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FORM 10-K

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SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549

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/x/	ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended September 30, 2001

Commission file number: 1-7196

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CASCADE NATURAL GAS CORPORATION
(Exact name of Registrant as specified in its charter)

Washington		91-0599090
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification No.)
222 Fairview Avenue North Seattle, WA 98109		(206) 624-3900
(Address of principal executive offices)		(Registrant's telephone number including area code)

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Securities registered pursuant to Section 12(b) of the Act:

Securities registered pursuant to section 12(g) of the Act: None

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    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. / /

    The aggregate market value of the voting and non-voting common equity held by non-affiliates of the registrant as of the close of business on November 21, 2001, was $238,384,000

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

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DOCUMENTS INCORPORATED BY REFERENCE

    Portions of the Registrant's definitive proxy statement for its 2001 Annual Meeting of Shareholders are incorporated by reference into Part III, Items 10, 11, 12, and 13.

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CASCADE NATURAL GAS CORPORATION
Annual Report to the Securities and Exchange Commission on Form 10-K
For the Fiscal Year Ended September 30, 2001

Table of Contents

					Page Number
Part I
	Item 1	—	Business		3
	Item 2	—	Properties		7
	Item 3	—	Legal Proceedings		7
	Item 4	—	Submission of Matters to a Vote of Security Holders		8
	Executive Officers of the Registrant				8
Part II
	Item 5	—	Market for Registrant's Common Equity and Related Stockholder Matters		9
	Item 6	—	Selected Financial Data		10
	Item 7	—	Management's Discussion and Analysis of Financial Condition and Results of Operations		12
	Item 7a	—	Quantitative and Qualitative Disclosures about Market Risk		16
	Item 8	—	Financial Statements and Supplementary Data		18
	Item 9	—	Changes in and Disagreements With Accountants on Accounting and Financial Disclosure		39
Part III
	Item 10	—	Directors and Executive Officers of the Registrant		39
	Item 11	—	Executive Compensation		39
	Item 12	—	Security Ownership of Certain Beneficial Owners and Management		39
	Item 13	—	Certain Relationships and Related Transactions		39
Part IV
	Item 14	—	Exhibits, Financial Statement Schedules and Reports on Form 8-K		40
Signatures					41
Index to Exhibits					42

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Part I

Item 1.  Business

General

    Cascade Natural Gas Corporation (Cascade or the Company) was incorporated under the laws of the state of Washington on January 2, 1953. Its principal business is the distribution of natural gas to customers in the states of Washington and Oregon. Approximately 82% of its gas distribution revenues are from customers in the state of Washington.

    As of September 30, 2001, the Company had approximately 162,600 residential customers, 27,500 commercial customers, 781 industrial and other customers. Residential, commercial, and most small industrial customers are generally core customers, who take traditional "bundled" natural gas service, which includes supply, peaking service, and upstream interstate pipeline transportation. Sales to core customers account for approximately 16% of gas deliveries and 68% of operating margin. The Company's sales to its core residential and commercial customers are influenced by fluctuations in temperature, particularly during the winter season. A warm winter season will tend to reduce gas consumption. Over the longer term, these fluctuations tend to offset each other, as rates charged to customers are developed based on the assumption of normal weather.

    Non-core customers are generally large industrial and institutional customers who have chosen "unbundled" service, meaning that they select from among several supply and upstream pipeline transportation options, independent of the Company's distribution service. The Company's margin from non-core customers is derived primarily from this distribution service and to a lesser extent from gas management service revenue.

State Regulation

    The Company's rates and practices are regulated by the Washington Utilities and Transportation Commission (WUTC) and the Oregon Public Utility Commission (OPUC).

    Cascade's gas supply contracts contain pricing provisions for fixed periods of time. To the extent that prices are changed with respect to supplies purchased for core customers, Cascade is able to pass the effect of such changes, subject to regulatory review, to its customers by means of a periodic purchased gas cost adjustment (PGA) in each state. Gas price changes occurring between times when PGA rate changes become effective are deferred for pass through in the next PGA.

    With respect to such gas supplies delivered to Oregon customers, 67% of the incremental change in the actual cost of gas supplies, as compared to the forecasted cost reflected in the PGA, is deferred. The remaining 33% (increase or decrease) is absorbed by the Company. This mechanism is intended to encourage the Company to seek opportunities to lower its cost of supplies and to be innovative in its management of the supply portfolio to avoid price spikes. Cascade's gas supply portfolio for Oregon core customers is comprised mostly of gas supplies that have a fixed commodity price, therefore management believes the risk or opportunity for the Company is not significant under the 67% / 33% sharing arrangement during the coming year. For the fiscal year ended September 2001, under this arrangement, Cascade's 33% share of savings achieved totaled $252,000.

    Cascade has an earnings sharing mechanism with respect to its Oregon jurisdictional operations. See "Regulatory Matters" under Item 7 for a description of the mechanism.

    The Company is also subject to state regulation with respect to integrated resource planning, and its most recent update of its Integrated Resource Plan (IRP) was filed in 1999 with both the WUTC and the OPUC. The IRP shows the Company's optimum set of supply and demand side resources that minimizes costs and risk over the twenty-year planning horizon. The IRP also sets forth possible core

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customer growth scenarios for a twenty-year period. In addition, the IRP sets forth the Company's demand side management goals of achieving certain conservation levels in customer usage.

    The IRP also sets forth the Company's supply side management plans regarding transportation capacity and gas supply acquisition over a twenty-year period. The Company develops updates of the IRP every two years. These updated documents take into account input solicited from the public and the WUTC and OPUC staffs. While the filing of the IRP with both commissions gives the Company no advance assurance that its acquisitions of pipeline transportation capacity and gas supplies will be recognized in rates, management believes that the integrated resource planning process benefits the Company by giving it the opportunity to obtain input from regulators and the public concurrently with making these important strategic decisions. Until the Company receives final regulatory approval of these decisions in the context of the rate making process, the Company cannot predict with certainty the extent to which the integrated resource planning process will affect its rates.

Natural Gas Supply

    The majority of Cascade's supply of natural gas is transported via Williams Gas Pipelines—West (Williams). Williams owns and operates a transmission system extending from points of interconnection with El Paso Natural Gas Company and Transwestern Pipeline Company near Blanco, New Mexico through the states of New Mexico, Colorado, Utah, Wyoming, Idaho, Oregon and Washington to the Canadian border near Sumas, Washington. Natural gas is transported north from the Colorado and New Mexico area, and south from British Columbia, Canada. The Company is also a shipper on the Pacific Gas and Electric National Energy Group (PG&E) system. PG&E owns and operates a gas transmission line that connects with the facilities of the TransCanada Pipeline (formerly Alberta Natural Gas Company, Ltd.) at the international border near Kingsgate, British Columbia and extends through Washington and central Oregon into California. Cascade also receives natural gas directly from Westcoast Energy, Inc. at the Canadian border near Sumas, Washington.

    Presently, baseload requirements for Cascade's core market are provided by six major gas supply contracts with various expiration dates from 2002 through 2008 and totaling 759,000 therms per day of Canadian supply. These contracts are supplemented by various service agreements to cover periods of peak demand including three storage agreements. One such agreement, with Williams, extends to October 31, 2014 and provides for 167,890 therms per day and a maximum, renewable inventory of 6,043,510 therms. The second storage agreement is with Avista Energy, and has a primary term ending April 30, 2003 and entitles Cascade to receive up to 150,000 therms per day and a maximum, renewable inventory of 4,800,000 therms. A third contract, also with Williams, for liquefied natural gas (LNG) storage is effective through October 31, 2014. Under this LNG agreement, Cascade is entitled to receive up to 600,000 therms per day to a maximum inventory of 5,622,000 therms. In addition to withdrawal and inventory capacity, Cascade maintains a corresponding amount of firm transportation from the storage facility to the city gate for each of these agreements.

    During 2001, Cascade purchased approximately 85% of its gas supplies from firm gas supply contracts and 15% from 30-day spot market contracts. In addition, 1.15 billion therms of customer purchased supplies were transported through Cascade facilities.

    Cascade's cost of gas depends primarily on the prices negotiated with producers and brokers, coupled with the cost of interstate and Canadian pipeline transportation. Substantially all gas supplies for Oregon core customers and the majority of gas supplies for Washington core customers are currently purchased on contracts with supplies and prices fixed through the 2003 - 2004 heating season. Management believes that this, together with use of storage volumes at a value determined at the time of injection, provides Cascade with the ability to mitigate the effects on Cascade and its customers of spikes in the market price of natural gas.

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Federal Energy Regulatory Commission (FERC) Matters

    Cascade is not subject to regulation by the FERC, however FERC actions can affect the amounts Cascade pays to interstate pipeline companies for interstate deliveries of natural gas supplies. Several issues are pending before FERC, or are on appeal before the U.S. Court of Appeals. The final outcome may affect prices Cascade pays. Since the policies of the WUTC and OPUC provide for 100% pass through of costs subject to FERC regulation, the Company expects that the final resolution of pending issues will not affect net income.

Curtailment Procedures

    In previous heating seasons, cold weather has required Cascade to significantly curtail deliveries to its interruptible customers. Cascade has not curtailed any firm customers, except under force majeure conditions. Cascade's tariffs effective in Washington and Oregon allow for curtailment of interruptible services, which are provided at rates lower than for firm services. In the event of curtailment by Cascade of firm service due to force majeure, Cascade's tariffs provide that it will not be liable for damages to any customer for failure to deliver gas curtailed in accordance with the provisions of the tariffs. The tariffs provide for appropriate adjustment of the monthly charges to firm customers curtailed by reason of an insufficient supply of gas.

Territory Served and Franchises

    The population of communities served by Cascade totals approximately 886,000. At the end of September 2001, Cascade had the franchises necessary for the distribution of natural gas in all of the communities it serves in Washington and Oregon. Under the laws of those states, incorporated municipalities and counties may grant non-exclusive franchises for a fixed term of years conferring upon the grantee certain rights with respect to public streets and highways in the location, construction, operation, maintenance and removal of gas distribution facilities.

    In the opinion of Cascade's management, none of its franchises contain any restrictions or requirements that are of a materially burdensome nature, and such franchises are adequate for the conduct of Cascade's present business. Franchises expire on various dates from fiscal 2002 to 2065. Management has not incurred significant difficulties in renewing franchises when they expire and does not expect any significant problems in the future.

