership, as it may be amended, supplemented or restated from time to time.

"ISSUE PRICE" means the price at which a Unit is purchased from the Partnership, after taking into account any sales commission or underwriting discount charged to the Partnership.

"LIMITED PARTNER" means, unless the context otherwise requires, each Substituted Limited Partner, each Initial Limited Partner, each Additional Limited Partner and any Departing Partner upon the change of its status from General Partner to Limited Partner pursuant to Section 13.3, subject to the provisions of Section 5.7; and solely for purposes of Articles IV, V and VI and Sections 14.3 and 14.4, an Assignee.

"LIQUIDATION DATE" means (a) in the case of an event giving rise to the dissolution of the Partnership of the type described in clauses (a) and (b) of the first sentence of Section 14.2, the date on which the applicable time period during which the holders of Outstanding Units have the right to elect to reconstitute the Partnership and continue its business has expired without such an election being made, and (b) in the case of any other event giving rise to the dissolution of the Partnership, the date on which such event occurs.

"LIQUIDATOR" means the Partnership Policy Committee or other Person approved pursuant to Section 14.3 who performs the functions described therein.

"MAINTENANCE CAPITAL EXPENDITURES" means cash capital expenditures, whether made by the Partnership, the Intermediate Partnership or Northern Border Pipeline, made to maintain, up to the level thereof that existed on the Closing Date, the throughput, deliverable capacity or storage capacity (assuming normal operating conditions, including, without limitation, down-time and maintenance) of the assets of the Partnership, the Intermediate Partnership and Northern Border Pipeline, taken as a whole, as such assets existed on the Closing Date and shall, therefore, not include cash capital expenditures or capital contributions to Northern Border Pipeline made in respect of Capital Additions and Improvements. Where cash capital expenditures are made in part to effectuate the capacity maintenance level referred to in the immediately preceding sentence and in part for other purposes, the Partnership Policy Committee's good faith allocation thereof between the portion used to maintain such capacity level and the portion used for other purposes shall be conclusive.

"MERGER AGREEMENT" has the meaning assigned to such term in Section 16.1.

"MINIMUM QUARTERLY DISTRIBUTION" means $0.55 per Unit per calendar quarter (or, with respect to the period commencing on the Closing Date and ending on December 31, 1993, the product of $0.55 multiplied by a fraction of which the numerator is the number of days in such period and of which the denominator is 92), subject to adjustment in accordance with Sections 5.6 and 9.6.

"NATIONAL SECURITIES EXCHANGE" means an exchange registered with the Securities and Exchange Commission under Section 6(a) of the Securities Exchange Act of 1934, as amended, supplemented or restated from time to time, and any successor to such statute.

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"NET AGREED VALUE" means, (a) in the case of any Contributed Property, the Agreed Value of such property reduced by any liabilities either assumed by the Partnership upon such contribution or to which such property is subject when contributed, and (b) in the case of any property distributed to a Partner or Assignee by the Partnership, the Partnership's Carrying Value of such property (as adjusted pursuant to Section 4.4(d)(ii)) at the time such property is distributed, reduced by any indebtedness either assumed by such Partner or Assignee upon such distribution or to which such property is subject at the time of distribution, in either case, as determined under Section 752 of the Code.

"NET INCOME" means, for any taxable period, the excess, if any, of the Partnership's items of income and gain (other than those items attributable to dispositions constituting Termination Capital Transactions) for such taxable period over the Partnership's items of loss and deduction (other than those items attributable to dispositions constituting Termination Capital Transactions) for such taxable period. The items included in the calculation of Net Income shall be determined in accordance with Section 4.4(b) and shall not include any items specially allocated under Section 5.1 (d). Once an item of income, gain, loss or deduction that has been included in the initial computation of Net Income is subjected to a Required Allocation or a Curative Allocation, Net Income or Net Loss, whichever the case may be, shall be recomputed without regard to such item.

"NET LOSS" means, for any taxable period, the excess, if any, of the Partnership's items of loss and deduction (other than those items attributable to dispositions constituting Termination Capital Transactions) for such taxable period over the Partnership's items of income and gain (other than those items attributable to dispositions constituting Termination Capital Transactions) for such taxable period. The items included in the calculation of Net Loss shall be determined in accordance with Section 4.4(b) and shall not include any items specially allocated under Section 5.1(d). Once an item of income, gain, loss or deduction that has been included in the initial computation of Net Loss is subjected to a Required Allocation or a Curative Allocation, Net Income, or Net Loss, whichever the case may be, shall be recomputed without regard to such item.

"NET TERMINATION GAIN" means, for any taxable period, the sum, if positive, of all items of income, gain, loss or deduction recognized by the Partnership (including, without limitation, such amounts recognized through the Intermediate Partnership) from Termination Capital Transactions occurring in such taxable period. The items included in the determination of Net Termination Gain shall be determined in accordance with Section 4.4(b) and shall not include any items of income, gain or loss specially allocated under Section 5.1 (d). Once an item of income, gain or loss that has been included in the initial computation of Net Termination Gain is subjected to a Required Allocation or a Curative Allocation, Net Termination Gain or Net Termination Loss, whichever the case may be, shall be recomputed without regard to such item.

"NET TERMINATION LOSS" means, for any taxable period, the sum, if negative, of all items of income, gain, loss or deduction recognized by the Partnership (including, without limitation, such amounts recognized through the Intermediate Partnership) from Termination Capital Transactions occurring in such taxable period. The items included in the determination of Net Termination Loss shall be determined in accordance with Section 4.4(b) and shall not include any items of income, gain or loss specially allocated under Section 5.1 (d). Once an item of gain or loss that has been included in the initial computation of Net Termination Loss is subjected to a Required Allocation or a Curative Allocation, Net Termination

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Gain or Net Termination Loss, whichever the case may be, shall be recomputed without regard to such item.

"NON-CITIZEN ASSIGNEE" means a Person who the Partnership Policy Committee has determined in its sole discretion does not constitute an Eligible Citizen and as to whose Partnership Interest the Partnership Policy Committee has become the Substituted Limited Partner, pursuant to
Section 11.5.

"NONRECOURSE BUILT-IN GAIN" means with respect to any Contributed Properties or Adjusted Properties that are subject to a mortgage or pledge securing a Nonrecourse Liability, the amount of any taxable gain that would be allocated to the Partners pursuant to Sections 5.2(b)(i)(A), 5.2(b)(ii)(A) or 5.2(b)(iv) if such properties were disposed of in a taxable transaction in full satisfaction of such liabilities and for no other consideration.

"NONRECOURSE DEDUCTIONS" means any and all items of loss, deduction or expenditures (described in Section 705(a)(2)(B) of the Code) that, in accordance with the principles of Treasury Regulation Section 1.704-2(b), are attributable to a Nonrecourse Liability.

"NONRECOURSE LIABILITY" has the meaning set forth in Treasury Regulation Section 1.752-1(a)(2).

"NORTHERN BORDER INTERIM CAPITAL TRANSACTIONS" means any transaction of the type described in the definition of "Interim Capital Transactions" that is undertaken by Northern Border Pipeline.

"NORTHERN BORDER PIPELINE" means Northern Border Pipeline Company, a Texas general partnership among Northern Plains, Pan Border, Northwest Border, TransCanada Border PipeLine Ltd., a Nevada corporation, and TransCan Northern Ltd., a Delaware corporation.

"NORTHERN BORDER PIPELINE PARTNERSHIP AGREEMENT" means that certain General Partnership Agreement of Northern Border Pipeline Company dated effective as of March 9, 1978, among Northern Plains, Pan Border, Northwest Border, TransCanada Border PipeLine Ltd. and TransCan Northern Ltd., as amended and supplemented.

"NORTHERN BORDER TERMINATION CAPITAL TRANSACTIONS" means any sale, transfer or other disposition of property of Northern Border Pipeline occurring upon or incident to the liquidation and winding up of Northern Border Pipeline.

"NORTHERN PLAINS" means Northern Plains Natural Gas Company, a Delaware corporation.

"NORTHWEST BORDER" means Northwest Border Pipeline Company, a Delaware corporation.

"NOTICE OF ELECTION TO PURCHASE" has the meaning assigned to such term in Section 17.1(b).

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"OPINION OF COUNSEL" means a written opinion of counsel (who may be regular counsel to any of the General Partners, their Affiliates or the Partnership) acceptable to the Partnership Policy Committee.

"ORGANIZATIONAL LIMITED PARTNER" means Northwest Border, in its capacity as the organizational limited partner of the Partnership pursuant to this Agreement, it being recognized that Northern Plains was such organizational limited partner at the time of the original Agreement of Limited Partnership of Northern Border Partners, L.P. but previously has transferred its rights in such capacity to Northwest Border.

"OUTSTANDING" means, with respect to the Units or other Partnership Securities, all Units or other Partnership Securities that are issued by the Partnership and reflected as outstanding on the Partnership's books and records as of the date of determination; provided that, if at any time any Person or Group (other than the General Partners and their Affiliates) owns beneficially 20% or more of all Common Units, such Common Units so owned shall not be voted on any matter and shall not be considered to be Outstanding when sending notices of a meeting of Limited Partners (unless otherwise required by law), calculating required votes, determining the presence of a quorum or for other similar purposes under this Agreement, except that such Common Units shall be considered to be Outstanding for purposes of Section 13.1(b)(iv) (such Common Units shall not, however, be treated as a separate class of Partnership Securities for purposes of this Agreement).

"OVERALLOTMENT OPTION" means the overallotment option granted to the Underwriters pursuant to the Underwriting Agreement.

"PAN BORDER" means Pan Border Gas Company, a Delaware corporation.

"PANHANDLE" means Panhandle Eastern Corporation, a Delaware corporation.

"PARTNER NONRECOURSE DEBT" has the meaning set forth in Treasury Regulation Section 1.704-2(b)(4).

"PARTNER NONRECOURSE DEBT MINIMUM GAIN" has the meaning set forth in Treasury Regulation Section 1.704-2(i)(2).

"PARTNER NONRECOURSE DEDUCTIONS" means any and all items of loss, deduction or expenditure (including, without limitation, any expenditure described in Section 705(a)(2)(B) of the Code) that, in accordance with the principles of Treasury Regulation Section 1.704-2(i), are attributable to a Partner Nonrecourse Debt.

"PARTNERS" means the General Partners and the Limited Partners.

"PARTNERSHIP" means the limited partnership heretofore formed and continued pursuant to this Agreement.

"PARTNERSHIP INTEREST" means an interest in the Partnership, which shall include general partner interests, Common Units, Subordinated Units or other Partnership Securities, or a combination thereof or interest therein, as the case may be.

"PARTNERSHIP MINIMUM GAIN" means that amount determined in accordance with the principles of Treasury Regulation Section 1.704-2(d).

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"PARTNERSHIP POLICY COMMITTEE" has the meaning assigned to such term in Section 6.1.

"PARTNERSHIP SECURITIES" has the meaning assigned to such term in
Section 4.2(a).

"PER UNIT CAPITAL AMOUNT" means, as of any date of determination, the Capital Account, stated on a per Unit basis, underlying any Unit held by a Person other than a General Partner or any Affiliate of such General Partner who holds Units.

"PERCENTAGE INTEREST" means as of the date of such determination (a) as to a General Partner, its General Partner Percentage Interest, (b) as to any Limited Partner or Assignee holding Units, the product of (i) 99% multiplied by (ii) the quotient of the number of Units held by such Limited Partner or Assignee divided by the total number of all Units then Outstanding; provided, however, that following any issuance of additional Partnership Securities by the Partnership in accordance with Section 4.2, proper adjustment shall be made to the Percentage Interest represented by each Unit to reflect such issuance, and (c) as to the holders of additional Partnership Securities issued by the Partnership in accordance with Section 4.2, the percentage established as a part of such issuance.

"PERSON" means an individual or a corporation, partnership, trust, unincorporated organization, association or other entity.

"PIPELINE SYSTEM" means the natural gas pipeline assets and related facilities that are owned by Northern Border Pipeline.

"PURCHASE DATE" means the date determined by the General Partners as the date for purchase of all Outstanding Units (other than Units owned by the General Partners and their Affiliates) pursuant to Article XVII.

"RECAPTURE INCOME" means any gain recognized by the Partnership (computed without regard to any adjustment required by Sections 734 or 743 of the Code) upon the disposition of any property or asset of the Partnership, which gain is characterized as ordinary income because it represents the recapture of deductions previously taken with respect to such property or asset.

"RECORD DATE" means the date established by the Partnership Policy Committee for determining (a) the identity of the Record Holder entitled to notice of, or to vote at, any meeting of Limited Partners or entitled to vote by ballot or give approval of Partnership action in writing without a meeting or entitled to exercise rights in respect of any lawful action of Limited Partners or (b) the identity of Record Holders entitled to receive any report or distribution.

"RECORD HOLDER" means the Person in whose name a Unit is registered on the books of the Transfer Agent as of the opening of business on a particular Business Day.

"REDEEMABLE UNITS" means any Units for which a redemption notice has been given, and has not been withdrawn, under Section 11.6.

"REGISTRATION STATEMENT" means the Registration Statement on Form S-1 (Registration No. 33-66158), as it has been or as it may be amended or supplemented from

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time to time, filed by the Partnership with the Securities and Exchange Commission under the Securities Act to register the offering and sale of the Common Units in the Initial Offering.

"REQUIRED ALLOCATIONS" means any allocation (or limitation imposed on any allocation) of an item of income, gain, deduction or loss pursuant to (a) Section 5.1 (b)(ii) or (b) Sections 5.1(d)(i), 5.1(d)(ii), 5.1(d)(iv), 5.1(d)(v), 5.1(d)(vi), 5.1(d)(vii) and 5.1(d)(ix), such allocations (or limitations thereon) being directly or indirectly required by the Treasury regulations promulgated under Section 704(b) of the Code.

"RESIDUAL GAIN" OR "RESIDUAL LOSS" means any item of gain or loss, as the case may be, of the Partnership recognized for federal income tax purposes resulting from a sale, exchange or other disposition of a Contributed Property or Adjusted Property, to the extent such item of gain or loss is not allocated pursuant to Sections 5.2(b)(i)(A) or 5.2(b)(ii)(A), respectively, to eliminate Book-Tax Disparities.

"SECOND LIQUIDATION TARGET AMOUNT" has the meaning assigned to such term in Section 5.1 (c)(i)(E).

"SECOND TARGET DISTRIBUTION" means $0.715 per Unit (or, with respect to the period commencing on the Closing Date and ending on December 31, 1993, the product of $0.715 multiplied by a fraction of which the numerator is equal to the number of days in such period and of which the denominator is 92), subject to adjustment in accordance with Sections 5.6 and 9.6.

"SECURITIES ACT" means the Securities Act of 1933, as amended, supplemented or restated from time to time and any successor to such statute.

"SPECIAL APPROVAL" means approval by the Audit Committee.

"SUBORDINATED UNIT" means a Unit representing a fractional part of the Partnership Interests of all Limited Partners and Assignees and having the rights and obligations specified with respect to Subordinated Units in this Agreement.

"SUBORDINATION PERIOD" means the period commencing on the Closing Date and ending on the first to occur of any one of the following dates:

(a) the date on which one or more of the General Partners is removed as a general partner of the Partnership upon the requisite vote by Limited Partners under circumstances where Cause does not exist,

(b) the first day of any calendar quarter commencing on or after January 1, 2004, provided that the Partnership has, with respect to each of the 20 most recently completed calendar quarters, distributed an amount equal to or greater than the Minimum Quarterly Distribution for each Common Unit and Subordinated Unit Outstanding during such quarter (it being agreed that the Subordination Period will be deemed to have ended effective as of the first day of any such quarter despite the fact that the distribution with respect to the 20th consecutive quarter will have been made during such quarter as contemplated by Section 5.3(a)),

(c) the first day of any calendar quarter commencing on or after January 1, 2004, provided that both of the following tests have been satisfied: (i) the

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aggregate amount of capital expenditures of the Partnership, the Intermediate Partnership and Northern Border Pipeline (in the case of Northern Border Pipeline, only to the extent such capital expenditures are attributable to the Intermediate Partnership's interest in Northern Border Pipeline) since the Closing Date equals or exceeds $248,000,000, and (ii) there are no Cumulative Common Unit Arrearages, and

(d) the first day of any calendar quarter that commences on or after January 1, 1999, but ends prior to January 1, 2004, provided that both of the following tests have been satisfied: (i) the aggregate amount of capital expenditures of the Partnership, the Intermediate Partnership and Northern Border Pipeline (in the case of Northern Border Pipeline, only to the extent such capital expenditures are attributable to the Intermediate Partnership's interest in Northern Border Pipeline) since the Closing Date equals or exceeds $248,000,000, and (ii) the Partnership has, with respect to each of the eight most recently completed calendar quarters, distributed an amount equal to or greater than the Minimum Quarterly Distribution for each Common Unit and Subordinated Unit Outstanding during such quarter (it being agreed that the Subordination Period will be deemed to have ended effective as of the first day of any such quarter despite the fact that the distribution with respect to the eighth consecutive quarter will have been made during such quarter as contemplated by Section 5.3(a)).

"SUBSTITUTED LIMITED PARTNER" means a Person who is admitted as a Limited Partner to the Partnership pursuant to Section 12.2 in place of and with all the rights of a Limited Partner and who is shown as a Limited Partner on the books and records of the Partnership.

"SURVIVING BUSINESS ENTITY" has the meaning assigned to such term in
Section 16.2(b).

"TERMINATION CAPITAL TRANSACTIONS" means any sale, transfer or other disposition of property of the Partnership or the Intermediate Partnership occurring upon or incident to the liquidation and winding up of the Partnership and the Intermediate Partnership pursuant to Article XIV.

"THIRD TARGET DISTRIBUTION" means $0.935 per Unit (or, with respect to the period commencing on the Closing Date and ending on December 31, 1993, the product of $0.935 multiplied by a fraction of which the numerator is equal to the number of days in such period and of which the denominator is 92), subject to adjustment in accordance with Sections 5.6 and 9.6.

"TRADING DAY" has the meaning assigned to such term in Section 17.1(a).

"TRANSFER AGENT" means First Chicago Trust Company of New York or such other bank, trust company or other Person (including, without limitation, any General Partner or one of its Affiliates) as shall be appointed from time to time by the Partnership to act as registrar and transfer agent for the Units.

"TRANSFER APPLICATION" means an application and agreement for transfer of Units in the form set forth on the back of a Certificate or in a form substantially to the same effect in a separate instrument.

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"UNDERWRITER" means each Person named as an underwriter in Schedule I to the Underwriting Agreement who purchases Common Units pursuant thereto.

"UNDERWRITING AGREEMENT" means the Underwriting Agreement dated September 23, 1993, among the Underwriters, the Partnership, Northern Plains, Pan Border, the Intermediate Partnership, Panhandle, and Enron providing for the purchase of Common Units by such Underwriters.

"UNIT" means a Partnership Interest of a Limited Partner or Assignee in the Partnership representing a fractional part of the Partnership Interests of all Limited Partners and Assignees and shall include, without limitation, Common Units and Subordinated Units; provided, that each Common Unit at any time Outstanding shall represent the same fractional part of the Partnership Interests of all Limited Partners and Assignees holding Common Units as each other Common Unit and each Subordinated Unit at any time Outstanding shall represent the same fractional part of the Partnership Interests of all Limited Partners and Assignees holding Subordinated Units as each other Subordinated Unit.

"UNPAID MQD" has the meaning assigned to such term in Section 5.1(c)(i)(B).

"UNREALIZED GAIN" attributable to any item of Partnership property means, as of any date of determination, the excess, if any, of (a) the fair market value of such property as of such date (as determined under
Section 4.4(d)) over (b) the Carrying Value of such property as of such date (prior to any adjustment to be made pursuant to Section 4.4(d) as of such date).

"UNREALIZED LOSS" attributable to any item of Partnership property means, as of any date of determination, the excess, if any, of (a) the Carrying Value of such property as of such date (prior to any adjustment to be made pursuant to Section 4.4(d) as of such date) over (b) the fair market value of such property as of such date (as determined under Section 4.4(d)).

"UNRECOVERED INITIAL UNIT PRICE" means, at any time, with respect to a class or series of Units (other than Subordinated Units), the price per Unit at which such class or series of Units was initially offered to the public for sale by the Underwriters in respect of such offering, as determined by the Partnership Policy Committee, less the sum of all distributions theretofore made in respect of a Unit of such class or series that was sold in the initial offering of Units of said class or series constituting Cash from Interim Capital Transactions and any distributions of cash (or the Net Agreed Value of any distributions in kind) in connection with the dissolution and liquidation of the Partnership theretofore made in respect of a Unit of such class or series that was sold in the initial offering of Units of such class or series, adjusted as the Partnership Policy Committee determines to be appropriate to give effect to any distribution, subdivision or combination of Units.

"UNRECOVERED SUBORDINATED UNIT CAPITAL" means, at any time, with respect to a Subordinated Unit, prior to its conversion into a Common Unit pursuant to Section 5.7(b), the excess, if any, of (a) the Net Agreed Value (at the time of conveyance) of the undivided interest in the Contributed Property conveyed to the Partnership pursuant to Section 4.1
(a) in exchange for such Subordinated Unit, over (b) any distributions of cash (or the Net Agreed Value of any distributions in kind) in connection with the dissolution and liquidation of the Partnership, adjusted as the Partnership Policy Committee determines to be appropriate to give effect to any distribution, subdivision or combination of Units.

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"WILLIAMS" means The Williams Companies, Inc., a Delaware corporation.

"WITHDRAWAL OPINION OF COUNSEL" has the meaning assigned to such term in Section 13.1(b).

ARTICLE III
PURPOSE

3.1 PURPOSE AND BUSINESS. The purpose and nature of the business to be conducted by the Partnership shall be (a) to serve as a limited partner in the Intermediate Partnership and, in connection therewith, to exercise all of the rights and powers conferred upon the Partnership as a limited partner in the Intermediate Partnership pursuant to the Intermediate Partnership Agreement or otherwise, (b) to engage directly in, or to enter into or form any corporation, partnership, joint venture, limited liability company or other arrangement to engage in, any business activity that the Intermediate Partnership is permitted to engage in by the Intermediate Partnership Agreement and, in connection therewith, to exercise all of the rights and powers conferred upon the Partnership pursuant to the agreements relating to such business activity (including, without limitation, all of the rights and powers conferred upon the Intermediate Partnership under the Northern Border Pipeline Partnership Agreement), (c) to engage directly in, or to enter or form into any corporation, partnership, joint venture, limited liability company or other arrangement to engage in, any business activity that is approved by unanimous vote of the Partnership Policy Committee and which lawfully may be conducted by a limited partnership organized pursuant to the Delaware Act and, in connection therewith, to exercise all of the rights and powers conferred upon the Partnership pursuant to the agreements relating to such business activity, and (d) to do anything necessary or appropriate to the foregoing, including, without limitation, the making of capital contributions or loans to the Intermediate Partnership (including, without limitation, those contributions or loans that may be required in connection with any business activity that may be made available to the Intermediate Partnership in connection with its involvement in the activities referred to in clauses (b) and (c) of this sentence). The Partnership Policy Committee has no obligation or duty to the Partnership, the Limited Partners or the Assignees to propose or approve, and in its sole discretion may decline to propose or approve, the conduct by the Partnership of any business.

3.2 POWERS. The Partnership shall be empowered to do any and all acts and things necessary, appropriate, proper, advisable, incidental to or convenient for the furtherance and accomplishment of the purposes and business described in
Section 3.1 and for the protection and benefit of the Partnership.

ARTICLE IV
CAPITAL CONTRIBUTIONS

4.1 CONTRIBUTIONS BY THE GENERAL PARTNERS. On the Closing Date, the General Partners shall, in the aggregate and as set forth in the Conveyance Agreement, contribute, transfer, convey, assign and deliver to the Partnership, as a Capital Contribution, Partnership Interests (as defined in the Intermediate Partnership Agreement) representing, in the aggregate, a 98.9899% Percentage Interest (as defined in the Intermediate Partnership Agreement) in the Intermediate Partnership, in exchange for the continuation of each General Partner's Partnership Interest as a general partner in the Partnership, subject to all of the rights, privileges and duties of the General Partners under this Agreement, and (a) in the case of Northern Plains, 8,600,000 Common Units and 4,500,000 Subordinated Units, (b) in the case of Pan Border, 5,590,000 Common Units and 2,925,000

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Subordinated Units and (c) in the case of Northwest Border, 3,010,000 Common Units and 1,575,000 Subordinated Units.

4.2 ISSUANCES OF ADDITIONAL UNITS AND OTHER SECURITIES. (a) Subject to
Section 4.2(c), the Partnership Policy Committee is hereby authorized to cause the Partnership to issue, in addition to the Partnership Interests and Units issued pursuant to Section 4.1, such additional Units, or classes or series thereof, or options, rights, warrants or appreciation rights relating thereto, or any other type of equity security that the Partnership may lawfully issue, any unsecured or secured debt obligations of the Partnership convertible into any class or series of equity securities of the Partnership (collectively, "PARTNERSHIP SECURITIES"),for any Partnership purpose, at any time or from time to time, to the Partners or to other Persons for such consideration and on such terms and conditions as shall be established by the Partnership Policy Committee in its sole discretion, all without the approval of any Limited Partners. The Partnership Policy Committee shall have sole discretion, subject to the guidelines set forth in this Section 4.2 and the requirements of the Delaware Act, in determining the consideration and terms and conditions with respect to any future issuance of Partnership Securities.

(b) Additional Partnership Securities to be issued by the Partnership pursuant to this Section 4.2 shall be issuable from time to time in one or more classes, or one or more series of any of such classes, with such designations, preferences and relative, participating, optional or other special rights, powers and duties, including, without limitation, rights, powers and duties senior to existing classes and series of Partnership Securities (except as provided in Section 4.2(c)), all as shall be fixed by the Partnership Policy Committee in the exercise of its sole discretion, subject to Delaware law and
Section 4.2(c), including, without limitation, (i) the allocations of items of Partnership income, gain, loss, deduction and credit to each such class or series of Partnership Securities; (ii) the right of each such class or series of Partnership Securities to share in Partnership distributions; (iii) the rights of each such class or series of Partnership Securities upon dissolution and liquidation of the Partnership; (iv) whether such class or series of additional Partnership Securities is redeemable by the Partnership and, if so, the price at which, and the terms and conditions upon which, such class or series of additional Partnership Securities may be redeemed by the Partnership; (v) whether such class or series of additional Partnership Securities is issued with the privilege of conversion and, if so, the rate at which, and the terms and conditions upon which, such class or series of Partnership Securities may be converted into any other class or series of Partnership Securities or other property; (vi) the terms and conditions upon which each such class or series of Partnership Securities will be issued, evidenced by certificates and assigned or transferred; and (vii) the right, if any, of each such class or series of Partnership Securities to vote on Partnership matters, including, without limitation, matters relating to the relative rights, preferences and privileges of each such class or series.

(c) Notwithstanding the terms of Sections 4.2(a) and 4.2(b), the issuance by the Partnership of any Partnership Securities pursuant to this Section 4.2 shall be subject to the following restrictions and limitations:

(i) For a period of 180 days following the Closing Date, the Partnership shall not issue additional Common Units or other Partnership Securities having rights to distribution or in liquidation ranking on a parity with the Common Units; and

(ii) During the Subordination Period, the Partnership shall not issue an aggregate of more than 17,200,000 additional Common Units or an equivalent amount of other Units having rights to distributions or in liquidation ranking on a parity with the Common Units, without the prior approval of a majority of the Outstanding Common Units (excluding Common Units held by the General Partners and their Affiliates);

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(iii) From and after the Closing Date, the Partnership shall not issue additional Partnership Securities having rights to distributions or in liquidation ranking senior to the Common Units, without the prior approval of a majority of the Outstanding Common Units (excluding, during the Subordination Period, Common Units held by the General Partners and their Affiliates); and

(iv) Upon the issuance of any Partnership Interests by the Partnership or the making of any other Capital Contributions to the Partnership, the General Partners shall be required to make additional Capital Contributions to the Partnership (each in the proportion of its General Partner Percentage Interest) such that the General Partners shall at all times have a balance in their Capital Account with respect to their general partner interests equal to, in the aggregate, 1% of the total positive Capital Account balances of all Partners.

(d) The Partnership Policy Committee is hereby authorized and directed to take all actions that it deems necessary or appropriate in connection with each issuance of Units or other Partnership Securities pursuant to Section 4.2(a) and to amend this Agreement in any manner that it deems necessary or appropriate to provide for each such issuance, to admit Additional Limited Partners in connection therewith and to specify the relative rights, powers and duties of the holders of the Units or other Partnership Securities being so issued.

(e) The Partnership Policy Committee shall do all things necessary to comply with the Delaware Act and is authorized and directed to do all things it deems to be necessary or advisable in connection with any future issuance of Partnership Securities, including, without limitation, compliance with any statute, rule, regulation or guideline of any federal, state or other governmental agency or any National Securities Exchange on which the Units or other Partnership Securities are listed for trading.

4.3 LIMITED PREEMPTIVE RIGHTS. Except as provided in this Section 4.3, no Person shall have any preemptive, preferential or other similar right with respect to (a) additional Capital Contributions; (b) issuance or sale of any class or series of Units or other Partnership Securities, whether unissued, held in the treasury or hereafter created; (c) issuance of any obligations, evidences of indebtedness or other securities of the Partnership convertible into or exchangeable for, or carrying or accompanied by any rights to receive, purchase or subscribe to, any such Units or other Partnership Securities; (d) issuance of any right of subscription to or right to receive, or any warrant or option for the purchase of, any such Units or other Partnership Securities; or (e) issuance or sale of any other securities that may be issued or sold by the Partnership. Each General Partner shall have the right, which it may from time to time assign in whole or in part to any of its Affiliates or to any other General Partner or its Affiliates, to purchase Units or other Partnership Securities from the Partnership whenever, and on the same terms that, the Partnership issues Units or other Partnership Securities to Persons other than the General Partners and their Affiliates, to the extent necessary to maintain the Percentage Interests of such General Partner and its Affiliates equal to that which existed immediately prior to the issuance of such Units or other Partnership Securities.

4.4 CAPITAL ACCOUNTS, (a) The Partnership shall maintain for each Partner (or a beneficial owner of Units held by a nominee in any case in which the nominee has furnished the identity of such owner to the Partnership in accordance with Section 6031 (c) of the Code or any other method acceptable to the Partnership Policy Committee in its sole discretion) owning a Partnership Interest a separate Capital Account with respect to such Partnership Interest in accordance with the rules of Treasury Regulation Section 1.704-1(b)(2)(iv). Such Capital Account shall be increased by (i) the amount of all Capital Contributions made to the Partnership with respect to such Partnership Interest pursuant to this Agreement and (ii) all items of Partnership income and gain (including, without

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limitation, income and gain exempt from tax) computed in accordance with Section 4.4(b) and allocated with respect to such Partnership Interest pursuant to
Section 5.1, and decreased by (x) the amount of cash or Net Agreed Value of all actual and deemed distributions of cash or property made with respect to such Partnership Interest pursuant to this Agreement and (y) all items of Partnership deduction and loss computed in accordance with Section 4.4(b) and allocated with respect to such Partnership Interest pursuant to Section 5.1.

(b) For purposes of computing the amount of any item of income, gain, loss or deduction to be reflected in the Partners' Capital Accounts, the determination, recognition and classification of any such item shall be the same as its determination, recognition and classification for federal income tax purposes (including, without limitation, any method of depreciation, cost recovery or amortization used for that purpose), provided, that:

(i) Solely for purposes of this Section 4.4, the Partnership shall be treated as owning directly its proportionate share (as determined by the Partnership Policy Committee based upon the provisions of the Intermediate Partnership Agreement) of all property owned by the Intermediate Partnership and by Northern Border Pipeline.

(ii) All fees and other expenses incurred by the Partnership to promote the sale of (or to sell) a Partnership Interest that can neither be deducted nor amortized under Section 709 of the Code, if any, shall, for purposes of Capital Account maintenance, be treated as an item of deduction at the time such fees and other expenses are incurred and shall be allocated among the Partners pursuant to Section 5.1.

(iii) Except as otherwise provided in Treasury Regulation Section 1.704-1 (b)(2)(iv)(m), the computation of all items of income, gain, loss and deduction shall be made without regard to any election under Section 754 of the Code which may be made by the Partnership and, as to those items described in Section 705(a)(1)(B) or 705(a)(2)(B) of the Code, without regard to the fact that such items are not includable in gross income or are neither currently deductible nor capitalized for federal income tax purposes.

(iv) Any income, gain or loss attributable to the taxable disposition of any Partnership property shall be determined as if the adjusted basis of such property as of such date of disposition were equal in amount to the Partnership's Carrying Value with respect to such property as of such date.

(v) In accordance with the requirements of Section 704(b) of the Code, any deductions for depreciation, cost recovery or amortization attributable to any Contributed Property shall be determined as if the adjusted basis of such property on the date it was acquired by the Partnership were equal to the Agreed Value of such property. Upon an adjustment pursuant to Section 4.4(d) to the Carrying Value of any Partnership property subject to depreciation, cost recovery or amortization, any further deductions for such depreciation, cost recovery or amortization attributable to such property shall be determined (A) as if the adjusted basis of such property were equal to the Carrying Value of such property immediately following such adjustment and (B) using a rate of depreciation, cost recovery or amortization derived from the same method and useful life (or, if applicable, the remaining useful life) as is applied for federal income tax purposes; provided, however, that, if the asset has a zero adjusted basis for federal income tax purposes, depreciation, cost recovery or amortization deductions shall be determined using any reasonable method that the Partnership Policy Committee may adopt.

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(vi) If the Partnership's adjusted basis in a depreciable or cost recovery property is reduced for federal income tax purposes pursuant to
Section 48(q)(1) or 48(q)(3) of the Code, the amount of such reduction shall, solely for purposes hereof, be deemed to be an additional depreciation or cost recovery deduction in the year such property is placed in service and shall be allocated among the Partners pursuant to
Section 5.1. Any restoration of such basis pursuant to Section 48(q)(2) of the Code shall, to the extent possible, be allocated in the same manner to the Partners to whom such deemed deduction was allocated.

(c) (i) Except as otherwise provided in Section 4.4(c)(ii), a transferee of a Partnership Interest shall succeed to a pro rata portion of the Capital Account of the transferor relating to the Partnership Interest so transferred; provided, however, that, if the transfer causes a termination of the Partnership under Section 708(b)(1)(B) of the Code, the Partnership's properties shall be deemed to have been distributed in liquidation of the Partnership to the Partners (including any transferee of a Partnership Interest that is a party to the transfer causing such termination) pursuant to Sections 14.3 and 14.4 and recontributed by such Partners in reconstitution of the Partnership. Any such deemed distribution shall be treated as an actual distribution for purposes of this Section 4.4. In such event, the Carrying Values of the Partnership properties shall be adjusted immediately prior to such deemed distribution pursuant to Section 4.4(d)(ii) and such Carrying Values shall then constitute the Agreed Values of such properties upon such deemed contribution to the reconstituted Partnership. The Capital Accounts of such reconstituted Partnership shall be maintained in accordance with the principles of this Section 4.4.

(ii) Immediately prior to the conversion of a Subordinated Unit into a Common Unit pursuant to Section 5.7(b) or the sale, exchange or other disposition of a Subordinated Unit by a holder thereof, the Capital Account maintained for such Person with respect to its Subordinated Units will (A) first, be allocated to the Subordinated Units to be transferred in an amount equal to the product of (x) the number of such Subordinated Units to be transferred and (y) the Per Unit Capital Amount for a Common Unit, and (B) second, any remaining balance in such Capital Account will be retained by the transferor, regardless of whether it has retained any Subordinated Units. Following any such allocation, the transferor's Capital Account, if any, maintained with respect to the retained Subordinated Units, if any, will have a balance equal to the amount allocated under clause (B) hereinabove, and the transferee's Capital Account established with respect to the transferred Subordinated Units will have a balance equal to the amount allocated under clause (A) hereinabove.