Customers

    Residential and commercial customers principally use natural gas for space heating and water heating. This market is very weather-sensitive. See "Seasonality" below.

    Agreements with Cascade's principal industrial customers are for fixed terms of not less than one year and provide for automatic extension from year to year unless terminated by either party on at least 30-days' notice.

    The principal industrial activities in Cascade's service area include the production of pulp, paper and converted paper products, plywood, chemical fertilizers, industrial chemicals, clay and ceramic products; refining of crude oil; producing and forming of aluminum; the processing, flash freezing and canning of many types of vegetable, fruit and fish products; processing of milk products; meat processing; drying and curing of wood and agricultural products; and electric power generation. Electric generation customers represent a significant portion of industrial revenues. The demand for gas fired generation tends to decrease as the availability of hydroelectric generation increases.

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Seasonality

    Weather is an important factor affecting gas revenues because of the large number of customers using gas for space heating. For the fiscal year ended September 30, 2001, 68% of operating revenues and 88% of income from operations were derived from the first two quarters (October 2000 through March 2001). Because of the seasonality of space heating revenues, financial results for interim periods are not indicative of results to be expected for an entire year. To mitigate the seasonality of space heating revenues, the Company pursues a marketing strategy of encouraging the installation of gas water heaters by customers, since they are not as influenced by weather conditions.

Competitive Conditions

    Cascade operates in a competitive market for natural gas service. Cascade competes with residual fuel oil and other alternative energy sources for industrial boiler uses, and oil, propane, and electricity for residential and commercial space heating, and electricity for water heating.

    Competition is primarily based on price. Though wholesale natural gas prices increased significantly in the 2000 - 2001 heating season, for residential and commercial space heating use, Cascade continues to maintain a price advantage over oil in its entire service territory and has an advantage over electricity in the vast majority of its territory. In the remaining areas of its service territory served by public electric utilities with their own hydro power supply, Cascade is almost equal in cost with respect to electricity furnished by those utilities for space heating and water heating uses. In addition, natural gas enjoys the advantage of being the preferred energy choice by builders for new home construction.

    Historically, the large volume industrial market was very sensitive to price fluctuations between the comparable cost of natural gas and alternate fuels, principally residual fuel oil used in boiler applications. However, the advent of open access transportation in the late 1980's and early 1990's and the subsequent restructuring of gas supply and contractual provisions with these customers have improved the Company's competitive position. Cascade has not experienced any significant loss of sales to alternate fuels to these customers during the last ten years, even though there have been periods when the residual fuel oil prices were lower than natural gas. However, with the escalation of wholesale natural gas prices that occurred in the 2000 - 2001 heating season, the Company experienced some movement of its gas load to alternative fuels and some plant curtailments by industrial customers.

    In addition to multiple alternative fuels, the Company is subject to bypass. Bypass refers to actual or prospective customers who install their own facilities and connect directly to an upstream pipeline and thereby "bypass" the distribution company's service. The Company has experienced bypass but has also experienced success in offering competitive rates to reduce economic incentives to bypass. In addition, other sellers of natural gas compete to sell the natural gas commodity over the Company's pipelines to its distribution customers.

    The Bonneville Power Administration (BPA) is a major supplier of hydro-electric power in the Pacific Northwest including Cascade's service area. BPA significantly influences the electric rates of all classes of customers including those applications in direct competition with natural gas marketed by Cascade.

Environmental

    The Company is subject to federal and state environmental regulation of its operations and properties through the United States Environmental Protection Agency, the Washington Department of Ecology and the Oregon Department of Environmental Quality. Such regulation may, at times, result in the imposition of liability or responsibility for the clean up or treatment of existing environmental

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problems or for the prevention of future environmental problems. For detailed descriptions of specific environmental issues, see "Environmental Matters" under Item 7.

Capital Expenditures

    Capital expenditures are primarily used to expand the Company's distribution system to serve its expanding customer base, as well as to increase deliverability on its existing system to accommodate increased customer utilization. Capital expenditures for the five fiscal years ended September 30, 2001 totaled approximately $100.3 million, and the budget for fiscal 2002 is $22.8 million.

    The Company is currently forecasting that capital expenditures will total approximately $110.8 million over the next five years, reflecting expectations that customer growth will continue at a pace similar to recent experience. Management performs quantitative and qualitative analyses to assure that the Company's goals and strategies are met. The overall objective is to invest limited capital to generate the highest possible returns within the shortest possible time, while assuming prudent risk, anticipating customer needs and complying with the requirements of regulators.

Non-Utility Subsidiaries

    Cascade has four non-utility subsidiaries, only two of which are actively engaged in business at present. Cascade Land Leasing is engaged in the servicing of loans that were made to Cascade's gas customers to finance their purchases of energy-efficient appliances. The subsidiary ceased making new loans in September 1997. Beginning in November 1998, CGC Resources began serving as an entity engaged in pipeline capacity management, with the objective of mitigating gas costs for Cascade. The subsidiaries, which in the aggregate account for less than 1% of the consolidated assets of the Company, do not currently have a significant impact on Cascade's financial statements.

Personnel

    At September 30, 2001, Cascade had 442 employees. Of the total employees, 201 are represented by the International Chemical Workers Union. The present contract with the union extends to April 1, 2006, and remains in force from year to year unless terminated by either party on sixty days' notice.

    Over the last three years, the number of employees has decreased by approximately 8%. These reductions have been accomplished through normal attrition, and an emphasis on achieving improved operating efficiencies.

Item 2.  Properties

    At September 30, 2001, Cascade's utility plant investments included approximately 4,734 miles of distribution mains ranging in diameter from two inches to sixteen inches, 214 miles of transmission mains ranging in diameter from two inches to sixteen inches, and 3,261 miles of service lines.

    The distribution and transmission mains are located under public property such as streets and highways or on private property with the permission or consent of the individual owner.

    Cascade owns twenty buildings used for operations, office space and warehousing in Washington and seven such buildings in Oregon. It leases seven commercial offices and warehouse buildings. Cascade considers its properties well maintained and in good operating condition, and adequate for Cascade's present and anticipated needs. All facilities are substantially utilized.

Item 3.  Legal Proceedings

    Incorporated herein by reference are the following:

    The information under "Environmental Matters" in Item 7.

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    The information under "Litigation" in Note 12 to the financial statements in Item 8. With respect to the lawsuit referred to under "Litigation", the parties have agreed in November 2001, to a settlement calling for payment of $250,000 to the plaintiffs. This settlement is subject to the approval of the courts.

Item 4.  Submission of Matters to a Vote of Security Holders

    None

Executive Officers of the Registrant

    The executive officers of the Company, as of December 1, 2001, are as follows:

Name		Office		Age		Year Became Officer
W. Brian Matsuyama		Chairman of the Board, President and Chief Executive Officer		55		1987
Jon T. Stoltz		Senior Vice President—Planning, Regulatory & Consumer Affairs		54		1981
J. D. Wessling		Senior Vice President—Finance and Chief Financial Officer		58		1995
Larry E. Anderson		Vice President—Operations		53		1995
King C. Oberg		Vice President—Gas Supply		60		1993
James E. Haug		Controller and Chief Accounting Officer		52		1981
Larry C. Rosok		Vice President—Human Resources and Corporate Secretary		45		1995
William H. Odell		Vice President—Districts		39		2000
Linda Cies		Vice President—Information Technology		44		2000

    None of the above officers is related by blood, marriage or adoption to any other of the above named officers. With the exception of Linda Cies, each of the above named officers has been employed by the Company in a management capacity for at least the past five years. None of the above officers hold directorships in other public corporations. All officers serve at the pleasure of the Board of Directors.

    Linda Cies was employed by the Company in February, 1997, as Director—Development Services, and subsequently was Director—Information Technology. Prior to 1997, she was Manager—Information Services for an engineering consulting firm.

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Part II

Item 5.  Market for Registrant's Common Equity and Related Stockholder Matters

    The Common Stock is traded on the New York Stock Exchange under the symbol CGC. The following table states the per share high and low sales prices of the Common Stock.

    At September 30, 2001, there were 6,582 holders of the Common Stock. The following table shows for the periods indicated the dividends paid per share on the Common Stock.

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Item 6. Selected Financial Data

			Year Ended Sep 30			Year Ended Sep 30			Year Ended Sep 30			Year Ended Sep 30			Year Ended Sep 30
			2001			2000			1999			1998			1997
			(dollars in thousands except per share data)
Statements of Income and Comprehensive Income:
Operating Revenues				335,814			241,936			208,610			189,656			195,786
Less: Gas Purchases				219,795			136,681			109,263			97,382			104,342
	Revenue taxes			20,987			15,261			13,280			12,037			12,430
Operating Margin				95,032			89,994			86,067			80,237			79,014
Cost of Operations:
	Operating expenses			39,182			36,970			36,313			37,310			35,670
	Depreciation and amortization			13,839			13,293			12,841			13,470			13,416
	Property and payroll taxes			5,027			4,734			4,574			4,420			3,989
				58,048			54,997			53,728			55,200			53,075
Income From Operations				36,984			34,997			32,339			25,037			25,939
Nonoperating Expense (Income):
	Interest			10,509			10,936			10,486			10,132			9,436
	Interest charged to construction			(333	)		(322	)		(383	)		(550	)		(532	)
				10,176			10,614			10,103			9,582			8,904
	Amortization of debt issuance expense			607			607			603			605			612
	Other			(313	)		(649	)		(495	)		(388	)		(467	)
				10,470			10,572			10,211			9,799			9,049
Income Before Income Taxes				26,514			24,425			22,128			15,238			16,890
Income Taxes				9,278			9,051			8,075			5,694			6,263
Net Income Before Preferred Dividends				17,236			15,374			14,053			9,544			10,627
Preferred Dividends				—			4			483			497			510
Net Income			$	17,236		$	15,370		$	13,570		$	9,047		$	10,117
Other Comprehensive Income (Loss), net of tax
	Minimum pension liability adjustment ($6,502, net of $2,341 income tax effect)			(4,161	)		—			—			—			—
Comprehensive Income			$	13,075		$	15,370		$	13,570		$	9,047		$	10,117
Earnings Per Common Share, Basic and Diluted			$	1.56		$	1.39		$	1.23		$	0.82		$	0.93