(d) (i) Consistent with the provisions of Treasury Regulation Section 1.704-1(b)(2)(iv)(f), on an issuance of additional Units for cash or Contributed Property or the conversion of a General Partner's Partnership Interest to Common Units pursuant to Section 13.3(b), the Capital Account of all Partners and the Carrying Value of each Partnership property immediately prior to such issuance shall be adjusted upward or downward to reflect any Unrealized Gain or Unrealized Loss attributable to such Partnership property, as if such Unrealized Gain or Unrealized Loss had been recognized on an actual sale of each such property immediately prior to such issuance and had been allocated to the Partners at such time pursuant to Section 5.1. In determining such Unrealized Gain or Unrealized Loss, the aggregate cash amount and fair market value of all Partnership assets (including, without limitation, cash or cash equivalents) immediately prior to the issuance of additional Units shall be determined by the Partnership Policy Committee using such reasonable method of valuation as it may adopt; provided, however, the Partnership Policy Committee, in arriving at such valuation, must take fully into account the fair market value of the Partnership

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Interests of all Partners at such time. The Partnership Policy Committee shall allocate such aggregate value among the assets of the Partnership
(in such manner as it determines in its sole discretion to be reasonable)
to arrive at a fair market value for individual properties.

(ii) In accordance with Treasury Regulation Section 1.704-1(b)(2)(iv)(f), immediately prior to any actual or deemed distribution to a Partner of any Partnership property (other than a distribution of cash that is not in redemption or retirement of a Partnership Interest), the Capital Accounts of all Partners and the Carrying Value of such Partnership property shall be adjusted upward or downward to reflect any Unrealized Gain or Unrealized Loss attributable to such Partnership property, as if such Unrealized Gain or Unrealized Loss had been recognized in a sale of such property immediately prior to such distribution for an amount equal to its fair market value, and had been allocated to the Partners, at such time, pursuant to Section 5.1. Any Unrealized Gain or Unrealized Loss attributable to such property shall be allocated in the same manner as Net Termination Gain or Net Termination Loss pursuant to Section 5.1 (c); provided, however, that, in making any such allocation, Net Termination Gain or Net Termination Loss actually realized shall be allocated first. In determining such Unrealized Gain or Unrealized Loss the aggregate cash amount and fair market value of all Partnership assets (including, without limitation, cash or cash equivalents) immediately prior to a distribution shall (A) in the case of a deemed distribution occurring as a result of a termination of the Partnership pursuant to Section 708 of the Code, be determined and allocated in the same manner as that provided in Section 4.4(d)(i) or (B) in the case of a liquidating distribution pursuant to Section 14.3 or 14.4, be determined and allocated by the Liquidator using such reasonable method of valuation as it may adopt.

4.5 INTEREST. No interest shall be paid by the Partnership on Capital Contributions or on balances in Partners' Capital Accounts.

4.6 NO WITHDRAWAL. No Partner shall be entitled to withdraw any part of his Capital Contributions or its Capital Account or to receive any distribution from the Partnership, except as provided in Section 4.2, Articles V, VII, XIII and XIV.

4.7 LOANS FROM PARTNERS. Loans by a Partner to the Partnership shall not constitute Capital Contributions. If any Partner shall advance funds to the Partnership in excess of the amounts required hereunder to be contributed by it to the capital of the Partnership, the making of such excess advances shall not result in any increase in the amount of the Capital Account of such Partner. The amount of any such excess advances shall be a debt obligation of the Partnership to such Partner and shall be payable or collectible only out of the Partnership assets in accordance with the terms and conditions upon which such advances are made.

4.8 NO FRACTIONAL UNITS. No fractional Units shall be issued by the Partnership.

4.9 SPLITS AND COMBINATIONS. (a) Subject to Section 4.9(d), the Partnership Policy Committee may make a pro rata distribution of Units or other Partnership Securities to all Record Holders or may effect a subdivision or combination of Units or other Partnership Securities; provided, however, that after any such distribution, subdivision or combination, each Partner shall have the same Percentage Interest in the Partnership as before such distribution, subdivision or combination.

(b) Whenever such a distribution, subdivision or combination of Units or other Partnership Securities is declared, the Partnership Policy Committee shall select a Record Date as of which the distribution, subdivision or combination shall be effective and shall send notice of the distribution, subdivision or combination at least 20 days prior to such Record Date to each Record Holder as of

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the date not less than 10 days prior to the date of such notice. The Partnership Policy Committee also may cause a firm of independent public accountants selected by it to calculate the number of Units to be held by each Record Holder after giving effect to such distribution, subdivision or combination. The Partnership Policy Committee shall be entitled to rely on any certificate provided by such firm as conclusive evidence of the accuracy of such calculation.

(c) Promptly following any such distribution, subdivision or combination, the Partnership Policy Committee may cause Certificates to be issued to the Record Holders of Units as of the applicable Record Date representing the new number of Units held by such Record Holders, or the Partnership Policy Committee may adopt such other procedures as it may deem appropriate to reflect such distribution, subdivision or combination;provided, however, if any such distribution, subdivision or combination results in a smaller total number of Units Outstanding, the Partnership Policy Committee shall require, as a condition to the delivery to a Record Holder of such new Certificate, the surrender of any Certificate held by such Record Holder immediately prior to such Record Date.

(d) The Partnership shall not issue fractional Units upon any distribution, subdivision or combination of Units. If a distribution, subdivision or combination of Units would result in the issuance of fractional Units but for the provisions of Section 4.8 and this Section 4.9(d), each fractional Unit shall be rounded to the nearest whole Unit (and a 0.5 Unit shall be rounded to the next higher Unit).

ARTICLE V
ALLOCATIONS AND DISTRIBUTIONS

5.1 ALLOCATIONS FOR CAPITAL ACCOUNT PURPOSES. For purposes of maintaining the Capital Accounts and in determining the rights of the Partners among themselves, the Partnership's items of income, gain, loss and deduction (computed in accordance with Section 4.4(b)) shall be allocated among the Partners in each taxable year (or portion thereof) as provided hereinbelow.

(a) Net Income. After giving effect to the special allocations set forth in Section 5.1(d), Net Income for each taxable period and all items of income, gain, loss and deduction taken into account in computing Net Income for such taxable period shall be allocated as follows:

(i) First, 100% to the General Partners in accordance with their relative General Partner Percentage Interests until the aggregate Net Income allocated to each General Partner pursuant to this Section 5.1 (a)(i) for the current taxable year and all previous taxable years is equal to the aggregate Net Losses allocated to such General Partner pursuant to Section 5.1(b)(iii) for all previous taxable years;

(ii) Second, 100% to the General Partners and the Limited Partners, in the same proportion as Net Losses were allocated pursuant to Section 5.1 (b)(ii), until the aggregate Net Income allocated to such Partners pursuant to this Section 5.1(a)(ii) for the current taxable year and all previous taxable years is equal to the aggregate Net Losses allocated to such Partners pursuant to
Section 5.1(b)(ii) for all previous taxable years; and

(iii) Third, the balance, if any, 100% to the General Partners and the Limited Partners in accordance with their respective Percentage Interests.

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(b) Net Losses. After giving effect to the special allocations set forth in Section 5.1(d), Net Losses for each taxable period and all items of income, gain, loss and deduction taken into account in computing Net Losses for such taxable period shall be allocated as follows:

(i) First, 100% to the General Partners and the Limited Partners, in accordance with their respective Percentage Interests, until the aggregate Net Losses allocated pursuant to this Section
5.1 (b)(i) for the current taxable year and all previous taxable years is equal to the aggregate Net Income allocated to such Partners pursuant to Section 5.1(a)(iii) for all previous taxable years;

(ii) Second, 100% to the General Partners and the Limited Partners in proportion to, and to the extent of, the positive balances in their respective Adjusted Capital Accounts; and

(iii) Third, the balance, if any, 100% to the General Partners in accordance with their relative General Partner Percentage Interests.

(c) Net Termination Gains and Losses. After giving effect to the special allocations set forth in Section 5.1(d), all items of income gain, loss and deduction taken into account in computing Net Termination Gain or Net Termination Loss for such taxable period shall be allocated in the same manner as such Net Termination Gain or Net Termination Loss is allocated hereunder. All allocations under this Section 5.1 (c) shall be made after Capital Account balances have been adjusted by all other allocations provided under this Section 5.1 and after all distributions of Available Cash provided under Section 5.4 have been made with respect to the taxable period ending on the date of the Partnership's liquidation pursuant to Section 14.3.

(i) If a Net Termination Gain is recognized (or deemed recognized pursuant to Section 4.4(d)) from Termination Capital Transactions, such Net Termination Gain shall be allocated between the General Partners and the Limited Partners in the following manner (and the Adjusted Capital Accounts of the Partners shall be increased by the amount so allocated in each of the following subclauses, in the order listed, before an allocation is made pursuant to the next succeeding subclause):

(A) First, to each Partner having a deficit balance in its Adjusted Capital Account, in the proportion that such deficit balance bears to the total deficit balances in the Adjusted Capital Accounts of all Partners, until each such Partner has been allocated Net Termination Gain equal to any such deficit balance in its Adjusted Capital Account;

(B) Second, 99% to all Limited Partners holding Common Units, in the proportion that the total number of Common Units held by each such Limited Partner bears to the total number of Common Units then Outstanding, and 1% to the General Partners, in accordance with their relative General Partner Percentage Interests, until the Adjusted Capital Account in respect of each Common Unit then Outstanding is equal to the sum of (1) its Unrecovered Initial Unit Price, plus (2) the Minimum Quarterly Distribution for the quarter during which such Net Termination Gain is recognized, reduced by any distribution pursuant to Section 5.4(a) with respect to such Common

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Unit for such quarter (the amount determined pursuant to this clause (2) is hereinafter defined as the "UNPAID MQD"), plus
(3) any then existing Cumulative Common Unit Arrearage with respect to a Common Unit sold by the Underwriters on the Closing Date;

(C) Third, if such Termination Capital Transaction occurs (or is deemed to occur) prior to the conversion of the last Outstanding Subordinated Unit pursuant to Section 5.7(b), 99% to the Limited Partners holding Subordinated Units, in the proportion that the total number of Subordinated Units held by each such Limited Partner bears to the total number of Subordinated Units then Outstanding, and 1% to the General Partners, in accordance with their relative General Partner Percentage Interests, in the amount which will increase the Adjusted Capital Account of each such Limited Partner maintained with respect to such Subordinated Units to that amount which equals the sum of (1) the Unrecovered Subordinated Unit Capital attributable to such Subordinated Units, determined for the taxable year (or portion thereof) to which this allocation of gain relates plus (2) the Minimum Quarterly Distribution for the quarter during which such Net Termination Gain is recognized, reduced by any distribution pursuant to Section 5.4(c) with respect to such Subordinated Unit for such quarter;

(D) Fourth, 99% to all Limited Partners, in accordance with their respective Percentage Interests, and 1% to the General Partners, in accordance with their relative General Partner Percentage Interests, until the Adjusted Capital Account in respect of each Common Unit then Outstanding is equal to the sum of (1) its Unrecovered Initial Unit Price, plus (2) the Unpaid MQD, if any, for such Common Unit with respect to the quarter during which such Net Termination Gain is recognized, plus (3) any then existing Cumulative Common Unit Arrearage with respect to a Common Unit sold by the Underwriters on the Closing Date, plus (4) the excess of (aa) the First Target Distribution less the Minimum Quarterly Distribution for each quarter of the Partnership's existence over (bb) the amount of any distributions of Cash from Operations that was distributed pursuant to Section 5.4(d) (the sum of (1) plus (2) plus (3) plus (4) is hereinafter defined as the "FIRST LIQUIDATION TARGET AMOUNT");

(E) Fifth, 85.8673% to all Limited Partners, in accordance with their respective Percentage Interests, and 14.1327% to the General Partners, in accordance with their relative General Partner Percentage Interests, until the Adjusted Capital Account in respect of each Common Unit then Outstanding is equal to the sum of (1) the First Liquidation Target Amount, plus (2) the excess of (aa) the Second Target Distribution less the First Target Distribution for each quarter of the Partnership's existence over (bb) the amount of any distributions of Cash from Operations that was distributed pursuant to Section 5.4(e) (the sum of (1) plus (2) is hereinafter defined as the "SECOND LIQUIDATION TARGET AMOUNT");

(F) Sixth, 75.7653% to all Limited Partners, in accordance with their respective Percentage Interests, and 24.2347% to the General Partners, in accordance with their relative General Partner Percentage Interests, until the Adjusted Capital Account in respect of each Common Unit then Outstanding

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is equal to the sum of (1) the Second Liquidation Target Amount, plus (2) the excess of (aa) the Third Target Distribution less the Second Target Distribution for each quarter of the Partnership's existence over (bb) the amount of any distributions of Cash from Operations that was distributed pursuant to Section 5.4(f); and

(G) Seventh, any remaining amount 50.5102% to all Limited Partners, in accordance with their respective Percentage Interests, and 49.4898% to the General Partners, in accordance with their relative General Partner Percentage Interests.

(ii) If a Net Termination Loss is recognized (or deemed recognized pursuant to Section 4.4(d)) from Termination Capital Transactions, such Net Termination Loss shall be allocated to the Partners in the following manner:

(A) First, 100% to the General Partners and the Limited Partners in proportion to, and to the extent of, the positive balances in their respective Adjusted Capital Accounts; and

(B) Second, the balance, if any, 100% to the General Partners, in accordance with their relative General Partner Percentage Interests.

(d) Special Allocations. Notwithstanding any other provision of this
Section 5.1, the following special allocations shall be made for such taxable period:

(i) Partnership Minimum Gain Chargeback. Notwithstanding any other provision of this Section 5.1, if there is a net decrease in Partnership Minimum Gain during any Partnership taxable period, each Partner shall be allocated items of Partnership income and gain for such period (and, if necessary, subsequent periods) in the manner and amounts provided in Treasury Regulation Sections 1.704-2(f)(6), 1.704-2(g)(2) and 1.704-2(j)(2)(i), or any successor provision. For purposes of this Section
5.1 (d), each Partner's Adjusted Capital Account balance shall be determined, and the allocation of income or gain required hereunder shall be effected, prior to the application of any other allocations pursuant to this Section 5.1(d) with respect to such taxable period (other than an allocation pursuant to Sections 5.1(d)(vi) and 5.1 (d)(vii)). This Section
5.1 (d)(i) is intended to comply with the Partnership Minimum Gain chargeback requirement in Treasury Regulation Section 1.704-2(f) and shall be interpreted consistently therewith.

(ii) Chargeback of Partner Nonrecourse Debt Minimum Gain. Notwithstanding the other provisions of this Section 5.1 (other than
Section 5.1 (d)(i)), except as provided in Treasury Regulation Section 1.704-2(i)(4), if there is a net decrease in Partner Nonrecourse Debt Minimum Gain during any Partnership taxable period, any Partner with a share of Partner Nonrecourse Debt Minimum Gain at the beginning of such taxable period shall be allocated items of Partnership income and gain for such period (and, if necessary, subsequent periods) in the manner and amounts provided in Treasury Regulation Sections 1.704-2(i)(4) and 1.704-2(j)(2)(ii), or any successor provisions. For purposes of this
Section 5.1 (d), each Partner's Adjusted Capital Account balance shall be determined, and the allocation of income or gain required hereunder shall be effected, prior to the application of any other allocations pursuant to this Section 5.1 (d), other than Section 5.1 (d)(i) and other than an allocation

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pursuant to Sections 5.1(d)(vi) and 5.1(d)(vii), with respect to such taxable period. This Section 5.1(d)(ii) is intended to comply with the chargeback of items of income and gain requirement in Treasury Regulation
Section 1.704-2(i)(4) and shall be interpreted consistently therewith.

(iii) Priority Allocations.

(A) If the amount of cash or the Net Agreed Value of any property distributed (except cash or property distributed pursuant to Section 14.3 or 14.4) to any Limited Partner with respect to a taxable year is greater (on a per Unit basis) than the amount of cash or the Net Agreed Value of property distributed to the other Limited Partners (on a per Unit basis), then (1) each Limited Partner receiving such greater cash or property distribution shall be allocated gross income in an amount equal to the product of (aa) the amount by which the distribution (on a per Unit basis) to such Limited Partner exceeds the distribution (on a per Unit basis) to the Limited Partners receiving the smallest distribution and (bb) the number of Units owned by the Limited Partner receiving the greater distribution; and (2) the General Partners shall be allocated gross income in an aggregate amount equal to 1/99 of the sum of the amounts allocated in clause (1) above.

(B) All or a portion of the remaining items of Partnership gross income or gain for the taxable period, if any, shall be allocated 100% to the General Partners, in accordance with their relative General Partner Percentage Interests, until the aggregate amount of such items allocated to the General Partners under this paragraph (iii) for such taxable period and all previous taxable periods is equal to the cumulative amount of cash distributed to the General Partners (or their assignees) as Incentive Distributions with respect to the period from the Closing Date through the end of such taxable period.

(iv) Qualified Income Offset. In the event any Partner unexpectedly receives any adjustments, allocations or distributions described in Treasury Regulation Sections 1.704-1 (b)(2)(ii)(d)(4), 1.704-1(b)(2)(ii)(d)(5), or 1.704-1 (b)(2)(ii)(d)(6), items of Partnership income and gain shall be specifically allocated to such Partner in an amount and manner sufficient to eliminate, to the extent required by the Treasury Regulations promulgated under Section 704(b) of the Code, the deficit balance, if any, in its Adjusted Capital Account created by such adjustments, allocations or distributions as quickly as possible unless such deficit balance is otherwise eliminated pursuant to
Section 5.1(d)(i) or (ii).

(v) Gross Income Allocations. In the event any Partner has a deficit balance in its Adjusted Capital Account at the end of any Partnership taxable period, such Partner shall be specially allocated items of Partnership gross income and gain in the amount of such excess as quickly as possible; provided, that an allocation pursuant to this Section 5.1(d)(v) shall be made only if and to the extent that such Partner would have a deficit balance in its Adjusted Capital Account after all other allocations provided for in this Section 5.1 have been tentatively made as if this Section 5.1(d)(v) were not in this Agreement.

(vi) Nonrecourse Deductions. Nonrecourse Deductions for any taxable period shall be allocated to the Partners in accordance with their respective

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Percentage Interests. If the Partnership Policy Committee determines in its good faith discretion that the Partnership's Nonrecourse Deductions must be allocated in a different ratio to satisfy the safe harbor requirements of the Treasury Regulations promulgated under Section 704(b) of the Code, the Partnership Policy Committee is authorized, upon notice to the Limited Partners, to revise the prescribed ratio to the numerically closest ratio that does satisfy such requirements.

(vii) Partner Nonrecourse Deductions. Partner Nonrecourse Deductions for any taxable period shall be allocated 100% to the Partner that bears the Economic Risk of Loss with respect to the Partner Nonrecourse Debt to which such Partner Nonrecourse Deductions are attributable in accordance with Treasury Regulation Section 1.704-2(i). If more than one Partner bears the Economic Risk of Loss with respect to a Partner Nonrecourse Debt, such Partner Nonrecourse Deductions attributable thereto shall be allocated between or among such Partners in accordance with the ratios in which they share such Economic Risk of Loss.

(viii) Nonrecourse Liabilities. For purposes of Treasury Regulation
Section 1.752-3(a)(3), the Partners agree that Nonrecourse Liabilities of the Partnership in excess of the sum of (A) the amount of Partnership Minimum Gain and (B) the total amount of Nonrecourse Built-in Gain shall be allocated among the Partners in accordance with their respective Percentage Interests.

(ix) Code Section 754 Adjustments. To the extent an adjustment to the adjusted tax basis of any Partnership asset pursuant to Section 734(b) or 743(b) of the Code is required, pursuant to Treasury Regulation Section 1.704-1(b)(2)(iv)(m), to be taken into account in determining Capital Accounts, the amount of such adjustment to the Capital Accounts shall be treated as an item of gain (if the adjustment increases the basis of the asset) or loss (if the adjustment decreases such basis), and such item of gain or loss shall be specially allocated to the Partners in a manner consistent with the manner in which their Capital Accounts are required to be adjusted pursuant to such Section of the Treasury regulations.

(x) Economic Uniformity. At the election of the Partnership Policy Committee with respect to any taxable period ending upon, or after, the termination of the Subordination Period, all or a portion of the remaining items of Partnership gross income or gain for such taxable period, if any, shall be allocated 100% to each Partner holding Subordinated Units in the proportion of the number of Subordinated Units held by such Partner to the total number of Subordinated Units then Outstanding, until each such Partner has been allocated an amount of gross income or gain which increases the Capital Account maintained with respect to such Subordinated Units to an amount equal to the product of (A) the number of Subordinated Units held by such Partner and (B) the Per Unit Capital Amount for a Common Unit. The purpose of this allocation is to establish uniformity between the Capital Accounts underlying Subordinated Units and the Capital Accounts underlying Common Units held by Persons other than the General Partners and their Affiliates immediately prior to the conversion of such Subordinated Units into Common Units. This allocation method for establishing such economic uniformity will only be available to the Partnership Policy Committee if the method for allocating the Capital Account maintained with respect to the Subordinated Units between the transferred and retained Subordinated Units pursuant to Section 4.4(c)(ii) does not otherwise provide such economic uniformity to the Subordinated Units.

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(xi) Curative Allocation.

(A) Notwithstanding any other provision of this Section 5.1, other than the Required Allocations, the Required Allocations shall be taken into account in making the Agreed Allocations so that, to the extent possible, the net amount of items of income, gain, loss and deduction allocated to each Partner pursuant to the Required Allocations and the Agreed Allocations, together, shall be equal to the net amount of such items that would have been allocated to each such Partner under the Agreed Allocations had the Required Allocations and the related Curative Allocation not otherwise been provided in this Section 5.1. Notwithstanding the preceding sentence, Required Allocations relating to (1) Nonrecourse Deductions shall not be taken into account except to the extent that there has been a decrease in Partnership Minimum Gain and (2) Partner Nonrecourse Deductions shall not be taken into account except to the extent that there has been a decrease in Partner Nonrecourse Debt Minimum Gain. Allocations pursuant to this Section 5.1(d)(xi)(A) shall only be made with respect to Required Alloca- tions to the extent the Partnership Policy Committee reasonably determines that such allocations will otherwise be inconsistent with the economic agreement among the Partners. Further, allocations pursuant to this Section 5.1(d)(xi)(A) shall be deferred with respect to allocations pursuant to clauses (1) and (2) hereof to the extent the Partnership Policy Committee reasonably determines that such allocations are likely to be offset by subsequent Required Allocations.

(B) The Partnership Policy Committee shall have reasonable discretion, with respect to each taxable period, to (1) apply the provisions of Section 5.1(d)(xi)(A) in whatever order is most likely to minimize the economic distortions that might otherwise result from the Required Allocations, and (2) divide all allocations pursuant to Section 5.1(d)(xi)(A) among the Partners in a manner that is likely to minimize such economic distortions.

5.2 ALLOCATIONS FOR TAX PURPOSES. (a) Except as otherwise provided herein, for federal income tax purposes, each item of income, gain, loss and deduction shall be allocated among the Partners in the same manner as its correlative item of "book" income, gain, loss or deduction is allocated pursuant to Section 5.1.

(b) In an attempt to eliminate Book - Tax Disparities attributable to a Contributed Property or Adjusted Property, items of income, gain, loss, depreciation, amortization and cost recovery deductions shall be allocated for federal income tax purposes among the Partners as follows:

(i) (A) In the case of a Contributed Property, such items attributable thereto shall be allocated among the Partners in the manner provided under Section 704(c) of the Code that takes into account the variation between the Agreed Value of such property and its adjusted basis at the time of contribution; and (B) except as otherwise provided in
Section 5.2(b)(iv), any item of Residual Gain or Residual Loss attributable to a Contributed Property shall be allocated among the Partners in the same manner as its correlative item of "book" gain or loss is allocated pursuant to Section 5.1.

(ii) (A) In the case of an Adjusted Property, such items shall
(1) first, be allocated among the Partners in a manner consistent with the principles of Section 704(c) of the Code

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to take into account the Unrealized Gain or Unrealized Loss attributable to such property and the allocations thereof pursuant to Section 4.4(d)(i) or (ii), and (2) second, in the event such property was originally a Contributed Property, be allocated among the Partners in a manner consistent with Section 5.2(b)(i)(A);and(B) except as otherwise provided in Section 5.2(b)(iv), any item of Residual Gain or Residual Loss attributable to an Adjusted Property shall be allocated among the Partners in the same manner as its correlative item of "book" gain or loss is allocated pursuant to Section 5.1.

(iii) Except as otherwise provided in Section 5.2(b)(iv), all other items of income, gain, loss and deduction shall be allocated among the Partners in the same manner as their correlative item of "book" gain or loss is allocated pursuant to Section 5.1.

(iv) Any items of income, gain, loss or deduction otherwise allocable under Section 5.2(b)(i)(B), 5.2(b)(ii)(B) or 5.2(b)(iii) shall be subject to allocation by the Partnership Policy Committee in a manner designed to eliminate, to the maximum extent possible, Book-Tax Disparities in a Contributed Property or Adjusted Property otherwise resulting from the application of the "ceiling" limitation (under Section 704(c) of the Code or Section 704(c) principles) to the allocations provided under Section 5.2(b)(i)(A) or 5.2(b)(ii)(A).

(c) For the proper administration of the Partnership and for the preservation of uniformity of the Units (or any class or classes thereof), the Partnership Policy Committee shall have sole discretion to (i) adopt such conventions as it deems appropriate in determining the amount of depreciation, amortization and cost recovery deductions; (ii) make special allocations for federal income tax purposes of income (including, without limitation, gross income) or deductions; and (iii) amend the provisions of this Agreement as appropriate (x) to reflect the proposal or promulgation of Treasury regulations under Section 704(b) or Section 704(c) of the Code or (y) otherwise to preserve or achieve uniformity of the Units (or any class or classes thereof). The Partnership Policy Committee may adopt such conventions, make such allocations and make such amendments to this Agreement as provided in this Section 5.2(c) only if such conventions, allocations or amendments would not have a material adverse effect on the Partners, the holders of any class or classes of Units issued and Outstanding or the Partnership, and if such allocations are consistent with the principles of Section 704 of the Code.

(d) The Partnership Policy Committee in its sole discretion may determine to depreciate the portion of an adjustment under Section 743(b) of the Code attributable to unrealized appreciation in any Adjusted Property (to the extent of the unamortized Book-Tax Disparity) using a predetermined rate derived from the depreciation method and useful life applied to the Partnership's common basis of such property, despite the inconsistency of such approach with Proposed Treasury Regulation Section 1.168-2(n) and Treasury Regulation Section 1.167(c)-1(a)(6). If the Partnership Policy Committee determines that such reporting position cannot reasonably be taken, the Partnership Policy Committee may adopt a depreciation convention under which all purchasers acquiring Units in the same month would receive depreciation, based upon the same applicable rate as if they had purchased a direct interest in the Partnership's property. If the Partnership Policy Committee chooses not to utilize such aggregate method, the Partnership Policy Committee may use any other reasonable depreciation convention to preserve the uniformity of the intrinsic tax characteristics of any Units that would not have a material adverse effect on the Limited Partners or the Record Holders of any class or classes of Units.

(e) Any gain allocated to the Partners upon the sale or other taxable disposition of any Partnership asset shall, to the extent possible, after taking into account other required allocations of gain pursuant to this Section 5.2, be characterized as Recapture Income in the same proportions and

34

to the same extent as such Partners (or their predecessors in interest) have been allocated any deductions directly or indirectly giving rise to the treatment of such gains as Recapture Income.

(f) All items of income, gain, loss, deduction and credit recognized by the Partnership for federal income tax purposes and allocated to the Partners in accordance with the provisions hereof shall be determined without regard to any election under Section 754 of the Code which may be made by the Partnership; provided, however, that such allocations, once made, shall be adjusted as necessary or appropriate to take into account those adjustments permitted or required by Sections 734 and 743 of the Code.

(g) Each item of Partnership income, gain, loss and deduction attributable to a transferred Partnership Interest of a General Partner or to transferred Units shall, for federal income tax purposes, be determined on an annual basis and prorated on a monthly basis and shall be allocated to the Partners as of the opening of the New York Stock Exchange on the first Business Day of each month; provided, however, that (i) if the Underwriter's Overallotment Option is not exercised, such items for the period beginning on the Closing Date and ending on the last day of the month in which the Closing Date occurs shall be allocated to Partners as of the opening of the New York Stock Exchange on the first Business Day of the next succeeding month or (ii) if the Underwriters' Overallotment Option is exercised, such items for the period beginning on the Closing Date and ending on the last day of the month in which the Second Time of Delivery (as defined in the Underwriting Agreement) occurs shall be allocated to the Partners as of the opening of the New York Stock Exchange on the first Business Day of the next succeeding month; and provided, further, that gain or loss on a sale or other disposition of any assets of the Partnership other than in the ordinary course of business shall be allocated to the Partners as of the opening of the New York Stock Exchange on the first Business Day of the month in which such gain or loss is recognized for federal income tax purposes. The Partnership Policy Committee may revise, alter or otherwise modify such methods of allocation as it determines necessary, to the extent permitted or required by
Section 706 of the Code and the regulations or rulings promulgated thereunder.

(h) Allocations that would otherwise be made to a Limited Partner under the provisions of this Article V shall instead be made to the beneficial owner of Units held by a nominee in any case in which the nominee has furnished the identity of such owner to the Partnership in accordance with Section 6031 (c) of the Code or any other method acceptable to the Partnership Policy Committee in its sole discretion.

5.3 REQUIREMENT AND CHARACTERIZATION OF DISTRIBUTIONS. (a) Within 45 days following the end of each calendar quarter (or following the period from the Closing Date to December 31, 1993) an amount equal to 100% of Available Cash with respect to such quarter (or period) shall be distributed in accordance with this Article V by the Partnership to the Partners, as of the Record Date selected by the Partnership Policy Committee in its reasonable discretion. All amounts of Available Cash distributed by the Partnership on any date from any source shall be deemed to be Cash from Operations until the sum of all amounts of Available Cash theretofore distributed by the Partnership to Partners pursuant to Section 5.4 equals the aggregate amount of all Cash from Operations generated by the Partnership since the Closing Date through the close of the immediately preceding calendar quarter. Any remaining amounts of Available Cash distributed by the Partnership on such date shall, except as otherwise provided in Section 5.5, be deemed to be Cash from Interim Capital Transactions.

(b) Notwithstanding the definitions of Available Cash and Cash from Operations contained herein, disbursements (including, without limitation, contributions to the Intermediate Partnership or disbursements on behalf of the Intermediate Partnership) made or reserves established after the end

35

of any quarter shall be deemed to have been made or established, for purposes of determining Available Cash and Cash from Operations, within such quarter if the Partnership Policy Committee so determines. Notwithstanding the foregoing, in the event of the dissolution and liquidation of the Partnership, all proceeds of such liquidation shall be applied and distributed in accordance with, and subject to the terms and conditions of, Sections 14.3 and 14.4.

5.4 DISTRIBUTIONS OF CASH FROM OPERATIONS. Available Cash with respect to any calendar quarter that is deemed to be Cash from Operations pursuant to the provisions of Section 5.3 or 5.5 shall be distributed as follows, except as otherwise required in respect of additional Partnership Securities issued pursuant to Section 4.2(b):

(a) First, 99% to the Limited Partners holding Common Units, in the proportion that the number of Common Units held by each such Limited Partner bears to the total number of Common Units Outstanding as of the last day of such quarter, and 1% to the General Partners, in accordance with their relative General Partner Percentage Interests, until there has been distributed in respect of each Common Unit Outstanding as of the last day of such quarter an amount equal to the Minimum Quarterly Distribution;

(b) Second, 99% to the Limited Partners holding Common Units, in the proportion that the number of Common Units held by each such Limited Partner bears to the total number of Common Units Outstanding as of the last day of such quarter, and 1% to the General Partners, in accordance with their relative General Partner Percentage Interests, until there has been distributed in respect of each Common Unit Outstanding as of the last day of such quarter an amount equal to the Cumulative Common Unit Arrearage, if any, existing with respect to such quarter;

(c) Third, 99% to the Partners holding Subordinated Units, in the proportion that the number of Subordinated Units held by each such Partner bears to the total number of Subordinated Units Outstanding as of the last day of such quarter, and 1% to the General Partners, in accordance with their relative General Partner Percentage Interests, until there has been distributed in respect of each Subordinated Unit Outstanding as of the last day of such quarter an amount equal to the Minimum Quarterly Distribution;

(d) Fourth, 99% to all Limited Partners holding Units, in the proportion that the total number of Units held by each such Limited Partner bears to the total number of Units Outstanding as of the last day of such quarter, and 1% to the General Partners, in accordance with their relative General Partner Percentage Interests, until there has been distributed in respect of each Unit Outstanding as of the last day of such quarter an amount equal to the excess of the First Target Distribution over the Minimum Quarterly Distribution;

(e) Fifth, 85.8673% to all Limited Partners holding Units, in the proportion that the total number of Units held by each such Limited Partner bears to the total number of Units Outstanding as of the last day of such quarter, and 14.1327% to the General Partners, in accordance with their relative General Partner Percentage Interests, until there has been distributed in respect of each Unit Outstanding as of the last day of such quarter an amount equal to the excess of the Second Target Distribution over the First Target Distribution;

(f) Sixth, 75.7653% to all Limited Partners holding Units, in the proportion that the total number of Units held by each such Limited Partner bears to the total number of Units Outstanding as of the last day of such quarter, and 24.2347% to the General Partners, in accordance with their relative General Partner Percentage Interests, until there has been

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distributed in respect of each Unit Outstanding as of the last day of such quarter an amount equal to the excess of the Third Target Distribution over the Second Target Distribution; and

(g) Thereafter, 50.5102% to all Limited Partners holding Units, in the proportion that the total number of Units held by each such Limited Partner bears to the total number of Units Outstanding as of the last day of such quarter, and 49.4898% to the General Partners, in accordance with their relative General Partner Percentage Interests;

provided, however, if the Minimum Quarterly Distribution, the First Target Distribution, the Second Target Distribution and the Third Target Distribution have been reduced to zero pursuant to the second sentence of Section 5.6, the distributions of Available Cash that is deemed to be Cash from Operations with respect to any quarter will be made in accordance with Section 5.4(g).

5.5 Distributions of Cash from Interim Capital Transactions. Available Cash that constitutes Cash from Interim Capital Transactions shall be distributed, unless the provisions of Section 5.3 require otherwise, 99% to all Limited Partners, in accordance with their respective Percentage Interests, and 1% to the General Partners, in accordance with their relative General Partner Percentage Interests, until a hypothetical holder of a Common Unit acquired on the Closing Date has received with respect to such Common Unit, during the period since the Closing Date through such date, distributions of Available Cash that are deemed to be Cash from Interim Capital Transactions in an aggregate amount equal to the Initial Unit Price. Thereafter, all Available Cash shall be distributed as if it were Cash from Operations and shall be distributed in accordance with Section 5.4.

5.6 Adjustment of Minimum Quarterly Distribution and Target Distribution Levels. (a) The Minimum Quarterly Distribution, First Target Distribution, Second Target Distribution and Third Target Distribution shall be proportionately adjusted in the event of any distribution, combination or subdivision (whether effected by a distribution payable in Units or otherwise) of Units or other Partnership Securities in accordance with Section 4.9. In the event of a distribution of Available Cash that is deemed to be Cash from Interim Capital Transactions, the Minimum Quarterly Distribution, First Target Distribution, Second Target Distribution and Third Target Distribution shall be adjusted proportionately downward to equal the product obtained by multiplying the otherwise applicable Minimum Quarterly Distribution, First Target Distribution, Second Target Distribution and Third Target Distribution, as the case may be, by a fraction of which the numerator is the Unrecovered Initial Unit Price of the Common Units immediately after giving effect to such distribution and of which the denominator is the Unrecovered Initial Unit Price of the Common Units immediately prior to giving effect to such distribution.

(b) The Minimum Quarterly Distribution, First Target Distribution, Second Target Distribution and Third Target Distribution shall also be subject to adjustment pursuant to Section 9.6.

5.7 Special Provisions Relating to the Subordinated Units.

(a) Except with respect to the right to vote on or approve matters requiring the vote or approval of a percentage of the holders of Outstanding Common Units and the right to participate in allocations of income, gain, loss and deduction and distributions of cash made with respect to Common Units pursuant to this Article V, the holder of a Subordinated Unit shall have all of the rights and obligations of a Limited Partner holding Common Units hereunder; provided, however, that immediately upon the end of the Subordination Period or upon the exercise by the Underwriters of the Overallotment Option (to the extent of any Subordinated Units affected thereby as provided in subparagraph (b) below), the holder of a Subordinated Unit shall possess all of the rights and obligations of a Limited Partner holding Common Units hereunder, including, without limitation, the

37

right to participate in allocations of income, gain, loss and deduction and distributions of cash made with respect to Common Units pursuant to this Article V (but such Subordinated Units shall remain subject to the provisions of Sections 4.4(c)(ii), 5.1(d)(x) and 11.7).