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				At September 30
				2001			2000			1999			1998			1997
				(dollars in thousands except per share data)
Retained Earnings:
	Beginning of the year			$	10,736		$	5,970		$	3,003		$	4,553		$	4,901
	Net income				17,236			15,370			13,570			9,047			10,117
	Common dividends				(10,603	)		(10,604	)		(10,603	)		(10,597	)		(10,465	)
	End of the year			$	17,369		$	10,736		$	5,970		$	3,003		$	4,553
Capital Structure:
	Common shareholders' equity			$	121,633		$	119,161		$	114,395		$	111,428		$	111,662
	Redeemable preferred stocks				—			62			6,186			6,408			6,630
	Debt:
		Long-term debt			125,000			125,000			125,000			110,650			121,150
		Notes payable and commercial paper			40,000			1,500			—			6,929			12,900
		Current maturities of long-term debt			—			—			—			10,000			—
					165,000			126,500			125,000			127,579			134,050
	Total capital			$	286,633		$	245,723		$	245,581		$	245,415		$	252,342
Financial Ratios:
	Return on common shareholders' equity				13.45	%		12.51	%		11.52	%		7.77	%		8.75	%
	Common stock dividend payout ratio				62	%		69	%		78	%		117	%		103	%
	Cash dividends declared per common share			$	0.96		$	0.96		$	0.96		$	0.96		$	0.96
	Fixed charge coverage (before income tax deduction):
		Times interest earned			3.39			3.12			3.00			2.42			2.68
		Times interest and preferred dividends earned			3.39			3.12			2.80			2.26			2.48
	Book value per year-end share of common stock			$	11.01		$	10.79		$	10.33		$	10.09		$	10.18
	Capitalization Ratios at End of Year
		Common shareholders' equity			42.4	%		48.5	%		46.6	%		45.4	%		44.3	%
		Preferred stock			0.0	%		0.0	%		2.5	%		2.6	%		2.6	%
		Long-term debt (incl. current)			43.6	%		50.9	%		50.9	%		49.2	%		48.0	%
		Short-term debt			14.0	%		0.6	%		0.0	%		2.8	%		5.1	%
					100.0	%		100.0	%		100.0	%		100.0	%		100.0	%
Utility Plant:
	Utility plant—end of year			$	488,231		$	468,789		$	453,278		$	433,568		$	416,365
	Accumulated depreciation				201,530			189,058			177,878			167,356			160,332
	Net plant			$	286,701		$	279,731		$	275,400		$	266,212		$	256,033
	Capital expenditures, net of contributions in aid			$	21,649		$	15,937		$	17,262		$	23,780		$	21,626
	Total assets			$	364,253		$	328,336		$	315,569		$	311,511		$	307,703

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Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations

    The following is management's assessment of the Company's financial condition and a discussion of the principal factors that affect consolidated results of operations and cash flows for the fiscal years ended September 30, 2001, 2000, and 1999. References herein to 2001, 2000, and 1999 refer to these fiscal years.

EARNINGS PER SHARE

    Net income was $17,236,000 for 2001, compared to $15,370,000 for 2000. Basic and diluted earnings per share for 2001 were $1.56, a 12% improvement over the $1.39 reported for 2000. Of the improved earnings, $0.09 per share resulted from non-recurring transactions. There was a $0.14 per share improvement resulting from one-time revenue opportunities dealing with off-system interstate pipeline capacity. This was partially offset by $0.05 per share from operating expenses related to the installation of a new integrated work management system. Excluding these one-time transactions, basic and diluted earnings per share were $1.47, a 6% improvement over 2000.

    2000 versus 1999.  Fiscal 2000 net income represents a 13% improvement over the $13,570,000, $1.23 per common share reported for fiscal 1999. The improvement in earnings is primarily the result of operating margin increases that exceeded the increase in operating and other costs.

OPERATING MARGIN

    Operating margin for the year improved $5.0 million, with $3.3 million attributed to growth in residential and commercial margin, $3.1 million in one-time revenue from off-system interstate pipeline capacity transactions, offset by a net reduction of $1.4 million in industrial and other margins.

    Residential and Commercial Margin for the fiscal years ended September 30, 2001, 2000, and 1999 are set forth in the table below:

			(12 months ended September 30)
			2001			2000			1999
			($ in thousands)
Degree Days				5,793			5,372			5,535
Average Number of Customers
	Residential			163,427			157,116			150,068
	Commercial			27,796			27,186			26,360
Average Therm Usage Per Customer
	Residential			776			776			799
	Commercial			4,023			3,926			4,058
Operating Margin
	Residential		$	37,824		$	35,915		$	34,850
	Commercial		$	23,273		$	21,863		$	21,845

    Operating margins from sales to residential and commercial customers were up $3,319,000, or 5.7%, in 2001 compared to 2000. The primary factors contributing to this improvement were increased deliveries to residential customers resulting from growth in the number of customers, and higher average consumption per commercial customer.

    Increases in the number of residential and commercial customers contributed approximately $1.6 million and $0.6 million respectively of new margin. Higher per-customer gas usage, primarily by commercial customers, contributed most of the remaining improvement. Average consumption by residential customers in 2001 was the same as in 2000 despite the fact that weather was 7% colder in 2001. This lack of increased consumption is attributed to rate increases in January, and general

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conservation efforts by customers in response to the West Coast power crisis in the winter of 2000 - 2001.

    2000 versus 1999.  Fiscal 2000 operating margins from sales to residential and commercial customers were up $1,206,000, or 2.1%, compared to 1999. The primary factors contributing to this improvement were increased deliveries to residential customers resulting from growth in the number of customers.

    Increases in the number of residential and commercial customers contributed approximately $1.8 million and $0.7 million respectively of new margin. These improvements were partially offset by reductions in consumption per customer resulting from warmer than normal weather. Weather in 2000, as measured by heating degree-days, was approximately 5% warmer than normal, and 3% warmer than 1999.

    Industrial and Other Margin.  Total margin from industrial and other customers in 2001 declined $777,000 from 2000. Increased consumption by electric generation customers resulted in a $600,000 margin increase from that sector, but this was offset by a $2.2 million decline in margin from customers in other industries. The energy crisis on the West Coast during the winter and spring of 2000 - 2001 was the major contributing factor in both these changes. There has been increased demand for electric generation, but higher energy prices have driven decisions by other customers to reduce their consumption.

    The Company has also earned $842,000 of increased margins from providing gas management services to industrial customers, as well as providing miscellaneous services to existing and new customers.

    Other margin in 2001 was reduced by a charge resulting from the Oregon earnings sharing mechanism. Under this arrangement between the Company and the OPUC, Cascade refunds to its Oregon customers one third of earnings that exceed a return on equity ceiling. The amount recorded as an estimate attributable to 2001 is $657,000.

    Capacity Contracts.  During 2001, the Company benefited from one-time opportunities to enter into two off-system interstate pipeline transactions. These transactions resulted in $3.1 million of operating margin. The Company has no expectation of additional revenues from such sources, and this is not an on-going part of Cascade's business.

    2000 versus 1999.  Margins from industrial and other customers in 2000 increased $2.7 million, or 9.2% from 1999. Approximately $1.9 million of this improvement resulted from increased gas deliveries to electric generation customers. Increased demand for electricity was the main reason for this higher gas usage. Historically, gas consumption by, and margin from electric generation customers has been subject to significant volatility. From 1997 to 2000, annual margins from these customers varied from $7.7 million to $10.7 million. Additionally, approximately $0.5 million in margins came from 35 smaller, new industrial customers and about $0.3 million resulted from consumption increases by other industrial customers.

COST OF OPERATIONS

    Cost of operations, which consists of operating expenses, depreciation and amortization, and property and payroll taxes, was $58.0 million, $55.0 million, and $53.7 million for the fiscal years ended September 30, 2001, 2000, and 1999, respectively.

    Operating Expenses for 2001, which are primarily labor and benefits expenses, increased $2,212,000, or 6.0% from 2000. Of this increase, $857,000 is attributable to one-time expenses related to the installation of a new integrated work management system. Excluding these one-time costs, ongoing

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expenses increased 3.7% for the year. This increase was due in large part to increases in regular compensation, and in profit sharing related to achievement of goals.

    2000 versus 1999.  Operating Expenses for 2000 increased $657,000, or 1.8% from 1999. The net increase reflected changes in various categories of expense. Significant changes included a $652,000 (2.7%) decrease in labor expense related to reductions in the number of employees. The average number of employees in fiscal 2000 was 446, compared to 468 in fiscal 1999. These reductions were achieved through normal attrition. Employee benefits expense increased $337,000 (3.3%) mostly attributable to higher accruals for medical benefits costs. The provision for uncollectible accounts increased $316,000 (52%) mostly due to establishing a reserve related to an account due from an industrial customer. Office and administrative expenses, including hiring costs, supplies, postage, and collection costs, increased $213,000 (9.1%). Purchased services expenses increased $198,000 (13.2%), and included $155,000 in fees paid related to mitigation of property tax increases. Services provided for those fees resulted in the avoidance of approximately $350,000 in annual property tax increases.

    Depreciation and Amortization for 2001 increased $546,000, or 4.1% over 2000. For 2000 the increase was $452,000, or 3.5% over 1999. The increased depreciation expense each year is the result of new depreciable assets placed in service.

    Property and Payroll Taxes for 2001 increased $293,000, or 6.2% over 2000. For 2000, the increase was $160,000, or 3.5% over 1999. For both years, the increase was primarily attributable to property tax increases related in large part to asset additions.

NONOPERATING EXPENSE (INCOME)

    Interest expense in 2001, net of interest capitalized, decreased $427,000 (3.9%) from 2000, mainly because of the interest benefit accrued on deferred gas costs. Other non-operating income decreased $336,000 mainly because of lower interest income on deposits of cash and cash equivalents.

    2000 versus 1999.  Interest expense in 2000, net of interest capitalized, increased $511,000 (5.1%) over fiscal 1999 because of higher average long-term debt balances, and higher average balances of deferred gas cost accounts. Other non-operating income increased $154,000 primarily from higher interest income on deposits of cash and cash equivalents.

INCOME TAXES

    The increase in the provision for federal and state income taxes in 2001 over 2000, and in 2000 over 1999 is attributable to improvements in pre-tax earnings.

OTHER COMPREHENSIVE INCOME

    During 2001, the value of the assets in the Company's pension plan declined, reflecting the general downward trend in common stock values. The decline in asset values resulted in an unfunded accumulated benefit obligation. To recognize this liability, the Company recorded a minimum pension liability adjustment in accordance with the provisions of Statement of Financial Accounting Standards No. 87. This adjustment included a $6,502,000 charge to other comprehensive income. Other comprehensive income also includes a $2,341,000 credit for the income tax benefit resulting from the charge.

LIQUIDITY AND CAPITAL RESOURCES

    The seasonal nature of the Company's business creates short-term cash requirements to finance customer accounts receivable and construction expenditures. Increases in wholesale natural gas prices may also result in short-term cash requirements to finance purchases of gas for resale to customers. To

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provide working capital for these requirements, the Company has a $50 million bank revolving credit commitment. This agreement has an annual 0.16% commitment fee with a term that expires in 2004. The Company also has $35 million of uncommitted lines from three banks. As of September 30, 2001, there was $40 million outstanding under the committed and uncommitted lines.

    To provide longer-term financing, the company has registrations under the Securities Act of 1933 providing ability to issue up to $125 million of new debt and equity securities. Of this amount, $15 million of Medium-Term Notes is available for issuance under one registration statement. The Company has an omnibus registration, providing flexibility to issue $150 million in new debt and equity securities. On November 26, 2001, the Company issued $40 million new long-term debt under the omnibus registration, leaving $110 million available under that registration for future financing. The $40 million proceeds were used to replace outstanding short-term debt.

OPERATING ACTIVITIES

    For fiscal 2001, operating activities resulted in a net use of cash of $7,996,000, compared to positive cash flow of $32,256,000 for 2000. This represents more than a $40 million difference in operating cash flow between the two years. This difference is due to higher costs of natural gas purchases not passed through to customers, but deferred. For the year, under-recovery of gas cost, including amortization of prior deferrals, was $43.9 million. In 2000, there was an over-recovery of $2.8 million.

    Wholesale gas prices reached unprecedented high levels in the Northwest during the 2000 - 2001 winter heating season. Effective January 12, 2001, the WUTC approved the Company's request to increase customer rates to recover higher gas costs. In its request to the WUTC, the Company chose to minimize the burden on customers, and not pass through all gas cost increases immediately. The Company experienced substantial under-recoveries during the March quarter, but by the end of that quarter, wholesale prices had declined to a level roughly equivalent to the amount in customer rates. The Company has subsequently entered into agreements with its major suppliers to lock in prices for a three-year period for most of its core supply requirements.

    Effective November 1, 2001, the WUTC approved new rates for Washington customers. The new rates reflect a surcharge to recover the deferred gas cost charges over a three-year period. This arrangement is expected to add cash flow of approximately $10 million per year for the three years, as well as stabilize rates for customers for that period.

INVESTING ACTIVITIES

    Cash used by investing activities in 2001 was $21,549,000, compared to $15,302,000 in 2000. Investing activities are substantially all capital expenditures, which were $3.8 million lower than budget for 2001. Postponement of a major reinforcement project was the major factor in lower than budgeted expenditures. Contributing to the increase over 2000 was $4.5 million spent to install a new integrated work management system.

    Budgeted capital expenditures for fiscal 2002 are approximately $22.8 million, which includes $19 million for new customer connections and distribution system reinforcement and replacement projects. The remainder is for equipment, facilities upgrades, and various technology projects.

FINANCING ACTIVITIES

    Financing activities for 2001 provided $27,835,000, compared to a use of $15,232,000 for 2000. Other than the payment of dividends, the primary financing activity in 2001 was the $38.5 million increase in short-term debt to fund operating activities and capital expenditures.

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ENVIRONMENTAL MATTERS

    In 1995, the Company received a claim from a property owner in Eugene, Oregon requesting that the Company assume responsibility for investigation and possible clean up of alleged contamination on property previously owned by a predecessor of Cascade. The predecessor company conducted a manufactured gas business on the property from approximately 1929 to 1948. Manufactured gas operations apparently were conducted on the site by several operators beginning about 1907. The site was used for other purposes beginning in 1949.

    The present owner has retained an environmental consultant, which is investigating possible contamination on the property. To date the consultant has reported that it believes contamination is present. The contamination is consistent with that which might originate from a manufactured gas operation. There have been no estimates as to possible clean up costs. The consultant's initial report has been furnished to the Oregon Department of Environmental Quality (DEQ). The owner has reached an intergovernmental agreement with the DEQ with respect to further investigation and possible remediation of contamination on the property under the voluntary cleanup program.

    Another northwest utility, which purchased the property from Cascade in 1958, has declined to participate in the site investigation, although it may, as a onetime owner of the property, bear some share of the responsibility as well.

    The Company has notified its insurance carriers of the claim and is keeping them advised as to the investigation. On one occasion in the past when hazardous materials on property formerly owned by a predecessor of the Company required clean up, the OPUC allowed the clean up costs to be passed on to customers. In the event the Company is responsible for clean up costs not covered by insurance, management anticipates asking for reimbursement through rates for such costs.

    In 1997, a property owner in Washington notified the Company that there is contamination on his property, and that he believes it comes from a former manufactured gas site, owned at one time by a predecessor company, which was merged with Cascade in 1953. The State of Washington Department of Ecology has categorized this site as a "listed site" ranked in its most hazardous category. As a former owner of the site, the Company may be strictly liable to the State of Washington for investigation and remediation of the contamination of the site, but may share that cost or allocate all the cost to others who actually caused or contributed to the contamination.

    The Company retained an environmental consultant who conducted a preliminary investigation of possible contamination at the site. There is evidence of contamination at the site, and there is also evidence of an oil line across the site property owned and operated by others, which may be a contributor to the contamination. There have been no estimates as to possible clean up costs. The Company has investigated title and other government records to identify other potentially liable parties. The Company has notified the other identified parties of the contamination claims, and has requested cooperation and financial contribution.

    In the event the Company is responsible for clean up costs not covered by insurance, management anticipates asking the WUTC for reimbursement for such costs, through rates charged to customers.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

    Cascade has evaluated its risk related to financial instruments whose values are subject to market sensitivity. The Company has fixed-rate debt obligations, but does not have derivative financial instruments subject to interest rate risk. Cascade makes interest and principal payments on these obligations in the normal course of its business, and does not plan to redeem these obligations prior to normal maturities.

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    The Company's natural gas purchase commodity prices are subject to fluctuations resulting from weather, congestion on interstate pipelines, and other unpredictable factors. The Company's PGA mechanisms assure the recovery of prudently incurred wholesale gas cost, therefore management believes the Company's commodity price risk is immaterial.

FORWARD-LOOKING STATEMENTS

    Statements contained in this report that are not historical in nature are forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements are subject to risks and uncertainties that may cause actual future results to differ materially. Such risks and uncertainties with respect to the Company include, among others, its ability to successfully implement internal performance goals, competition from alternative forms of energy, consolidation in the energy industry, performance issues with key natural gas suppliers, the capital-intensive nature of the Company's business, regulatory issues, including the need for adequate and timely rate relief to recover increased capital and operating costs resulting from customer growth and to sustain dividend levels, the weather, increasing competition brought on by deregulation initiatives at the federal and state regulatory levels, the potential loss of large volume industrial customers due to "bypass" or the shift by such customers to special competitive contracts at lower per unit margins, exposure to environmental cleanup requirements, and economic conditions, particularly in the Company's service area.

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Item 8.  Financial Statements and Supplementary Data

INDEPENDENT AUDITORS' REPORT

Board of Directors
Cascade Natural Gas Corporation
Seattle, Washington

    We have audited the accompanying consolidated balance sheets of Cascade Natural Gas Corporation and subsidiaries (the Corporation) as of September 30, 2001 and 2000, and the related consolidated statements of income and comprehensive income, common shareholders' equity, and cash flows for each of the three years in the period ended September 30, 2001. Our audits also included the financial statement schedule listed in Item 14(a)2. These financial statements and financial statement schedule are the responsibility of the Corporation's management. Our responsibility is to express an opinion on the financial statements and financial statement schedule based on our audits.

    We conducted our audits in accordance with auditing standards generally accepted in the United States of America. 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, such consolidated financial statements present fairly, in all material respects, the financial position of Cascade Natural Gas Corporation and subsidiaries as of September 30, 2001 and 2000, and the results of their operations and their cash flows for each of the three years in the period ended September 30, 2001, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, such financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly in all material respects the information set forth therein.

Deloitte & Touche LLP
Seattle, Washington
November 9, 2001

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CASCADE NATURAL GAS CORPORATION
CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME

				Year Ended September 30,
				2001			2000			1999
				(Dollars in thousands except per share data)
Operating Revenues				$	335,814		$	241,936		$	208,610
	Less
		Gas purchases			219,795			136,681			109,263
		Revenue taxes			20,987			15,261			13,280
Operating Margin					95,032			89,994			86,067
Cost of Operations
	Operating expenses				39,182			36,970			36,313
	Depreciation and amortization				13,839			13,293			12,841
	Property and payroll taxes				5,027			4,734			4,574
					58,048			54,997			53,728
	Income from operations				36,984			34,997			32,339
Nonoperating Expense (Income)
	Interest				10,509			10,936			10,486
	Interest charged to construction				(333	)		(322	)		(383	)
					10,176			10,614			10,103
	Amortization of debt issuance expense				607			607			603
	Other				(313	)		(649	)		(495	)
					10,470			10,572			10,211
Income Before Income Taxes					26,514			24,425			22,128
Income Taxes					9,278			9,051			8,075
Net Income Before Preferred Dividends					17,236			15,374			14,053
Preferred Dividends					—			4			483
Net Income				$	17,236		$	15,370		$	13,570
Other Comprehensive Income (Loss), Net of Tax Minimum pension liability adjustment ($6,502, net of $2,341 income tax effect)					(4,161	)		—			—
Comprehensive Income				$	13,075		$	15,370		$	13,570
Earnings Per Common Share, Basic and Diluted				$	1.56		$	1.39		$	1.23

The accompanying notes are an integral part of these financial statements

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CASCADE NATURAL GAS CORPORATION