(b) Upon exercise by the Underwriters of the Overallotment Option, Subordinated Units owned by Northern Plains and Pan Border shall be sold by them to the Underwriters, and upon such sale such Subordinated Units shall be converted (automatically, without any action on the part of Northern Plains or Pan Border and subject to subparagraph (c) immediately below) into Common Units in the hands of the Underwriters, and for each 33 Units so purchased by the Underwriters pursuant to exercise of the Overallotment Option, (i) 20 Subordinated Units sold by Northern Plains shall be converted into 20 Common Units in the hands of the Underwriters, and (ii) 13 Subordinated Units sold by Pan Border shall be converted into 13 Common Units in the hands of the Underwriters. Simultaneously with the purchase of Units by the Underwriters pursuant to exercise of the Overallotment Option, for each 33 Units so purchased by the Underwriters from Northern Plains and Pan Border, 7 Subordinated Units owned by Northwest Border shall be converted (automatically, without any action on the part of Northwest Border and subject to subparagraph (c) immediately below) into 7 Common Units in the hands of Northwest Border.

(c) After the end of the Subordination Period or upon the exercise by the Underwriters of the Overallotment Option (to the extent of any Subordinated Units affected by such exercise of the Overallotment Option as provided in subparagraph (b) immediately above), once the Partnership Policy Committee determines, based on advice of counsel, that a Subordinated Unit has, as a substantive matter, like intrinsic economic and federal income tax characteristics, in all material respects, to the intrinsic economic and federal income tax characteristics of a Common Unit then Outstanding, then the Subordinated Unit shall be converted to a Common Unit (on a one-for-one basis) and from that time forward (which time shall, except as provided in subparagraph
(b) above, in no event commence before the first day following the end of the Subordination Period) shall constitute a Common Unit for all purposes under this Agreement. In connection with the condition set forth above, it is understood that the Partnership Policy Committee may take whatever reasonable steps are required to provide economic uniformity to the Common Units in preparation for a conversion into Common Units, including the application of Sections 4.4(c) and
5.1 (d)(x); provided, however, that no such steps may be taken that would have a material adverse effect on the Limited Partners holding Common Units or the Record Holders of any class of Units.

ARTICLE VI
MANAGEMENT AND OPERATION OF BUSINESS

6.1 Partnership Policy Committee, (a) As provided in Section 6.2, the powers of the Partnership shall be exercised by or under authority of, and the business and affairs of the Partnership shall be managed by or under the direction of, a committee (the "Partnership Policy Committee") consisting of one person appointed by each General Partner. Each member of the Partnership Policy Committee shall serve in such capacity until his successor or replacement shall have been appointed by the General Partner that originally appointed such member. The appointment of any such successor or replacement, which decision may be made in the sole discretion of the appointing General Partner from time to time, shall become effective upon the delivery by the appointing General Partner of written notice to each other General Partner. As of the date hereof, the General Partners have notified each other of their respective initial appointments to the Partnership Policy Committee. The Chairman of the Partnership Policy Committee shall be the appointee of Northern Plains, who shall preside at all meetings of the Partnership Policy Committee.

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(b) Voting; Quorum; Required Vote for Action. Unless otherwise required by law or the provisions hereof,

(i) each member of the Partnership Policy Committee shall have a number of votes that corresponds to the General Partner Percentage Interest of the General Partner that appointed such member (if the Combined Interest of a General Partner is purchased by another General Partner or General Partners pursuant to the terms hereof, the voting power of the Departing Partner shall be reallocated to such purchasing General Partner(s) based on the portion of the Departing Partner's General Partner Percentage Interest purchased by such General Partner(s));

(ii) the presence at a meeting of members of the Partnership Policy Committee that in the aggregate represent a majority of the total number of votes held by all members of the Partnership Policy Committee shall constitute a quorum at any such meeting for the transaction of business; and

(iii) the act of members of the Partnership Policy Committee that in the aggregate represent a majority of the total number of votes held by all members of the Partnership Policy Committee shall be deemed to constitute the act of the Partnership Policy Committee. In the event of a 50-50 split in voting with respect to any matter before the Partnership Policy Committee, any member of the Partnership Policy Committee shall have the right, exercisable by delivery of written notice to the other members of the Partnership Policy Committee within 30 days after such vote, to cause such matter to be submitted to binding arbitration in accordance with the following procedures:

(A) The members of the Partnership Policy Committee shall, within 15 Business Days following the receipt by each non-submitting member of the notice referred to above, attempt to agree upon an independent expert qualified to decide on the particular matter with respect to which a 50-50 split in voting has occurred (the expert so selected being herein referred to as the "Arbitrator"); provided, however, that if such agreement cannot be reached within such period, the member(s) of the Partnership Policy Committee voting affirmatively on such matter shall select a qualified independent expert within 15 days thereafter, the member(s) of the Partnership Policy Committee voting against such matter shall select a qualified independent expert, and the two experts so selected shall, within ten days following the selection of the latter of the two, select a third qualified independent expert, and the three experts so selected shall constitute the Arbitrator;

(B) The Arbitrator shall promptly gather all materials, information, testimony and evidence it deems relevant to the particular matter before it (and each member of the Partnership Policy Committee will provide any such materials, information, testimony and evidence requested by the Arbitrator, except to the extent any information so requested is proprietary, subject to a third party confidentiality agreement or subject to an attorney-client or other privilege);

(C) The sole consideration of the Arbitrator in determining its decision with respect to any matter submitted to it shall be the best interests of the Partnership;

(D) All decisions of the Arbitrator, including the final decision of the Arbitrator with respect to any matters submitted to it, shall be final and binding on the

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General Partners and the Partnership Policy Committee; if the Arbitrator consists of three experts as contemplated by clause (A) above, all decisions of such experts, including the final decision of such experts as the Arbitrator, shall be made by approval of a majority of such experts;

(E) The Arbitrator shall use all reasonable efforts to render its decision with respect to any matter submitted to it as soon as practicable, but in any event on or before the 30th Business Day following the date on which the identity of the Arbitrator is finally determined pursuant to clause (A) above;

(F) The costs and expenses of any such arbitration shall be borne by the Partnership; and

(G) To the extent not inconsistent with the terms of this Agreement, any such arbitration shall be conducted in Houston, Texas in accordance with the then current rules of the American Arbitration Association.

(c) Meetings. Regular meetings of the Partnership Policy Committee shall be held at least once each calendar quarter on such date(s) and at such time(s) as may be determined by the Chairman of the Partnership Policy Committee. Written notice stating the place, day and hour of each regular meeting of the Partnership Policy Committee shall be delivered by the Chairman to every other member not less than 10 nor more than 60 days prior to the date of the meeting. Special meetings of the Partnership Policy Committee may be called by written request of any member of the Partnership Policy Committee, on at least 48 hours prior written notice to the other members (which notice may be personally delivered or sent by telecopy, with confirmation of receipt by return telecopy). Any such notice, or waiver thereof, need not state the purpose of such meeting. Attendance of a member at a meeting shall constitute a waiver of notice of such meeting, unless such member attends for the express purpose of objecting, at the beginning of the meeting, to the transaction of any business because the meeting was not properly called or convened. Unless otherwise agreed upon by all members, all meetings of the Partnership Policy Committee shall be held at the principal office of the Partnership.

(d) Action Without a Meeting; Telephone Conference Meeting. Any action required or permitted to be taken at any meeting of the Partnership Policy Committee may be taken without a meeting, and without prior notice, if a consent or consents in writing, setting forth the action so taken, shall be signed by all members of the Partnership Policy Committee. Any such consent shall be filed with the minutes of proceedings of the Partnership Policy Committee and shall have the same force and effect as a unanimous vote at a meeting. Subject to the requirement for notice of such meetings, members of the Partnership Policy Committee may participate in a meeting of the Partnership Policy Committee by means of a conference telephone or similar communications equipment, by means of which all persons participating in the meeting can hear each other, and participation in such meetings shall constitute presence in person at the meeting, except where a person participates in the meeting for the express purpose of objecting to the transaction of any business on the ground that the meeting is not properly called or convened.

(e) Designation; Powers. The Partnership Policy Committee may delegate to one or more Persons, or designate one or more committees, that shall have and may exercise such of the powers and authority of the Partnership Policy Committee with respect to the management of the business and affairs of the Partnership as may be provided in a written resolution of the Partnership Policy Committee. Pursuant to such authority and as set forth in the Administrative Services Agreement, the Partnership Policy Committee has delegated the performance of certain administrative services

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in connection with the day-to-day business and affairs of the Partnership to NBP Services Corporation, a Delaware corporation.

(f) Substitution of Members. Each member of the Partnership Policy Committee may designate one or more persons to act as alternate members of the Partnership Policy Committee, who may replace such member at any meeting of the Partnership Policy Committee.

6.2 MANAGEMENT. (a) Except as otherwise expressly provided in this Agreement, all management powers over the business and affairs of the Partnership shall be exclusively vested in the Partnership Policy Committee, and no General Partner, Limited Partner or Assignee shall have any management power over the business and affairs of the Partnership. In addition to the powers now or hereafter granted a general partner of a limited partnership under applicable law or which are granted to the Partnership Policy Committee under any other provision of this Agreement, the Partnership Policy Committee, subject to
Section 6.4, shall have full power and authority to do all things and on such terms as it, in its sole discretion, may deem necessary or appropriate to conduct the business of the Partnership, to exercise all powers set forth in
Section 3.2 and to effectuate the purposes set forth in Section 3.1, including, without limitation, (i) the making of any expenditures, the lending or borrowing of money, the assumption or guarantee of, or other contracting for, indebtedness and other liabilities, the issuance of evidences of indebtedness and the incurring of any other obligations; (ii) the making of tax, regulatory and other filings, or rendering of periodic or other reports to governmental or other agencies having jurisdiction over the business or assets of the Partnership;
(iii) the acquisition, disposition, mortgage, pledge, encumbrance, hypothecation or exchange of any or all of the assets of the Partnership or the merger or other combination of the Partnership with or into another Person (the matters described in this clause (iii) being subject, however, to any prior approval that may be required by Section 6.4); (iv) the use of the assets of the Partnership (including, without limitation, cash on hand) for any purpose consistent with the terms of this Agreement, including, without limitation, the financing of the conduct of the operations of the Partnership, the Intermediate Partnership or Northern Border Pipeline, the lending of funds to other Persons (including, without limitation, the Intermediate Partnership and Northern Border Pipeline) and the repayment of obligations of the Partnership, the Intermediate Partnership or Northern Border Pipeline and the making of capital contributions to the Intermediate Partnership; (v) the negotiation, execution and performance of any contracts, conveyances or other instruments (including, without limitation, instruments that limit the liability of the Partnership under contractual arrangements to all or particular assets of the Partnership, with the other party to the contract to have no recourse against the General Partners or their assets other than its interest in the Partnership, even if same results in the terms of the transaction being less favorable to the Partnership than would otherwise be the case); (vi) the distribution of Partnership cash; (vii) the selection and dismissal of officers, employees and agents (including, without limitation, officers having titles such as "president," "chief executive officer," "vice president," "chief financial and accounting officer," "secretary" and "treasurer"), outside attorneys, accountants, consultants and contractors and the determination of their compensation and other terms of employment or hiring; (viii) the maintenance of such insurance for the benefit of the Partnership, the Intermediate Partnership and the Partners as it deems necessary or appropriate; (ix) the formation of, or acquisition of an interest in, and the contribution of property to, any further limited or general partnerships, joint ventures, corporations or other relationships (including, without limitation, the acquisition of interests in, and the contributions of property to, the Intermediate Partnership from time to time); (x) the control of any matters affecting the rights and obligations of the Partnership, including, without limitation, the bringing and defending of actions at law or in equity and otherwise engaging in the conduct of litigation and the incurring of legal expense and the settlement of claims and litigation; (xi) the indemnification of any Person against liabilities and contingencies to the extent permitted by law;
(xii) the entering into of listing agreements with the New York Stock Exchange and any other securities exchange and the delisting of some or all of the Units

41

from, or requesting that trading be suspended on, any such exchange (subject to any prior approval that may be required under Section 1.6); (xiii) the purchase, sale or other acquisition or disposition of Units; and (xiv) the undertaking of any action in connection with the Partnership's participation in the Intermediate Partnership as a limited partner (including, without limitation, contributions or loans of funds by the Partnership to the Intermediate Partnership).

(b) Notwithstanding any other provision of this Agreement, the Intermediate Partnership Agreement, the Delaware Act or any applicable law, rule or regulation, each of the Partners and Assignees and each other Person who may acquire an interest in Units or any other Partnership Interest hereby (i) approves, ratifies and confirms the execution, delivery and performance by the parties thereto of this Agreement, the Intermediate Partnership Agreement, the Underwriting Agreement, the Conveyance Agreement, the Credit Agreement and the Administrative Services Agreement, and the engaging by any Affiliate of a General Partner in the transportation of natural gas and related activities, including, without limitation, the expansion of existing facilities owned or operated by such Affiliate, the acquisition of additional facilities or the construction of new facilities, even if such activities are in direct competition with the business and activities of the Partnership, the Intermediate Partnership or Northern Border Pipeline; (ii) agrees that the Partnership Policy Committee (on its own or through any officer selected as the chief executive officer, chief financial and accounting officer, president or any vice-president of the Partnership pursuant to Section 6.2(a)(vii)) is authorized to execute, deliver and perform the agreements referred to in clause
(i) of this sentence and the other agreements, acts, transactions and matters described in the Registration Statement on behalf of the Partnership without any further act, approval or vote of the Partners or the Assignees or the other Persons who may acquire an interest in Units; (iii) agrees that the execution, delivery or performance by the General Partners, the Partnership Policy Committee, the Partnership, the Intermediate Partnership or any Affiliate of any of them of this Agreement or any agreement authorized or permitted under this Agreement (including, without limitation, the exercise by a General Partner or any Affiliate of a General Partner of the rights accorded pursuant to Article
XVII), or the engaging by any Affiliate of a General Partner in any of the activities specified in clause (i) above, even if such activities are in direct competition with the business and activities of the Partnership, the Intermediate Partnership or Northern Border Pipeline, shall not constitute a breach by the General Partners, the members of the Partnership Policy Committee, any officers of the Partnership or any such Affiliate of any duty that such Persons may owe the Partnership, the General Partners, the Limited Partners, the Assignees or any other Persons under this Agreement (or any other agreements) or of any duty stated or implied by law or equity; and (iv) agrees that each General Partner and its designated representative on the management committee for Northern Border Pipeline shall not be in breach of any standard of care or duty imposed by this Agreement or under the Delaware Act or any applicable law, rule or regulation with respect to the voting of the Intermediate Partnership's interest on the management committee for Northern Border Pipeline if such designated representative acted in good faith and in a manner reasonably believed by such person to be in, or not inconsistent with, the best interests of the Partnership and the Intermediate Partnership.

6.3 CERTIFICATE OF LIMITED PARTNERSHIP. The General Partners have caused the Certificate of Limited Partnership to be filed with the Secretary of State of the State of Delaware as required by the Delaware Act, and the Partnership Policy Committee shall use all reasonable efforts to cause to be filed such other certificates or documents as may be determined by the Partnership Policy Committee in its sole discretion to be reasonable and necessary or appropriate for the formation, continuation, qualification and operation of a limited partnership (or a partnership in which the limited partners have limited liability) in the State of Delaware or any other state in which the Partnership may elect to do business or own property. To the extent that such action is determined by the Partnership Policy Committee in its sole discretion to be reasonable and necessary or appropriate, the Partnership Policy Committee shall file amendments to and restatements of the Certificate of Limited

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Partnership and do all things to maintain the Partnership as a limited partnership (or a partnership in which the limited partners have limited liability) under the laws of the State of Delaware or of any other state in which the Partnership may elect to do business or own property. Subject to the terms of Section 7.5(a), the Partnership Policy Committee shall not be required, before or after filing, to deliver or mail a copy of the Certificate of Limited Partnership, any qualification document or any amendment thereto to any Limited Partner or Assignee.

6.4 RESTRICTIONS ON THE PARTNERSHIP POLICY COMMITTEE'S AUTHORITY. (a) The Partnership Policy Committee may not, without written approval of the specific act by all of the Outstanding Units or by other written instrument executed and delivered by all of the Outstanding Units subsequent to the date of this Agreement, take any action in contravention of this Agreement, including, without limitation, (i) any act that would make it impossible to carry on the ordinary business of the Partnership, except as otherwise provided in this Agreement; (ii) possess Partnership property, or assign any rights in specific Partnership property, for other than a Partnership purpose; (iii) admit a Person as a Partner, except as otherwise provided in this Agreement; or (iv) amend this Agreement in any manner, except as otherwise provided in this Agreement.

(b) Except as provided in Articles XIV and XVI, the Partnership Policy Committee may not (i) sell, exchange or otherwise dispose of all or substantially all of the Partnership's assets in a single transaction or a series of related transactions, (ii) approve on behalf of the Partnership the sale, exchange or other disposition of all or substantially all of the assets of the Intermediate Partnership, or (iii) vote the interest of the Partnership as a limited partner of the Intermediate Partnership in favor of the voting by the representatives of the Intermediate Partnership on the Northern Border Management Committee in favor of (A) the sale, exchange or other disposition of all or substantially all of Northern Border Pipeline's assets in a single transaction or in a series of related transactions or (B) the liquidation or merger, consolidation or other combination of Northern Border Pipeline with or into another entity, in any such case without the approval of at least two-thirds of the Outstanding Units during the Subordination Period and thereafter without the approval of at least a majority of the Outstanding Units; provided, however, that this provision shall not preclude or limit the Partnership Policy Committee's ability to mortgage, pledge, hypothecate or grant a security interest in all or substantially all of the Partnership's assets and shall not apply to any forced sale of any or all of the Partnership's assets pursuant to the foreclosure of, or other realization upon, any such encumbrance. Without the approval of at least two-thirds of the Outstanding Units, the Partnership Policy Committee shall not, on behalf of the Partnership, (aa) consent to any amendment to the Intermediate Partnership Agreement or, except as expressly permitted by Section 6.10(d), take any action permitted to be taken by a partner of the Intermediate Partnership, in either case, that would have a material adverse effect on the Partnership as a partner of the Intermediate Partnership or (bb) except as permitted under Sections 11.2,13.1 and 13.2, elect or cause the Partnership to elect a successor general partner of the Intermediate Partnership.

(c) Unless approved by the affirmative vote of the holders of at least two-thirds of each class of Outstanding Units, including two-thirds of Common Units (excluding for purposes of such determination, during the Subordination Period, Common Units owned by the General Partners and their Affiliates), the Partnership Policy Committee shall not take any action or refuse to take any reasonable action the effect of which, if taken or not taken, as the case may be, would be to cause the Partnership, the Intermediate Partnership or Northern Border Pipeline to be treated as an association taxable as a corporation or otherwise to be taxed as an entity for federal income tax purposes; provided that this Section 6.4(c) shall not be construed to apply to amendments to this Agreement (which are governed by Article XV) or mergers or consolidations of the Partnership with any Person (which, in the case of mergers or consolidations of the Partnership, the Intermediate Partnership or Northern Border Pipeline with any Person, are governed by Article XVI).

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(d) Each General Partner agrees that, at all times while serving as a general partner of the Partnership, it will not make any dividend or distribution on, or repurchase any shares of, its stock or take any other action within its control if the effect of such dividend, distribution, repurchase or other action would be to reduce its net worth below an amount necessary to receive an Opinion of Counsel that the Partnership will be treated as a partnership for federal income tax purposes.

6.5 REIMBURSEMENT OF THE GENERAL PARTNERS AND THE PARTNERSHIP POLICY COMMITTEE. (a) Except as provided in this Section 6.5 and elsewhere in this Agreement or in the Intermediate Partnership Agreement, neither the General Partners nor the members of the Partnership Policy Committee shall be compensated for their services as general partners of the Partnership or the Intermediate Partnership or as members of the Partnership Policy Committee, respectively.

(b) Each of the General Partners and the members of the Partnership Policy Committee shall be reimbursed on a monthly basis, or such other basis as the Partnership Policy Committee may determine in its reasonable discretion, for (i) all direct and indirect expenses it incurs or payments it makes on behalf of the Partnership (including, without limitation, amounts paid to any Person to perform services for the Partnership or for the General Partners or the Partnership Policy Committee in the discharge of their duties to the Partnership), and (ii) all other necessary or appropriate expenses allocable to the Partnership or otherwise reasonably incurred by such Person in connection with operating the Partnership's business (including, without limitation, expenses allocated to such Person by its Affiliates); provided, however, that (A) NBP Services Corporation and its Affiliates, including Northern Plains, shall not be reimbursed hereunder for any amounts that are duplicative of amounts paid by the Partnership or the Intermediate Partnership to NBP Services Corporation pursuant to the Administrative Services Agreement, (B) Northern Plains shall not be reimbursed for any amounts that are duplicative of amounts paid to it by Northern Border Pipeline pursuant to that certain Operating Agreement dated February 28,1980, as amended, by and between Northern Plains and Northern Border Pipeline and (C) nothing herein shall be construed to grant to any of the General Partners the power or authority to operate the Partnership's business (it being understood that the business and affairs of the Partnership shall be managed by or under the direction of the Partnership Policy Committee). The Partnership Policy Committee shall determine the fees and expenses that are allocable to the Partnership in any reasonable manner determined by the Partnership Policy Committee in its sole discretion. Reimbursements pursuant to this Section 6.5 shall be in addition to any reimbursement to such Persons as a result of indemnification pursuant to Section 6.8.

(c) Subject to Section 4.2(c), the Partnership Policy Committee in its sole discretion and without the approval of the Limited Partners may propose and adopt on behalf of the Partnership employee benefit and incentive plans (including, without limitation, plans involving the issuance of Units), or issue Partnership Securities pursuant to any employee benefit or incentive plan maintained or sponsored by a General Partner or one of its Affiliates, the Partnership or the Intermediate Partnership, in each case for the benefit of employees of the General Partners, the Partnership, the Intermediate Partnership or any Affiliate of any of them in respect of services performed, directly or indirectly, for the benefit of the Partnership or the Intermediate Partnership.

6.6 OUTSIDE ACTIVITIES. (a) After the Closing Date, each General Partner, for so long as it is a general partner of the Partnership, (i) agrees that its sole business will be to act as a general partner of the Partnership and the Intermediate Partnership and to undertake activities that are ancillary or related thereto (including being a limited partner in the Partnership) and to take such other action and conduct such other activities permitted to be taken or conducted by a general partner of Northern Border Pipeline pursuant to the terms of the Northern Border Pipeline Partnership

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Agreement (including, in the case of Northern Plains, acting as operator of the Pipeline System pursuant to the Operating Agreement), and (ii) shall not enter into or conduct any business or incur any debts or liabilities except (A) in connection with or incidental to (Y) its performance of the activities required or authorized by the Intermediate Partnership Agreement or this Agreement or described in or contemplated by the Registration Statement and (Z) the acquisition, ownership or disposition of partnership interests in the Partnership and the Intermediate Partnership (except that, notwithstanding the foregoing, employees of each General Partner may perform services for Affiliates of such General Partner) and (B) any business, debts or liabilities permitted of a general partner of Northern Border Pipeline pursuant to the terms of the Northern Border Pipeline Partnership Agreement.

(b) Except as described in the Registration Statement or Section 6.6(a), no Indemnitee shall be expressly or implicitly restricted or proscribed pursuant to this Agreement, the Intermediate Partnership Agreement, the Northern Border Pipeline Partnership Agreement or the partnership relationship established hereby or thereby from engaging in other activities for profit, whether in the businesses engaged in by the Partnership, the Intermediate Partnership or Northern Border Pipeline or anticipated to be engaged in by the Partnership, the Intermediate Partnership, Northern Border Pipeline or otherwise, including, without limitation, in the case of any Affiliates of the General Partners, those businesses and activities described in or contemplated by Section 6.2(b)(i) and by the Registration Statement. Without limitation of and subject to the foregoing, each Indemnitee (other than a General Partner) shall have the right to engage in businesses of every type and description and to engage in and possess an interest in other business ventures of any and every type or description, independently or with others, including, without limitation, in the case of any Affiliates of the General Partners, business interests and activities of the type described in Section 6.2(b)(i), and none of the same shall constitute a breach of this Agreement, the Intermediate Partnership Agreement or any duty to the Partnership, the Intermediate Partnership or any Partners. Neither the Partnership, the Intermediate Partnership, any Limited Partner nor any other Person shall have any rights by virtue of this Agreement, the Intermediate Partnership Agreement, the Northern Border Pipeline Partnership Agreement or the partnership relationship established hereby or thereby in any business ventures of any Indemnitee (subject, in the case of a General Partner, to compliance with Section 6.6(a)), and such Indemnitees shall have no obligation to offer any interest in any such business ventures to the Partnership, the Intermediate Partnership, Northern Border Pipeline, any Limited Partner or any other Person. The General Partners and any other Persons affiliated with the General Partners may acquire Units or other Partnership Securities, in addition to those acquired by any of such Persons on the Closing Date, and shall be entitled to exercise all rights of an Assignee or Limited Partner, as applicable, relating to such Units or Partnership Securities, as the case may be.

(c) Without limitation of Sections 6.6(a) and 6.6(b), and notwithstanding anything to the contrary in this Agreement, the competitive activities of any Indemnitees are hereby approved by all Partners, and it shall not be deemed to be a breach of the fiduciary duties of the General Partners and the members of the Partnership Policy Committee for such Persons to permit an Indemnitee to engage in a business opportunity in preference to or to the exclusion of the Partnership, if such activities are permitted by this Agreement or the Intermediate Partnership Agreement.

6.7 LOANS TO AND FROM THE GENERAL PARTNERS; CONTRACTS WITH AFFILIATES. (a)
(i) Each General Partner or any Affiliate thereof may lend to the Partnership or the Intermediate Partnership, and the Partnership and the Intermediate Partnership may borrow, funds needed or desired by the Partnership and the Intermediate Partnership for such periods of time as the Partnership Policy Committee may determine and (ii) each General Partner or any Affiliate thereof may borrow from the Partnership or the Intermediate Partnership, and the Partnership and the Intermediate Partnership

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may lend to such General Partner or such Affiliate, excess funds of the Partnership and the Intermediate Partnership for such periods of time and in such amounts as the Partnership Policy Committee may determine; provided, however, that in either such case the lending party may not charge the borrowing party interest at a rate greater than the rate that would be charged the borrowing party (without reference to the lending party's financial abilities or guarantees), by unrelated lenders on comparable loans. The borrowing party shall reimburse the lending party for any costs (other than any additional interest costs) incurred by the lending party in connection with the borrowing of such funds. For purposes of this Section 6.7(a) and Section 6.7(b), the term "Partnership" shall include any Affiliate of the Partnership that is controlled by the Partnership and the term "Intermediate Partnership" shall include any Affiliate of the Intermediate Partnership that is controlled by the Intermediate Partnership.

(b) The Partnership may lend or contribute to the Intermediate Partnership, and the Intermediate Partnership may borrow, funds on terms and conditions established in the sole discretion of the Partnership Policy Committee; provided, however, that the Partnership may not charge the Intermediate Partnership interest at a rate greater than the rate that would be charged to the Intermediate Partnership (without reference to the financial abilities or guarantees of the General Partners), by unrelated lenders on comparable loans. The foregoing authority shall be exercised by the Partnership Policy Committee in its sole discretion and shall not create any right or benefit in favor of the Intermediate Partnership or any other Person.

(c) The Partnership Policy Committee may permit the Partnership to enter into one or more agreements, in addition to the Administrative Services Agreement, with one or more of the General Partners and their Affiliates to render services to the Partnership or to the Partnership Policy Committee in the discharge of its duties to the Partnership. Any services rendered to the Partnership by a General Partner or any of its Affiliates shall be on terms that are fair and reasonable to the Partnership; provided, however, that the requirements of this Section 6.7(c) shall be deemed satisfied as to (i) any transaction approved by Special Approval, (ii) any transaction, the terms of which are no less favorable to the Partnership than those generally being provided to or available from unrelated third parties or (iii) any transaction that, taking into account the totality of the relationships between the parties involved (including other transactions that may be particularly favorable or advantageous to the Partnership), is equitable to the Partnership. The provisions of Section 6.5 shall apply to the rendering of services described in this Section 6.7(c).

(d) The Partnership Policy Committee may cause the Partnership to transfer assets to joint ventures, other partnerships, corporations, limited liability companies, or other business entities in which it is or thereby becomes a participant upon such terms and subject to such conditions as are consistent with this Agreement and applicable law.

(e) Neither the General Partners nor any of their Affiliates shall sell, transfer or convey any property to, or purchase any property from, the Partnership, directly or indirectly, except pursuant to transactions that are fair and reasonable to the Partnership; provided, however, that the requirements of this Section 6.7(e) shall be deemed to be satisfied as to (i) the transactions effected pursuant to Sections 4.2 and 4.1, the Conveyance Agreement and any other transactions described in or contemplated by the Registration Statement, (ii) any transaction approved by Special Approval, (iii) any transaction, the terms of which are no less favorable to the Partnership than those generally being provided to or available from unrelated third parties, or
(iv) any transaction that, taking into account the totality of the relationships between the parties involved (including other transactions that may be particularly favorable or advantageous to the Partnership), is equitable to the Partnership.

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(f) The General Partners and their Affiliates will have no obligation to permit the Partnership, the Intermediate Partnership or Northern Border Pipeline to use any facilities or assets of the General Partners and their Affiliates, except as may be provided in contracts entered into from time to time specifically dealing with such use, nor shall there be any obligation on the part of the General Partners or their Affiliates to enter into such contracts.

(g) Without limitation of Sections 6.7(a) through 6.7(f), and notwithstanding anything to the contrary in this Agreement, the existence of the conflicts of interest described in the Registration Statement are hereby approved by all Partners.

6.8 INDEMNIFICATION. (a) To the fullest extent permitted by law but subject to the limitations expressly provided in this Agreement, each General Partner, the members of the Partnership Policy Committee, any Departing Partner, any Person who is or was an officer or director of the Partnership, a General Partner or any Departing Partner and all other Indemnitees shall be indemnified and held harmless by the Partnership from and against any and all losses, claims, damages, liabilities, joint or several, expenses (including, without limitation, legal fees and expenses), judgments, fines, penalties, interest, settlements and other amounts arising from any and all claims, demands, actions, suits or proceedings, whether civil, criminal, administrative or investigative, in which any Indemnitee may be involved, or is threatened to be involved, as a party or otherwise, by reason of its status as (i) a General Partner, a member of the Partnership Policy Committee, a Departing Partner or any of their Affiliates, (ii) an officer, director, employee, partner, agent or trustee of the Partnership, a General Partner, any Departing Partner or any of their Affiliates or (iii) a Person serving at the request of the Partnership in another entity in a similar capacity, provided, that in each case the Indemnitee acted in good faith and in a manner which such Indemnitee believed to be in, or not opposed to, the best interests of the Partnership and, with respect to any criminal proceeding, had no reasonable cause to believe its conduct was unlawful; provided, further, no indemnification pursuant to this Section 6.8 shall be available to the General Partners with respect to their obligations incurred pursuant to the Indemnity Agreement, the Underwriting Agreement or the Conveyance Agreement (other than obligations incurred by the General Partners on behalf of the Partnership or the Intermediate Partnership). The termination of any action, suit or proceeding by judgment, order, settlement, conviction or upon a plea of nolo contendere, or its equivalent, shall not create a presumption that the Indemnitee acted in a manner contrary to that specified above. Any indemnification pursuant to this Section 6.8 shall be made only out of the assets of the Partnership, it being agreed that the General Partners shall not be personally liable for such indemnification and shall have no obligation to contribute or loan any monies or property to the Partnership to enable it to effectuate such indemnification.

(b) To the fullest extent permitted by law, expenses (including, without limitation, legal fees and expenses) incurred by an Indemnitee who is indemnified pursuant to Section 6.8(a) in defending any claim, demand, action, suit or proceeding shall, from time to time, be advanced by the Partnership prior to the final disposition of such claim, demand, action, suit or proceeding upon receipt by the Partnership of an undertaking by or on behalf of the Indemnitee to repay such amount if it shall be determined that the Indemnitee is not entitled to be indemnified as authorized in this Section 6.8.

(c) The indemnification provided by this Section 6.8 shall be in addition to any other rights to which an Indemnitee may be entitled under any agreement, pursuant to any vote of the holders of Outstanding Units, as a matter of law or otherwise, both as to actions in the Indemnitee's capacity as (i) a General Partner, a member of the Partnership Policy Committee, a Departing Partner or an Affiliate thereof, (ii) an officer, director, employee, partner, agent or trustee of the Partnership, a General Partner, any Departing Partner or an Affiliate thereof or (iii) a Person serving at the request

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of the Partnership in another entity in a similar capacity, and as to actions in any other capacity (including, without limitation, any capacity under the Underwriting Agreement), and shall continue as to an Indemnitee who has ceased to serve in such capacity and shall inure to the benefit of the heirs, successors, assigns and administrators of the Indemnitee.

(d) The Partnership may purchase and maintain (or reimburse the General Partners or their Affiliates for the cost of) insurance, on behalf of the General Partners, the members of the Partnership Policy Committee and such other Persons as the Partnership Policy Committee shall determine, against any liability that may be asserted against or expense that may be incurred by such Person in connection with the Partnership's activities, regardless of whether the Partnership would have the power to indemnify such Person against such liability under the provisions of this Agreement.

(e) For purposes of this Section 6.8, the Partnership shall be deemed to have requested an Indemnitee to serve as fiduciary of an employee benefit plan whenever the performance by it of its duties to the Partnership also imposes duties on, or otherwise involves services by, it to the plan or participants or beneficiaries of the plan; excise taxes assessed on an indemnitee with respect to an employee benefit plan pursuant to applicable law shall constitute "fines" within the meaning of Section 6.8(a); and action taken or omitted by it with respect to an employee benefit plan in the performance of its duties for a purpose reasonably believed by it to be in the interest of the participants and beneficiaries of the plan shall be deemed to be for a purpose which is in, or not opposed to, the best interests of the Partnership.

(f) In no event may an Indemnitee subject the Limited Partners to personal liability by reason of the indemnification provisions set forth in this Agreement.

(g) An Indemnitee shall not be denied indemnification in whole or in part under this Section 6.8 because the Indemnitee had an interest in the transaction with respect to which the indemnification applies if the transaction was otherwise permitted by the terms of this Agreement.

(h) The provisions of this Section 6.8 are for the benefit of the Indemnitees, their heirs, successors, assigns and administrators and shall not be deemed to create any rights for the benefit of any other Persons.

(i) No amendment, modification or repeal of this Section 6.8 or any provision hereof shall in any manner terminate, reduce or impair the right of any past, present or future Indemnitee to be indemnified by the Partnership, nor the obligation of the Partnership to indemnify any such Indemnitee under and in accordance with the provisions of this Section 6.8 as in effect immediately prior to such amendment, modification or repeal with respect to claims arising from or relating to matters occurring, in whole or in part, prior to such amendment, modification or repeal, regardless of when such claims may arise or be asserted.

6.9 LIABILITY OF INDEMNITEES. (a) Notwithstanding anything to the contrary set forth in this Agreement, no Indemnitee shall be liable for monetary damages to the Partnership, the Limited Partners, the Assignees or any other Persons who have acquired interests in the Units, for losses sustained or liabilities incurred as a result of any act or omission if such Indemnitee acted in good faith.

(b) Subject to its obligations and duties as set forth in Section 6.2, the Partnership Policy Committee may exercise any of the powers granted to it by this Agreement and perform any of the duties imposed upon it hereunder either directly or by or through its agents, and the General Partners

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and the Partnership Policy Committee shall not be responsible for any misconduct or negligence on the part of any such agent appointed by the Partnership Policy Committee in good faith.

(c) Any amendment, modification or repeal of this Section 6.9 or any provision hereof shall be prospective only and shall not in any way affect the limitations on the liability to the Partnership and the Limited Partners of the members of the Partnership Policy Committee, the General Partners, their directors, officers and employees under this Section 6.9 as in effect immediately prior to such amendment, modification or repeal with respect to claims arising from or relating to matters occurring, in whole or in part, prior to such amendment, modification or repeal, regardless of when such claims may arise or be asserted.