CONSOLIDATED BALANCE SHEETS

			September 30,
			2001			2000
			(Dollars in thousands)
ASSETS
Utility Plant			$	488,231		$	468,789
	Less accumulated depreciation			201,530			189,058
				286,701			279,731
	Construction work in progress			7,485			5,113
				294,186			284,844
Other Assets
	Investments in non utility property			202			202
	Notes receivable, less current maturities			311			411
				513			613
Current Assets
	Cash and cash equivalents			422			2,132
	Accounts receivable and current maturities of notes receivable, less allowance of $1,421 and $1,224 for doubtful accounts			18,865			21,073
	Materials, supplies, and inventories			8,870			6,238
	Prepaid expenses and other assets			3,783			6,497
	Deferred income taxes			559			482
				32,499			36,422
Deferred Charges
	Gas cost changes			28,861			—
	Other			8,194			6,457
				37,055			6,457
			$	364,253		$	328,336
COMMON SHAREHOLDERS' EQUITY, PREFERRED STOCKS, AND LIABILITIES
Common Shareholders' Equity
	Common stock, par value $1 per share; Authorized, 15,000,000 shares Issued and outstanding, 11,045,095 shares		$	11,045		$	11,045
	Additional paid-in capital			97,380			97,380
	Accumulated other comprehensive income (loss)			(4,161	)		—
	Retained earnings			17,369			10,736
				121,633			119,161
Redeemable Preferred Stocks, aggregate redemption amount of $0 and $73				—			62
Long-Term Debt				125,000			125,000
Current Liabilities
	Notes payable and commercial paper			40,000			1,500
	Accounts payable			13,466			14,741
	Property, payroll, and excise taxes			4,921			4,509
	Dividends and interest payable			7,539			7,525
	Other current liabilities			6,426			5,060
				72,352			33,335
Deferred Credits and Other
	Gas cost changes			—			15,047
	Income taxes			19,649			21,249
	Investment tax credits			1,896			2,100
	Other			23,723			12,382
				45,268			50,778
Commitments and Contingencies (Note 12)				—			—
			$	364,253		$	328,336

The accompanying notes are an integral part of these financial statements

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CASCADE NATURAL GAS CORPORATION

CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY

				Common Stock								Accumulated Other Comprehensive Income (Loss)
									Paid-In Capital						Retained Earnings
				Shares		Par Value
				(Dollars in thousands except per share data)
Balance, September 30, 1998				11,045,095		$	11,045		$	97,380		$	—		$	3,003
	Cash dividends:
		Common stock, $.96 per share														(10,603	)
		Preferred stock, senior, $.55 per share														(12	)
		7.85% cumulative preferred stock, $7.85 per share														(471	)
	Net Income Before Preferred Dividends															14,053
Balance, September 30, 1999				11,045,095		$	11,045		$	97,380		$	—		$	5,970
	Cash dividends:
		Common stock, $.96 per share														(10,604	)
		Preferred stock, senior, $.55 per share														(4	)
	Net Income Before Preferred Dividends															15,374
Balance, September 30, 2000				11,045,095		$	11,045		$	97,380		$	—		$	10,736
	Cash dividends:
		Common stock, $.96 per share														(10,603	)
	Other comprehensive income (loss)												(4,161	)
	Net Income Before Preferred Dividends															17,236
Balance, September 30, 2001				11,045,095		$	11,045		$	97,380		$	(4,161	)	$	17,369

The accompanying notes are an integral part of these financial statements

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CASCADE NATURAL GAS CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

				Year Ended September 30,
				2001			2000			1999
				(Dollars in thousands)
Operating Activities
	Net Income Before Preferred Dividends			$	17,236		$	15,374		$	14,053
	Adjustments to reconcile net income before preferred dividends to net cash provided by operating activities:
		Depreciation and amortization			13,839			13,293			12,841
		Deferrals of gas cost changes			(40,801	)		1,298			818
		Amortization of gas cost changes			(3,108	)		1,539			1,062
		Other deferrals and amortizations			3,706			2,310			2,359
		Deferred income taxes and tax credits—net			1,403			783			2,373
		Other			—			(212	)		(174	)
		Change in current assets and liabilities			(271	)		(2,129	)		(5,154	)
	Net cash provided (used) by operating activities				(7,996	)		32,256			28,178
Investing Activities
	Capital expenditures				(23,829	)		(18,252	)		(19,942	)
	Customer contributions in aid of construction				2,180			2,315			2,680
	Other				100			635			1,155
	Net cash used by investing activities				(21,549	)		(15,302	)		(16,107	)
Financing Activities
	Redemption of preferred stock				(62	)		(6,124	)		(222	)
	Proceeds from long-term debt, net				—			—			14,888
	Repayment of long-term debt				—			—			(10,650	)
	Changes in notes payable and commercial paper, net				38,500			1,500			(6,929	)
	Dividends paid				(10,603	)		(10,608	)		(11,086	)
	Net cash provided (used) by financing activities				27,835			(15,232	)		(13,999	)
Net Increase (Decrease) in Cash and Cash Equivalents					(1,710	)		1,722			(1,928	)
Cash and Cash Equivalents
	Beginning of year				2,132			410			2,338
	End of year			$	422		$	2,132		$	410

The accompanying notes are an integral part of these financial statements

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Notes to Consolidated Financial Statements

Note 1—Nature of Business

    Cascade Natural Gas Corporation (the Company) is a local distribution company (LDC) engaged in the distribution of natural gas. The Company's service territory consists of towns in Washington and Oregon, ranging from the Canadian border in northwestern Washington to the Idaho border in eastern Oregon.

    As of September 30, 2001, the Company had approximately 190,653 core customers and 171 non-core customers. Core customers are principally residential and small commercial and industrial customers who take traditional "bundled" natural gas service, which includes supply, peaking service, and upstream interstate pipeline transportation. Sales to core customers account for approximately 16% of gas deliveries and 68% of operating margin. The Company's sales to its core residential and commercial customers are influenced by fluctuations in temperature, particularly during the winter season. A warm winter season will tend to reduce gas consumption. Over the longer term, these fluctuations tend to offset each other, as rates charged to customers are developed based on the assumption of normal weather.

    Non-core customers are generally large industrial and institutional customers who have chosen "unbundled" service, meaning that they select from among several supply and upstream pipeline transportation options, independent of the Company's distribution service. The Company's margin from non-core customers is derived primarily from this distribution service. The principal industrial activities of its customers include the generation of electricity, processing of food, processing of forest products, production of chemicals, refining of crude oil, and production of aluminum.

    The Company is subject to regulation of most aspects of its operations by the Washington Utilities and Transportation Commission (WUTC) and the Oregon Public Utility Commission (OPUC). It is subject to regulatory risk primarily with respect to recovery of costs incurred. Various deferred charges and deferred credits reflect assumptions regarding recovery of certain costs through temporary customer rate adjustments during future periods.

Note 2—Summary of Significant Accounting Policies

    The Company's accounting records and practices conform to the requirements and uniform system of accounts prescribed by the WUTC and the OPUC.

    Principles of consolidation:  The consolidated financial statements include the accounts of Cascade Natural Gas Corporation and its wholly owned subsidiaries: Cascade Land Leasing Co.; CGC Properties, Inc.; CGC Energy, Inc.; and CGC Resources, Inc. All intercompany transactions are eliminated in consolidation.

    Utility plant:  Utility plant is stated at the historical cost of construction or purchase. These costs include payroll-related costs such as taxes and other employee benefits, general and administrative costs, and the estimated cost of funds used during construction. Maintenance and repairs of property, and replacements and renewals of items deemed to be less than units of property, are charged to operations. Units of utility plant retired or replaced are credited to property accounts at cost. Such amounts plus removal cost, less salvage, are charged to accumulated depreciation. In the case of a sale of non-depreciable property or major operating units, the resulting gain or loss on the sale is included in other income or expense.

    Depreciation of utility plant is computed using the straight-line method. The Company periodically conducts depreciation studies to establish and update asset depreciation lives. Asset lives used for computing depreciation range from six to seventy years, and the weighted average annual depreciation

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rate is approximately 3.0%. The Company periodically reviews the carrying amount of its utility plant and other long-lived assets for impairment. An asset is considered impaired when estimated future cash flows are less than the carrying amount of the asset. In the event the carrying amount of such asset is deemed not recoverable, the asset is adjusted to its fair value. Fair value is generally determined based on discounted future cash flow.

    Investments in non-utility property:  Real estate, carried at the lower of cost or estimated net realizable value is the primary investment.

    Notes receivable:  Notes receivable includes loans made to customers for the purchase of energy efficient appliances, which are generally the security for the loan. The loans have terms ranging from one to ten years at interest rates varying from 6.5% to 12%. Current maturities include a note receivable from one industrial customer.

    Cash and cash equivalents:  For purposes of reporting cash flows, the Company accounts for all liquid investments, with a purchased maturity of three months or less, as cash equivalents. The following provides additional information to the Consolidated Statements of Cash Flows:

    Materials, supplies and inventories:  Materials and supplies for construction, operations, and maintenance, and inventories of natural gas are recorded at cost.

    Regulatory accounts:  The Company's financial statements are prepared in accordance with Statement of Financial Accounting Standards (FAS) No. 71, "Accounting for the Effects of Certain Types of Regulation". This statement provides for the deferral of certain costs and benefits that would otherwise be recognized in revenue or expense, if it is probable that future rates will result in recovery from customers or refund to customers of such amounts.

    Regulatory assets (liabilities) at September 30, 2001 and 2000 include the following:

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    Effective November 1, 2001, the WUTC approved new rates for Washington customers, that include a surcharge to recover the balance of deferred gas cost charges over a three year period, at approximately $10 million per year.

    Revenue recognition:  The Company recognizes operating revenues based on deliveries of gas to customers. This includes estimated revenues for gas delivered but not billed to residential and commercial customers from the latest meter reading date to the end of the accounting period.

    Leases:  The Company leases a majority of its vehicle fleet. These leases are classified as operating leases. The Company's primary obligation under these leases is for a twelve-month period, with options to extend the lease thereafter. Commitments beyond one year are not material. Rent expense under operating leases totaled $980,000, $919,000, and $921,000 for fiscal years ended September 30, 2001, 2000, and 1999, respectively.

    Federal income taxes:  The Company normalizes temporary differences between book income and taxable income, with the exception of depreciation differences on assets placed in service prior to 1981, consistent with the policies of the WUTC and OPUC. Deferred income taxes are determined using the asset and liability method, under which deferred tax assets and liabilities are measured based upon the temporary differences between the financial statement and income tax bases of assets and liabilities, using current tax rates.

    Investment tax credits:  Investment tax credits were deferred and are amortized over the remaining lives of the properties that gave rise to the credits.

    Use of estimates:  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 these estimates. The Company has used estimates in measuring certain deferred charges and deferred credits related to items subject to approval of the WUTC and the OPUC. Estimates are also used in the development of discount rates and trend rates related to the measurement of retirement benefit obligations and accrual amounts, allowances for doubtful accounts, and in the determination of depreciable lives of utility plant.

    Stock-Based Compensation:  Compensation cost for stock options is measured as the excess of the market price of the Company's stock at the date of the grant over the price the employee must pay to acquire the stock. The Company accounts for its stock-based compensation using the intrinsic value method prescribed in Accounting Principles Board Opinion No. 25, "Accounting for Stock Issued to Employees" rather than using the fair-value-based method prescribed under FAS No. 123, "Accounting for Stock-Based Compensation." The Company has adopted the disclosure requirements of FAS No. 123. See Note 6 for more information about the Company's stock-based compensation plan.

    Comprehensive Income (Loss):  Comprehensive income for the fiscal year ended September 30, 2001, included a charge to Other Comprehensive Income in the amount of $4,161,000 net of income tax. The charge is related to a minimum pension liability adjustment. See Note 11 for more information. Comprehensive income for fiscal years ended September 30, 2000, and 1999 was equal to the Company's net income.

    Segment Reporting:  Management views the Company as operating as a single segment, that of a local distribution company in the Pacific Northwest. Therefore the financial statements do not include disclosure of segment information.

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New Accounting Standards:

    FAS Nos. 133 and 138.  As of the first quarter of fiscal 2001, the Company adopted Statement of Financial Accounting Standards (FAS) No. 133, titled "Accounting for Derivative Instruments and Hedging Activities", as amended by FAS No. 138, "Accounting for Certain Derivative Instruments and Certain Hedging Activities". These standards require that the fair value of all derivative financial instruments be recognized as either assets or liabilities on the Company's balance sheet. Changes during a period in the fair value of a derivative instrument would be included in earnings or other comprehensive income for the period.

    The Company has reviewed its various contractual arrangements to determine applicability of the standards, and has concluded only certain of its natural gas purchase contracts meet the criteria for definition of derivative assets or liabilities. The contracts to which the standard is applicable generally do not qualify for the "normal purchases and sales" exemption because they contain fixed-price and option provisions. These contracts are short-term in nature and have minimal fixed price components. For these contracts, the Company recorded a derivative asset of $205,000 and a derivative liability of $84,000, representing the values as of the October 1, 2000 date of adoption of the standard. The majority of contracts for the purchase, sale, transportation and storage of natural gas constitute "normal purchases and sales" under FAS Nos. 133 and 138, and as such, they are not subject to the accounting requirements of the new standards.

    Generally, gains or losses resulting from the eventual settlement of these contracts are subject to deferral under the Company's tariffs with the Washington Utilities and Transportation Commission and Oregon Public Utility Commission. Therefore, related derivative assets and liabilities are offset with corresponding regulatory liability and asset amounts included in "Other Deferred Credits" and "Deferred Charges", pursuant to FAS No. 71. Thus, as gains and losses on contracts in place as of October 1, 2000 were subject to deferral, the adoption of FAS Nos. 133 and 138 had no impact on net income. Gains and losses on contracts not subject to deferral are recognized currently. As of and for the year ended September 30, 2001, natural gas purchase contracts required to be accounted for as derivatives under FAS Nos. 133 and 138 had an insignificant impact on the financial position and results of operations.

    In March, 2001, the Financial Accounting Standards Board approved the Derivative Implementation Group (DIG) Issue C-10, Scope Exceptions: Can Option Contracts and Forward Contracts with Optionality Features Qualify for the Normal Purchases and Normal Sales Exception, which states that derivative contracts containing volumetric optionality can not constitute "normal purchases and sales." The Company adopted the provisions of DIG Issue C-10 beginning July 1, 2001. Based on natural gas purchase contracts in place as of July 1, adoption of DIG Issue C-10 had an insignificant impact on the financial position and results of operations.

    During fiscal 2001, the Company entered into a contract for pipeline capacity unrelated to its regulated natural gas distribution operations. As of September 30, 2001, the value of this derivative asset was $87,000.

    FAS No. 141.  The FASB has issued FAS No. 141, titled "Business Combinations", effective July 1, 2001. This statement prescribes that business combinations initiated after June 30, 2001, be accounted for using one method, the purchase method. Implementation of this standard has no impact on Cascade's financial statements.

    FAS No. 142.  The FASB has issued FAS No. 142, titled "Goodwill and Other Intangible Assets." This standard is effective for fiscal years beginning after December 15, 2001. Management believes adoption of this standard will not have a significant impact on the Company's financial statements.

26

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    FAS No. 143.  The FASB has issued FAS No. 143, titled "Accounting for Asset Retirement Obligations." This standard is effective for fiscal years beginning after June 15, 2002. The Company is assessing whether this statement will have a significant impact on its financial statements.

    FAS No. 144.  The FASB has issued FAS No. 144, titled "Accounting for the Impairment or Disposal of Long-Lived Assets." This standard is effective for fiscal years beginning after December 15, 2001. The Company is assessing whether this statement will have a significant impact on its financial statements.

Note 3—Earnings per Share

    The following table sets forth the calculation of earnings per share as prescribed in FAS No. 128.

    The only dilutive securities are the stock options described in Note 6.

Note 4—Utility Plant

    Utility plant at September 30, 2001 and 2000 consists of the following components:

Note 5—Common Stock

    At September 30, 2001, shares of common stock are reserved for issuance as follows:

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    The price of shares issued to the above plans is determined by the market price of shares on the day of, or immediately preceding the issuance date. The Company's practice is to purchase shares on the open market for these plans rather than issue new shares.

    Holders of Common Stock have rights ("Rights") to purchase shares of Series Z Preferred Stock on the basis of one Right for each share of Common Stock. The Rights may not be exercised and will be attached to and trade with shares of Common Stock until the Distribution Date, which will occur on the earlier of (i) the tenth day following a public announcement that there has been a "Share Acquisition", i.e., that a person or group (other than the Company and certain other persons) has acquired or obtained the right to acquire 20% or more of the outstanding Common Stock and (ii) the tenth business day following the commencement or announcement of certain offers to acquire beneficial ownership of 30% or more of the outstanding Common Stock. Subject to restrictions on exercisability while the Rights are redeemable, each Right entitles the holder to buy from the Company one one-hundredth of a share of Series Z Preferred Stock at a price of $85, subject to adjustment. Upon the occurrence of a Share Acquisition, and provided that all necessary regulatory approvals have been obtained, each Right will thereafter entitle the holder (other than the acquiring person or group and transferees) to buy from the Company for $85, shares of Common Stock having a market value of $170, subject to adjustment.

Note 6—Stock Compensation Plan

    Under the Company's stock incentive plan, officers and other key management employees may be granted options to purchase stock. The grants vest ¹/3 per year over three years, and expire five years after the grant date. The weighted average remaining life of options outstanding at September 30, 2001 is 4.1 years.

    The following table summarizes the grants under option at September 30:

		2001					2000					1999
		Wtd. Avg. Exercise Price			No. Shares Under Option		Wtd. Avg. Exercise Price			No. Shares Under Option		Wtd. Avg. Exercise Price			No. Shares Under Option
Balance at October 1		$	15.90		91,100		$	16.50		38,000		$	—		—
Options granted		$	18.57		58,900		$	14.94		53,100		$	16.50		38,000
Options exercised		$	15.63		6,033		$	—		—		$	—		—
Balance at September 30		$	16.81		143,967		$	15.90		91,100		$	16.50		38,000
Exercisable at September 30		$	15.86		43,033		$	16.50		12,667			none		none
Weighted average fair value of options granted during the fiscal year		$	2.90				$	2.56				$	2.44

    As of September 30, 2001, no options under the plan have expired or been cancelled. The fair value was estimated at the date of the grants using a Black-Scholes option pricing model using the following assumptions:

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    The Company accounts for stock-based compensation using APB Opinion No. 25, "Accounting for Stock Issued to Employees". Under this method, compensation cost is recognized on the excess, if any, of the market price of the stock at grant date over the exercise price of the option. The exercise price of each grant was equal to the market price at the respective grant date, therefore no compensation expense has been recorded in connection with the Plan. Under FAS No. 123, "Accounting for Stock-Based Compensation," compensation expense is determined based on the fair value of the award and is recognized over the vesting period. Had compensation expense been determined in accordance with FAS 123, the Company's net income would have been as follows:

Note 7—Redeemable Preferred Stocks

    As of September 30, 2001, the Company has no preferred stock. As of September 30, 2000, there were 7,250 shares of $0.55 Cumulative Senior Preferred Stock, Series C, which was fully redeemed in November 2000 for $73,000.

Note 8—Notes Payable and Commercial Paper

    The Company's short-term borrowing needs are met with a $50,000,000 revolving credit agreement with one of its banks. This agreement has an annual 0.16% commitment fee with a term that expires in 2004. The Company also has $35,000,000 of uncommitted lines from three banks.

    Various debt and credit agreements restrict the Company and its subsidiaries as to indebtedness, payment of cash dividends on common stock, and other matters. Under the most conservative restriction, approximately $12,668,000 is available for payment of dividends as of September 30, 2001.

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Note 9—Long-Term Debt

    Long-term debt at September 30, 2001 and 2000 consists of the following:

    None of the long-term debt includes sinking fund requirements. Annual obligations for redemption of long-term debt are as follows: None in fiscal years 2002 through 2003, $22,000,000 in fiscal year 2004, $14,000,000 in fiscal year 2005, none in fiscal year 2006, and $89,000,000 thereafter.

    A Medium-Term Note program provides longer term financing with $125 million outstanding at September 30, 2001. There is $15 million remaining registered under the Securities Act of 1933 and available for issuance of Medium-Term Notes. The Company has an additional shelf registration providing ability to issue up to $150 million new long-term debt and equity securities.

Note 10—Income Taxes

    The provision for income tax expense consists of the following:

    A $2,341,000 tax benefit associated with a charge related to accrual of minimum pension liability has been recorded in Other Comprehensive Income for the year ended September 30, 2001. See Note 11 for more information.