6.10 RESOLUTION OF CONFLICTS OF INTEREST. (a) Unless otherwise expressly provided in this Agreement or the Intermediate Partnership Agreement, whenever a potential conflict of interest exists or arises between a General Partner or any of its Affiliates or the member of the Partnership Policy Committee designated by it, on the one hand, and the Partnership, the Intermediate Partnership, any Partner or any Assignee, on the other hand, any resolution or course of action in respect of such conflict of interest shall be permitted and deemed approved by all Partners, and shall not constitute a breach of this Agreement, of the Intermediate Partnership Agreement, of any agreement contemplated herein or therein, or of any duty stated or implied by law or equity, if the resolution or course of action is or, by operation of this Agreement is deemed to be, fair and reasonable to the Partnership. Each General Partner and Partnership Policy Committee Member shall be authorized but not required in connection with its resolution of such conflict of interest to seek Special Approval of a resolution of such conflict or course of action. Any conflict of interest and any resolution of such conflict of interest shall be conclusively deemed fair and reasonable to the Partnership if such conflict of interest or resolution is (i) approved by Special Approval, (ii) on terms no less favorable to the Partnership than those generally being provided to or available from unrelated third parties or (iii) fair to the Partnership, taking into account the totality of the relationships between the parties involved (including other transactions that may be particularly favorable or advantageous to the Partnership). A General Partner or Partnership Policy Committee Member may also adopt a resolution or course of action that has not received Special Approval. Each General Partner and Partnership Policy Committee member (and the Audit Committee in connection with Special Approval) shall be authorized in connection with its determination of what is "fair and reasonable" to the Partnership and in connection with its resolution of any conflict of interest to consider (A) the relative interests of any party to such conflict, agreement, transaction or situation and the benefits and burdens relating to such interest; (B) any customary or accepted industry practices and any customary or historical dealings with a particular Person; (C) any applicable generally accepted accounting or engineering practices or principles; and (D) such additional factors as such General Partner or Partnership Policy Committee member (and, if applicable, the Audit Committee) determines in its sole discretion to be relevant, reasonable or appropriate under the circumstances. Nothing contained in this Agreement, however, is intended to nor shall it be construed to require a General Partner or Partnership Policy Committee member (or the Audit Committee) to consider the interests of any Person other than the Partnership. In the absence of bad faith by a General Partner or Partnership Policy Committee member, the resolution, action or terms so made, taken or provided by such General Partner or Partnership Policy Committee member with respect to such matter shall not constitute a breach of this Agreement or any other agreement contemplated herein or a breach of any standard of care or duty imposed herein or therein or under the Delaware Act or any other law, rule or regulation.

(b) Whenever this Agreement or any other agreement contemplated hereby provides that the Partnership Policy Committee, or a General Partner or any of its Affiliates, is permitted or required to make a decision (i) in its "sole discretion" or "discretion," that it deems "necessary or appropriate"

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or under a grant of similar authority or latitude, the Partnership Policy Committee, such General Partner or such Affiliate shall be entitled to consider only such interests and factors as it desires and shall have no duty or obligation to give any consideration to any interest of, or factors affecting, the Partnership, the Intermediate Partnership, any Limited Partner or any Assignee, (ii) it may make such decision in its sole discretion (regardless of whether there is a reference to "sole discretion" or "discretion") unless another express standard is provided for, or (iii) in "good faith" or under another express standard, the Partnership Policy Committee, such General Partner or such Affiliate shall act under such express standard and shall not be subject to any other or different standards imposed by this Agreement, the Intermediate Partnership Agreement, any other agreement contemplated hereby or under the Delaware Act or any other law, rule or regulation. In addition, any actions taken by the Partnership Policy Committee, a General Partner or such Affiliate consistent with the standards of "reasonable discretion" set forth in the definitions of Available Cash or Cash from Operations shall not constitute a breach of any duty of the members of the Partnership Policy Committee, or a General Partner to the Partnership or the Limited Partners. The Partnership Policy Committee and the General Partners shall have no duty, express or implied, to sell or otherwise dispose of any asset of the Intermediate Partnership or of the Partnership, other than in the ordinary course of business. No borrowing by the Partnership or the Intermediate Partnership or the approval thereof by the Partnership Policy Committee shall be deemed to constitute a breach of any duty of the Partnership Policy Committee or a General Partner to the Partnership or the Limited Partners by reason of the fact that the purpose or effect of such borrowing is directly or indirectly to (A) enable a General Partner to receive or increase the amount of Incentive Distributions or (B) shorten the Subordination Period.

(c) Whenever a particular transaction, arrangement or resolution of a conflict of interest is required under this Agreement to be "fair and reasonable" to any Person, the fair and reasonable nature of such transaction, arrangement or resolution shall be considered in the context of all similar or related transactions.

(d) Subject to the terms of Section 6.4, the Limited Partners hereby authorize the Partnership Policy Committee, on behalf of the Partnership as a partner of the Intermediate Partnership, to approve of actions by the partnership policy committee or general partners of the Intermediate Partnership similar to those actions permitted to be taken by the Partnership Policy Committee pursuant to this Section 6.10.

6.11 OTHER MATTERS CONCERNING THE GENERAL PARTNERS AND THE PARTNERSHIP POLICY COMMITTEE. (a) The General Partners and the Partnership Policy Committee may rely and shall be protected in acting or refraining from acting upon any resolution, certificate, statement, instrument, opinion, report, notice, request, consent, order, bond, debenture, or other paper or document believed by it to be genuine and to have been signed or presented by the proper party or parties.

(b) The General Partners and the Partnership Policy Committee may consult with legal counsel, accountants, appraisers, management consultants, investment bankers and other consultants and advisers selected by it, and any act taken or omitted to be taken in reliance upon the opinion (including, without limitation, an Opinion of Counsel) of such Persons as to matters that the General Partners and the Partnership Policy Committee reasonably believe to be within such Person's professional or expert competence shall be conclusively presumed to have been done or omitted in good faith and in accordance with such opinion.

(c) The Partnership Policy Committee shall have the right, in respect of any of its powers or obligations hereunder, to act through any of the duly authorized officers of the Partnership or the General Partners and their duly appointed attorney or attorneys-in-fact. Each such attorney shall, to the extent provided by the Partnership Policy Committee in the power of attorney, have full power and

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authority to do and perform each and every act and duty that is permitted or required to be done by the Partnership Policy Committee hereunder.

(d) Any standard of care and duty imposed by this Agreement or under the Delaware Act or any applicable law, rule or regulation shall be modified, waived or limited as required to permit the General Partners and the members of the Partnership Policy Committee to act under this Agreement or any other agreement contemplated by this Agreement and to make any decision pursuant to the authority prescribed in this Agreement so long as such action is reasonably believed by the General Partners or the members of the Partnership Policy Committee, as applicable, to be in, or not inconsistent with, the best interests of the Partnership.

6.12 TITLE TO PARTNERSHIP ASSETS. Title to Partnership assets, whether real, personal or mixed and whether tangible or intangible, shall be deemed to be owned by the Partnership as an entity, and no Partner or Assignee, individually or collectively, shall have any ownership interest in such Partnership assets or any portion thereof. Title to any or all of the Partnership assets may be held in the name of the Partnership, the General Partners, one or more of their Affiliates or one or more nominees, as the Partnership Policy Committee may determine. Each General Partner hereby declares and warrants that any Partnership assets for which record title is held in the name of such General Partner or one or more of its Affiliates or one or more nominees shall be held by such General Partner or such Affiliate or nominee for the use and benefit of the Partnership in accordance with the provisions of this Agreement; provided, however, that such General Partner shall use its reasonable efforts to cause record title to such assets (other than those assets in respect of which such General Partner determines that the expense and difficulty of conveyancing makes transfer of record title to the Partnership impracticable) to be vested in the Partnership as soon as reasonably practicable; provided that, prior to the withdrawal or removal of such General Partner or as soon thereafter as practicable, such General Partner shall use reasonable efforts to effect the transfer of record title to the Partnership and, prior to any such transfer, will provide for the use of such assets in a manner satisfactory to the Partnership. All Partnership assets shall be recorded as the property of the Partnership in its books and records, irrespective of the name in which record title to such Partnership assets is held.

6.13 PURCHASE OR SALE OF UNITS. The Partnership Policy Committee may cause the Partnership to purchase or otherwise acquire Units; provided that the Partnership Policy Committee may not cause the Partnership to purchase Subordinated Units during the Subordination Period. As long as Units are held by the Partnership or the Intermediate Partnership, such Units shall not be considered Outstanding for any purpose, except as otherwise provided herein. Each General Partner or any Affiliate of such General Partner may also purchase or otherwise acquire and sell or otherwise dispose of Units for its own account, subject to the provisions of Articles XI and XII.

6.14 REGISTRATION RIGHTS OF CERTAIN PERSONS. (a) Prior to the end of the Subordination Period, if Northwest Border desires to sell any of its Initial Common Units, then upon the request of Northwest Border (which request may not be made more than once during any twelve month period without the approval of the Partnership Policy Committee), the Partnership shall file with the Commission as promptly as practicable after receiving such request, and use all reasonable efforts to cause to become effective and remain effective for a period of not more than six months following its effective date, a registration statement under the Securities Act registering the offering and sale of the number of Initial Common Units specified by Northwest Border; provided, however, that the Partnership shall not be required to effect more than three registrations pursuant to this Section 6.14(a).

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(b) At any time following the Closing Date, if (i) Northern Plains, Pan Border, Northwest Border or any Affiliate of any such Person (including, without limitation, for purposes of this Section 6.14, any Person that is an Affiliate at the date hereof notwithstanding that it may later cease to be an Affiliate) holds Units or other Partnership Securities that it desires to sell (excluding, in the case of Northwest Border and only during the Subordination Period, its Initial Common Units) and (ii) Rule 144 of the Securities Act (or any successor rule or regulation to Rule 144) or another exemption from registration is not available to enable such Person to dispose of such Units or other Partnership Securities (in the amount such person desires to sell and in accordance with such Person's intended method of disposition) without registration under the Securities Act, then upon the request of Northern Plains, Pan Border or Northwest Border (in each case for its own account and/or on behalf of one or more of its Affiliates), which request may, without the prior approval of the Partnership Policy Committee, only be made once during any 12 month period following the Closing Date (it being agreed that such limitation shall apply to such parties as a group and not individually), the Partnership shall file with the Commission as promptly as practicable after receiving such request, and use all reasonable efforts to cause to become effective and remain effective for a period of not more than six months following its effective date, a registration statement under the Securities Act registering the offering and sale of the number of Units or other Partnership Securities specified by the requesting party, subject to the terms of Section 6.14(c); provided, however, that each of Northern Plains, Pan Border and Northwest Border shall not have the right to request more than three registrations pursuant to this Section 6.14(b).

(c) If Northern Plains, Pan Border or Northwest Border requests that the Partnership register Units or other Partnership Securities on its or its Affiliates behalf pursuant to Section 6.14(b), such requesting party shall simultaneously send a copy of such request to the other two parties, and each such other party, by delivery of written notice to the Partnership and the requesting party on or before the 15th day following receipt of the requesting parry's notice to the Partnership, shall have the right to participate in such registered offering in accordance with the terms of this Section 6.14(c) and subject to the other provisions of this Section 6.14. The requesting party and each party that sends timely notice of its desire to participate in a registration requested pursuant to Section 6.14(b) shall have the right to participate to the full extent of any Units or Partnership Securities that it desires to sell; provided, however, that if the managing underwriter for such registered offering advises the Partnership that the purchase of all or some of the such parties' Units or other Partnership Securities would adversely and materially affect the success of the proposed offering, the requesting party and such additional participating parties shall have the right to include their Units or other Partnership Securities (and/or those of any Affiliates on whose behalf a request or notice of intent to participate was sent by such party) in such registered offering on a pro rata basis according to their relative General Partner Percentage Interests, to the extent such managing underwriter deems advisable. No priority shall be given to the Units or other Partnership Securities of the party that first made a request for registration pursuant to
Section 6.14(b).

(d) With respect to any registrations requested pursuant to Sections 6.14(a) or (b), if the Partnership Policy Committee determines in its good faith judgment that a postponement of a requested registration for up to six months would be in the best interests of the Partnership and its Partners due to a pending transaction, investigation or other event, the filing of such registration statement or the effectiveness thereof may be deferred for up to six months, but not thereafter.

(e) In connection with any registration requested pursuant to Sections 6.14(a) or (b), subject to the terms of Section 6.14(d), the Partnership shall promptly prepare and file (x) such documents as may be necessary to register or qualify the securities subject to such registration under the securities laws of such states as the participating party or parties shall reasonably request; provided, however, that no such qualification shall be required in any jurisdiction where, as a result

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thereof, the Partnership or any General Partner (other than a General Partner that consents thereto) would become subject to general service of process or to taxation or qualification to do business as a foreign corporation or partnership doing business in such jurisdiction, and (y) such documents as may be necessary to apply for listing or to list the securities subject to such registration on such National Securities Exchange as the participating party or parties shall reasonably request, and do any and all other acts and things that may reasonably be necessary or advisable to enable the participating party or parties to consummate a public sale of such securities in such states.

(f) Except as set forth in the remaining provisions of this Section 6.14(f), all costs and expenses of any registration and offering undertaken by the Partnership pursuant to Sections 6.14(a), (b) or (g) shall be paid by the Partnership, without reimbursement from the Persons whose Units or other Partnership Securities are included in such registration and offering, except that all underwriting discounts and commissions attributable to any Units or other Partnership Securities of a Person that are included in such registration and offering shall be borne by such Person. With respect to any registration and offering of Initial Common Units by Northwest Border pursuant to Section 6.14(a), Northwest Border shall pay or reimburse the Partnership for all costs and expenses (including underwriting discounts and commissions) incurred by the Partnership in connection with such registration and offering. If Northwest Border participates in any registration and offering pursuant to Sections 6.14(b) or (g), any Common Units offered for inclusion in such registration and offering by Northwest Border shall be deemed to include its Initial Common Units (to the extent same have not already been sold by Northwest Border to a non-Affiliate pursuant to a transaction exempt from registration under the Securities Act or otherwise pursuant to a registration and offering under
Section 6.14(a)), and Northwest Border shall pay or reimburse the Partnership for a portion of the costs and expenses (including underwriting discounts and commissions) incurred by the Partnership in connection with such registration and offering based on the ratio that the number of Initial Common Units of Northwest Border deemed to be included in such registration bears to the total number of Units or other Partnership Securities included in such registration and offering.

(g) If the Partnership shall at any time propose to file a registration statement under the Securities Act for an offering of equity securities of the Partnership for cash (other than an offering relating solely to an employee benefit or incentive plan), the Partnership shall so notify Northern Plains, Pan Border and Northwest Border and shall use all reasonable efforts to include in such registration statement such number or amount of securities as such Persons (or their Affiliates) may notify the Partnership that they desire to include in such registration statement. If the proposed offering pursuant to this Section 6.14(g) shall be an underwritten offering, then, in the event that the managing underwriter of such offering advises the Partnership and such Persons (to the extent they desire to participate) in writing that in its opinion the inclusion of all or some of such Persons' securities would adversely and materially affect the success of the offering, the Partnership shall include in such offering only that number or amount, if any, of securities held by such Persons which, in the opinion of the managing underwriter, will not so adversely and materially affect the offering. Such number or amount of such Persons' securities that the managing underwriter allows to be included in such registration and offering shall be allocated among the participating Persons in accordance with the principles set forth in the proviso clause of section 6.14(c).

(h) If underwriters are engaged in connection with any registration referred to in this Section 6.14, the Partnership shall provide indemnification, representations, covenants, opinions and other assurance to the underwriters in form and substance reasonably satisfactory to such under writers. Further, in addition to and not in limitation of the Partnership's obligation under Section 6.8, the Partnership shall, to the fullest extent permitted by law, indemnify and hold harmless any Person participating in a registration and offering pursuant to Sections 6.14(a), (b) or (g), its officers, directors and each Person who controls such Person (within the meaning of the Securities Act) and any agent

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thereof (collectively, "INDEMNIFIED PERSONS") against any losses, claims, demands, actions, causes of action, assessments, damages, liabilities (joint or several), costs and expenses (including, without limitation, interest, penalties and reasonable attorneys' fees and disbursements), resulting to, imposed upon, or incurred by the Indemnified Persons, directly or indirectly, under the Securities Act or otherwise (hereinafter referred to in this Section 6.14(c) as A "CLAIM" and in the plural as "CLAIMS"), based upon, arising out of, or resulting from any untrue statement or alleged untrue statement of any material fact contained in any registration statement under which any Units were registered under the Securities Act or any state securities or Blue Sky laws, in any preliminary prospectus (if used prior to the effective date of such registration statement), or in any summary or final prospectus or in any amendment or supplement thereto (if used during the period the Partnership is required to keep the registration statement current), or arising out of, based upon or resulting from the omission or alleged omission to state therein a material fact required to be stated therein or necessary to make the statements made therein not misleading; provided, however, that the Partnership shall not be liable to any Indemnified Person to the extent that any such claim arises out of, is based upon or results from an untrue statement or alleged untrue statement or omission or alleged omission made in such registration statement, such preliminary, summary or final prospectus or such amendment or supplement, in reliance upon and in conformity with written information furnished to the Partnership by or on behalf of such Indemnified Person specifically for use in the preparation thereof. To the extent any of the indemnification provisions set forth in this Section 6.14(h) are inconsistent or in conflict with the indemnification provisions set forth in the Indemnity Agreement, the indemnification provisions set forth in such Indemnity Agreement shall control.

(i) The provisions of Sections 6.14(a), (b) and (g) shall continue to be applicable with respect to each of Northern Plains, Pan Border and Northwest Border (and any of their Affiliates) after such Person ceases to be a General Partner of the Partnership, during a period of three years subsequent to the effective date of such cessation and for so long thereafter as is required for such Person to sell all of the Units or other Partnership Securities with respect to which it has requested during such three-year period that a registration statement be filed; provided, however, that the Partnership shall not be required to file successive registration statements covering the same securities for which registration was demanded during such three-year period. The provisions of Section 6.14(h) shall continue in effect thereafter.

(j) Any request to register Partnership Securities pursuant to this
Section 6.14 shall (i) specify the Partnership Securities intended to be offered and sold by the Person making the request, (ii) express such Person's present intent to offer such Partnership Securities for distribution, (iii) describe the nature or method of the proposed offer and sale of Partnership Securities, and
(iv) contain the undertaking of such Person to provide all such information and materials and take all action as may be required in order to permit the Partnership to comply with all applicable requirements in connection with the registration of such Partnership Securities.

6.15 RELIANCE BY THIRD PARTIES. Notwithstanding anything to the contrary in this Agreement, any Person dealing with the Partnership shall be entitled to assume that the Partnership Policy Committee and any officer of the Partnership authorized by the Partnership Policy Committee to act on behalf and in the name of the Partnership has full power and authority to encumber, sell or otherwise use in any manner any and all assets of the Partnership and to enter into any contracts on behalf of the Partnership, and such Person shall be entitled to deal with the Partnership Policy Committee or any such officer as if it were the Partnership's sole party in interest, both legally and beneficially. Each Limited Partner hereby waives any and all defenses or other remedies that may be available against such Person to contest, negate or disaffirm any action of the Partnership Policy Committee or any such officer in connection with any such dealing. In no event shall any Person dealing with the Partnership Policy Committee or any such officer be obligated to ascertain that the

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terms of this Agreement have been complied with or to inquire into the necessity or expedience of any act or action of the Partnership Policy Committee or any such officer. Each and every certificate, document or other instrument executed on behalf of the Partnership by the Partnership Policy Committee or any such officer shall be conclusive evidence in favor of any and every Person relying thereon or claiming thereunder that (a) at the time of the execution and delivery of such certificate, document or instrument, this Agreement was in full force and effect, (b) the Person executing and delivering such certificate, document or instrument was duly authorized and empowered to do so for and on behalf of the Partnership and (c) such certificate, document or instrument was duly executed and delivered in accordance with the terms and provisions of this Agreement and is binding upon the Partnership.

ARTICLE VII
RIGHTS AND OBLIGATIONS OF LIMITED PARTNERS

7.1 LIMITATION OF LIABILITY. The Limited Partners, the Organizational Limited Partner and the Assignees shall have no liability under this Agreement except as expressly provided in this Agreement or the Delaware Act.

7.2 MANAGEMENT OF BUSINESS. No Limited Partner or Assignee (other than the General Partners, any of their Affiliates or any officer, director, employee, partner, agent or trustee of the Partnership, General Partners or any of their Affiliates, in its capacity as such, if such Person shall also be a Limited Partner or Assignee) shall participate in the operation, management or control (within the meaning of the Delaware Act) of the Partnership's business, transact any business in the Partnership's name or have the power to sign documents for or otherwise bind the Partnership. The transaction of any such business by the Partnership Policy Committee, the General Partners, any of their Affiliates or any officer, director, employee, partner, agent or trustee of the Partnership, the General Partners or any of its Affiliates, in its capacity as such, shall not affect, impair or eliminate the limitations on the liability of the Limited Partners or Assignees under this Agreement.

7.3 OUTSIDE ACTIVITIES. Subject to the provisions of Section 6.6, which shall continue to be applicable to the Persons referred to therein, regardless of whether such Persons shall also be Limited Partners or Assignees, any Limited Partner or Assignee shall be entitled to and may have business interests and engage in business activities in addition to those relating to the Partnership, including, without limitation, business interests and activities in direct competition with the Partnership or the Intermediate Partnership. Neither the Partnership nor any of the other Partners or Assignees shall have any rights by virtue of this Agreement in any business ventures of any Limited Partner or Assignee.

7.4 RETURN OF CAPITAL. No Limited Partner or Assignee shall be entitled to the withdrawal or return of his Capital Contribution, except to the extent, if any, that distributions made pursuant to this Agreement or upon termination of the Partnership may be considered as such by law and then only to the extent provided for in this Agreement. Except to the extent provided by Article V or as otherwise expressly provided in this Agreement, no Limited Partner or Assignee shall have priority over any other Limited Partner or Assignee either as to the return of Capital Contributions or as to profits, losses or distributions. Any such return shall be a compromise to which all Partners and Assignees agree within the meaning of section. 17-502(b) of the Delaware Act.

7.5 RIGHTS OF LIMITED PARTNERS RELATING TO THE PARTNERSHIP. (a) In addition to other rights provided by this Agreement or by applicable law, and except as limited by Section 7.5(b), each Limited Partner shall have the right, for a purpose reasonably related to such Limited Partner's

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interest as a limited partner in the Partnership, upon reasonable demand and at such Limited Partner's own expense:

(i) to obtain true and full information regarding the status of the business and financial condition of the Partnership;

(ii) promptly after becoming available, to obtain a copy of the Partnership's federal, state and local tax returns for each year;

(iii) to have furnished to him, upon notification to the Partnership, a current list of the name and last known business, residence or mailing address of each Partner;

(iv) to have furnished to him, upon notification to the Partnership, a copy of this Agreement, the Administrative Services Agreement and the Certificate of Limited Partnership and all amendments thereto, together with a copy of the executed copies of all powers of attorney pursuant to which this Agreement, the Certificate of Limited Partnership and all amendments thereto have been executed;

(v) to obtain true and full information regarding the amount of cash and description and statement of the Agreed Value of any other Capital Contribution by each Partner and which each Partner has agreed to contribute in the future, and the date on which each became a Partner; and

(vi) to obtain such other information regarding the affairs of the Partnership as is just and reasonable.

(b) Notwithstanding any other provision of this Agreement, the Partnership Policy Committee may keep confidential from the Limited Partners and Assignees, for such period of time as the Partnership Policy Committee deems reasonable, any information that the Partnership Policy Committee reasonably believes to be in the nature of trade secrets or other information the disclosure of which the Partnership Policy Committee in good faith believes is not in the best interests of the Partnership, the Intermediate Partnership or Northern Border Pipeline or could damage the Partnership, the Intermediate Partnership or Northern Border Pipeline or that the Partnership, the Intermediate Partnership or Northern Border Pipeline is required by law or by agreements with third parties to keep confidential (other than agreements with Affiliates of the General Partners the primary purpose of which is to circumvent the obligations set forth in this
Section 7.5).

ARTICLE VIII
BOOKS, RECORDS, ACCOUNTING AND REPORTS

8.1 RECORDS AND ACCOUNTING. The Partnership Policy Committee shall keep or cause to be kept at the principal office of the Partnership appropriate books and records with respect to the Partnership's business, including, without limitation, all books and records necessary to provide to the Limited Partners any information, lists and copies of documents required to be provided pursuant to Section 7.5(a). Any books and records maintained by or on behalf of the Partnership in the regular course of its business, including, without limitation, the record of the Record Holders and Assignees of Units or other Partnership Securities, books of account and records of Partnership proceedings, may be kept on, or be in the form of, computer disks, hard disks, punch cards, magnetic tape, photographs, micrographics or any other information storage device, provided, that the books and records so maintained are convertible into clearly legible written form within a reasonable period of

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time. The books of the Partnership shall be maintained, for financial reporting purposes, on an accrual basis in accordance with generally accepted accounting principles.

8.2 FISCAL YEAR. The fiscal year of the Partnership shall be the calendar year.

8.3 REPORTS. (a) As soon as practicable, but in no event later than 120 days after the close of each fiscal year of the Partnership, the Partnership Policy Committee shall cause to be mailed to each Record Holder of a Unit as of a date selected by the Partnership Policy Committee in its sole discretion, an annual report containing financial statements of the Partnership for such fiscal year of the Partnership, presented in accordance with generally accepted accounting principles, including a balance sheet and statements of operations, Partners' equity and cash flows, such statements to be audited by a firm of independent public accountants selected by the Partnership Policy Committee.

(b) As soon as practicable, but in no event later than 90 days after the close of each calendar quarter except the last calendar quarter of each year, the Partnership Policy Committee shall cause to be mailed to each Record Holder of a Unit, as of a date selected by the Partnership Policy Committee in its sole discretion, a report containing unaudited financial statements of the Partnership and such other information as may be required by applicable law, regulation or rule of any National Securities Exchange on which the Units are listed for trading, or as the Partnership Policy Committee determines to be necessary or appropriate.

ARTICLE IX
TAX MATTERS

9.1 PREPARATION OF TAX RETURNS. The Partnership Policy Committee shall arrange for the preparation and timely filing of all returns of Partnership income, gains, deductions, losses and other items required of the Partnership for federal and state income tax purposes and shall use all reasonable efforts to furnish, within 90 days of the close of each taxable year of the Partnership, the tax information reasonably required by holders of Outstanding Units for federal and state income tax reporting purposes. The classification, realization and recognition of income, gain, losses and deductions and other items shall be on the accrual method of accounting for federal income tax purposes. The taxable year of the Partnership shall be the calendar year.

9.2 TAX ELECTIONS. Except as otherwise provided herein, the Partnership Policy Committee shall, in its sole discretion, determine whether to make any available election pursuant to the Code; provided, however, that the Partnership Policy Committee shall make the election under Section 754 of the Code in accordance with applicable regulations thereunder. The Partnership Policy Committee shall have the right to seek to revoke any such election (including, without limitation, the election under Section 754 of the Code) upon the Partnership Policy Committee's determination in its sole discretion that such revocation is in the best interests of the Limited Partners and Assignees. For purposes of computing the adjustments under Section 743(b) of the Code, the Partnership Policy Committee shall be authorized (but not required) to adopt a convention whereby the price paid by a transferee of Units will be deemed to be the lowest quoted closing price of the Units on any National Securities Exchange on which such Units are traded during the calendar month in which such transfer is deemed to occur pursuant to Section 5.2(g) without regard to the actual price paid by such transferee.

9.3 TAX CONTROVERSIES. Subject to the provisions hereof, Northern Plains is designated the Tax Matters Partner (as defined in Section 6231 of the Code), and is authorized and required to

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represent the Partnership (at the Partnership's expense) in connection with all examinations of the Partnership's affairs by tax authorities, including, without limitation, resulting administrative and judicial proceedings, and to expend Partnership funds for professional services and costs associated therewith. Each Partner and Assignee agrees to cooperate with the Partnership Policy Committee and to do or refrain from doing any or all things reasonably required by the Partnership Policy Committee to conduct such proceedings.

9.4 ORGANIZATIONAL EXPENSES. The Partnership shall elect to deduct expenses, if any, incurred by it in organizing the Partnership ratably over a 60-month period as provided in Section 709 of the Code.

9.5 WITHHOLDING. Notwithstanding any other provision of this Agreement, the Partnership Policy Committee is authorized to take any action that it determines in its sole discretion to be necessary or appropriate to cause the Partnership and the Intermediate Partnership to comply with any withholding requirements established under the Code or any other federal, state or local law including, without limitation, pursuant to Sections 1441, 1442, 1445 and 1446 of the Code. To the extent that the Partnership is required to withhold and pay over to any taxing authority any amount resulting from the allocation or distribution of income to any Partner or Assignee (including, without limitation, by reason of Section 1446 of the Code), the amount withheld shall be treated as a distribution of cash pursuant to Section 5.3 in the amount of such withholding from such Partner.

9.6 ENTITY-LEVEL TAXATION. If legislation is enacted or the interpretation of existing legislation is modified which causes the Partnership, the Intermediate Partnership or Northern Border Pipeline to be treated as an association taxable as a corporation or otherwise subjects the Partnership, the Intermediate Partnership or Northern Border Pipeline to entity-level taxation for federal, state or local income tax purposes, the Minimum Quarterly Distribution, First Target Distribution, Second Target Distribution or Third Target Distribution, as the case may be, shall be equal to the product obtained by multiplying (a) the amount thereof by (b) 1 minus the sum of (i) the highest marginal federal corporate (or other entity, as applicable) income tax rate of the Partnership (directly or through its interest in Northern Border Pipeline) for the fiscal year of the Partnership in which such quarter occurs (expressed as a percentage) plus (ii) the effective overall state and local income tax rate (expressed as a percentage) applicable to the Partnership (directly or through its interest in Northern Border Pipeline) for the calendar year next preceding the calendar year in which such quarter occurs (after taking into account the benefit of any deduction allowable for federal income tax purposes with respect to the payment of state and local income taxes), but only to the extent of the increase in such rates resulting from such legislation or interpretation. Such effective overall state and local income tax rate shall be determined for the calendar year next preceding the first calendar year during which the Partnership, the Intermediate Partnership or Northern Border Pipeline is taxable for federal income tax purposes as an association taxable as a corporation or is otherwise subject to entity-level taxation by determining such rate as if the Partnership, the Intermediate Partnership or Northern Border Pipeline had been subject to such state and local taxes during such preceding calendar year.

9.7 ENTITY-LEVEL ARREARAGE COLLECTIONS. If the Partnership is required by applicable law to pay any federal, state or local income tax on behalf of, or withhold such amount with respect to, any Partner or Assignee or any former Partner or Assignee (a) the Partnership Policy Committee shall cause the Partnership to pay such tax on behalf of such Partner or Assignee or former Partner or Assignee from the funds of the Partnership; (b) any amount so paid on behalf of, or withheld with respect to, any Partner or Assignee shall constitute a distribution out of Available Cash to such Partner or Assignee pursuant to
Section 5.3; and (c) to the extent any such Partner or Assignee (but not a former Partner or Assignee) is not then entitled to such distribution under this Agreement, the

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Partnership Policy Committee shall be authorized, without the approval of any Partner or Assignee, to amend this Agreement insofar as is necessary to maintain the uniformity of intrinsic tax characteristics as to all Units and to make subsequent adjustments to distributions in a manner which, in the reasonable judgment of the Partnership Policy Committee, will make as little alteration as practicable in the priority and amount of distributions otherwise applicable under this Agreement, and will not otherwise alter the distributions to which Partners and Assignees are entitled under this Agreement. If the Partnership is permitted (but not required) by applicable law to pay any such tax on behalf of, or withhold such amount with respect to, any Partner or Assignee or former Partner or Assignee, the Partnership Policy Committee shall be authorized (but not required) to cause the Partnership to pay such tax from the funds of the Partnership and to take any action consistent with this Section 9.7. The Partnership Policy Committee shall be authorized (but not required) to take all necessary or appropriate actions to collect all or any portion of a deficiency in the payment of any such tax that relates to prior periods and that is attributable to Persons who were Limited Partners or Assignees when such deficiencies arose, from such Persons.

9.8 OPINIONS OF COUNSEL. Notwithstanding any other provision of this Agreement, if the Partnership, the Intermediate Partnership or Northern Border Pipeline is treated as an association taxable as a corporation at any time or is otherwise taxable for federal income tax purposes as an entity at any time and, pursuant to the provisions of this Agreement, an Opinion of Counsel would otherwise be required to the effect that an action will not cause the Partnership, the Intermediate Partnership or Northern Border Pipeline to become so treated as an association taxable as a corporation or otherwise taxable as an entity for federal income tax purposes, such requirement for an Opinion of Counsel shall be deemed automatically waived.

ARTICLE X
CERTIFICATES

10.1 CERTIFICATES. Upon the Partnership's issuance of Common Units or Subordinated Units to any Person, the Partnership shall issue one or more Certificates in the name of such Person evidencing the number of such Units being so issued. Certificates shall be executed on behalf of the Partnership by an Authorized Officer. No Common Unit Certificate shall be valid for any purpose until it has been countersigned by the Transfer Agent and by an Authorized Officer of the Partnership. The Partners holding Certificates evidencing Subordinated Units may exchange such Certificates for Certificates evidencing Common Units on or after the date on which such Subordinated Units are converted into Common Units pursuant to the terms of Section 5.7(c).

10.2 REGISTRATION, REGISTRATION OF TRANSFER AND EXCHANGE. (a) The Partnership Policy Committee shall cause to be kept on behalf of the Partnership a register in which, subject to such reasonable regulations as it may prescribe and subject to the provisions of Section 10.2(b), the Partnership Policy Committee will provide for the registration and transfer of Units. The Transfer Agent is hereby appointed registrar and transfer agent for the purpose of registering Units and transfers of such Units as herein provided. The Partnership shall not recognize transfers of Certificates representing Units unless same are effected in the manner described in this Section 10.2. Upon surrender for registration of transfer of any Units evidenced by a Certificate, and subject to the provisions of Section 10.2(b), an Authorized Officer on behalf of the Partnership shall execute, and the Transfer Agent shall countersign and deliver, in the name of the holder or the designated transferee or transferees, as required pursuant to the holder's instructions, one or more new Certificates evidencing the same aggregate number of Units as was evidenced by the Certificate so surrendered.

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(b) Except as otherwise provided in Section 11.5, the Partnership shall not recognize any transfer of Units until the Certificates evidencing such Units are surrendered for registration of transfer and such Certificates are accompanied by a Transfer Application duly executed by the transferee (or the transferee's attorney-in-fact duly authorized in writing). No charge shall be imposed by the Partnership for such transfer, provided, that, as a condition to the issuance of any new Certificate under this Section 10.2, the Partnership Policy Committee may require the payment of a sum sufficient to cover any tax or other governmental charge that may be imposed with respect thereto.

10.3 MUTILATED, DESTROYED, LOST OR STOLEN CERTIFICATES. (a) If any mutilated Certificate is surrendered to the Transfer Agent, an Authorized Officer on behalf of the Partnership shall execute, and upon its request the Transfer Agent shall countersign and deliver in exchange therefor, a new Certificate evidencing the same number of Units as the Certificate so surrendered.

(b) An Authorized Officer on behalf of the Partnership shall execute, and upon its request the Transfer Agent shall countersign and deliver a new Certificate in place of any Certificate previously issued if the Record Holder of the Certificate:

(i) makes proof by affidavit, in form and substance satisfactory to the Partnership Policy Committee, that a previously issued Certificate has been lost, destroyed or stolen;

(ii) requests the issuance of a new Certificate before the Partnership has notice that the Certificate has been acquired by a purchaser for value in good faith and without notice of an adverse claim;

(iii) if requested by an Authorized Officer, delivers to the Partnership a bond, in form and substance satisfactory to the Authorized Officer, with surety or sureties and with fixed or open penalty as an Authorized Officer may reasonably direct, in its sole discretion, to indemnify the General Partners, the Partnership, the Partnership Policy Committee and the Transfer Agent against any claim that may be made on account of the alleged loss, destruction or theft of the Certificate; and

(iv) satisfies any other reasonable requirements imposed by the Partnership Policy Committee.

If a Limited Partner or Assignee fails to notify the Partnership within a reasonable time after he has notice of the loss, destruction or theft of a Certificate, and a transfer of the Units represented by the Certificate is registered before the Partnership, the Partnership Policy Committee or the Transfer Agent receives such notification, the Limited Partner or Assignee shall be precluded from making any claim against the Partnership, the General Partners, the Partnership Policy Committee, the General Partners or the Transfer Agent for such transfer or for a new Certificate.

(c) As a condition to the issuance of any new Certificate under this
Section 10.3, the Partnership Policy Committee may require the payment of a sum sufficient to cover any tax or other governmental charge that may be imposed in relation thereto and any other expenses (including, without limitation, the fees and expenses of the Transfer Agent) reasonably connected therewith.

10.4 RECORD HOLDER. In accordance with Section 10.2(b), the Partnership shall be entitled to recognize the Record Holder as the Limited Partner or Assignee with respect to any Units and, accordingly, shall not be bound to recognize any equitable or other claim to or interest in such Units on the part of any other Person, whether or not the Partnership shall have actual or other notice thereof, except as otherwise provided by law or any applicable rule, regulation, guideline or requirement

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of any National Securities Exchange on which the Units are listed for trading. Without limiting the foregoing, when a Person (such as a broker, dealer, bank, trust company or clearing corporation or an agent of any of the foregoing) is acting as nominee, agent or in some other representative capacity for another Person in acquiring and/or holding Units, as between the Partnership on the one hand and such other Persons on the other hand, such representative Person (a) shall be the Limited Partner or Assignee (as the case may be) of record and beneficially, (b) must execute and deliver a Transfer Application and
(c) shall be bound by this Agreement and shall have the rights and obligations of a Limited Partner or Assignee (as the case may be) hereunder and as provided for herein.

ARTICLE XI
TRANSFER OF INTERESTS

11.1 TRANSFER. (a) The term "TRANSFER," when used in this Article XI with respect to a Partnership Interest, shall be deemed to refer to a transaction by which a General Partner assigns its Partnership Interest as a general partner in the Partnership to another Person or by which the holder of a Unit assigns such Unit to another Person who is or becomes an Assignee, and includes a sale, assignment, gift, pledge, encumbrance, hypothecation, mortgage, exchange or any other disposition by law or otherwise.

(b) No Partnership Interest shall be transferred, in whole or in part, except in accordance with the terms and conditions set forth in this Article XI. Any transfer or purported transfer of a Partnership Interest not made in accordance with this Article XI shall be null and void.

(c) Nothing contained in this Article XI shall be construed to prevent a disposition by the parent entity of a General Partner of all of the issued and outstanding capital stock of such General Partner.

(d) Nothing contained in this Article XI, or elsewhere in this Partnership Agreement, shall preclude the settlement of any transactions involving Common Units entered into through the facilities of the New York Stock Exchange.

11.2 TRANSFER OF A GENERAL PARTNER'S PARTNERSHIP INTEREST. Except for a transfer by a General Partner of all or any part of its Partnership Interest as a general partner in the Partnership to an Affiliate of such General Partner or to another General Partner pursuant to the terms of Section 11.7(b) or (c), the transfer by a General Partner of all or any part of its Partnership Interest as a general partner in the Partnership to another Person shall be subject to the following restrictions:

(i) compliance with the notice requirements of Section 11.7(a);

(ii) in the case of such a transfer by Northern Plains or Pan Border prior to December 31, 2003, the prior approval of at least a majority of the Outstanding Units (excluding for purposes of such determination Common Units owned by Northern Plains or Pan Border, as applicable, and its Affiliates); and

(iii) in the case of a transfer by a General Partner of less than all of its Partnership Interest as a general partner in the Partnership, the prior written consent of every other General Partner (it being agreed by the General Partners that the consent of the non-transferring General Partners shall not be required if a General Partner transfers all of its Partnership Interest as a general partner in the Partnership to another Person).

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Notwithstanding anything herein to the contrary, no transfer by a General Partner of all or any part of its Partnership Interest as a general partner in the Partnership to another Person shall be permitted unless (i) the transferee agrees to assume and be bound by the provisions of this Agreement and Intermediate Partnership Agreement, (ii) the Partnership receives an Opinion of Counsel that such transfer would not result in the loss of limited liability of any Limited Partner or of any limited partner of the Intermediate Partnership or cause the Partnership, the Intermediate Partnership or Northern Border Pipeline to be treated as an association taxable as a corporation or otherwise to be taxed as an entity for federal income tax purposes and (iii) such transferee also agrees to purchase all (or the appropriate portion thereof, if applicable) of the partnership interest of such General Partner as a general partner of the Intermediate Partnership. In the case of a transfer pursuant to and in compliance with this Section 11.2, the transferee or successor (as the case may be) shall, subject to compliance with the terms of Section 12.3, be admitted to the Partnership as a General Partner immediately prior to the transfer of the Partnership Interest, and the business of the Partnership shall continue without dissolution.

11.3 TRANSFER OF UNITS. (a) Units may be transferred only in the manner described in Section 10.2. The transfer of any Units and the admission of any new Partner shall not constitute an amendment to this Agreement.

(b) Until admitted as a Substituted Limited Partner pursuant to Article XII, the Record Holder of a Unit shall be an Assignee in respect of such Unit. Limited Partners may include custodians, nominees, or any other individual or entity in its own or any representative capacity.

(c) Each distribution in respect of Units shall be paid by the Partnership, directly or through the Transfer Agent or through any other Person or agent, only to the Record Holders thereof as of the Record Date set for the distribution. Such payment shall constitute full payment and satisfaction of the Partnership's liability in respect of such payment, regardless of any claim of any Person who may have an interest in such payment by reason of an assignment or otherwise.

(d) A transferee who has completed and delivered a Transfer Application shall be deemed to have (i) requested admission as a Substituted Limited Partner, (ii) agreed to comply with and be bound by and to have executed this Agreement, (iii) represented and warranted that such transferee has the right, power and authority and, if an individual, the capacity to enter into this Agreement, (iv) made the powers of attorney set forth in this Agreement and (v) given the consents and approvals and made the waivers contained in this Agreement.

11.4 RESTRICTIONS ON TRANSFERS. Notwithstanding the other provisions of this Article XI, no transfer of any Unit or interest therein of any Limited Partner or Assignee shall be made if such transfer would (a) violate the then applicable federal or state securities laws or rules and regulations of the Securities and Exchange Commission, any state securities commission or any other governmental authorities with jurisdiction over such transfer, (b) result in the taxation of the Partnership, the Intermediate Partnership or Northern Border Pipeline as an association taxable as a corporation or otherwise subject the Partnership, the Intermediate Partnership or Northern Border Pipeline to entity- level taxation for federal income tax purposes or (c) affect the Partnership's or the Intermediate Partnership's existence or qualification as a limited partnership under the Delaware Act.

11.5 CITIZENSHIP CERTIFICATES; NON-CITIZEN ASSIGNEES. (a) If the Partnership, the Intermediate Partnership or Northern Border Pipeline is or becomes subject to any federal, state or local law or regulation that, in the reasonable determination of the Partnership Policy Committee provides for the cancellation or forfeiture of any property in which the Partnership, the Intermediate Partnership or Northern Border Pipeline has an interest based on the nationality, citizenship or other related

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status of a Limited Partner or Assignee, the Partnership Policy Committee may request any Limited Partner or Assignee to furnish to the Partnership Policy Committee, within 30 days after receipt of such request, an executed Citizenship Certification or such other information concerning his nationality, citizenship or other related status (or, if the Limited Partner or Assignee is a nominee holding for the account of another Person, the nationality, citizenship or other related status of such Person) as the Partnership Policy Committee may request. If a Limited Partner or Assignee fails to furnish to the Partnership Policy Committee within the aforementioned 30-day period such Citizenship Certification or other requested information or if upon receipt of such Citizenship Certification or other requested information the Partnership Policy Committee determines, with the advice of counsel, that a Limited Partner or Assignee is not an Eligible Citizen, the Units owned by such Limited Partner or Assignee shall be subject to redemption in accordance with the provisions of Section
11.6. In addition, the Partnership Policy Committee may require that the status of any such Limited Partner or Assignee be changed to that of a Non-citizen Assignee, and, thereupon, the Partnership Policy Committee or its designee shall be substituted for such Non-citizen Assignee as the Limited Partner in respect of his Units.

(b) The Partnership Policy Committee or its designee shall, in exercising voting rights in respect of Units held by it on behalf of Non-citizen Assignees, distribute the votes in the same ratios as the votes of Limited Partners in respect of Units other than those of Non-citizen Assignees are cast, either for, against or abstaining as to the matter.

(c) Upon dissolution of the Partnership, a Non-citizen Assignee shall have no right to receive a distribution in kind pursuant to Section 14.4 but shall be entitled to the cash equivalent thereof, and the Partnership Policy Committee shall provide cash in exchange for an assignment of the Non-citizen Assignee's share of the distribution in kind. Such payment and assignment shall be treated for Partnership purposes as a purchase by the Partnership Policy Committee from the Non- citizen Assignee of his Partnership Interest (representing his right to receive his share of such distribution in kind).

(d) At any time after he can and does certify that he has become an Eligible Citizen, a Non-citizen Assignee may, upon application to the Partnership Policy Committee, request admission as a Substituted Limited Partner with respect to any Units of such Non-citizen Assignee not redeemed pursuant to
Section 11.6, and upon his admission pursuant to Section 12.2 the Partnership Policy Committee shall cease to be deemed to be the Limited Partner in respect of the Non-citizen Assignee's Units.

11.6 REDEMPTION OF INTERESTS. (a) If at any time a Limited Partner or Assignee fails to furnish a Citizenship Certification or other information requested within the 30-day period specified in Section 11.5(a), or if upon receipt of such Citizenship Certification or other information the Partnership Policy Committee determines, with the advice of counsel, that a Limited Partner or Assignee is not an Eligible Citizen, the Partnership may, unless the Limited Partner or Assignee establishes to the satisfaction of the Partnership Policy Committee that such Limited Partner or Assignee is an Eligible Citizen or has transferred his Units to a Person who furnishes a Citizenship Certification to the Partnership Policy Committee prior to the date fixed for redemption as provided below, redeem the Partnership Interest of such Limited Partner or Assignee as follows:

(i) The Partnership Policy Committee shall, not later than the 30th day before the date fixed for redemption, give notice of redemption to the Limited Partner or Assignee, at his last address designated on the records of the Partnership or the Transfer Agent, by registered or certified mail, postage prepaid. The notice shall be deemed to have been given when so mailed. The notice shall specify the Redeemable Units, the date fixed for redemption, the

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place of payment, that payment of the redemption price will be made upon surrender of the Certificate evidencing the Redeemable Units and that on and after the date fixed for redemption no further allocations or distributions to which the Limited Partner or Assignee would otherwise be entitled in respect of the Redeemable Units will accrue or be made.

(ii) The aggregate redemption price for Redeemable Units shall be an amount equal to the Current Market Price (the date of determination of which shall be the dated fixed for redemption) of Units of the class to be so redeemed multiplied by the number of Units of each such class included among the Redeemable Units. The redemption price shall be paid, in the sole discretion of the Partnership Policy Committee, in cash or by delivery of a promissory note of the Partnership in the principal amount of the redemption price, bearing interest at the rate of 10% annually and payable in three equal annual installments of principal together with accrued interest, commencing one year after the redemption date.

(iii) Upon surrender by or on behalf of the Limited Partner or Assignee, at the place specified in the notice of redemption, of the Certificate evidencing the Redeemable Units, duly endorsed in blank or accompanied by an assignment duly executed in blank, the Limited Partner or Assignee or his duly authorized representative shall be entitled to receive the payment therefor.

(iv) After the redemption date, Redeemable Units shall no longer constitute issued and Outstanding Units.

(b) The provisions of this Section 11.6 shall also be applicable to Units held by a Limited Partner or Assignee as nominee of a Person determined to be other than an Eligible Citizen.

(c) Nothing in this Section 11.6 shall prevent the recipient of a notice of redemption from transferring his Units before the redemption date if such transfer is otherwise permitted under this Agreement. Upon receipt of notice of such a transfer, the Partnership Policy Committee shall withdraw the notice of redemption, provided, the transferee of such Units certifies in the Transfer Application that he is an Eligible Citizen. If the transferee fails to make such certification, such redemption shall be effected from the transferee on the original redemption date.

11.7 RIGHT TO MAKE OFFER; PREFERENTIAL PURCHASE RIGHT; BUYOUT RIGHT. (a) If a General Partner desires to transfer all of its Combined Interest to a party other than an Affiliate of such General Partner, such selling General Partner must first provide every other General Partner with notice of such intent to transfer and for a period of 30 days following the receipt by each non-selling General Partner of such notice, each non-selling General Partner shall have the right to submit an offer for the Combined Interest of such selling General Partner (and any other interests in the Partnership proposed to be sold by such selling General Partner). Such selling General Partner shall have no obligation to consider or accept any offers received from the non-selling General Partners, and from and after such 30 day period, such selling General Partner shall be free to consummate the proposed transaction referred to in its notices to the non-selling General Partners.

(b) If any of the following events occurs: (i) the removal of a General Partner is approved by the requisite percentage of Limited Partners pursuant to
Section 13.2; or (ii) an Event of Withdrawal of the type described in Sections 13.1(a)(i), (iv), (v) or (vi) occurs with respect to a General Partner; upon written notice to the Partnership and the Departing Partner, the remaining General Partners shall have the right, exercisable on a pro rata basis according to their relative General Partner Percentage Interests or on such other basis as may be agreed upon, to purchase all (but not less than all) of the Combined Interest of the Departing Partner for an amount equal to

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the fair market value of such Combined Interest, as such fair market value is determined in accordance with the second paragraph of Section 13.3(a). If such remaining General Partners fail to send such notice to the Partnership and the Departing Partner on or before the 30th day following the date on which all of the remaining General Partners had received written or actual notice of the occurrence of such event, such remaining General Partners shall be deemed to have waived the right to purchase set forth in this Section 11.7(b).

(c) If at any time during the Subordination Period a General Partner ceases to own at least 250,000 Subordinated Units, such General Partner shall promptly notify every other General Partner of such fact (the occurrence of such event being herein referenced to as a "BUYOUT EVENT"). At any time following the occurrence of a Buyout Event, the General Partners that did not suffer such Buyout Event shall have the right, exercisable by the delivery of written notice to the Partnership and the General Partner suffering such Buyout Event, to purchase all (but not less than all) of the Combined Interest of such General Partner and any Subordinated Units owned by such General Partner (on a pro-rata basis according to their relative General Partner Percentage Interests or on such other basis as may be agreed upon) for an amount equal to the Buyout Price (which amount shall be calculated using as the date of determination the date on which the General Partner(s) exercising such buyout right notified the Partnership and the affected General Partner of the desire to exercise such buyout right).

ARTICLE XII
ADMISSION OF PARTNERS

12.1 ADMISSION OF GENERAL PARTNERS AND UNDERWRITERS AS LIMITED PARTNERS. Upon the issuance by the Partnership of Common Units and Subordinated Units to the General Partners as described in Section 4.1(b) and the execution by each such party of a Transfer Application, the Partnership Policy Committee shall admit the General Partners to the Partnership as Limited Partners in respect of the Common Units and Subordinated Units issued to them. Upon the transfer by Northern Plains and Pan Border of Common Units to the Underwriters in connection with the Initial Offering (and the exercise by the Underwriters of the Overallotment Option, if applicable) and the execution by each Underwriter of a Transfer Application, the Partnership Policy Committee shall admit the Underwriters to the Partnership as Limited Partners in respect of the Common Units purchased by them.

12.2 ADMISSION OF SUBSTITUTED LIMITED PARTNERS. By transfer of a Unit in accordance with Article XI, the transferor shall be deemed to have given the transferee the right to seek admission as a Substituted Limited Partner subject to the conditions of, and in the manner permitted under, this Agreement. A transferor of a Certificate shall, however, only have the authority to convey to a purchaser or other transferee who does not execute and deliver a Transfer Application (a) the right to negotiate such Certificate to a purchaser or other transferee and (b) the right to transfer the right to request admission as a Substituted Limited Partner to such purchaser or other transferee in respect of the transferred Units. Each transferee of a Unit (including, without limitation, any nominee holder or an agent acquiring such Unit for the account of another Person) who executes and delivers a Transfer Application shall, by virtue of such execution and delivery, be an Assignee and be deemed to have applied to become a Substituted Limited Partner with respect to the Units so transferred to such Person. Such Assignee shall become a Substituted Limited Partner (x) at such time as the Partnership Policy Committee consents thereto, which consent may be given or withheld in the Partnership Policy Committee's sole discretion, and (y) when any such admission is shown on the books and records of the Partnership. If such consent is withheld, such transferee shall be an Assignee. An Assignee shall have an interest in the Partnership equivalent to that of a Limited Partner with respect to allocations and distributions, including, without limitation, liquidating distributions, of the Partnership. With respect to voting rights attributable to Units that are held by Assignees, the Partnership Policy Committee shall

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be deemed to be the Limited Partner with respect thereto and shall, in exercising the voting rights in respect of such Units on any matter, vote such Units at the written direction of the Assignee who is the Record Holder of such Units. If no such written direction is received, such Units will not be voted. An Assignee shall have no other rights of a Limited Partner.

12.3 ADMISSION OF SUCCESSOR GENERAL PARTNER. A successor General Partner approved pursuant to Section 13.1 or 13.2 or the transferee of or successor to all of a General Partner's Partnership Interest as a general partner in the Partnership pursuant to Section 11.2 who is proposed to be admitted as a successor General Partner shall be admitted to the Partnership as a General Partner, effective immediately prior to the withdrawal or removal of such General Partner pursuant to Section 13.1 or 13.2 or the transfer of a General Partner's Partnership Interest as a general partner in the Partnership pursuant to Section 11.2; provided, however, that no such successor shall be admitted to the Partnership until compliance with the terms of Section 11.2 has occurred and such successor has executed and delivered such other documents or instruments as may be required to effect such admission. Any such successor, together with any remaining General Partner, shall, subject to the terms hereof, carry on the business of the Partnership and the Intermediate Partnership without dissolution.

12.4 ADMISSION OF ADDITIONAL LIMITED PARTNERS. (a) A Person (other than a
General Partner or a Substituted Limited Partner) who makes a Capital Contribution to the Partnership in accordance with this Agreement shall be admitted to the Partnership as an Additional Limited Partner only upon furnishing to the Partnership Policy Committee (i) evidence of acceptance in form satisfactory to the Partnership Policy Committee of all of the terms and conditions of this Agreement, including, without limitation, the power of attorney granted in Section 1.4, and (ii) such other documents or instruments as may be required in the discretion of the Partnership Policy Committee to effect such Person's admission as an Additional Limited Partner.

(b) Notwithstanding anything to the contrary in this Section 12.4, no Person shall be admitted as an Additional Limited Partner without the consent of the Partnership Policy Committee, which consent may be given or withheld in the Partnership Policy Committee's sole discretion. The admission of any Person as an Additional Limited Partner shall become effective on the date upon which the name of such Person is recorded as such in the books and records of the Partnership, following the consent of the Partnership Policy Committee to such admission.

12.5 AMENDMENT OF AGREEMENT AND CERTIFICATE OF LIMITED PARTNERSHIP. To effect the admission to the Partnership of any Partner, the Partnership Policy Committee shall take all steps necessary and appropriate under the Delaware Act to amend the records of the Partnership to reflect such admission and, if necessary, to prepare as soon as practical an amendment of this Agreement and, if required by law, to prepare and file an amendment to the Certificate of Limited Partnership and may for this purpose, among others, exercise the power of attorney granted pursuant to Section 1.4.

ARTICLE XIII
WITHDRAWAL OR REMOVAL OF PARTNERS

13.1 WITHDRAWAL OF A GENERAL PARTNER. (a) A General Partner shall be deemed to have withdrawn from the Partnership upon the occurrence of any one of the following events (each such event herein referred to as an "EVENT OF WITHDRAWAL");

(i) a General Partner voluntarily withdraws from the Partnership by giving written notice to the other Partners (and it shall be deemed that a General Partner has given notice of withdrawal pursuant to this Section 13.1(a)(i) if a General Partner voluntarily withdraws as general partner of the Intermediate Partnership);

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(ii) a General Partner notifies the other General Partners that it desires to transfer all of its rights as General Partner pursuant to
Section 11.2;

(iii) a General Partner is removed pursuant to Section 13.2;

(iv) a General Partner (A) makes a general assignment for the benefit of creditors; (B) files a voluntary bankruptcy petition; (C) files a petition or answer seeking for itself a reorganization, arrangement, composition, readjustment, liquidation, dissolution or similar relief under any law; (D) files an answer or other pleading admitting or failing to contest the material allegations of a petition filed against such General Partner in a proceeding of the type described in clauses (A)-(C) of this Section 13.1(a)(iv); or (E) seeks, consents to or acquiesces in the appointment of a trustee, receiver or liquidator of such General Partner or of all or any substantial part of its properties;

(v) a final and non-appealable judgment is entered by a court with appropriate jurisdiction ruling that a General Partner is bankrupt or insolvent, or a final and non-appealable order for relief is entered by a court with appropriate jurisdiction against a General Partner, in each case under any federal or state bankruptcy or insolvency laws as now or hereafter in effect; or

(vi) a certificate of dissolution or its equivalent is filed for a General Partner, or 90 days expire after the date of notice to a General Partner of revocation of its charter without a reinstatement of its charter, under the laws of its state of incorporation.

If an Event of Withdrawal specified in Section 13.1(a)(iv), (v) or (vi) occurs, the withdrawing General Partner shall give notice to the Limited Partners within 30 days after such occurrence. The Partners hereby agree that only the Events of Withdrawal described in this Section 13.1 shall result in the withdrawal of a General Partner from the Partnership.

(b) Withdrawal of a General Partner from the Partnership upon the occurrence of an Event of Withdrawal shall not constitute a breach of this Agreement under the following circumstances: (i) at any time during the period beginning on the Closing Date and ending at 12:00 Midnight, Central Standard Time, on December 31, 2003, a General Partner voluntarily withdraws by giving at least 90 days' advance notice of its intention to withdraw to the Limited Partners, provided, that prior to the effective date of such withdrawal the withdrawal is approved by Limited Partners holding at least two-thirds of the Outstanding Units (excluding for purposes of such determination Units owned by the Departing Partner and its Affiliates) and such General Partner delivers to the Partnership an Opinion of Counsel (" WITHDRAWAL OPINION OF COUNSEL") that such withdrawal (following the purchase by one or more of the remaining General Partners of the Combined Interest of such Departing Partner pursuant to Section 11.7(b) or the selection of a successor General Partner, as applicable) would not result in the loss of the limited liability of any Limited Partner or of the limited partner of the Intermediate Partnership or cause the Partnership, the Intermediate Partnership or Northern Border Pipeline to be treated as an association taxable as a corporation or otherwise to be taxed as an entity for federal income tax purposes; (ii) at any time after 12:00 Midnight, Central Standard Time, on December 31, 2003, a General Partner voluntarily withdraws by giving at least 90 days' advance notice to the Limited Partners, such withdrawal to take effect on the date specified in such notice; (iii) at any time that a General Partner ceases to be a General Partner pursuant to Section 13.1(a)(ii) or is removed pursuant to Section 13.2; or (iv) notwithstanding clause (i) of this sentence, at any time that a General Partner voluntarily withdraws by giving at least 90 days' advance notice of its intention to withdraw to the Limited Partners, such withdrawal to take effect on the date specified in the notice, if at the time such notice is given one Person and its Affiliates (other than such General Partner and

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its Affiliates) own beneficially or of record or control at least 50% of the Outstanding Units. The withdrawal of a General Partner from the Partnership upon the occurrence of an Event of Withdrawal shall also constitute the withdrawal of such General Partner as a general partner of the Intermediate Partnership. If a General Partner gives a notice of withdrawal pursuant to Section 13.1(a)(i) or an Event of Withdrawal of the type described in Sections 13.1(a)(iv)-(vi) occurs, and in any such case one or more of the remaining General Partners do not elect to purchase the Combined Interest of such Departing Partner pursuant to Section 11.7(b), holders of at least a majority of the Outstanding Units (excluding for purposes of such determination Units owned by the Departing Partner and its Affiliates) may, prior to the effective date of such withdrawal, elect a successor General Partner. The Person so elected as successor General Partner shall automatically become a successor general partner of the Intermediate Partnership, as provided in Intermediate Partnership Agreement. If, prior to the effective date of a General Partner's withdrawal, one or more of the remaining General Partners have not elected to purchase the Combined Interest of such Departing Partner pursuant to Section 11.7(b) and a successor is not selected by the Limited Partners as provided herein, or the Partnership does not receive a Withdrawal Opinion of Counsel, the Partnership shall be dissolved in accordance with Section 14.1. Any successor General Partner elected in accordance with the terms of this Section 13.1 shall be subject to the provisions of Section 12.3.

13.2 REMOVAL OF A GENERAL PARTNER. A General Partner may be removed if such removal is approved by Limited Partners holding at least two-thirds of the Outstanding Units (excluding for purposes of such determination Units owned by the General Partners and their Affiliates). Any such action by such Limited Partners for removal of a General Partner must, if one or more of the remaining General Partners do not elect to purchase all of the Combined Interest of such Departing Partner pursuant to Section 11.7(b), also provide for the election of a successor General Partner by Limited Partners holding at least a majority of the Outstanding Units (excluding for purposes of such determination Units owned by such Departing Partner and its Affiliates). Such removal shall be effective immediately following the purchase by one or more of the remaining General Partners of such Departing Partner's Combined Interest pursuant to Section 11.7(b) or the admission of a successor General Partner pursuant to Article XII, as applicable. The removal of a General Partner shall also automatically constitute the removal of such General Partner as general partner of the Intermediate Partnership, as provided in the Intermediate Partnership Agreement. If a person is elected as a successor General Partner in accordance with the terms of this Section 13.2, such person shall, upon admission pursuant to Article XII, automatically become a successor general partner of the Intermediate Partnership, as provided in the Intermediate Partnership Agreement. The right of the Limited Partners holding Outstanding Units to remove a General Partner shall not exist or be exercised unless the Partnership has received an opinion opining as to the matters covered by a Withdrawal Opinion of Counsel. Any successor General Partner elected in accordance with the terms of this
Section 13.2 shall be subject to the provisions of Section 12.3.

13.3 INTEREST OF DEPARTING PARTNER AND SUCCESSOR GENERAL PARTNER. (a) In the event of (i) the withdrawal of a General Partner under circumstances where such withdrawal does not violate this Agreement or (ii) removal of a General Partner by the Limited Partners under circumstances where Cause does not exist, if a successor General Partner is elected in accordance with the terms of
Section 13.1 or 13.2, the Departing Partner shall, at its option exercisable prior to the effective date of the departure of such Departing Partner, promptly receive from its successor in exchange for its Partnership Interest as a general partner in the Partnership and its partnership interest as a general partner of the Intermediate Partnership (collectively, the "COMBINED INTEREST") an amount in cash equal to the fair market value of such Combined Interest, such amount to be determined and payable as of the effective date of its departure. If a General Partner is removed by the Limited Partners under circumstances where Cause exists or if a General Partner withdraws under circumstances where such withdrawal violates this Agreement or the Intermediate Partnership Agreement, and if a successor

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General Partner is elected in accordance with the terms of Section 13.1 or 13.2, such successor shall have the option, exercisable prior to the effective date of the departure of such Departing Partner, to purchase the Combined Interest of the Departing Partner for such fair market value of such Combined Interest. In either event, the Departing Partner shall be entitled to receive all reimbursements due such Departing Partner pursuant to Section 6.5, including, without limitation, any employee-related liabilities (including, without limitation, severance liabilities), incurred in connection with the termination of any employees employed by such General Partner for the benefit of the Partnership or the Intermediate Partnership. Subject to Section 13.3(b), the Departing Partner shall, as of the effective date of its departure, cease to share in any allocations or distributions with respect to its Partnership Interest as a general partner in the Partnership and Partnership income, gain, loss, deduction and credit will be prorated and allocated as set forth in
Section 5.2(g).

For purposes of this Section 13.3(a) and Section 11.7(b), the fair market value of a Departing Partner's Combined Interest shall be deemed to equal the product of (x) such Departing Partner's Gross General Partner Percentage Interest and (y) an amount equal to the Hypothetical Equity Value of the Partnership as of the effective date of the departure of such Departing Partner.

(b) If the Combined Interest of a Departing Partner is not acquired by one or more of the remaining General Partners pursuant to Section 11.7(b) or by a successor in the manner set forth in Section 13.3(a), the Departing Partner shall become a Limited Partner and the Combined Interest shall be converted into Common Units based on the fair market value of such Combined Interest as calculated pursuant to Section 13.3(a), without reduction in such Partnership Interest (but subject to proportionate dilution by reason of the admission of its successor). Any successor General Partner shall indemnify the Departing Partner as to all debts and liabilities of the Partnership arising on or after the date on which the Departing Partner becomes a Limited Partner. For purposes of this Agreement, conversion of a General Partner's Partnership Interest as a general partner in the Partnership to Common Units will be characterized as if such General Partner contributed its Partnership Interest to the Partnership in exchange for the newly-issued Common Units.

(c) If one or more of the remaining General Partners do not elect to purchase the Departing Partner's Combined Interest pursuant to Section 11.7(b), a successor General Partner is elected in accordance with the terms of Section 13.1 or 13.2, and the option described in Section 13.3(a) is not exercised by the party entitled to do so, a successor General Partner shall, at the effective date of its admission to the Partnership, contribute to the capital of the Partnership cash in an amount such that its Capital Account, after giving effect to such contribution and any adjustments made to the Capital Accounts of all Partners pursuant to Section 4.4(d)(i), shall be equal to that percentage of the Capital Accounts of all Partners that is equal to its Percentage Interest as a General Partner. In such event, each successor General Partner shall, subject to the following sentence, be entitled to such Percentage Interest of all Partnership allocations and distributions and any other allocations and distributions to which the Departing Partner was entitled. In addition, the Partnership Policy Committee shall cause this Agreement to be amended to reflect that, from and after the date of such successor General Partner's admission, the aggregate interest of all remaining General Partners and such successor General Partner in all Partnership distributions and allocations shall be 1%, and that of the holders of Outstanding Units shall be 99%.

13.4 WITHDRAWAL OF LIMITED PARTNERS. No Limited Partner shall have any right to withdraw from the Partnership; provided, however, that when a transferee of a Limited Partner's Units becomes a Record Holder, such transferring Limited Partner shall cease to be a Limited Partner with respect to the Units so transferred.

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ARTICLE XIV
DISSOLUTION AND LIQUIDATION

14.1 DISSOLUTION. The Partnership shall not be dissolved by the admission of Substituted Limited Partners or Additional Limited Partners or by the admission of a successor General Partner in accordance with the terms of this Agreement. Upon the removal or withdrawal of a General Partner, if one or more of the remaining General Partners agrees to purchase the Combined Interest of such Departing Partner pursuant to Section 11.7, or if a successor General Partner is elected pursuant to Section 13.1 or 13.2, the Partnership shall not be dissolved and the remaining General Partners and/or such successor General Partner shall continue the business of the Partnership. The Partnership shall dissolve, and (subject to Section 14.2) its affairs should be wound up, upon:

(a) the expiration of its term as provided in Section 1.5;

(b) an Event of Withdrawal of a General Partner as provided in
Section 13.1(a)(other than Section 13.1(a)(ii)), unless (i) one or more of the remaining General Partners agree to purchase the Combined Interest of such Departing Partner pursuant to Section 11.7(b) or (ii) a successor is elected and an Opinion of Counsel is received as provided in Section
13.1 (b) or 13.2 and such successor is admitted to the Partnership pursuant to Section 12.3;

(c) an election by the Partnership Policy Committee to dissolve the Partnership that is approved by at least two-thirds of the Outstanding Units during the Subordination Period and at least a majority of the Outstanding Units thereafter (and all Limited Partners hereby expressly consent that such approval may be effected upon written consent of said applicable percentage of the Outstanding Units);

(d) entry of a decree of judicial dissolution of the Partnership pursuant to the provisions of the Delaware Act; or

(e) the sale of all or substantially all of the assets and properties of the Partnership and the Intermediate Partnership.

14.2 CONTINUATION OF THE BUSINESS OF THE PARTNERSHIP AFTER DISSOLUTION. Upon (a) dissolution of the Partnership following an Event of Withdrawal caused by the withdrawal or removal of a General Partner as provided in Section 13.1
(a)(i) or (iii) and the failure to occur of either (i) the purchase by one or more of the remaining General Partners of such Departing Partner's Combined Interest pursuant to Section 11.7(b) or (ii) the selection of a successor to such Departing Partner pursuant to Section 13.1 or 13.2, then within 90 days thereafter or (b) dissolution of the Partnership upon an event constituting an Event of Withdrawal as defined in Section 13.1(a)(iv), (v) or (vi) and the failure to occur of either (i) the purchase by one or more of the remaining General Partners of such Departing Partner's Combined Interest pursuant to
Section 11.7(b) or (ii) the selection of a successor to such Departing Partner pursuant to Section 13.1 or 13.2, then within 180 days thereafter, a majority of the Outstanding Units may elect to reconstitute the Partnership and continue its business on the same terms and conditions set forth in this Agreement by forming a new limited partnership on terms identical to those set forth in this Agreement and having as the successor general partners the remaining General Partners (if they desire to continue in such capacity) and/or a Person approved by a majority of the Outstanding Units. Upon any such election by a majority of the Outstanding Units, all Partners shall be bound thereby and shall be deemed to have approved same. Unless such an election is made within the applicable time period as set forth

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above, the Partnership shall conduct only activities necessary to wind up its affairs. If such an election is so made, then:

(i) the reconstituted Partnership shall continue until the end of the term set forth in Section 1.5 unless earlier dissolved in accordance with this Article XIV;

(ii) if one or more of the successor General Partners is not a former General Partner, or if one or more of the remaining General Partners does not desire to continue as a General Partner, then the interest of such former General Partner and/or such remaining General Partners shall be treated thenceforth as interests of a Limited Partner and converted into Common Units in the manner provided in Section 13.3(b); and

(iii) all necessary steps shall be taken to cancel this Agreement and the Certificate of Limited Partnership and to enter into and, as necessary, to file a new partnership agreement and certificate of limited partnership, and the remaining General Partner(s) and such successor general partner may for this purpose exercise the powers of attorney granted the members of the Partnership Policy Committee pursuant to
Section 1.4; provided, that the right of a majority of Outstanding Units to approve a successor General Partner and to reconstitute and to continue the business of the Partnership shall not exist and may not be exercised unless the Partnership has received an Opinion of Counsel that (x) the exercise of the right would not result in the loss of limited liability of any Limited Partner and (y) neither the Partnership, the reconstituted limited partnership, the Intermediate Partnership nor Northern Border Pipeline would be treated as an association taxable as a corporation or otherwise be taxable as an entity for federal income tax purposes upon the exercise of such right to continue.

14.3 LIQUIDATION. Upon dissolution of the Partnership, unless the Partnership is continued under an election to reconstitute and continue the Partnership pursuant to Section 14.2, the Partnership Policy Committee or its designee, or if it fails to act, a liquidator or liquidating committee approved by a majority of the Outstanding Units, shall be the Liquidator. The Liquidator (if other than the Partnership Policy Committee or its designee) shall be entitled to receive such compensation for its services as may be approved by a majority of the Outstanding Units. The Liquidator shall agree not to resign at any time without 15 days' prior notice and (if other than the Partnership Policy Committee or its designee) may be removed at any time, with or without cause, by notice of removal approved by a majority of the Outstanding Units. Upon dissolution, removal or resignation of the Liquidator, a successor and substitute Liquidator (who shall have and succeed to all rights, powers and duties of the original Liquidator) shall within 30 days thereafter be approved by a majority of the Outstanding Units. The right to approve a successor or substitute Liquidator in the manner provided herein shall be deemed to refer also to any such successor or substitute Liquidator approved in the manner herein provided. Except as expressly provided in this Article XIV, the Liquidator approved in the manner provided herein shall have and may exercise, without further authorization or consent of any of the parties hereto, all of the powers conferred upon the Partnership Policy Committee and the General Partners under the terms of this Agreement (but subject to all of the applicable limitations, contractual and otherwise, upon the exercise of such powers, other than the limitation on sale set forth in Section 6.4(b)) to the extent necessary or desirable in the good faith judgment of the Liquidator to carry out the duties and functions of the Liquidator hereunder for and during such period of time as shall be reasonably required in the good faith judgment of the Liquidator to complete the winding-up and liquidation of the Partnership as provided for herein. The Liquidator shall liquidate the assets of the Partnership, and apply and distribute the proceeds of such liquidation in the following order of priority, unless otherwise required by mandatory provisions of applicable law:

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(a) the payment to creditors of the Partnership, including, without limitation, Partners who are creditors, in the order of priority provided by law; and the creation of a reserve of cash or other assets of the Partnership for contingent liabilities in an amount, if any, determined by the Liquidator to be appropriate for such purposes; and

(b) to all Partners in accordance with, and to the extent of, the positive balances in their respective Capital Accounts, as determined after taking into account all Capital Account adjustments (other than those made by reason of this clause) for the taxable year of the Partnership during which the liquidation of the Partnership occurs (with the date of such occurrence being determined pursuant to Treasury Regulation Section 1.704-1(b)(2)(ii)(g)); and such distribution shall be made by the end of such taxable year (or, if later, within 90 days after said date of such occurrence).