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    A reconciliation between income taxes calculated at the statutory federal tax rate and income taxes reflected in the financial statements is as follows:

    Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. There is no deferred tax provision for temporary differences related to depreciation of pre-1981 assets because with respect to those assets, there is no regulatory recognition of deferred tax accounting.

    Deferred tax assets and liabilities are calculated under FAS No. 109, "Accounting for Income Taxes". FAS No. 109 requires recording deferred tax balances, at the currently enacted tax rate, for all temporary differences between the book and tax bases of assets and liabilities, including temporary differences for which no deferred taxes had been previously provided because of use of flow-through tax accounting for ratemaking purposes. Because of prior and expected future ratemaking treatment of temporary differences for which flow-through accounting has been utilized, a regulatory liability for income taxes payable through future rates related to those temporary differences has been established. At September 30, 2001, the balance of this regulatory liability is $4,769,000.

    The tax effects of significant items comprising the Company's net deferred tax liability at September 30, 2001 and 2000 are as follows:

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Note 11—Retirement Plans

    The Company's noncontributory defined benefit pension plan covers substantially all employees over 21 years of age with one year of service. The benefits are based on a formula which includes credited years of service and the employee's annual compensation. The Company's policy is to fund the plan by contributing an amount equal to the actuarially determined normal cost plus ten-year amortization payments towards the unfunded actuarial liability, subject to the limits on deductible contributions. The Company also provides executive officers with supplemental retirement, death, and disability benefits. Under the plan, vesting occurs on a stepped basis, with full vesting at age 55 and completing either five years of participation under the plan or seventeen years of employment with the Company, upon death, or upon a change in control. The plan supplements the benefit received through Social Security and the defined benefit pension plan so that the total retirement benefits are equal to 70% of the executive's highest salary during any of the five years preceding retirement. The plan also provides a death benefit equivalent to ten years of vested benefits. The Company funds the plan by making contributions to the Trust sufficient to assure assets held by the Trust always exceed the accumulated benefit obligation for benefits payable by the plan.

    The Company's health care plan provides Postretirement Benefits Other than Pensions (PBOP), consisting of medical and prescription drug benefits, to its retired employees hired prior to June 1, 1992, and their eligible dependents. The Company's policy is generally to fund the plan to the extent allowable under Internal Revenue Service rules.

    The pension plan was amended, effective January 1, 2000, so that for salaried employees, the past service benefit calculation was changed to the five-year period ended December 31, 1998 from the five-year period ended December 31, 1994. In fiscal 2001, the retiree medical plan was amended to increase the amount of health care and prescription drugs costs paid by plan participants.

    The special termination benefit for the retirement plan represents the recognition of the increase in the projected benefit obligation for five employees that retired in fiscal 1999.

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    The following tables set forth the pension and health care plan disclosures:

		Pension Benefits									Other Benefits
		2001			2000			1999			2001			2000			1999
Components of net periodic benefit cost
Service cost		$	1,928		$	1,765		$	1,784		$	484		$	469		$	434
Interest cost			3,373			3,187			2,838			1,949			1,739			1,316
Expected return on plan assets			(4,171	)		(3,841	)		(3,346	)		(903	)		(833	)		(699	)
Amortization of transition obligation			100			102			106			657			657			657
Amortization of prior service cost			500			481			424			—			—
Recognized net actuarial loss / (gain)			—			1			41			(124	)		(218	)		(341	)
Special termination benefit			—			—			210			—			—			—
Net periodic benefit cost		$	1,730		$	1,695		$	2,057		$	2,063		$	1,814		$	1,367

 

			Pension Benefits						Other Benefits
			2001			2000			2001			2000
			(dollars in thousands)
Change in benefit obligations
Projected benefit obligation at beginning of year			$	44,407		$	40,887		$	24,401		$	18,280
Service Cost				1,928			1,765			484			469
Interest Cost				3,373			3,188			1,949			1,739
Plan participants' contributions				—			—			—			25
Amendments				4			1,015			(827	)		—
Benefits paid				(1,920	)		(1,928	)		(1,264	)		(821	)
Changes in assumptions				2,356			65			—			—
Actuarial (gain)/loss				(748	)		(585	)		4,523			4,709
Projected benefit obligation at end of year			$	49,400		$	44,407		$	29,266		$	24,401
Change in Plan Assets
Fair value of plan assets at beginning of year			$	48,299		$	41,854		$	10,280		$	9,514
Actual return on plan assets				(8,250	)		6,104			(1,188	)		736
Employer contributions				2,437			2,269			867			826
Plan participants' contributions				—			—			—			25
Benefits Paid				(1,920	)		(1,928	)		(1,264	)		(821	)
Fair value of plan assets at end of year			$	40,566		$	48,299		$	8,695		$	10,280
Funded Status			$	(8,834	)	$	3,891		$	(20,571	)	$	(14,121	)
Unrecognized prior service cost				3,004			3,499			(827	)		—
Unrecognized net (gain)/loss				11,429			(2,599	)		9,964			3,226
Unrecognized transition obligation/(asset)				526			627			7,391			8,048
Net amount recognized			$	6,125		$	5,418		$	(4,043	)	$	(2,847	)
Amounts recognized in the balance sheet consist of:
	Prepaid pension cost		$	3,047		$	5,418		$	—		$	—
	Accrued pension (liability)			(6,569	)		—			(4,043	)		(2,847	)
	Intangible asset			3,145			—			—			—
	Accumulated other comprehensive income (loss)			6,502			—			—			—
	Net amount recognized		$	6,125		$	5,418		$	(4,043	)	$	(2,847	)

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    The assumed health care cost trend rate used in measuring the APBO at September 30, 2001 for medical costs is 8.0% for fiscal 2002, trending down to 5.5% in 2007. For prescription drug costs, the rate is 11.0% for 2002, trending down to 5.5% in 2013. A one percent change in the assumed health care cost trend rate would have the following effects as of September 30, 2001:

		One Percentage Point
		Increase			Decrease
		(thousands)
Effect on service and interest cost		$	423		$	(343	)
Effect on postretirement benefit obligation as of 10/1/2000		$	3,871		$	(3,191	)
Effect on postretirement benefit obligation as of 9/30/2001		$	4,449		$	(3,667	)

    During fiscal 2001, the value of the pension plan assets declined, reflecting the general downward trend in common stock values. The decline in asset values resulted in an unfunded accumulated benefit obligation. To recognize this liability, the Company recorded a minimum pension liability adjustment in accordance with the provisions of FAS No. 87. This adjustment included a reversal of a $3,078,000 prepaid pension asset, recording a pension liability of $6,569,000, establishment of an intangible asset account of $3,145,000, and a charge to other comprehensive income of $4,161,000, net of tax.

    The Company has an Employee Savings Plan and Retirement Trust (401(k) plan). All employees 21 years of age or older with one full year of service are eligible to enroll in the plan. Under the terms of the plan, the Company will match contributions at a rate of 75% of each employee's contribution up to 6% of the employee's compensation, as defined. The Company recognized costs for contributions to this plan of $842,000, $889,000, and $810,000, for 2001, 2000 and 1999, respectively.

Note 12—Commitments and Contingencies

Gas Service Contracts

    The Company has entered into various long-term contracts for natural gas supply, transportation, storage, and peaking services. These contracts assure that adequate supplies of gas will be available to provide firm service to core customers and to meet obligations under long-term non-core customer agreements, and to assure that adequate capacity is available on interstate pipelines for the delivery of these supplies. These contracts have maturities ranging up to 25 years, and generally provide for monthly and annual fixed demand charges and minimum purchase obligations.

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    The Company's minimum obligations under these contracts are set forth in the following table. The amounts are based on current contract price terms and estimated commodity prices, which are subject to change:

Fiscal Year Ending September 30		Firm Gas Supply			Interstate Pipeline Transportation			Storage and Peaking Service			Total
		(dollars in thousands)
2002		$	133,135		$	25,273		$	2,414		$	160,822
2003			111,301			25,273			1,765			138,339
2004			109,288			25,273			1,765			136,326
2005			9,755			25,273			1,765			36,793
2006			6,929			25,273			1,765			33,967
Thereafter			14,435			209,405			14,119			237,959
		$	384,843		$	335,770		$	23,593		$	744,206

    Purchases under these contracts for fiscal 2001, 2000, and 1999, including commodity purchases, as well as demand charges have been as follows:

		Firm Gas Supply			Interstate Pipeline Transportation			Storage and Peaking Service			Total
		(dollars in thousands)
2001		$	166,912		$	35,276		$	3,030		$	205,218
2000		$	69,168		$	31,852		$	3,423		$	104,443
1999		$	60,231		$	30,224		$	3,786		$	94,241

Environmental Matters

    There are two claims against the Company for as yet unknown costs for clean up of alleged environmental contamination related to manufactured gas plant sites that were previously operated by companies, which were subsequently merged into Cascade.

    The first claim was received in 1995, and relates to a site in Oregon. An investigation has shown that contamination does exist, but there is currently not enough information available to estimate the potential liability associated with this claim. It is expected that other parties will participate in the clean up costs, and negotiations are ongoing as to the sharing arrangement. Through the end of the fiscal year the amounts spent, primarily on investigation and containment, have been immaterial.

    The second claim was received in 1997, and relates to a site in Washington. An investigation has determined there is evidence of contamination at the site, but there is also evidence of an oil line crossing the property, operated by an unrelated party, which may have also contributed to the contamination. There is currently not enough information available to estimate the potential liability associated with this claim. The party who originally made this claim has not been actively pursuing it.

    Management intends to pursue reimbursement from its insurance carriers, and recovery from its customers through increased rates, for any remediation costs for which the Company is determined to be liable. There is precedent for such recovery through increased rates, as both the WUTC and OPUC have previously allowed regulated utilities to increase customer rates to recover similar costs. No claims now pending, in the opinion of management, are expected to have a material effect on the Company's financial position, results of operations, or liquidity.