14.4 DISTRIBUTIONS IN KIND. (a) Notwithstanding the provisions of Section 14.3, which require the liquidation of the assets of the Partnership, but subject to the order of priorities set forth therein, if prior to or upon dissolution of the Partnership the Liquidator determines that an immediate sale of part or all of the Partnership's assets would be impractical or would cause undue loss to the Partners, the Liquidator may, in its absolute discretion, defer for a reasonable time the liquidation of any assets except those necessary to satisfy liabilities of the Partnership (including, without limitation, those to Partners as creditors) and/or distribute to the Partners or to specific classes of Partners, in lieu of cash, as tenants in common and in accordance with the provisions of Section 14.3, undivided interests in such Partnership assets as the Liquidator deems not suitable for liquidation. Any such distributions in kind shall be made only if, in the good faith judgment of the Liquidator, such distributions in kind are in the best interest of the Limited Partners, and shall be subject to such conditions relating to the disposition and management of such properties as the Liquidator deems reasonable and equitable and to any agreements governing the operation of such properties at such time. The Liquidator shall determine the fair market value of any property distributed in kind using such reasonable method of valuation as it may adopt.

(b) In accordance with Section 704(c)(1)(B) of the Code, in the case of any deemed distribution occurring as a result of a termination of the Partnership pursuant to Section 708(b)(1)(B) of the Code, to the maximum extent possible consistent with the priorities of Section 14.3, the Partnership Policy Committee shall have sole discretion to treat the deemed distribution of Partnership assets to Partners as occurring in a manner that will not cause a shift of the Book-Tax Disparity attributable to a Partnership asset existing immediately prior to the deemed distribution to another asset upon the deemed contribution of assets to the reconstituted Partnership, including, without limitation, deeming the distribution of any Partnership assets to be made either to the Partner who contributed such assets or to the transferee of such Partner.

14.5 CANCELLATION OF CERTIFICATE OF LIMITED PARTNERSHIP. Upon the completion of the distribution of Partnership cash and property as provided in Sections 14.3 and 14.4 in connection with the liquidation of the Partnership, the Partnership shall be terminated and the Certificate of Limited Partnership and all qualifications of the Partnership as a foreign limited partnership in jurisdictions other than the State of Delaware shall be cancelled and such other actions as may be necessary to terminate the Partnership shall be taken.

14.6 REASONABLE TIME FOR WINDING UP. A reasonable time shall be allowed for the orderly winding up of business and affairs of the Partnership and the liquidation of its assets pursuant to Section 14.3 in order to minimize any losses otherwise attendant upon such winding up, and the provisions of this Agreement shall remain in effect between the Partners during the period of liquidation.

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14.7 RETURN OF CAPITAL. The General Partners shall not be personally liable for, and shall have no obligation to contribute or loan any monies or property to the Partnership to enable it to effectuate, the return of the Capital Contributions of the Limited Partners, or any portion thereof, it being expressly understood that any such return shall be made solely from Partnership assets.

14.8 NO CAPITAL ACCOUNT RESTORATION. No Partner shall have any obligation to restore any negative balance in its Capital Account upon liquidation of the Partnership.

14.9 WAIVER OF PARTITION. Each Partner hereby waives any right to partition of the Partnership property.

ARTICLE XV
AMENDMENT OF PARTNERSHIP AGREEMENT;
MEETINGS; RECORD DATE

15.1 AMENDMENT TO BE ADOPTED SOLELY BY PARTNERSHIP POLICY COMMITTEE. Each Limited Partner agrees that the Partnership Policy Committee (pursuant to its powers of attorney from the Limited Partners and Assignees), without the approval of any Limited Partner or Assignee, may amend any provision of this Agreement, and execute, swear to, acknowledge, deliver, file and record whatever documents may be required in connection therewith, to reflect:

(a) a change in the name of the Partnership, the location of the principal place of business of the Partnership, the registered agent of the Partnership or the registered office of the Partnership;

(b) admission, substitution, withdrawal or removal of Partners in accordance with this Agreement;

(c) a change that, in the sole discretion of the Partnership Policy Committee, is reasonable and necessary or appropriate to qualify or continue the qualification of the Partnership as a limited partnership or a partnership in which the limited partners have limited liability under the laws of any state or that is necessary or advisable in the opinion of the Partnership Policy Committee to ensure that none of the Partnership, the Intermediate Partnership or Northern Border Pipeline will be treated as an association taxable as a corporation or otherwise taxed as an entity for federal income tax purposes;

(d) a change (i) that, in the sole discretion of the Partnership Policy Committee, does not adversely affect the Limited Partners in any material respect, (ii) that is necessary or desirable to satisfy any requirements, conditions or guidelines contained in any opinion, directive, order, ruling or regulation of any federal or state agency or judicial authority or contained in any federal or state statute (including, without limitation, the Delaware Act) or that is necessary or desirable to facilitate the trading of the Units (including, without limitation, the division of Outstanding Units into different classes to facilitate uniformity of tax consequences within such classes of Units) or comply with any rule, regulation, guideline or requirement of any National Securities Exchange on which the Units are or will be listed for trading, compliance with any of which the Partnership Policy Committee determines in its sole discretion to be in the best interests of the Partnership and the Limited Partners or (iii) that is required to effect the intent of the provisions of this Agreement or is otherwise contemplated by this Agreement;

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(e) an amendment that is necessary, in the Opinion of Counsel, to prevent the Partnership or the General Partners or their directors or officers from in any manner being subjected to the provisions of the Investment Company Act of 1940, as amended, the Investment Advisers Act of 1940, as amended, or "plan asset" regulations adopted under the Employee Retirement Income Security Act of 1974, as amended, whether or not substantially similar to plan asset regulations currently applied or proposed by the United States Department of Labor;

(f) subject to the terms of Section 4.2, an amendment that the Partnership Policy Committee determines in its sole discretion to be necessary or appropriate in connection with the authorization for issuance of any class or series of Partnership Securities pursuant to Section 4.2;

(g) any amendment expressly permitted in this Agreement to be made by the Partnership Policy Committee acting alone;

(h) an amendment effected, necessitated or contemplated by a Merger Agreement approved in accordance with Section 16.3;

(i) an amendment that, in the sole discretion of the Partnership Policy Committee, is necessary or desirable to reflect, account for and deal with appropriately the formation by the Partnership of, or investment by the Partnership in, any corporation, partnership, joint venture, limited liability company or other entity other than the Intermediate Partnership, in connection with the conduct by the Partnership of activities permitted by the terms of Section 3.1; or

(j) any other amendments substantially similar to the foregoing.

15.2 AMENDMENT PROCEDURES. Except as provided in Sections 15.1 and 15.3, all amendments to this Agreement shall be made in accordance with the following requirements. Amendments to this Agreement may be proposed only by or with the consent of the Partnership Policy Committee. Each such proposal shall contain the text of the proposed amendment. If an amendment is proposed, the Partnership Policy Committee shall seek the written approval of the requisite percentage of Outstanding Units or call a meeting of the Limited Partners to consider and vote on such proposed amendment. A proposed amendment shall be effective upon its approval by the holders of at least two-thirds of the Outstanding Units unless a greater or different percentage is required under this Agreement. The Partnership Policy Committee shall notify all Record Holders upon final adoption of any proposed amendment, including both amendments proposed and voted upon in accordance with this Section 15.2 and those proposed and voted upon under the special requirements of Section 15.3.

15.3 AMENDMENT REQUIREMENTS. (a) Notwithstanding the provisions of Sections 15.1 and 15.2, no provision of this Agreement that establishes a percentage of Outstanding Units required to take any action shall be amended, altered, changed, repealed or rescinded in any respect that would have the effect of reducing such voting requirement unless such amendment is approved by the written consent or the affirmative vote of holders of Outstanding Units whose aggregate Outstanding Units constitute not less than the voting requirement sought to be reduced.

(b) Notwithstanding the provisions of Sections 15.1 and 15.2, no amendment to this Agreement may (i) enlarge the obligations of any Limited Partner without its consent, (ii) enlarge the obligations of any General Partner without its consent, which may be given or withheld in such General Partner's sole discretion, (iii) modify the amounts distributable, reimbursable or otherwise payable to a General Partner by the Partnership, (iv) change Section 14.1 (a) or
(c), (v) restrict in any way any action by or rights of the General Partners or the Partnership Policy Committee as set forth in this Agreement or (vi) change the term of the Partnership or, except as set forth in Section 14.1(c), give any Person the right to dissolve the Partnership.

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(c) Except as otherwise provided, and without limitation of the Partnership Policy Committee's authority to adopt amendments to this Agreement as contemplated in Section 15.1, the Partnership Policy Committee may amend the Partnership Agreement without the approval of holders of Outstanding Units, except that any amendment that would have a material adverse effect on the rights or preferences of any class of Outstanding Units in relation to other classes of Units must be approved by the holders of not less than two-thirds of the Outstanding Units of the class affected.

(d) Notwithstanding any other provision of this Agreement, except for amendments pursuant to Section 6.4 or 15.1 and except as otherwise provided by
Section 16.3(b), no amendments shall become effective without the approval of the holders of at least 95% of the Outstanding Units unless the Partnership obtains an Opinion of Counsel to the effects that (a) such amendment will not cause the Partnership, the Intermediate Partnership or Northern Border Pipeline to be treated as an association taxable as a corporation or otherwise taxable as an entity for federal income tax purposes and (b) such amendment will not affect the limited liability of any Limited Partner or any limited partner of the Intermediate Partnership under applicable law.

(e) This Section 15.3 shall only be amended with the approval of the holders of not less than 95% of the Outstanding Units.

15.4 MEETINGS. All acts of Limited Partners to be taken hereunder shall be taken in the manner provided in this Article XV. Meetings of the Limited Partners may be called by the Partnership Policy Committee or by Limited Partners owning 20% or more of the Outstanding Units of the class or classes for which a meeting is proposed. Limited Partners shall call a meeting by delivering to the Partnership Policy Committee of one or more requests in writing stating that the signing Limited Partners wish to call a meeting and indicating the general or specific purposes for which the meeting is to be called. Within 60 days after receipt of such a call from Limited Partners or within such greater time as may be reasonably necessary for the Partnership to comply with any statutes, rules, regulations, listing agreements or similar requirements governing the holding of a meeting or the solicitation of proxies for use at such a meeting, the Partnership Policy Committee shall send a notice of the meeting to the Limited Partners either directly or indirectly through the Transfer Agent. A meeting shall be held at a time and place determined by the Partnership Policy Committee on a date not more than 60 days after the mailing of notice of the meeting. Limited Partners shall not vote on matters that would cause the Limited Partners to be deemed to be taking part in the management and control of the business and affairs of the Partnership so as to jeopardize the Limited Partners' limited liability under the Delaware Act or the law of any other state in which the Partnership is qualified to do business.

15.5 NOTICE OF A MEETING. Notice of a meeting called pursuant to Section 15.4 shall be given to the Record Holders in writing by mail or other means of written communication in accordance with Section 17.1. The notice shall be deemed to have been given at the time when deposited in the mail or sent by other means of written communication.

15.6 RECORD DATE. For purposes of determining the Limited Partners entitled to notice of or to vote at a meeting of the Limited Partners or to give approvals without a meeting as provided in Section 15.11, the Partnership Policy Committee may set a Record Date, which shall not be less than 10 nor more than 60 days before (a) the date of the meeting (unless such requirement conflicts with any rule, regulation, guideline or requirement of any National Securities Exchange on which the Units are listed for trading, in which case the rule, regulation, guideline or requirement of such exchange shall govern) or (b) in the event that approvals are sought without a meeting, the date by which Limited Partners are requested in writing by the Partnership Policy Committee to give such approvals.

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15.7 ADJOURNMENT. When a meeting is adjourned to another time or place, notice need not be given of the adjourned meeting and a new Record Date need not be fixed, if the time and place thereof are announced at the meeting at which the adjournment is taken, unless such adjournment shall be for more than 45 days. At the adjourned meeting, the Partnership may transact any business which might have been transacted at the original meeting. If the adjournment is for more than 45 days or if a new Record Date is fixed for the adjourned meeting, a notice of the adjourned meeting shall be given in accordance with this Article XV.

15.8 WAIVER OF NOTICE; APPROVAL OF MEETING; APPROVAL OF MINUTES. The transactions of any meeting of Limited Partners, however called and noticed, and whenever held, shall be as valid as if had at a meeting duly held after regular call and notice, if a quorum is present either in person or by proxy, and if, either before or after the meeting, Limited Partners representing such quorum who were present in person or by proxy and entitled to vote, sign a written waiver of notice or an approval of the holding of the meeting or an approval of the minutes thereof. All waivers and approvals shall be filed with the Partnership records or made a part of the minutes of the meeting. Attendance of a Limited Partner at a meeting shall constitute a waiver of notice of the meeting, except when the Limited Partner does not approve, at the beginning of the meeting, of the transaction of any business because the meeting is not lawfully called or convened; and except that attendance at a meeting is not a waiver of any right to disapprove the consideration of matters required to be included in the notice of the meeting, but not so included, if the disapproval is expressly made at the meeting.

15.9 QUORUM. The holders of two-thirds of the Outstanding Units of the class or classes for which a meeting has been called represented in person or by proxy shall constitute a quorum at a meeting of Limited Partners of such class or classes unless any such action by the Limited Partners requires approval by holders of a majority in interest of such Units, in which case the quorum shall be a majority (excluding, in either case, if such are to be excluded from the vote, Outstanding Units owned by the General Partners and their Affiliates). At any meeting of the Limited Partners duly called and held in accordance with this Agreement at which a quorum is present, the act of Limited Partners holding Outstanding Units that in the aggregate represent a majority of the Outstanding Units entitled to vote and be present in person or by proxy at such meeting shall be deemed to constitute the act of all Limited Partners, unless a greater or different percentage is required with respect to such action under the provisions of this Agreement, in which case the act of the Limited Partners holding Outstanding Units that in the aggregate represent at least such greater or different percentage shall be required. The Limited Partners present at a duly called or held meeting at which a quorum is present may continue to transact business until adjournment, notwithstanding the withdrawal of enough Limited Partners to leave less than a quorum, if any action taken (other than adjournment) is approved by the required percentage of Outstanding Units specified in this Agreement. In the absence of a quorum, any meeting of Limited Partners may be adjourned from time to time by the affirmative vote of a majority of the Outstanding Units represented either in person or by proxy, but no other business may be transacted, except as provided in Section 15.7.

15.10 CONDUCT OF MEETING. The Chairman of the Partnership Policy Committee or, in the absence of the Chairman, such other person as may be selected by the Partnership Policy Committee shall have full power and authority concerning the manner of conducting any meeting of the Limited Partners or solicitation of approvals in writing, including, without limitation, the determination of Persons entitled to vote, the existence of a quorum, the satisfaction of the requirements of Section 15.4, the conduct of voting, the validity and effect of any proxies and the determination of any controversies, votes or challenges arising in connection with or during the meeting or voting. The Chairman of the Partnership Policy Committee or such other person shall serve as chairman of any meeting and shall designate a Person to take the minutes of any meeting.

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All minutes shall be kept with the records of the Partnership maintained by the Partnership Policy Committee. The Partnership Policy Committee may make such other regulations consistent with applicable law and this Agreement as it may deem advisable concerning the conduct of any meeting of the Limited Partners or solicitation of approvals in writing, including, without limitation, regulations in regard to the appointment of proxies, the appointment and duties of inspectors of votes and approvals, the submission and examination of proxies and other evidence of the right to vote, and the revocation of approvals in writing.

15.11 ACTION WITHOUT A MEETING. Any action that may be taken at a meeting of the Limited Partners may be taken without a meeting if an approval in writing setting forth the action so taken is signed by Limited Partners owning not less than the minimum percentage of the Outstanding Units that would be necessary to authorize or take such action at a meeting at which all the Limited Partners were present and voted. Prompt notice of the taking of action without a meeting shall be given to the Limited Partners who have not approved in writing. The Partnership Policy Committee may specify that any written ballot submitted to Limited Partners for the purpose of taking any action without a meeting shall be returned to the Partnership within the time period, which shall be not less than 20 days, specified by the Partnership Policy Committee. If a ballot returned to the Partnership does not vote all of the Units held by the Limited Partner, the Partnership shall be deemed to have failed to receive a ballot for the Units that were not voted. If approval of the taking of any action by the Limited Partners is solicited by any Person other than by or on behalf of the Partnership Policy Committee, the written approvals shall have no force and effect unless and until (a) they are deposited with the Partnership in care of the Partnership Policy Committee, (b) approvals sufficient to take the action proposed are dated as of a date not more than 90 days prior to the date sufficient approvals are deposited with the Partnership and (c) an Opinion of Counsel is delivered to the Partnership Policy Committee to the effect that the exercise of such right and the action proposed to be taken with respect to any particular matter (i) will not cause the Limited Partners to be deemed to be taking part in the management and control of the business and affairs of the Partnership so as to jeopardize the Limited Partners' limited liability, (ii) will not jeopardize the status of the Partnership as a partnership under applicable tax laws and regulations and (iii) is otherwise permissible under the state statutes then governing the rights, duties and liabilities of the Partnership and the Partners.

15.12 VOTING AND OTHER RIGHTS. (a) Only those Record Holders of Units on the Record Date set pursuant to Section 15.6 (and also subject to the limitations contained in the definition of "Outstanding") shall be entitled to notice of, and to vote at, a meeting of Limited Partners or to act with respect to matters as to which the holders of the Outstanding Units have the right to vote or to act. All references in this Agreement to votes of, or other acts that may be taken by, the Outstanding Units shall be deemed to be references to the votes or acts of the Record Holders of such Outstanding Units.

(b) With respect to Units that are held for a Person's account by another Person (such as a broker, dealer, bank, trust company or clearing corporation, or an agent of any of the foregoing), in whose name such Units are registered, such broker, dealer or other agent shall, in exercising the voting rights in respect of such Units on any matter, and unless the arrangement between such Persons provides otherwise, vote such Units in favor of, and at the direction of, the Person who is the beneficial owner, and the Partnership shall be entitled to assume it is so acting without further inquiry. The provisions of this Section 15.12(b) (as well as all other provisions of this Agreement) are subject to the provisions of Section 10.4.

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ARTICLE XVI
MERGER

16.1 AUTHORITY. The Partnership may merge or consolidate with one or more corporations, business trusts or associations, real estate investment trusts, common law trusts or unincorporated businesses, including, without limitation, a general partnership or limited partnership, formed under the laws of the State of Delaware or any other state of the United States of America, pursuant to a written agreement of merger or consolidation ("MERGER AGREEMENT") in accordance with this Article.

16.2 PROCEDURE FOR MERGER OR CONSOLIDATION. Merger or consolidation of the Partnership pursuant to this Article requires the prior approval of the Partnership Policy Committee. If the Partnership Policy Committee shall determine, in the exercise of its sole discretion, to consent to the merger or consolidation, the Partnership Policy Committee shall approve the Merger Agreement, which shall set forth:

(a) The names and jurisdictions of formation or organization of each of the business entities proposing to merge or consolidate;

(b) The name and jurisdictions of formation or organization of the business entity that is to survive the proposed merger or consolidation (the "SURVIVING BUSINESS ENTITY");

(c) The terms and conditions of the proposed merger or consolidation;

(d) The manner and basis of exchanging or converting the equity securities of each constituent business entity for, or into, cash, property or general or limited partnership interests, rights, securities or obligations of the Surviving Business Entity; and (i) if any general or limited partnership interests, securities or rights of any constituent business entity are not to be exchanged or converted solely for, or into, cash, property or general or limited partnership interests, rights, securities or obligations of the Surviving Business Entity, the cash, property or general or limited partnership interests, rights, securities or obligations of any limited partnership, corporation, trust or other entity (other than the Surviving Business Entity) which the holders of such general or limited partnership interest are to receive in exchange for, or upon conversion of, their securities or rights, and (ii) in the case of securities represented by certificates, upon the surrender of such certificates, which cash, property or general or limited partnership interests, rights, securities or obligations of the Surviving Business Entity or any limited partnership, corporation, trust or other entity (other than the Surviving Business Entity), or evidences thereof, are to be delivered;

(e) A statement of any changes in the constituent documents or the adoption of new constituent documents (the articles or certificate of incorporation, articles of trust, declaration of trust, certificate or agreement of limited partnership or other similar charter or governing document) of the Surviving Business Entity to be effected by such merger or consolidation;

(f) The effective time of the merger, which may be the date of the filing of the certificate of merger pursuant to Section 16.4 or a later date specified in or determinable in accordance with the Merger Agreement (provided, that if the effective time of the merger is to be later than the date of the filing of the certificate of merger, the effective time shall be fixed no later than the time of the filing of the certificate of merger and stated therein); and

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(g) Such other provisions with respect to the proposed merger or consolidation as are deemed necessary or appropriate by the Partnership Policy Committee.

16.3 APPROVAL BY LIMITED PARTNERS OF MERGER OR CONSOLIDATION. (a) The Partnership Policy Committee of the Partnership, upon its approval of the Merger Agreement, shall direct that the Merger Agreement be submitted to a vote of Limited Partners whether at a meeting or by written consent, in either case in accordance with the requirements of Article XV. A copy or a summary of the Merger Agreement shall be included in or enclosed with the notice of a meeting or the written consent.

(b) The Merger Agreement shall be approved upon receiving the affirmative vote or consent of the holders of at least two-thirds of the Outstanding Units during the Subordination Period and at least a majority of the Outstanding Units thereafter unless the Merger Agreement contains any provision which, if contained in an amendment to this Agreement, the provisions of this Agreement or the Delaware Act would require the vote or consent of a greater percentage of the Outstanding Units or of any class of Limited Partners, in which case such greater percentage vote or consent shall be required for approval of the Merger Agreement; provided that, in the case of a merger or consolidation in which the surviving entity is a corporation or other entity intended to be treated as an association taxable as a corporation or otherwise taxable as an entity for federal income tax purposes, if in the opinion of the Partnership Policy Committee it is necessary to effect, in contemplation of such merger or consolidation, an amendment that would otherwise require a vote pursuant to
Section 15.3(d), no such vote pursuant to Section 15.3(d) shall be required unless such amendment by its terms will be applicable to the Partnership in the event the merger or consolidation is abandoned or unless such amendment will be applicable to the Partnership during a period in excess of ten days prior to the merger or consolidation.

(c) After such approval by vote or consent of the Limited Partners, and at any time prior to the filing of the certificate of merger pursuant to Section 16.4, the merger or consolidation may be abandoned pursuant to provisions therefor, if any, set forth in the Merger Agreement.

16.4 CERTIFICATE OF MERGER. Upon the required approval by the Partnership Policy Committee and the Limited Partners of a Merger Agreement, a certificate of merger shall be executed and filed with the Secretary of State of the State of Delaware in conformity with the requirements of the Delaware Act.

16.5 EFFECT OF MERGER. (a) At the effective time of the certificate of merger:

(i) all of the rights, privileges and powers of each of the business entities that has merged or consolidated, and all property, real, personal and mixed, and all debts due to any of those business entities and all other things and causes of action belonging to each of those business entities shall be vested in the Surviving Business Entity and after the merger or consolidation shall be the property of the Surviving Business Entity to the extent they were of each constituent business entity;

(ii) the title to any real property vested by deed or otherwise in any of those constituent business entities shall not revert and is not in any way impaired because of the merger or consolidation;

(iii) all rights of creditors and all liens on or security interest in property of any of those constituent business entities shall be preserved unimpaired; and

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(iv) all debts, liabilities and duties of those constituent business entities shall attach to the Surviving Business Entity, and may be enforced against it to the same extent as if the debts, liabilities and duties had been incurred or contracted by it.

(b) A merger or consolidation effected pursuant to this Article shall not be deemed to result in a transfer or assignment of assets or liabilities from one entity to another having occurred.

ARTICLE XVII
RIGHT TO ACQUIRE UNITS

17.1 RIGHT TO ACQUIRE UNITS. (a) Notwithstanding any other provision of this Agreement, if at any time not more than 20% of the total Units of any class then Outstanding are held by Persons other than the General Partners and their Affiliates, the General Partners shall then have the right (exercisable in the sole discretion of the General Partners and on a pro rata basis in accordance with their relative General Partner Percentage Interests, or as otherwise agreed), which right each General Partner may assign and transfer to the Partnership, any other General Partner, or any Affiliate of such General Partner or any other General Partner, exercisable in its sole discretion, to purchase all, but not less than all, of the Units of such class then Outstanding held by Persons other than the General Partners and their Affiliates, at the greater of
(x) the Current Market Price as of the date five days prior to the date that the notice described in Section 17.1(b) is mailed, and (y) the highest cash price paid by a General Partner or any of its Affiliates for any such Unit purchased during the 90-day period preceding the date that the notice described in Section
17.1 (b) is mailed. As used in this Agreement, (i) "CURRENT MARKET PRICE" as of any date of any class of Units listed or admitted to trading on any National Securities Exchange means the average of the daily Closing Prices (as hereinafter defined) per Unit of such class for the 20 consecutive Trading Days (as hereinafter defined) immediately prior to such date; (ii) "CLOSING PRICE" for any day means the last sale price on such day, regular way, or in case no such sale takes place on such day, the average of the closing bid and asked prices on such day, regular way, in either case as reported in the principal consolidated transaction reporting system with respect to securities listed on the principal National Securities Exchange on which the Units of such class are listed or admitted to trading or if the Units of such class are not listed or admitted to trading on any National Securities Exchange, the last quoted price on such day or, if not so quoted, the average of the high bid and low asked prices on such day in the over-the-counter market, as reported by the National Association of Securities Dealers, Inc. Automated Quotation System or such other system then in use, or if on any such day the Units of such class are not quoted by any such organization, the average of the closing bid and asked prices on such day as furnished by a professional market maker making a market in the Units of such class selected by the Partnership Policy Committee, or if on any such day no market maker is making a market in the Units of such class, the fair value of such Units on such day as determined reasonably and in good faith by the Partnership Policy Committee; and (iii) "TRADING DAY" means a day on which the principal National Securities Exchange on which the Units' of any class are listed or admitted to trading is open for the transaction of business or, if Units of a class are not listed or admitted to trading on any National Securities Exchange, a day on which banking institutions in New York City generally are open.

(b) If a General Partner, any Affiliate of a General Partner or the Partnership elects to exercise the right to purchase Units granted pursuant to
Section 17.1 (a), the exercising party or parties shall deliver to the Transfer Agent notice of such election to purchase (the "NOTICE OF ELECTION TO PURCHASE") and shall cause the Transfer Agent to mail a copy of such Notice of Election to Purchase to the Record Holders of Units (as of a Record Date selected by the Partnership Policy Committee) at least 10, but not more than 60, days prior to the Purchase Date. Such Notice of

80

Election to Purchase shall also be published for a period of at least three consecutive days in at least two daily newspapers of general circulation printed in the English language and published in the Borough of Manhattan, New York. The Notice of Election to Purchase shall specify the Purchase Date and the price (determined in accordance with Section 17.1 (a) at which Units will be purchased and state that the General Partner(s), its Affiliate(s) or the Partnership, as the case may be, elects to purchase such Units, upon surrender of Certificates representing such Units in exchange for payment, at such office or offices of the Transfer Agent as the Transfer Agent may specify, or as may be required by any National Securities Exchange on which the Units are listed or admitted to trading. Any such Notice of Election to Purchase mailed to a Record Holder of Units at his address as reflected in the records of the Transfer Agent shall be conclusively presumed to have been given whether or not the owner receives such notice. On or prior to the Purchase Date, such General Partner(s), its Affiliate(s) or the Partnership, as the case may be, shall deposit with the Transfer Agent cash in an amount sufficient to pay the aggregate purchase price of all of the Units to be purchased in accordance with this Section 17.1. If the Notice of Election to Purchase shall have been duly given as aforesaid at least 10 days prior to the Purchase Date, and if on or prior to the Purchase Date the deposit described in the preceding sentence has been made for the benefit of the holders of Units subject to purchase as provided herein, then from and after the Purchase Date, notwithstanding that any Certificate shall not have been surrendered for purchase, all rights of the holders of such Units (including, without limitation, any rights pursuant to Articles IV, V and XIV) shall thereupon cease, except the right to receive the purchase price (determined in accordance with Section 17.1 (a)) for Units therefor, without interest, upon surrender to the Transfer Agent of the Certificates representing such Units, and such Units shall thereupon be deemed to be transferred to the General Partner(s), its Affiliate(s) or the Partnership, as the case may be, on the record books of the Transfer Agent and the Partnership, and such exercising party or parties shall be deemed to be the owner of all such Units from and after the Purchase Date and shall have all rights as the owner of such Units (including, without limitation, all rights as owner of such Units pursuant to Articles IV, V and XIV).

(c) At any time from and after the Purchase Date, a holder of an Outstanding Unit subject to purchase as provided in this Section 17.1 may surrender his Certificate, as the case may be, evidencing such Unit to the Transfer Agent in exchange for payment of the amount described in Section 17.1
(a), therefor, without interest thereon.

ARTICLE XVIII
GENERAL PROVISIONS

18.1 ADDRESSES AND NOTICES. Any notice, demand, request, report or proxy materials required or permitted to be given or made to a Partner or Assignee under this Agreement shall be in writing and shall be deemed given or made when delivered in person or when sent by first-class United States mail or by other means of written communication to the Partner or Assignee at the address described below. Any notice, payment or report to be given or made to a Partner or Assignee hereunder shall be deemed conclusively to have been given or made, and the obligation to give such notice or report or to make such payment shall be deemed conclusively to have been fully satisfied, upon sending of such notice, payment or report to the Record Holder of such Unit at his address as shown on the records of the Transfer Agent or as otherwise shown on the records of the Partnership, regardless of any claim of any Person who may have an interest in such Unit or the Partnership Interest of a General Partner by reason of any assignment or otherwise. An affidavit or certificate of making of any notice, payment or report in accordance with the provisions of this Section 18.1 executed by a General Partner, a member of the Partnership Policy Committee, the Transfer Agent or the mailing organization shall be prima facie evidence of the giving or making of such notice, payment or report. If any notice, payment or report addressed to a Record Holder at

81

the address of such Record Holder appearing on the books and records of the Transfer Agent or the Partnership is returned by the United States Post Office marked to indicate that the United States Postal Service is unable to deliver it, such notice, payment or report and any subsequent notices, payments and reports shall be deemed to have been duly given or made without further mailing (until such time as such Record Holder or another Person notifies the Transfer Agent or the Partnership of a change in his address) if they are available for the Partner or Assignee at the principal office of the Partnership for a period of one year from the date of the giving or making of such notice, payment or report to the other Partners and Assignees. Any notice to the Partnership or the Partnership Policy Committee shall be deemed given if received by the Chairman of the Partnership Policy Committee at the principal office of the Partnership designated pursuant to Section 1.3. The General Partners and the Partnership Policy Committee may rely and shall be protected in relying on any notice or other document from a Partner, Assignee or other Person if believed by it to be genuine.

18.2 REFERENCES. Except as specifically provided otherwise, references to "Articles" and "Sections" are to Articles and Sections of this Agreement.

18.3 PRONOUNS AND PLURALS. Whenever the context may require, any pronoun used in this Agreement shall include the corresponding masculine, feminine or neuter forms, and the singular form of nouns, pronouns and verbs shall include the plural and vice versa.

18.4 FURTHER ACTION. The parties shall execute and deliver all documents, provide all information and take or refrain from taking action as may be necessary or appropriate to achieve the purposes of this Agreement.

18.5 BINDING EFFECT. This Agreement shall be binding upon and inure to the benefit of the parties hereto and their heirs, executors, administrators, successors, legal representatives and permitted assigns.

18.6 INTEGRATION. This Agreement constitutes the entire agreement among the parties hereto pertaining to the subject matter hereof and supersedes all prior agreements and understandings pertaining thereto.

18.7 CREDITORS. None of the provisions of this Agreement shall be for the benefit of, or shall be enforceable by, any creditor of the Partnership.

18.8 WAIVER. No failure by any party to insist upon the strict performance of any covenant, duty, agreement or condition of this Agreement or to exercise any right or remedy consequent upon a breach thereof shall constitute waiver of any such breach or any other covenant, duty, agreement or condition.

18.9 COUNTERPARTS. This Agreement may be executed in counterparts, all of which together shall constitute an agreement binding on all the parties hereto, notwithstanding that all such parties are not signatories to the original or the same counterpart. Each party shall become bound by this Agreement immediately upon affixing its signature hereto or, in the case of a Person acquiring a Unit, upon accepting the certificate evidencing such Unit or executing and delivering a Transfer Application as herein described, independently of the signature of any other party.

18.10 APPLICABLE LAW. This Agreement shall be construed in accordance with and governed by the laws of the State of Delaware, without regard to the principles of conflicts of law.

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18.11 INVALIDITY OF PROVISIONS. If any provision of this Agreement is or becomes invalid, illegal or unenforceable in any respect, the validity, legality and enforceability of the remaining provisions contained herein shall not be affected thereby.

IN WITNESS WHEREOF, the parties hereto have executed this Agreement as of the date first written above.

GENERAL PARTNERS:

NORTHERN PLAINS NATURAL GAS COMPANY

By: /s/ Larry L. Deroin
    -------------------
Name: LARRY L. DEROIN
Title: PRESIDENT

NORTHWEST BORDER PIPELINE COMPANY

By: /s/ G. L. Best
    ---------------
Name: G. L. BEST
Title: VICE PRESIDENT

PAN BORDER GAS COMPANY

By: /s/ J. D. Thomas
    ---------------
Name: J. D.THOMAS
Title: TREASURER

ORGANIZATIONAL LIMITED PARTNER:

NORTHWEST BORDER PIPELINE COMPANY

By: /s/ G. L. Best
    -----------------
Name: G. L. Best
Title: VICE PRESIDENT

83

LIMITED PARTNERS:

All Limited Partners now and hereafter
admitted as limited partners of the
Partnership, pursuant to Powers of
Attorney now and hereafter executed in
favor of, and granted and delivered to,
the Members of the Partnership Policy
Committee.

By: /s/ Larry L. Deroin
    ------------------------------------
    Chairman of Partnership Policy
    Committee, as attorney-in-fact for
    all Limited Partners pursuant to
    the Powers of Attorney granted
    pursuant to Section 1.4.

84

EXHIBIT A

to the Amended and Restated Agreement of
Limited Partnership of
NORTHERN BORDER PARTNERS, L.P.

CERTIFICATE EVIDENCING COMMON UNITS
REPRESENTING LIMITED PARTNER INTERESTS
NORTHERN BORDER PARTNERS, L.P.

No.__________ __________ Common Units

The undersigned officers of NORTHERN BORDER PARTNERS, L.P., a Delaware limited partnership (the "PARTNERSHIP"), hereby certifies that__________________________________ (the "HOLDER") is the registered owner of__________ Common Units representing limited partner interests in the Partnership (the "COMMON UNITS") transferable on the books of the Partnership, in person or by duly authorized attorney, upon surrender of this Certificate properly endorsed and accompanied by a properly executed application for transfer of the Common Units represented by this Certificate. The rights, preferences and limitations of the Common Units are set forth in, and this Certificate and the Common Units represented hereby are issued and shall in all respects be subject to the terms and provisions of, the Amended and Restated Agreement of Limited Partnership of NORTHERN BORDER PARTNERS, L.P., as amended, supplemented or restated from time to time (the "PARTNERSHIP AGREEMENT"). Copies of the Partnership Agreement are on file at, and will be furnished without charge on delivery of written request to the Partnership at, the principal office of the Partnership located at 1400 Smith Street, Houston, Texas 77002. Capitalized terms used herein but not defined shall have the meaning given them in the Partnership Agreement.

The Holder, by accepting this Certificate, is deemed to have (i) requested admission as, and agreed to become, a Limited Partner and to have agreed to comply with and be bound by and to have executed the Partnership Agreement, (ii) represented and warranted that the Holder has all right, power and authority and, if an individual, the capacity necessary to enter into the Partnership Agreement, (iii) given the powers of attorney provided for in the Partnership Agreement and (iv) made the waivers and given the consents and approvals contained in the Partnership Agreement.

This Certificate shall not be valid for any purpose unless it has been countersigned and registered by the Transfer Agent and Registrar.

Dated: __________________

NORTHERN BORDER PARTNERS, LP.

                                     By: ______________________________________
Countersigned and Registered by:                Chief Executive Officer

_______________________________,     By: ______________________________________
as Transfer Agent and Registrar          Chief Financial and Accounting Officer

By: ___________________________
      Authorized Signature

Exhibit A-Page 1


[Reverse of Certificate]

ABBREVIATIONS

The following abbreviations, when used in the inscription on the face of this Certificate, shall be construed as follows according to applicable laws or regulations:

TEN COM- as tenants in common           UNIF GIFT MIN ACT-.......Custodian.....
TEN ENT- as tenants by the entireties            (Cust)                  (Minor)
JT TEN - as joint tenants with right of           under Uniform Gifts to Minors
         survivorship and not as                  Act.......................
         tenants in common                                               (State)

Additional abbreviations, though not in the above list, may also be used.

ASSIGNMENT OF COMMON UNITS
in
NORTHERN BORDER PARTNERS, L.P.

IMPORTANT NOTICE REGARDING INVESTOR RESPONSIBILITIES
DUE TO TAX SHELTER STATUS OF NORTHERN BORDER PARTNERS, L.P.

You have acquired an interest in Northern Border Partners, L.P., 1400 Smith Street, Houston, Texas 77002, whose taxpayer identification number is______________. The Internal Revenue Service has issued Northern Border Partners, L.P. the following tax shelter registration number:______________

YOU MUST REPORT THIS REGISTRATION NUMBER TO THE INTERNAL REVENUE SERVICE IF YOU CLAIM ANY DEDUCTION, LOSS, CREDIT, OR OTHER TAX BENEFIT OR REPORT ANY INCOME BY REASON OF YOUR INVESTMENT IN NORTHERN BORDER PARTNERS, L.P.

You must report the registration number as well as the name and taxpayer identification number of Northern Border Partners, L.P. on Form 8271. FORM 8271 MUST BE ATTACHED TO THE RETURN ON WHICH YOU CLAIM THE DEDUCTION, LOSS, CREDIT, OR OTHER TAX BENEFIT OR REPORT ANY INCOME BY REASON OF YOUR INVESTMENT IN NORTHERN BORDER PARTNERS, L.P.

If you transfer your interest in Northern Border Partners, L.P. to another person, you are required by the Internal Revenue Service to keep a list containing (a) that person's name, address and taxpayer identification number,
(b) the date on which you transferred the interest and (c) the name, address and tax shelter registration number of Northern Border Partners, L.P. If you do not want to keep such a list, you must (1) send the information specified above to the Partnership, which will keep the list for this tax shelter, and (2) give a copy of this notice to the person to whom you transfer your interest. Your failure to comply with any of the above-described responsibilities could result in the imposition of a penalty under Section 6707(b) or 6708(a) of the Internal Revenue Service Code of 1986, as amended, unless such failure is shown to be due to reasonable cause.

ISSUANCE OF A REGISTRATION NUMBER DOES NOT INDICATE THAT THIS INVESTMENT OR THE CLAIMED TAX BENEFITS HAVE BEEN REVIEWED, EXAMINED, OR APPROVED BY THE INTERNAL REVENUE SERVICE.

Exhibit A-Page 2


FOR VALUE RECEIVED, ____________________________________ hereby assigns, conveys, sells and transfers unto____________________________________________

____________________________________     ______________________________________
(Please print or typewrite name               (Please insert Social Security or
and address of Assignee)                  other identifying number of Assignee)

_________________________________________Common Units representing limited partner interests evidenced by this Certificate, subject to the Partnership Agreement, and does hereby irrevocably constitute and appoint _________________ as its attorney-in-fact with full power of substitution to transfer the same on the books of Northern Border Partners, L.P.

Date: __________________________       NOTE: The signature to any endorsement
                                       hereon must correspond with the name as
                                       written upon the face of this
                                       Certificate in every particular,
                                       without alteration, enlargement or
                                       change.

SIGNATURE(S) MUST BE GUARANTEED
BY A MEMBER FIRM OF THE NATIONAL       ________________________________________
ASSOCIATION OF SECURITIES DEALERS,                   (Signature)
INC. OR BY A COMMERCIAL BANK OR

TRUST COMPANY                          ________________________________________
                                                     (Signature)

SIGNATURE(S) GUARANTEED

No transfer of the Common Units evidenced hereby will be registered on the books of the Partnership, unless the Certificate evidencing the Common Units to be transferred is surrendered for registration or transfer and an Application for Transfer of Common Units has been executed by a transferee either (a) on the form set forth below or (b) on a separate application that the Partnership will furnish on request without charge. A transferor of the Common Units shall have no duty to the transferee with respect to execution of the transfer application in order for such transferee to obtain registration of the transfer of the Common Units.


APPLICATION FOR TRANSFER OF COMMON UNITS

The undersigned ("ASSIGNEE") hereby applies for transfer to the name of the Assignee of the Common Units evidenced hereby.

The Assignee (a) requests admission as a Substituted Limited Partner and agrees to comply with and be bound by, and hereby executes, the Amended and Restated Agreement of Limited Partnership of Northern Border Partners, L.P. (the "Partnership"), as amended, supplemented or restated to the date hereof (the "PARTNERSHIP AGREEMENT"), (b) represents and warrants that the Assignee has all right, power and authority and, if an individual, the capacity necessary to enter into the Partnership Agreement, (c) gives the powers of attorney provided for in the Partnership Agreement and (d) makes the waivers and gives the consents and approvals contained in the Partnership Agreement.

Capitalized terms not defined herein have the meanings assigned to such terms in the Partnership Agreement.

Exhibit A-Page 3


 Date:___________________________           __________________________________
                                                   Signature of Assignee


_________________________________           __________________________________
Social Security or other                       Name and Address of Assignee
identifying number of Assignee

_________________________________
         Purchase Price
  including commissions, if any

Type of Entity (check one)

________________Individual_______________Partnership________________Corporation ________________Trust____________________Other (specify)______________________

Nationality (Check One):

___________U.S. Citizen, Resident or Domestic Entity ___________Foreign Corporation, or____________Non-resident alien

If the U.S. Citizen, Resident or Domestic Entity box is checked, the following certification must be completed.

Under Section 1445(e) of the Internal Revenue Code of 1986, as amended (the "CODE"), the Partnership must withhold tax with respect to certain transfers of property if a holder of an interest in the Partnership is a foreign person. To inform the Partnership that no withholding is required with respect to the undersigned interest-holder's interest in it, the undersigned hereby certifies the following (or, if applicable, certifies the following on behalf of the interest-holder).

Complete Either A or B:

A. Individual Interest-Holder

1. I am not a non-resident alien for purposes of U.S. income taxation.

2. My U.S. taxpayer identifying number (Social Security Number) is _______________________________________________________.

3. My home address is_________________________________________.

B. Partnership, Corporate or Other Interest-Holder

1. _____________________________________________ is not a foreign
(Name of Interest-Holder) corporation, foreign partnership, foreign trust or foreign estate (as those terms are defined in the Code and Treasury Regulations).

2. The interest-holder's U.S. employer identification number is __________________________________________________________.

3. The interest-holder's office address and place of incorporation (if applicable) is____________________________.

Exhibit A-Page 4


The interest-holder agrees to notify the Partnership within 60 days of the date the interest-holder becomes a foreign person.

The interest-holder understands that this certificate may be disclosed to the Internal Revenue Service by the Partnership and that any false statement contained herein could be punishable by fine, imprisonment or both.

Under penalties of perjury, I declare that I have examined this certification and to the best of my knowledge and belief it is true, correct and complete and, if applicable, I further declare that I have authority to sign this document on behalf of


(Name of Interest-Holder)


Signature and Date


Title (if applicable)

Note: If the Assignee is a broker, dealer, bank, trust company, clearing corporation, other nominee holder or an agent of any of the foregoing, and is holding for the account of any other person, this application should be completed by an officer thereof or, in the case of a broker or dealer, by a registered representative who is a member of a registered national securities exchange or a member of the National Association of Securities Dealers, Inc., or, in the case of any other nominee holder, a person performing a similar function. If the Assignee is a broker, dealer, bank trust company, clearing corporation, other nominee owner or an agent of any of the foregoing, the above certification as to any Person for whom the Assignee will hold the Common Units shall be made to the best of the Assignee's knowledge.

Exhibit A-Page 5


Exhibit 3.3

CERTIFICATE OF LIMITED PARTNERSHIP
OF
NORTHERN BORDER INTERMEDIATE LIMITED PARTNERSHIP

This Certificate of Limited Partnership has been duly executed, is being filed pursuant to 6 Del. C. Section 17-201, and shall be effective immediately upon filing.

1. The name of this limited partnership is "Northern Border Intermediate Limited Partnership"

2. The address of the registered office is:

Corporation Trust Company
1209 Orange Street
Wilmington, New Castle County, Delaware 19801

The name and address of the registered agent for service of process are:

The Corporation Trust Company
Corporation Trust Center
1209 Orange Street
Wilmington, New Castle County, Delaware 19801

3. The name and the business address of each general partner are:

Northern Plains Natural                       Pan Border Gas
Gas Company                                   Company
1111 South 103 Street                         5400 Westheimer Court
Omaha, Nebraska 68124                         Houston, Texas 77056

Northwest Border Pipeline Company
One Williams Center
East Second Street
Tulsa, Oklahoma 74172

                                           NORTHERN PLAINS NATURAL
                                           GAS COMPANY
                                           General Partner

                                           By: /s/ Gary A. McConnell
                                               ---------------------
                                               Gary A. McConnell
                                               Vice President

                                          PAN BORDER GAS COMPANY
                                          General Partner

                                          By: /s/ George L. Mazanec
                                              ----------------------
                                              George L. Mazanec
                                              Vice President

                                              NORTHWEST BORDER PIPELINE
                                              COMPANY
                                              General Partner

                                              By: /s/ G. L. Best
                                                  ---------------
                                                  G. L. Best
                                                  Vice President

                                              Date:  July 12, 1993

                                                 STATE OF DELAWARE
                                                SECRETARY OF STATE
                                             DIVISION OF CORPORATIONS
                                             FILED 09:00 AM 02/27/2001
                                                010101869 - 2343479

CERTIFICATE OF AMENDMENT

TO

CERTIFICATE OF LIMITED PARTNERSHIP

OF

NORTHERN BORDER INTERMEDIATE LIMITED PARTNERSHIP

Northern Border Intermediate Limited Partnership (hereinafter called the "partnership"), a limited partnership organized under the Delaware Revised Uniform Limited Partnership Act (the "Act"), for the purpose of amending Certificate of Limited Partnership filed with the office of the Secretary of State of Delaware on July 13, 1993, hereby certifies that:

1.The name of the limited partnership is Northern Border Intermediate Limited Partnership.

2.Pursuant to the provisions of Section 17-202, Title 6, Delaware Code, the amendment to the Certificate of Limited partnership effected by this Certificate of Amendment is to change the address of the registered office of the partnership in the State of Delaware to 9 East Loockerman Street, Dover, Delaware 19901, and to change the name of the registered agent of the partnership in the State of Delaware at the said address to National Registered Agents, Inc.

The undersigned, a general partner of the partnership, executes this Certificate of Amendment on February 16,2001.

Northern Plains Natural Gas Company General Partner

/s/ Geneva K. Holland
---------------------------------------
Geneva K. Holland, Assistant Secretary


CERTIFICATE OF AMENDMENT

TO

CERTIFICATE OF LIMITED PARTNERSHIP

OF

NORTHERN BORDER INTERMEDIATE LIMITED PARTNERSHIP

NORTHERN BORDER INTERMEDIATE LIMITED PARTNERSHIP (hereinafter called the "partnership"), a limited partnership organized under the Delaware Revised Uniform Limited Partnership Act (the "Act"), for the purpose of amending the Certificate of Limited Partnership filed with the office of the Secretary of State of Delaware on July 13, 1993, hereby certifies that:

1.The name of the limited partnership is Northern Border Intermediate Limited Partnership.

2. Pursuant to provisions of Section 17-202, Title 6, Delaware Code, the Certificate of Limited Partnership is amended as follows:

The name and business address of each general partner are:

Northern Plains Natural Gas Company 13710 FNB Parkway
Omaha, NE 68154-5200

Northwest Border Pipeline Company c/o TransCanada PipeLines Limited 450-1st Street S.W.

Calgary, Alberta
T2P 5H1

Pan Border Gas Company
13710 FNB Parkway
Omaha, NE 68154-5200

The undersigned, an authorized officer of a general partner of the partnership, executed this Certificate of Amendment on May 20, 2003.

NORTHERN PLAINS NATURAL GAS
COMPANY, General Partner

/s/ Lori Pinder-Metz
-------------------------------------

Lori Pinder-Metz, Assistant Secretary


Exhibit 10.24

EXECUTION COPY

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

This Northern Border Transition Services Agreement ("Agreement") is made and entered into as of this 17th day of November, 2004, by and between ONEOK, Inc., an Oklahoma corporation ("ONEOK"), and CCE Holdings, LLC, a Delaware limited liability company ("CCE"). ONEOK and CCE are referred to herein individually as a "Party", and collectively as the "Parties".

W I T N E S S E T H:

WHEREAS, commencing on December 2, 2001, Enron Corp., an Oregon corporation ("Enron"), and certain of its subsidiaries filed voluntary petitions for relief under Chapter 11 of the Bankruptcy Code; and

WHEREAS, Enron, Enron Operations Services, LLC, a Delaware limited liability company, Enron Transportation Services, LLC, a Delaware limited liability company, EOC Preferred, L.L.C., a Delaware limited liability company (referred to collectively as the "Enron Parties"), CrossCountry Energy, LLC ("CrossCountry"), CrossCountry Energy Corp., a Delaware corporation, and CrossCountry Citrus Corp., a Delaware corporation, are parties to that certain Amended and Restated Contribution and Separation Agreement, dated as of March 31, 2004, as amended on the date hereof (as the same may be amended and supplemented from time to time, the "Contribution and Separation Agreement"); and

WHEREAS, as a mutual condition to closing under the Contribution and Separation Agreement, Enron and CrossCountry entered into that certain Transition Services Agreement (as amended, the "TSA") and that certain Transition Services Supplemental Agreement (as amended, the "TSSA"), both dated as of March 31, 2004, as amended on March 31, 2004 and as of the date hereof, under which Enron and CrossCountry agreed, subject to certain conditions, to provide and transfer, if appropriate, certain services between Enron and its Affiliates and CrossCountry and its Affiliates for a specific period of time as set forth in the TSA and the TSSA; and

WHEREAS, the Enron Parties and CCE entered into a Purchase Agreement, dated as of June 24, 2004, as amended by that certain Amendment No. 1 to Purchase Agreement dated September 1, 2004, and Amendment No. 2 to Purchase Agreement dated November 11, 2004, whereby CCE agreed to purchase 100% of the membership interests of CrossCountry; and

WHEREAS, CCE and ONEOK entered into a Purchase Agreement, dated as of September 16, 2004 (the "ONEOK Purchase Agreement"), whereby ONEOK agreed to purchase the common stock of Northern Plains Natural Gas Company, a Delaware corporation ("Northern Plains"), and NBP Services Corporation, a Delaware corporation ("NBP Services"), or the ownership interests in limited liability companies into which such common stock may be converted; and

1

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

WHEREAS, ONEOK agreed to provide, or cause the provision of, certain transition services to Enron as required by the TSA, TSSA and this Agreement and to provide, or cause the provision of, certain transition services to CCE; and

WHEREAS, CCE agreed to provide, or cause the provision of, certain transition services to Northern Plains and NBP Services (referred to collectively as the "Transfer Group Companies") and the Northern Border Companies, as required by the TSA, the TSSA and this Agreement; and

WHEREAS, CCE agreed to request, and use commercially reasonable efforts to have the request honored, that Enron provide all transition services to be performed for the Transfer Group Companies and/or the Northern Border Companies as required by the TSA, the TSSA and this Agreement; and

WHEREAS, CCE and ONEOK agreed in the ONEOK Purchase Agreement to memorialize the understandings regarding the provision of transition services in agreements entitled Northern Border Transition Services Agreement and Northern Border Transition Services Supplemental Agreement, however the Parties agree to memorialize such understandings in this Agreement.

NOW THEREFORE, in consideration of the premises and the agreements contained herein, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, and intending to be legally bound hereby, the Parties hereby agree as follows:

ARTICLE I.
SERVICES TO BE PROVIDED

1.01 Transition Services to Be Provided to the Transfer Group Companies and the Northern Border Companies.

(a) Subject to Section 2.02(c), CCE will provide, or cause the provision of, transition services, in the following categories to the Transfer Group Companies and the Northern Border Companies or their respective successors and assigns as required by this Agreement during the Term on the terms and conditions set out in this Agreement including specifically, but not by way of limitation, the service standard set out in Article II:

(i) Technical, support, pipeline integrity management and other services as described on Schedule 1.01(a)(i).

(ii) Accounts Payable, including document imaging, invoice processing, payment voids in SAP, other support and usage of the Envision system. Usage of the Envision system includes access to the imaged invoices and documents used in conjunction with the accounting system. This service includes the ability to store imaged documents related to payables and to recall those documents for documentation and research purposes.

2

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

(iii) Information technology, infrastructure (both hardware and software), and disaster recovery expertise and assistance, including the support required for the services and systems described in Schedule 1.01(a)(i) and otherwise necessary to provide the services in this Section 1.01(a). The Parties acknowledge that disaster recovery from HotTap and Operations environments will not be available during certain periods of the Term of the Agreement.

(iv) Floor space for servers and other such information technology equipment and related administrative services, including operation, management, maintenance services and the floor space necessary at Planet in Dallas, Texas.

(v) Supervision of outside auditors in completing 2004 testing requirements of Sarbanes-Oxley Act of 2002 through March 31, 2005.

(vi) Corporate secretary services related to the services provided in this Section 1.01(a) through December 31, 2004.

(vii) Website support for informational postings and customer activities.

(viii) Pay and Data Services. Historical employee payroll and benefits information and reports.

(ix) Notwithstanding Article III, from the date of this Agreement though March 31. 2005, office space, office equipment and related services at 4 Houston Center or other facility for any Transfer Group Companies employees currently located at such facility, which shall be equivalent in quality to such space, equipment and related services as currently utilized by such employee.

(x) All types of IT transition work to transition/migrate from Enron and CCE to ONEOK, the Transfer Group Companies and the Northern Border Companies the data, applications, systems and infrastructure of the Transfer Group Companies and the Northern Border Companies associated with and supporting the following areas: Finance and Accounting, Procurement, IT, Tax, HR, Facilities, Infrastructure, Records Management, Operations, Commercial, Market Services, Communications, Regulatory Affairs and Legal. All services under this Section 1.01(a)(x) shall be performed in accordance with Section 1.04 of this Agreement.

(collectively, the "CCE Services").

(b) CCE will request, and use commercially reasonable efforts to have such request honored, that Enron provide any and all transition services in the following categories to be performed for the benefit of the Transfer Group Companies and/or the

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Northern Border Companies or their respective successors and assigns during the Term on the terms and conditions set out in this Agreement including specifically, but not by way of limitation, the service standard set out in Article II:

(i) IT (including Telephony) services, access (e.g., e-mail service, network access and administrative support, internet access, and help desk support) and related services including:

- Workstation Image Management
- Security Administration
- Server Support
- Messaging
- Voice Communications (e.g., conference bridge, handsets)
- Network Communications (e.g., VSAT services)
- Video conferencing
- Network Communications - Direct
- EC Outlook
- Administrative/EPSC
- Pass Throughs (e.g., Long Distance, Pagers, 800, dedicated circuits, WAN)
- Reasonable access for ONEOK, Inc., Northern Plains, NBP Services, and Pan Border employees, agents and authorized representatives, to networks, applications and data center facilities (other than any human resources information technology) of Enron and its Affiliates (the "Enron Systems"). The obligation to provide such access will be subject to the satisfaction of Enron and CCE, in their sole discretion, that sufficient firewalls and other systems, procedures and information technology are in effect to maintain the security and integrity of the Enron Systems, including protection against unauthorized access to the information contained therein. In the event of the termination of any employee, agent, authorized representative or designee of ONEOK, Northern Plains, NBP Services, and Pan Border that was permitted access to the Enron Systems, ONEOK agrees to promptly, and in any event no later than twenty-four (24) hours following such termination, (x) notify CCE and Enron of (i) the name of such terminated employee, agent, authorized representative or designee, and (ii) the Enron Systems to which such terminated employee, agent, authorized representative or designee had access; and (y) take such actions as are necessary to prevent unauthorized access by such terminated employee, agent, authorized representative or designee to the Enron Systems. ONEOK agrees to indemnify CCE and its Affiliates from any failure of ONEOK, Northern Plains, NBP Services and Pan

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Border employees, agents and authorized representatives to comply with the obligations in the preceding sentence. Notwithstanding the foregoing, (A) Enron's obligation to provide ONEOK, Northern Plains, NBP Services and Pan Border employees, agents, authorized representatives and designees reasonable access to the Enron Systems is subject to any limitations or restrictions contained in any license, software agreement or similar agreement applicable to the provision of Enron Services, and (B) such reasonable access shall be limited to the infrastructure of the Enron Systems as it currently exists on the date hereof and as it may be modified from time to time by Enron in its sole discretion. Enron and CCE shall have no obligation to enhance the infrastructure of the Enron Systems (including, but not limited to, enhanced connectivity or additional communication lines). Any such enhancement shall be effected by Enron in its sole discretion and shall be governed by a project work description to be mutually agreed upon by Enron and CCE.

(ii) SAP Usage and ISC Support. Usage rights and support to the SAP system and the related accounting systems, 1099 reporting, accounting services and infrastructure and support features.

(iii) Off-site and on-site storage of the Transfer Group Companies' and Northern Border Companies' documents and records.

(iv) Floor space for servers and other such information technology equipment located at the Ardmore Data Center as of the Closing Date, and related administrative services, including operation, management and maintenance services.

(v) Cash management services, services related to cash management as more specifically set forth on Schedule 1.01(b)(vi).

(vi) All types of IT transition work to transition/migrate from Enron and CCE to ONEOK, the Transfer Group Companies and the Northern Border Companies the data, applications, systems and infrastructure of the Transfer Group Companies and the Northern Border Companies associated with and supporting the following areas: Finance and Accounting, Procurement, IT, Tax, HR, Facilities, Infrastructure, Records Management, Operations, Commercial, Market Services, Communications, Regulatory Affairs and Legal. All services under this Section 1.01(b)(vi) shall be performed pursuant to Section 1.04 of this Agreement.

(vii) The use of automated expense reporting on Concur XMS system for processing expense reports.

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(viii) Access to and support of Vertex software.

(collectively, the "Enron Services").

1.02 Transition Services to Be Provided to Enron and CCE. ONEOK will provide, or cause to be provided, technical expertise and assistance, including but not limited to pipeline integrity, pipeline safety, environmental compliance, engineering and construction safety and compliance audits and related technical support services as described on Schedule 1.02 ("ONEOK Services") to Enron and CCE or their respective successors and assigns during the Term on the terms and conditions set out in this Agreement, including specifically, but not by way of limitation, the service standard set out in Article II.

1.03 Commitment to Take and Pay for Transition Services. During the Term of this Agreement, (a) with respect to Transition Services (as defined below) that are priced on a fixed, monthly basis, the Purchaser (as defined below) shall take and pay for such Transition Services that were actually made available by the Provider (as defined below), without any setoff or deduction, except as provided in Sections 1.05, 4.02 and 4.04 hereof, and (b) with respect to Transition Services that are priced on a variable or hourly basis, such Transition Services shall be paid for by Purchaser on an "as requested and provided" basis according to the rate per hour set forth on Schedule 1.03, plus out-of- pocket expenses. Each Party taking and paying for Transition Services is referred to hereinafter as a "Purchaser". Each Party providing a Transition Service is referred to hereinafter as a "Provider". For the avoidance of doubt, the definitions of Purchaser, Provider, Party and Parties do not include Enron or its successors or assigns as permitted under the TSA or the TSSA. The CCE Services, the Enron Services and the ONEOK Services are collectively referred to herein as the "Transition Services".

1.04 Additional Transition Services as Requested. After the date hereof, either Party can request that the other Party provide additional services according to the rate per hour set forth on Schedule 1.03, plus out-of-pocket expenses pursuant and subject to the terms and conditions of this Agreement. Each Party agrees to provide such services as reasonably requested and as personnel are reasonably available, provided, however, no such request will result in any obligation of any Party unless and until both Parties sign a written amendment to this Agreement providing for the requested additional service. Notwithstanding the foregoing, in the event that ONEOK requests services in connection with Sections 1.01(a)(x) or 1.01(b)(vi) (as scheduled in Schedule 1.06(b)) and such services cannot be adequately provided by personnel involved with providing services hereunder, then the Parties shall cooperate in good faith in determining the scope, timeline and cost, which upon ONEOK's agreement shall be at ONEOK's expense, related to such requested services.

1.05 Use of Facilities. The Purchaser acknowledges and agrees that the use of the Provider's facilities by the Purchaser does not constitute a leasehold interest in favor of the Purchaser. The Purchaser further agrees that it shall use the facilities in a reasonably efficient manner. To the extent that the Purchaser operates the space in a manner that materially increases the Provider's or Enron's facilities costs, the Purchaser

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acknowledges that the Provider reserves the right to seek reimbursement for the excess costs of such practices. The Purchaser shall keep the Provider's, or Enron's, as applicable, facilities in reasonably good order, not commit or permit any material waste or damage to such facilities, not use such facilities for any unlawful purpose or act and comply with all of the Provider's or Enron's, as applicable, standard policies and procedures as in effect from time to time, including procedures for the physical security of the facilities. The Purchaser shall permit the Provider or Enron and their respective agents to enter into those portions of the Provider's facilities occupied by the Purchaser's staff at any time to perform facilities-related services. The Purchaser shall not make any material improvements or changes involving structural, mechanical or electrical alterations to the facilities without the Provider's or Enron's, as applicable, prior written approval. Upon termination or expiration of this Agreement or all of the facilities-related Transition Services pursuant to Section 3.02 hereof, the Purchaser shall return the Provider's or Enron's, as applicable, facilities to the Provider in substantially the same condition as when the Purchaser began using such locations, ordinary wear and tear excepted.

1.06 Compensation.

(a) As compensation for the ONEOK Services set forth on Schedule 1.06(a), CCE will pay ONEOK the Monthly Costs as set forth on Schedule
1.06(a) (the "ONEOK Fee"). Schedule 1.06(a) will contain a list of each individual ONEOK Service to be provided under Section 1.02.

(b) As compensation for the CCE Services set forth on Schedule 1.06(b), ONEOK will pay CCE the Monthly Costs as set forth on Schedule 1.06(b) (the "CCE Fee"). As compensation for the Enron Services set forth on Schedule 1.06(b), ONEOK will pay CCE the Monthly Costs as set forth on Schedule 1.06(b) under Enron Services (the "Enron Fee"). Schedule 1.06(b) will contain a list of each individual CCE Service and Enron Service to be provided under Section 1.01.

(c) The compensation to be paid and the terms of billing and payment for any additional service agreed upon pursuant to Section 1.04 of this Agreement shall be included in any written amendment to this Agreement providing for such additional service.

1.07 W-2s, Labor Distribution, Payroll and Benefit Data. CCE will request and use its commercially reasonable efforts to have such request honored, that Enron, at ONEOK's sole cost, provide the data for W-2s, labor distribution, payroll and benefits for the Transfer Group Companies for all pay periods up to and including December 31, 2004.

1.08 Indemnification. The provision of CCE Services may require consents, waivers, or approvals from certain third parties under Permits and Contracts to which CCE or any of its Affiliates is a party or is otherwise subject to enable CCE to provide CCE Services to ONEOK, the Transfer Group Companies and/or the Northern Border Companies (such Permits and Contracts being the "Third Party Agreements"). Until the

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date that is thirty (30) days after the date hereof, at the request and sole expense of ONEOK, CCE agrees to cooperate reasonably with ONEOK and use commercially reasonable efforts to seek such consents, waivers or approvals necessary to allow CCE to utilize the services provided under such Third Party Agreements to provide CCE Services to ONEOK, or to seek standstill agreements pursuant to which such third parties would agree not to take any adverse actions against CCE or any of its Affiliates, or ONEOK or any of its Affiliates, under the Third Party Agreements as a result of CCE's provision of CCE Services. If such consents, waivers, approvals, or standstill agreements are not obtained, or are not reasonably satisfactory to CCE in its sole discretion, then CCE shall not be obligated to provide the CCE Services to which such consents, waivers, approvals or standstill agreements relate, effective as of the later of (i) the date thirty (30) days after the date hereof and (ii) if applicable, the expiration of a standstill agreement, and in each case CCE shall have no further liability to ONEOK with regard thereto, notwithstanding anything to the contrary contained herein. Notwithstanding any limitations on indemnification contained herein (including, without limitation, the last sentence of Section 11.06) and in the ONEOK Purchase Agreement (including, without limitation, the provisions of Article X), ONEOK hereby agrees to indemnify the Seller Indemnified Parties against, and hold them harmless from, any and all liabilities, losses, damages, claims, reasonable and documented out-of-pocket costs and expenses (including reasonable attorneys', accountants' or other fees and expenses), including consequential, exemplary, special and punitive damages and lost profits, incurred by the Seller Indemnified Parties and arising, directly or indirectly, out of CCE's utilization of the services provided under the Third Party Agreements to provide CCE Services to ONEOK.

ARTICLE II.
SERVICE STANDARD

2.01 Standard of Care; Limited Warranty. Subject to Section 2.02(c), the CCE Services and ONEOK Services shall be performed with a degree of skill, diligence and prudence with which the Provider (or its predecessor-in-interest), its Affiliates and their respective personnel have performed such services for the Purchaser or Enron, as applicable, subsequent to December 2, 2001 and prior to March 31, 2004 and shall be of substantially equivalent quality. In addition, subject to Section 2.02(c), the CCE Services and ONEOK Services shall be performed with at least the same level of skill, diligence, prudence and quality as the Provider utilizes in performing similar services for its Affiliates. With respect to the Enron Services, CCE will request, and use commercially reasonable efforts to have such request honored, that Enron perform such Enron Services (i) with a degree of skill, diligence and prudence with which Enron, its Affiliates and their respective personnel have performed such services for the Transfer Group Companies subsequent to December 2, 2001 and prior to March 31, 2004 and that such Enron Services shall be of substantially equivalent quality, and (ii) with at least the same level of skill, diligence, prudence and quality as Enron utilizes in performing similar services for its Affiliates. THE PRECEDING IS THE ONLY WARRANTY CONCERNING THE TRANSITION SERVICES AND ANY RESULTS, WORK PRODUCT OR PRODUCTS RELATED THERETO, AND IS MADE EXPRESSLY IN LIEU OF ALL OTHER WARRANTIES AND REPRESENTATIONS EXPRESSED OR

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NORTHERN BORDER TRANSITION SERVICES AGREEMENT

IMPLIED, INCLUDING, WITHOUT LIMITATION, THE WARRANTIES OF FITNESS FOR A PARTICULAR PURPOSE, MERCHANTABILITY OR NONINFRINGEMENT. THE PARTIES UNDERSTAND, ACKNOWLEDGE AND AGREE THAT THE LEVEL OF COMPENSATION THE PARTIES HAVE AGREED TO ACCEPT IS PREDICATED ON THIS LIMITATION OF LIABILITY AND DISCLAIMER OF WARRANTIES.

2.02 Consequences of Breach or Non-Performance.

(a) The Purchaser shall promptly notify the Provider of any failure by the Provider to perform one or more of the Transition Services in accordance with the terms of this Agreement. In the event that the Provider (a) does not cure such non-performance within ten (10) Business Days of the receipt of such notice (the "Cure Period"), or (b) has not performed a particular Transition Service in accordance with the terms of this Agreement for thirty (30) Business Days in the aggregate, then the Purchaser may terminate such Transition Service(s) by delivering notice to the Provider and the Provider shall be obligated to pay to the Purchaser liquidated damages as set forth in Section 2.03 hereof. No liquidated damages shall be payable by the Provider with respect to non-performance before or during any Cure Period, however, the Purchaser shall receive a pro-rata reduction in the fees payable by the Purchaser for the period of time, including the Cure Period, for which the Provider failed to perform its obligations.

(b) Notwithstanding anything to the contrary in this Agreement, including Section 2.02(a) above, ONEOK shall promptly notify CCE of any failure of Enron or its Affiliates to perform one or more of the Enron Services in accordance with the terms of this Agreement. CCE shall request, and shall use commercially reasonable efforts to have such request honored, that Enron cure such non-performance; provided, however, that CCE shall not be required to cure such non-performance by Enron or its Affiliates nor shall CCE be liable for any damages (including any liquidated damages referred to in this Agreement) caused by such non-performance by Enron or its Affiliates, as long as CCE uses commercially reasonable efforts to have such requests honored.

(c) Notwithstanding anything to the contrary in this Agreement, and as long as CCE requests, and uses commercially reasonable efforts to have such requests honored, that Enron provide the Enron Services, CCE shall not be required to cure any non-performance of CCE Services to the extent caused by the failure of Enron and its Affiliates to provide the Enron Services to CCE and its Affiliates or to the Transfer Group Companies and/or the Northern Border Companies nor shall CCE be liable for the non-performance of any CCE Services including any damages (including any liquidated damages referred to in this Agreement) to the extent caused by the failure of Enron and its Affiliates to provide the Enron Services set forth in Section 1.01(b) hereof to CCE and its Affiliates or to the Transfer Group Companies and/or the Northern Border Companies

2.03 Liquidated Damages. (a) The Parties hereto agree that the economic injury to the Purchaser caused by unexcused non-performance of the Provider's obligations under this Agreement will be difficult or impossible to precisely calculate. Accordingly, the Parties agree that an amount equal to 100% of the price of the

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NORTHERN BORDER TRANSITION SERVICES AGREEMENT

applicable Transition Service calculated for the period of such unexcused non-performance (exclusive of the period before or during any Cure Period), up to a maximum of ninety (90) days with respect to any Transition Service, shall be a reasonable, fair and non-punitive approximation of the economic injury suffered by the Purchaser upon the Provider's unexcused failure to provide such Transition Service in accordance with the terms of this Agreement. The Purchaser shall invoice the non-performing Provider, and the Provider shall pay any applicable liquidated damages pursuant to the terms of Article IV. The remedy described in this Section 2.03 shall be the Purchaser's sole and exclusive remedy with respect to a failure by the Provider to perform the Transition Services in accordance with the terms of this Agreement, and once the Provider has paid any applicable liquidated damages, the Provider and its Affiliates shall be fully released and discharged from any liability or obligation resulting from the non-performance of such Transition Service. No liquidated damages shall be payable upon and following the termination of any Transition Service pursuant to Section 3.02 (a), (b) or (c) of this Agreement.

(b) Solely for the purposes of computing liquidated damages as provided in Section 2.03(a) of this Agreement where the Parties have not agreed upon a fixed, monthly price for a Transition Service, the Parties agree that the average of the cost of the applicable Transition Service in the three month period, or a lesser period if this Agreement shall not have been in effect for three months, prior to the period of the unexcused non-performance will be deemed to be the monthly price of the applicable Transition Service.

(c) In the event that CCE is obligated to pay to Enron any liquidated damages pursuant to the TSA or the TSSA arising from ONEOK's failure to perform any of the ONEOK Services, then ONEOK promptly will reimburse CCE for such payment of damages. ONEOK agrees to fully indemnify CCE with respect to any claims Enron may bring against CCE due to ONEOK's non-performance of any of the ONEOK Services.

(d) CCE shall not be liable for, any damages as a result of Enron or any Enron Affiliate's failure to perform the services contemplated by Section 1.01(b) hereof or the failure of CCE or CCE's Affiliates to perform any services to the extent caused by the failure of Enron and its Affiliates to provide the services set forth in Section 1.01(b) hereof to CCE and its Affiliates or to the Transfer Group Companies and/or the Northern Border Companies to the extent CCE has requested, and used commercially reasonable efforts to have such request honored, that Enron provide Enron Services.

2.04 Relationship of Parties. It is understood and agreed that in providing the Transition Services and otherwise in connection with this Agreement, the Provider is an independent contractor and is not, and shall not hold itself out as, an agent, employee or legal representative of the Purchaser or Enron, as applicable, or otherwise as having power or authority to bind the Purchaser or Enron, as applicable, in any manner.

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ARTICLE III.
TERM

3.01 Term. Subject to Section 11.06, unless earlier terminated as provided in Section 3.02 of this Agreement, this Agreement shall become effective as of the closing date of the ONEOK Purchase Agreement (the "Closing Date") and shall remain in effect for a period of six (6) months thereafter (the "Term"). The Parties may mutually agree in writing to extend the provision of any Transition Service beyond the Term.

3.02 Termination. A Party may not terminate this Agreement during the Term except under the following circumstances:

(a) The Parties may terminate any Transition Service or this Agreement by the execution of a written agreement signed by authorized representatives of both Parties, in which event the termination shall be effective on the date specified in such agreement.

(b) The Provider shall be permitted to terminate any Transition Service in the event the Purchaser fails to pay the Provider's invoice for such Transition Service within sixty (60) days of the invoice date, in which event the termination shall be effective on the date on which the Purchaser receives notice from the Provider of such termination.

(c) Termination of any Transition Service shall be effective on the date on which the Provider receives notice of termination pursuant to Section 2.02 hereof.

(d) Except as otherwise may be provided in this Agreement, Purchaser shall be permitted to terminate any CCE Service or ONEOK Service upon sixty (60) days' prior written notice to Provider, in which event the termination shall be effective on the date that is sixty (60) days after Provider receives such notice.

ARTICLE IV.
BILLING AND PAYMENT

4.01 Exclusive Arrangement. It is the express intent of CCE and ONEOK that this Agreement shall provide the exclusive means for CCE and ONEOK to provide Transition Services to one another after the date hereof, and that there shall be no cost recovery for Transition Services separate from or in addition to the monthly fees set forth in and billed pursuant to this Agreement.

4.02 Effect of Discontinuance of Purchase of any Transition Service. If the purchase of a Transition Service is terminated pursuant to Section 3.02 hereof, the Provider shall, upon termination of that Transition Service, discontinue billing the Purchaser for any fees for such Transition Service; provided, however, that, subject to Section 2.02 hereof, the Purchaser will be obligated to pay for Transition Services received up to and through the date of termination of such Transition Services, on a pro rata basis. Subject to Section 2.02 hereof, Purchaser shall be obligated to pay for the provision of a Transition Service unless this Agreement or such Transition Service has been terminated pursuant to Section 3.02 hereof.

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4.03 Invoices. Charges for Transition Services to be performed by the Parties under this Agreement shall be invoiced to the Purchaser by the Provider monthly on or before the twenty-third (23rd) Business Day following the calendar month in which the Transition Services were provided. Invoices shall contain sufficient detail to permit the Purchaser to determine the basis for the charges, the specific services and the applicable affiliate(s) of the Purchaser to which the billed amounts relate. The Purchaser shall pay such invoice by wire transfer or other means of immediate payment, on or before the tenth (10th) Business Day after receipt of each invoice without setoff or deduction of any kind, except as provided in Section 2.02 or 4.04 herein. Any payment by the Purchaser made more than thirty (30) days after the Purchaser is invoiced shall incur a late fee of ten percent (10%) per annum, calculated from and after the expiration of such thirty (30) day period until the date of payment.

4.04 Disputed Amounts. In the event that a good-faith dispute arises as to the amount of any statement or invoice or any portions thereof submitted by one Party to the other pursuant to this Article IV, the Party invoiced may withhold all disputed amounts on such invoice or statement but shall pay all charges on such invoice or statement that are not disputed. A Party disputing any amount on an invoice or statement shall promptly notify the Party issuing the invoice or statement in writing of such disputed amounts and the reasons each such charge is disputed by the Party invoiced. The Party who submitted the invoice or statement shall provide the Party disputing the invoice or statement sufficient records relating to the disputed charge so as to enable the Parties to resolve the dispute. In the event the determination is that the Party invoiced should have paid the disputed amount, the Party invoiced shall pay the disputed amount to the other Party, with interest on the disputed amount at a rate of ten percent (10%) per annum, calculated from and after the thirtieth
(30th) day following the date of such invoice until the date of payment.

4.05 Billing and Payment. Notwithstanding anything to the contrary set forth herein, CCE will have no obligation to pay, or any other liabilities with respect to, any invoices that Enron fails to pay for ONEOK Services. Regardless of whether Enron invoices CCE for Enron Services received by ONEOK, ONEOK will be fully responsible for such invoices, and will indemnify CCE for any claims arising out of ONEOK's failure to satisfy its payment obligations. To the extent that ONEOK pays CCE for Enron Services, then CCE will indemnify ONEOK for any claims arising out of CCE's failure to remit such payment to Enron.

ARTICLE V.
ASSET OWNERSHIP AND USAGE RIGHTS

5.01 Other Property. To the extent CrossCountry obtains from Enron pursuant to the TSA, any rights, title or interests with respect thereto, CCE shall cause to be conveyed, to ONEOK or its designees at no cost, (a) all of CrossCountry's right to use (i) all telephone numbers or (ii) circuits used by the Transfer Group Companies and/or the Northern Border Companies as of the date of the TSA, and not by CrossCountry, for their respective business operations, except for those numbers or circuits that are not necessary for the Transfer Group Companies' and/or the Northern Border Companies' business

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operations, and (b) all right, title, and interest obtained by CrossCountry from Enron pursuant to the TSA to all domain names, trademarks, service marks and trade names, used by one or more of the Transfer Group Companies and/or the Northern Border Companies as of the date of the TSA, and not CrossCountry, for their respective business operations. Notwithstanding the foregoing, CCE may unplug, dispose of, or otherwise terminate any of such telephone numbers or circuits in the ordinary course of business. The property to be conveyed to ONEOK or its designees pursuant to this Section 5.01 and the terms and conditions for such conveyance shall be set forth on Schedule 5.01.

5.02 Timetable. The transactions contemplated by this Article V shall be consummated no later than the end of the Term to the extent required by Section 5.01.

5.03 Use of Name. As of the date of this Agreement, none of the Transfer Group Companies or the Northern Border Companies shall have any right, title or interest in the name "Enron" or "CrossCountry" (or any variations thereof) or any trademarks, trade names, logo or symbols related thereto. As soon as reasonably practicable following the date hereof (and in any event no later than March 31, 2005), ONEOK shall cause the Transfer Group Companies to, and shall use commercially reasonable efforts to cause the Northern Border Companies and their respective subsidiaries to, amend the organizational documents of each such entity to the extent necessary to remove the "Enron" and "CrossCountry" names (and any variations thereof) from their names and to remove, at the sole expense of ONEOK, all trademarks, trade names, logos and symbols related to the name "Enron" or "CrossCountry" from any properties and assets (including all signs) that are visible to, or obtainable by, members of the public.

ARTICLE VI.
LIMITATION OF LIABILITY AND INDEMNITIES

6.01 Provider's Limitation of Liability. Except as set forth in Sections 2.02, 2.03, and 6.02 each Purchaser of Transition Services agrees that the Provider of such services shall not be liable for, and the Purchaser hereby releases the Provider and its Affiliates, and each officer, director, employee, agent, representative, permitted successor and assign of the Provider and/or any of its Affiliates (the "Provider Parties") from any loss, liability, cost, expense, penalty, damage, claim or cause of action (the "Liabilities") arising from any act or omission of the Provider in connection with the Transition Services. Except with respect to the indemnity for third-party claims in Section 6.02, in no event shall any Party (or its Affiliates) be liable to any other Party (or its Affiliates) for any consequential, exemplary, special, incidental or punitive damages or expenses (including, without limit, lost data, profits, revenues, income or savings, cost of capital or loss of business reputation or opportunity) arising from this Agreement or any breach thereof or breach of warranty or error in the performance of the Transition Services regardless of the fault or negligence (whether sole, joint or concurrent, active or passive) of a Party or its Affiliates even if the other Party has been advised of the possibility of the occurrence of such damages. EACH RECIPIENT OF TRANSITION SERVICES HEREUNDER UNDERSTANDS, ACKNOWLEDGES AND AGREES THAT THE LEVEL OF COMPENSATION THE PROVIDER HAS AGREED TO ACCEPT IS

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NORTHERN BORDER TRANSITION SERVICES AGREEMENT

PREDICATED ON THIS LIMITATION OF LIABILITY AND DISCLAIMER OF WARRANTIES.

6.02 Purchaser's Indemnification.

(a) Subject to the limitations set forth in Article X of the ONEOK Purchase Agreement and Section 11.06 of this Agreement, the Purchaser, at its expense, agrees to defend, protect, release, indemnify, and hold harmless the Provider Parties from and against any and all claims, demands, damages, losses, liabilities, suits and causes of action of every kind (collectively "Claims") brought by any Person, other than any Party hereto or its respective Affiliates, for economic losses, damage to property (tangible or intangible), or injuries or death of persons, and all reasonable costs and expenses (including the reasonable costs of investigation and reasonable and necessary attorneys' fees and all reasonable expenses of litigation and court costs), liabilities, awards, and judgments incurred by any of the Provider Parties in connection therewith arising out of, or resulting from, the Transition Services provided under this Agreement.

(b) The Provider or one of its Affiliates shall give the Purchaser reasonably prompt notice of any Claim of which it learns. The Purchaser's obligation of indemnification shall survive even if the Provider or its Affiliate does not provide the Purchaser with reasonably prompt notice of any such Claim of which it learns, so long as such failure does not materially prejudice the Purchaser.

(c) Notwithstanding anything in this Agreement to the contrary, ONEOK, at its expense, agrees to defend, protect, release, indemnify, and hold harmless CCE and its Affiliates from and against any and all Claims brought by Enron or its Affiliates arising out of either the provision of Transition Services by ONEOK to Enron or ONEOK's receipt of Transition Services from Enron, and all reasonable costs and expenses (including the reasonable costs of investigation and reasonable and necessary attorneys' fees and all reasonable expenses of litigation and court costs), liabilities, awards, and judgments incurred by CCE in connection therewith.

(d) Notwithstanding anything in this Agreement to the contrary, CCE, at its expense, agrees to defend, protect, release, indemnify, and hold harmless ONEOK and its Affiliates from and against any and all Claims brought by Enron or its Affiliates arising out of either the provision of Transition Services by CCE to Enron or CCE's receipt of Transition Services from Enron, and all reasonable costs and expenses (including the reasonable costs of investigation and reasonable and necessary attorneys' fees and all reasonable expenses of litigation and court costs), liabilities, awards, and judgments incurred by ONEOK in connection therewith.

6.03 Defense of Claims. Subject to the limitations set forth in Article X of the ONEOK Purchase Agreement and Section11.06 of this Agreement, it is understood and agreed by the Purchaser that in the event any of the Provider Parties is made a defendant in any suit, action or proceeding for which it is indemnified pursuant to this Agreement, and the Purchaser fails or refuses to assume the defense thereof, after having been notified by the Provider Party to do so, that said Provider Party may compromise and

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settle or defend any such Claim, and the Purchaser shall be bound and obligated to reimburse said Provider Party for the amount expended by the Provider Party in settling and compromising any such Claim, or for the amount expended by the Provider Party in paying any judgment rendered therein, together with all reasonable attorneys' fees incurred by the Provider Parties for defense or settlement of such Claim. Any judgment rendered against the Provider Parties or amount expended by the Provider Party in compromising or settling such Claim shall be conclusive as determining the amount for which the Purchaser is liable to reimburse the Provider Party hereunder.

ARTICLE VII.
INSURANCE

7.01 Insurance Policies. The following insurance procedures shall apply:

(a) Each of CCE and ONEOK agree to procure and maintain insurance coverage with reputable insurers for the Term of this Agreement for the Transition Services provided to the other hereunder. All insurance policies procured and maintained by either of ONEOK or CCE must be written with insurance companies authorized to do business in the state where the work will be performed, and under forms of policies reasonably satisfactory to the other, in the kinds and amounts set forth in Exhibit A hereto.

(b) It is understood and agreed that the insurance requirements set forth in this Section 7.01 and Exhibit A hereto shall in no way limit ONEOK's or CCE's liability or responsibility under this Agreement or be construed to be the only types and amounts of insurance ONEOK or CCE should maintain to adequately cover themselves from the hazards of their respective occupations.

(c) All policies of insurance referred to herein must be primary to any other insurance policies carried by CCE or ONEOK with respect to the Transition Services provided by ONEOK or CCE respectively. All policies of insurance referred to herein, held by ONEOK or CCE, as applicable, with the exception of Workers' Compensation and Employer's Liability, shall name CCE and ONEOK, as applicable, as additional insureds, only to the extent of the other Party's indemnity obligations contained herein, covering completed operations, as respects the services performed and materials provided, and shall contain a "Cross-Liability" and "Severability of Interest" provision. Further, each of ONEOK and CCE shall use its best efforts to have all of the above insurance policies provide for thirty (30) days' written notice by certified mail (return receipt requested) to the other in the event of cancellation or a material change.

(d) Except where prohibited by law, all policies of insurance pertaining to this Agreement which are procured, held or maintained by either of ONEOK or CCE, whether required by this Agreement or not, shall be endorsed to provide that the underwriters or insurers waive any and all rights of subrogation against the Seller Indemnified Parties (as defined in the ONEOK Purchase Agreement), or the Purchaser Indemnified Parties (as defined in the ONEOK Purchase Agreement), as applicable.

15

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

(e) Upon request of either one of CCE or ONEOK to the other, CCE or ONEOK, as applicable, shall provide the other with copies of certificates of insurance for itself signed by an authorized representative evidencing the coverages, limits, endorsements and extensions required herein and CCE or ONEOK, as applicable, shall provide the other a copy of its master services agreement listing the insurance requirements for its subcontractors. Each of ONEOK and CCE shall duly file all claims with respect to insurance carried and maintained by it under this Section and shall take all necessary and proper steps to collect any proceeds. CCE and ONEOK, as applicable, shall promptly notify the other of any such loss, damage or claim. Each of CCE or ONEOK, as applicable, shall give prompt notification to the other of each incident or accident that could reasonably be expected to result in a loss in excess of $250,000 related to services under this Agreement.

7.02 No Benefit or Release of Insurer. Nothing in this Agreement is intended to provide or shall be construed as providing a benefit or release to any insurer or claims service organization of any obligation under any Insurance Policy. ONEOK and CCE confirm that this Article 7 is not intended to alter in any manner the rights and obligations of any insurer or contract claims service company thereunder. Nothing herein shall be construed as creating or permitting any insurer or contract claims service company the right of subrogation against any of ONEOK or CCE or any of their respective Affiliates in respect of payments made by one to the other under any Insurance Policy.

ARTICLE VIII.
CONFIDENTIALITY

8.01 Confidentiality. The obligations of CCE and ONEOK and their agents, contractors and employees with respect to confidentiality shall be governed by
Section 6.5 of the ONEOK Purchase Agreement.

ARTICLE IX.
FORCE MAJEURE

9.01 Force Majeure. Subject to the standards set forth in Article II, if, by reason of force majeure, a Party is rendered unable, wholly or in part, to carry out its obligations under this Agreement, and if the non-performing Party declaring force majeure gives notice and reasonable particulars of such force majeure to the Party to whom the performance is due within a reasonable time after the occurrence of the cause relied on, upon giving such notice, so far as and to the extent that it is affected by such force majeure, the non-performing Party declaring force majeure shall not be liable solely on account of such inability to perform during the continuance of any inability so caused; provided, however, the non-performing Party shall use commercially reasonable efforts to recommence performance of the affected services; provided, further, however, that an event of force majeure shall not excuse payment for Transition Services provided hereunder.

9.02 Definition of Force Majeure. The term "force majeure" as employed in this Agreement shall mean acts of God; strikes, lockouts or industrial disputes or

16

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

disturbances; civil disturbances; arrests and restraints from rulers of people; interruptions by government, administrative agency or court orders, other than as a result of a failure to comply with Laws; present and future valid orders, decisions or rulings of any governmental or administrative entity having proper jurisdiction; acts of a public enemy; wars; riots; blockades; insurrections; inability to secure materials by reason of allocations promulgated by authorized governmental agencies; epidemics; landslides; lightning; earthquakes; fire; storm; floods; washouts; whether of the kind herein enumerated or otherwise, not reasonably within the control of the Party claiming force majeure and not caused, in whole or in part, by the acts or omissions of the Party so affected by force majeure.

ARTICLE X.
NOTICES AND REPORTS

10.01 Notices. All notices and other communications under this Agreement shall be in writing and shall be deemed duly given (i) when delivered personally or by prepaid overnight courier, with a record of receipt, (ii) the fourth day after mailing if mailed by certified mail, return receipt requested, or (iii) the day of transmission, if sent by facsimile or telecopy during regular business hours, or the day after transmission, if sent after regular business hours (with a copy promptly sent by prepaid overnight courier with record of receipt or by certified mail, return receipt requested), to the Parties at the following addresses or telecopy numbers (or to such other address or telecopy number as a Party may have specified by notice given to the other Party pursuant to this provision):

If to CCE:

CCE Holdings, LLC

c/o Southern Union Company One PEI Center, Second Floor Wilkes-Barre, PA 18711 Attention: Thomas F. Karam, President and COO Facsimile: (570) 829-8900

And to:

General Electric Capital Corporation 120 Long Ridge Road
Stamford, CT 06927
Attention: Manager of Operations Facsimile: (203) 961-5818

With a copy to:

Fleischman and Walsh, LLP 1919 Pennsylvania Avenue, N.W., Suite 600 Washington, DC 20006
Attention: Sean P. McGuinness Facsimile: (202) 265-5706

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NORTHERN BORDER TRANSITION SERVICES AGREEMENT

And to:

Paul, Hastings, Janofsky & Walker LLP 1055 Washington Boulevard Stamford, CT 06901

      Attention  Jonathan Birenbaum
      Facsimile: (203) 359-3031

If to ONEOK:

ONEOK, Inc.
100 West Fifth Street
Tulsa, OK 74103

Attention: David Kyle, Chairman, President and Chief Executive Officer

Facsimile: (918) 588-7961

With a copy to:

Gable & Gotwals
100 West Fifth Street, Suite 1100 Tulsa, OK 74103
Attention: John R. Barker Facsimile: (918) 595-4990

ARTICLE XI.
MISCELLANEOUS

11.01 Applicable Law. THIS AGREEMENT, THE RIGHTS AND OBLIGATIONS OF THE PARTIES UNDER THIS AGREEMENT, AND ANY CLAIM OR CONTROVERSY DIRECTLY OR INDIRECTLY BASED UPON OR ARISING OUT OF THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED BY THIS AGREEMENT (WHETHER BASED ON CONTRACT, TORT, OR ANY OTHER THEORY), INCLUDING ALL MATTERS OF CONSTRUCTION, VALIDITY AND PERFORMANCE, SHALL IN ALL RESPECTS BE GOVERNED BY AND INTERPRETED, CONSTRUED, AND DETERMINED IN ACCORDANCE WITH, THE INTERNAL LAWS OF THE STATE OF TEXAS (WITHOUT REGARD TO ANY CONFLICTS OF LAW PROVISION THAT WOULD REQUIRE THE APPLICATION OF THE LAW OF ANY OTHER JURISDICTION).

11.02 Waiver. The performance of or compliance with a Party's obligation hereunder may be waived, but only in writing signed by an authorized representative of the other Party. No waiver or failure of enforcement by any Party of any default by any other Party in the performance of any provision, condition or requirement herein shall be deemed to be a waiver of, or in any manner a release of the defaulting Party from, performance of any other provision, condition or requirement herein, nor deemed to be a waiver of, or in any manner a release of the defaulting Party from, future performance of the same provision, condition or requirement; nor shall any delay or omission of any non-

18

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

defaulting Party to exercise any right hereunder in any manner impair the exercise of any such right or any like right accruing to it thereafter.

11.03 Modification. This Agreement may not be modified, varied or amended except by an instrument in writing signed by the Parties.

11.04 Headings. The headings to each of the various Articles and Sections in this Agreement are included for convenience and reference only and shall have no effect on, or be deemed as part of the text of, this Agreement.

11.05 Third Parties. Except as provided in Article VI hereof, this Agreement is not intended to confer upon any Person not a Party hereto any rights or remedies hereunder, and no Person other than the Parties hereto is entitled to rely on or enforce any representation, warranty or covenant contained herein.

11.06 Survival; Limitations Period. Notwithstanding any other provisions in this Agreement, all indemnity, limitation of liability, and payment obligations (including Sections 2.02, 2.03, 4.03 and 4.04) set forth in this Agreement and the provisions set forth in Articles VI, VIII, X, XI and XII shall survive the termination of this Agreement or the expiration of the Term, in whole or in part. NO PARTY MAY ASSERT ANY CAUSE OF ACTION AGAINST ANY OTHER PARTY ARISING UNDER OR IN CONNECTION WITH THIS AGREEMENT MORE THAN SIX (6) MONTHS AFTER THE EXPIRATION OF THE TERM.

11.07 Binding Effect; Assignment.

(a) Subject to paragraph (b) below, no Party hereto may assign this Agreement, in whole or in part, except with the prior written approval of each other Party, which approval shall not be unreasonably withheld; provided, however, that a Party may assign this Agreement to any successor in interest of such Party, including the Purchaser of all or substantially all of the assets of such Party provided, however, that such assignment shall not release the liability of the assignor under this Agreement. This Agreement shall inure to the benefit of, and shall be binding upon, the Parties and their respective permitted successors and assigns.

(b) The Provider may assign the performance by it of any Transition Service to an Affiliate or subsidiary or any successor in interest to such Affiliate or subsidiary. In addition, the Provider may subcontract or outsource the performance of any Transition Service to a third party if necessary to cure any non-performance pursuant to Section 2.02 hereof.

11.08 Entire Agreement. This Agreement, including any exhibits, attachments and schedules hereto, constitutes the entire agreement between the Parties concerning the subject matter hereof, and same supersedes any prior understandings or written or oral agreements relative to said matter.

19

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

11.09 Submission to Jurisdiction; Consent to Service of Process.

(a) Any and all Actions to enforce the terms of this Agreement and to decide any claims or disputes which may arise or result from, or be connected hereby, shall be filed and maintained exclusively in the United States District Court for the Southern District of Texas sitting in Harris County or the Civil Trial Division of the District Court of the State of Texas sitting in Harris County and any appellate court from any thereof, and the Parties hereto consent to and submit to the jurisdiction and venue of such courts and shall receive notices at such locations as indicated in Section 10.01; provided, however, unless the Enron Bankruptcy Cases have closed, any and all Actions to decide any claims or disputes which may arise or result from, or be connected hereby, and involving Enron shall be filed and maintained exclusively in the Bankruptcy Court, and the Parties hereby consent to and submit to the jurisdiction and venue of the Bankruptcy Court and shall receive notices at such locations as indicated in Section 10.01.

(b) The Parties hereby unconditionally and irrevocably waive, to the fullest extent permitted by Applicable Law, any objection which they may now or hereafter have to the laying of venue or any dispute arising out of or relating to this Agreement or any of the transactions contemplated hereby brought in any court specified in paragraph (a) above, or any defense of inconvenient forum of the maintenance of such dispute. Each of the Parties hereto agrees that a judgment in any such dispute may be enforced in other jurisdictions by suit on the judgment or in any other manner provided by law.

(c) Each of the Parties hereto consents to process being served by any Party to this Agreement in any suit, Action or proceeding by the mailing of a copy thereof in accordance with the provisions of Section 10.01.

11.10 Waiver of Jury Trial. THE PARTIES HEREBY IRREVOCABLY AND UNCONDITIONALLY WAIVE, TO THE FULLEST EXTENT PERMITTED BY APPLICABLE LAW, ANY RIGHT THAT THEY MAY HAVE TO TRIAL BY JURY OF ANY CLAIM OR CAUSE OF ACTION, OR IN ANY LEGAL PROCEEDING, DIRECTLY OR INDIRECTLY BASED UPON OR ARISING OUT OF THIS AGREEMENT OR THE TRANSACTIONS CONTEMPLATED BY THIS AGREEMENT (WHETHER BASED ON CONTRACT, TORT, OR ANY OTHER THEORY). EACH PARTY (A) CERTIFIES THAT NO REPRESENTATIVE, AGENT, OR ATTORNEY OF ANY OTHER PARTY HAS REPRESENTED, EXPRESSLY OR OTHERWISE, THAT SUCH OTHER PARTIES WOULD NOT, IN THE EVENT OF LITIGATION, SEEK TO ENFORCE THE FOREGOING WAIVER AND (B) ACKNOWLEDGES THAT IT AND THE OTHER PARTIES HAVE BEEN INDUCED TO ENTER INTO THIS AGREEMENT BY, AMONG OTHER THINGS, THE MUTUAL WAIVERS AND CERTIFICATIONS IN THIS SECTION.

11.11 No Strict Construction. The Parties to this Agreement have participated jointly in the negotiation and drafting of this Agreement. In the event an ambiguity or question of intent or interpretation arises with respect to this Agreement, this Agreement shall be construed as if drafted jointly by the Parties, and no presumption or burden of

20

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

proof shall arise favoring or disfavoring a Party by virtue of the authorship of any of the provisions of this Agreement.

11.12 Severability. If any provision of this Agreement is invalid or unenforceable, the balance of this Agreement shall remain in effect.

11.13 Counterparts. This Agreement may be executed in any number of counterparts, each of which will be deemed an original, but all of which together will constitute one and the same instrument.

11.14 Audit Rights. (a) CCE shall cause its Subsidiaries (other than Citrus Corp., Citrus Energy Services, Inc., Citrus Trading Corp., Florida Gas Transmission Company and each of their respective subsidiaries) to permit ONEOK and any Transfer Group Company, and any Northern Border Company (in each case, only to the extent such entity is subject to Section 404 of the Sarbanes-Oxley Act of 2002 (as may be amended from time to time, the "Sarbanes-Oxley Act")) and authorized agents and representatives, including the internal and external auditors, of any such entity, reasonable access (during normal business hours, upon reasonable advance notice and in accordance with CCE's or its Affiliates' policies and procedures, as may be amended from time to time in CCE's sole discretion) to the internal control structures and procedures of CCE and its Subsidiaries utilized in connection with the CCE Services provided pursuant to this Agreement solely for the purpose of such entity complying with Section 404 of the Sarbanes-Oxley Act. Notwithstanding the foregoing, neither CCE nor any of its Affiliates are making any representation whatsoever as to (i) the adequacy of the internal control structures and procedures or the systems related thereto of CCE or any of its Affiliates or any other entity, or (ii) compliance with any requirement of the Sarbanes-Oxley Act (or the rules or regulations related thereto) to which CCE, ONEOK, and any Transfer Group Company, or any of their Affiliates or any other entity is or may be subject to, and no such requirement (or obligation to comply therewith) shall relieve ONEOK of any of its obligations under this Agreement. CCE agrees to cooperate in good faith with ONEOK to resolve any issues relating to the adequacy of the internal control structures and procedures of CCE or any of its Affiliates; provided, that CCE and its Affiliates shall have no obligation to modify existing internal control structures and procedures or create additional internal control structures and procedures, except as CCE may determine in its sole discretion or as may be required by law applicable to CCE without regard to the provision of CCE Services; and, provided, further, that any modifications or additions to the internal control structures and procedures of CCE and its Affiliates made at the request of ONEOK shall be at the sole cost and expense of ONEOK and subject to
Section 1.04. ONEOK acknowledges and agrees that neither CCE nor any Affiliate of CCE shall in any way be liable for any Claim arising from or relating to, directly or indirectly, the access provided to ONEOK or any Transfer Group Company pursuant to this Section 11.14(a) or the subject matter set forth in clauses (i) and (ii) of the second sentence of this Section 11.14(a), and ONEOK shall fully indemnify the Seller Indemnified Parties for any Losses incurred by any Seller Indemnified Party in connection therewith.

21

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

(b) CCE will request, and use commercially reasonable efforts to have such request honored, that Enron and its Affiliates permit any Transfer Group Company, and any Northern Border Company (in each case, only to the extent such entity is subject to Section 404 of the Sarbanes-Oxley Act of 2002 (as may be amended from time to time, the "Sarbanes-Oxley Act")) and authorized agents and representatives, including the internal and external auditors, of any such entity, reasonable access (during normal business hours, upon reasonable advance notice and in accordance with Enron's policies and procedures, as may be amended from time to time in Enron's sole discretion) to the internal control structures and procedures of Enron and its Affiliates utilized in connection with the Enron Services provided pursuant to this Agreement solely for the purpose of such entity complying with Section 404 of the Sarbanes-Oxley Act. Notwithstanding the foregoing, ONEOK acknowledges that in the performance of the Enron Services, none of Enron or any of its Affiliates or CCE or any of its Affiliates are making any representation whatsoever as to (i) the adequacy of the internal control structures and procedures or the systems related thereto of Enron or any of its Affiliates or any other entity, or (ii) compliance with any requirement of the Sarbanes-Oxley Act (or the rules or regulations related thereto) to which Enron, CCE, ONEOK and any Transfer Group Company or any of their Affiliates or any other entity is or may be subject to, and no such requirement (or obligation to comply therewith) shall relieve ONEOK of any of its obligations under this Agreement. CCE shall request, and use commercially reasonable efforts to have such request honored that Enron cooperate in good faith with ONEOK and the Transfer Group Companies to resolve any issues relating to the adequacy of the internal control structures and procedures of Enron or any of its Affiliates; provided, that Enron and its Affiliates shall have no obligation to modify existing internal control structures and procedures or create additional internal control structures and procedures, except as Enron may determine in its sole discretion or as may be required by law applicable to Enron without regard to the provision of Enron Services; and, provided, further, that any modifications or additions to the internal control structures and procedures of Enron and its Affiliates made at the request of ONEOK or the Transfer Group Companies shall be at the sole cost and expense of ONEOK and shall be governed by the terms and conditions of a project work description to be agreed upon by Enron and CCE. ONEOK acknowledges and agrees that none of Enron or any of its Affiliates or CCE or any its Affiliates shall in any way be liable for any Claim arising from or relating to, directly or indirectly, the access provided to ONEOK or any Transfer Group Company pursuant to this Section 11.14(b) or the subject matter set forth in clauses (i) and (ii) of the second sentence of this
Section 11.14(b), and ONEOK shall fully indemnify the Seller Indemnified Parties for any Losses incurred by any Seller Indemnified Party in connection therewith.

ARTICLE XII.
INTERPRETATION; DEFINITIONS

12.01 Construction and Interpretation. All references herein to agreements and other contractual instruments shall be deemed to include all exhibits, attachments and appendices attached thereto and all amendments and other modifications to such agreements and instruments. Words used herein in the singular, where the context so permits, shall also apply to words when used in the plural and visa versa. The term

22

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

"including" when used in the Agreement will be by way of example and not considered in any way to be a limitation, and means "including, without limitation".

12.02 Definitions. Capitalized terms used in this Agreement and the attached Exhibits, which are hereby incorporated into and made a part of this Agreement, but not defined herein or in such Exhibits have the respective meanings given to them in the ONEOK Purchase Agreement.

IN WITNESS WHEREOF, the Parties have caused this Agreement to be signed in multiple originals by their respective officers thereunto duly authorized, all as of the date first above written.

CCE Holdings, LLC

By: /s/ Richard N. Marshall
    --------------------------------
Name: Richard N. Marshall
Title: Vice President and Treasurer

23

NORTHERN BORDER TRANSITION SERVICES AGREEMENT

ONEOK, INC.

By:    /s/ David L. Kyle
       ----------------------------
Name:  David L. Kyle
Title: Chairman of the Board, President
       and Chief Executive Officer

24

.

.
.
Exhibit 12.1

Northern Border Partners, L.P.
Ratio of earnings to fixed charges

                                                             Year ended December 31,
                                                 ----------------------------------------------
                                                   2000      2001      2002      2003      2004
                                                 -------   -------   -------   -------   -------
Fixed charges:
Interest expensed and capitalized                 81,881    91,653    83,227    79,159    77,346
Estimate of interest within rental expense           864     1,091     1,112     1,210     1,192
                                                 -------   -------   -------   -------   -------
Total fixed charges                               82,745    92,744    84,339    80,369    78,538
                                                 -------   -------   -------   -------   -------
Earnings:
Pretax income from continuing operations          77,098    88,332   112,625   (92,444)  146,057
Minority interest in net income                   38,119    42,138    42,816    44,460    50,033
Equity (earnings) losses from equity investees       647    (1,697)  (12,983)  (18,815)  (18,015)
Distributed income of equity investees               933     7,083    10,820    16,262    13,946
Interest capitalized                                 (58)     (834)     (304)     (117)     (366)
Fixed charges                                     82,745    92,744    84,339    80,369    78,538
                                                 -------   -------   -------   -------   -------
Total earnings                                   199,484   227,766   237,313    29,715   270,193
                                                 -------   -------   -------   -------   -------
Ratio of earnings to fixed charges                  2.41      2.46      2.81      0.37      3.44
                                                 =======   =======   =======   =======   =======




EXHIBIT 21

SUBSIDIAIRIES OF NORTHERN BORDER PARTNERS, L.P.

Bear Paw Investments, LLC, organized in Delaware

Bear Paw Energy, LLC, organized in Delaware

Border Midwestern Company, incorporated in Delaware

Border Viking Company, incorporated in Delaware

Crestone Energy Ventures, L.L.C., organized in Delaware

Midwestern Gas Transmission Company, incorporated in Delaware

Northern Border Intermediate Limited Partnership, organized in Delaware

Northern Border Pipeline Company, a Texas general partnership

Viking Gas Transmission Company, incorporated in Delaware


Exhibit 23

CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Partnership Policy Committee
Northern Border Partners, L.P.:

We consent to the incorporation by reference in the registration statements (No. 333-101469) on Form S-3, (Nos. 333-66949 and 333-72696) on Form S-8 of Northern Border Partners, L.P. (the Partnership) of our report dated March 2, 2005 with respect to the consolidated balance sheets of the Partnership as of December 31, 2004 and 2003, and the related consolidated statements of income, comprehensive income, cash flows, and changes in partners' equity for each of the years in the three-year period ended December 31, 2004, and the related financial statement schedule, management's assessment of the effectiveness of internal control over financial reporting as of December 31, 2004 and the effectiveness of internal control over financial reporting as of December 31, 2004, which reports appear in the December 31, 2004 annual report on Form 10-K of the Partnership.

Our report refers to the Partnership's adoption of Statement of Financial Accounting Standards (SFAS) No. 143, Accounting for Asset Retirement Obligations, in 2003.

/S/ KPMG LLP

Omaha, Nebraska


March 11, 2005


EXHIBIT 31.1

CERTIFICATION

I, William R. Cordes, certify that:

1. I have reviewed this annual report on Form 10-K of Northern Border Partners, L.P.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:  March 11, 2005           /s/ William R. Cordes
                                ------------------------------------------------
                                William R. Cordes
                                Chief Executive Officer


EXHIBIT 31.2

CERTIFICATION

I, Jerry L. Peters, certify that:

1. I have reviewed this annual report on Form 10-K of Northern Border Partners, L.P.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles ;

c) Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5. The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and


b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:  March 11, 2005            /s/ Jerry L. Peters
                                 -----------------------------------------------
                                 Jerry L. Peters
                                 Chief Financial and Accounting Officer


EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of Northern Border Partners, L.P. (the "Partnership") for the year ended December 31, 2004 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), William R. Cordes, as Chief Executive Officer of the Partnership, hereby certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or section 15(d), as applicable, of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

Dated:  March 11, 2005              /s/ William R. Cordes
                                    -----------------------------------
                                    William R. Cordes
                                    Chief Executive Officer

This certification is made solely for the purpose of 18 U.S.C. Section 1350, and not for any other purpose.


EXHIBIT 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K of Northern Border Partners, L.P. (the "Partnership") for the year ended December 31, 2004 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), Jerry L. Peters, as Chief Financial and Accounting Officer of the Partnership, hereby certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of section 13(a) or section 15(d), as applicable, of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Partnership.

Dated:  March 11, 2005              /s/ Jerry L. Peters
                                    --------------------------------------------
                                    Jerry L. Peters
                                    Chief Financial and Accounting Officer

This certification is made solely for the purpose of 18 U.S.C. Section 1350, and not for any other purpose.