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Litigation

    Various lawsuits, claims, and contingent liabilities may arise from time to time from the conduct of the Company's business. In 1998, the Company was served with a lawsuit by six plaintiffs, claiming unspecified damages for personal injuries in connection with carbon monoxide exposure. The plaintiffs were residents of a house served by the Company at the time of the incident. The Company denies any responsibility for these injuries, and the parties are engaged in discovery. This case is scheduled for trial in April 2002. There is currently not enough information available to estimate the Company's potential liability associated with this claim, but its self-insured exposure with respect to such claims is $1 million. No claims now pending, in the opinion of management, are expected to have a material effect on the Company's financial position, results of operations, or liquidity.

Note 13—Fair Value of Financial Instruments

    The following estimated fair value amounts have been determined by the Company, using available market information and appropriate valuation methodologies. However, considerable judgment is required in interpreting market data to develop the estimates of fair value. Accordingly, these estimates are not necessarily indicative of the amounts that the Company could realize in a current market exchange. Thus, the use of different market assumptions or estimation methodologies may have a material effect on the estimated fair value amounts. The estimated fair values have been determined by using interest rates that are currently available to the Company for issuance of instruments with similar terms and remaining maturities. The estimated fair value amounts, at September 30, 2001 and 2000, of financial instruments whose values are sensitive to market conditions are set forth in the following table:

		2001						2000
		Carrying Amount			Estimated Fair Value			Carrying Amount			Estimated Fair Value
		(dollars in thousands)
Redeemable Preferred Stock		$	—		$	—		$	62		$	73
Long-term Debt		$	125,000		$	142,585		$	125,000		$	133,209

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Note 14—Interim Results of Operations (unaudited)

		Quarter Ended
		9/30/01			6/30/01			3/31/01			12/31/00
		(thousands except per share data)
Operating revenues		$	42,036		$	64,085		$	124,728		$	104,965
Gas costs and revenue taxes			28,544			42,960			93,933			75,345
Operating margin			13,492			21,125			30,795			29,620
Cost of operations			14,958			15,244			14,172			13,674
Income (loss) from operations			(1,466	)		5,881			16,623			15,946
Interest and other, net			2,629			2,643			2,472			2,726
Income (loss) before income taxes			(4,095	)		3,238			14,151			13,220
Income taxes			(1,894	)		1,182			5,165			4,825
Net income (loss)		$	(2,201	)	$	2,056		$	8,986		$	8,395
Other comprehensive income (loss)			(4,161	)		—			—			—
Comprehensive Income (loss)		$	(6,362	)	$	2,056		$	8,986		$	8,395
Earnings (loss) per common share—basic and diluted		$	(0.20	)	$	0.19		$	0.81		$	0.76
		Quarter Ended
		9/30/00			6/30/00			3/31/00			12/31/99
Operating revenues		$	37,752		$	41,563		$	88,830		$	73,791
Gas costs and revenue taxes			23,926			25,495			56,338			46,183
Operating margin			13,826			16,068			32,492			27,608
Cost of operations			14,293			13,444			14,243			13,017
Income (loss) from operations			(467	)		2,624			18,249			14,591
Interest and other, net			2,612			2,692			2,709			2,559
Income (loss) before income taxes			(3,079	)		(68	)		15,540			12,032
Income taxes			(990	)		(23	)		5,672			4,392
Net income (loss) before preferred dividends			(2,089	)		(45	)		9,868			7,640
Preferred dividends			1			1			1			1
Net income (loss)		$	(2,090	)	$	(46	)	$	9,867		$	7,639
Earnings (loss) per common share—basic and diluted		$	(0.19	)	$	(0.00	)	$	0.89		$	0.69

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SCHEDULE II

CASCADE NATURAL GAS CORPORATION

VALUATION AND QUALIFYING ACCOUNTS
(Thousands of Dollars)

Column A				Column B			Column C				Column D		Column E
							Additions
Description				Balance at Beginning of Period			Charged to Costs and Expenses		Charged to Other Accounts		Deductions (Note)		Balance at End of Period
Allowance for Doubtful Accounts:
	Year ended:
		September 30, 1999		$	645		686		—		709		$	622
		September 30, 2000		$	622		561		—		476		$	707
		September 30, 2001		$	707		713				516		$	904
	Reserve—Notes Receivable
		September 30, 1999		$	1,925		32		—		1,838		$	119
		September 30, 2000		$	119		520		—		—		$	639
		September 30, 2001		$	639		4						$	643

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Note: Accounts written off, net of recoveries

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Item 9.  Changes in and Disagreements With Accountants on Accounting and Financial Disclosure

    None.

PART III

Item 10.  Directors and Executive Officers of the Registrant

    Reference is made to the information regarding directors under the caption "Election of Directors" on pages 1 through 4 and the caption "Section 16(a) Beneficial Ownership Reporting Compliance" on page 7 of the Proxy Statement sent to shareholders for the 2002 Annual Meeting (the 2002 Proxy Statement), which information is incorporated herein by reference.

Item 11.  Executive Compensation

    Reference is made to the information regarding executive compensation set forth in the 2002 Proxy Statement under "Executive Compensation" on pages 11 through 12, "Retirement Plan" on page 13, "Executive Supplemental Retirement Income Plan" on pages 13 and 14, "Employment Agreements" on page 14, "Supplemental Benefit Trust" on page 14, "Director Compensation" on page 15, and under "Compensation Committee Interlocks and Insider Participation" on page 15, which information is incorporated herein by reference. Certain information concerning the executive officers of the Company is set forth in Part I, under the caption "Executive Officers of the Registrant."

Item 12.  Security Ownership of Certain Beneficial Owners and Management

    Reference is made to the information regarding security ownership of certain beneficial owners and management under the caption "Security Ownership of Certain Beneficial Owners and Management" on pages 6 and 7 of the 2002 Proxy Statement (excluding the information under the subheading "Section 16(a) Beneficial Ownership Reporting Compliance"), which information is incorporated herein by reference.

Item 13.  Certain Relationships and Related Transactions

    Reference is made to the information regarding certain relationships and transactions under the caption "Compensation Committee Interlocks and Insider Participation" on page 15 of the 2002 Proxy Statement, which information is incorporated herein by reference.

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PART IV

Item 14.  Exhibits, Financial Statement Schedules, and Reports on Form 8-K

(a) 1.	Financial Statements (Included in Part II of this report):
	Independent Auditors' Report
	Consolidated Statements of Income and Comprehensive Income for the Years Ended September 30, 2001, 2000, and 1999
	Consolidated Balance Sheets, September 30, 2001 and 2000
	Consolidated Statements of Common Shareholders' Equity for the Years Ended September 30, 2001, 2000, and 1999
	Consolidated Statements of Cash Flows for the Years Ended September 30, 2001, 2000, and 1999
	Notes to Consolidated Financial Statements
(a) 2.	Financial Statement Schedule (Included in Part II of this report):
	Schedule II—Valuation and Qualifying Accounts
(a) 3.	Exhibits:
	Reference is directed to the index to exhibits following the signature page of this report. Each management contract or compensatory plan or arrangement required to be filed as an exhibit to this report is identified in the list.
(b)	Reports on Form 8-K:
	None

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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.

				CASCADE NATURAL GAS CORPORATION
December 14, 2001 Date				By	/s/ J. D. WESSLING    J. D. Wessling Sr. Vice President—Finance, Chief Financial Officer

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

/s/ W. BRIAN MATSUYAMA    W. Brian Matsuyama		Chairman of the Board, President and Chief Executive Officer and Director (Principal Executive Officer)		December 14, 2001 Date
/s/ J. D. WESSLING    J. D. Wessling		Sr. Vice President—Finance, Chief Financial Officer (Principal Financial Officer)		December 14, 2001 Date
/s/ JAMES E. HAUG    James E. Haug		Controller and Chief Accounting Officer (Principal Accounting Officer)		December 14, 2001 Date
/s/ MELVIN C. CLAPP    Melvin C. Clapp		Director		December 14, 2001 Date
/s/ THOMAS E. CRONIN    Thomas E. Cronin		Director		December 14, 2001 Date
/s/ DAVID A. EDERER    David A. Ederer		Director		December 14, 2001 Date
/s/ HOWARD L. HUBBARD    Howard L. Hubbard		Director		December 14, 2001 Date
/s/ LARRY L. PINNT    Larry L. Pinnt		Director		December 14, 2001 Date
/s/ BROOKS G. RAGEN    Brooks G. Ragen		Director		December 14, 2001 Date
/s/ CARL BURNHAM, JR.    Carl Burnham, Jr.		Director		December 14, 2001 Date
/s/ MARY E. PUGH    Mary E. Pugh		Director		December 14, 2001 Date

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INDEX TO EXHIBITS

Exhibit No		Description
3.1		Restated Articles of Incorporation of the Registrant as amended through March 28, 1996. Incorporated by reference to Exhibit 3.1 to the Registrant's current report on Form 8-K filed July 19, 1996.
3.2		Restated Bylaws of the Registrant. Incorporated by reference to Exhibit 3.2 to the Registrant's current report on Form 8-K filed July 19, 1996.
4.1		Indenture dated as of August 1, 1992, between the Registrant and The Bank of New York relating to Medium-Term Notes. Incorporated by reference to Exhibit 4 to the Registrant's current report on Form 8-K dated August 12, 1992.
4.2		First Supplemental Indenture dated as of October 25, 1993, between the Registrant and The Bank of New York relating to Medium-Term Notes. Incorporated by reference to Exhibit 4 to the Registrant's quarterly report on Form 10-Q for the quarter ended June 30, 1993.
4.3		Rights Agreement dated as of March 19, 1993, between the Registrant and Harris Trust and Savings Bank. Incorporated by reference to Exhibit 2 to the Registrant's registration statement on Form 8-A dated April 21, 1993.
4.4		First Amendment to Rights Agreement dated June 15, 1993, between the Registrant and The Bank of New York. Incorporated by reference to Exhibit 4 to the Registrant's quarterly report on Form 10-Q for the quarter ended June 30, 1993.
10.1		1998 Stock Incentive Plan of the Registrant.* Incorporated by reference to Exhibit 10.1 to the Registrant's Annual Report on Form 10-K for the year ended September 30, 1998.
10.2		Service Agreement (Storage Gas Service under Rate Schedule SGS-1) dated January 12, 1994, between Northwest Pipeline Corporation and the Registrant. Incorporated by reference to Exhibit 10.2 to the Registrant's Annual Report on Form 10-K for the year ended December 31, 1993 (1993 Form 10-K).
10.3		Service agreement (assigned Storage Gas Service under Rate Schedule SGS-1) dated January 12, 1994, between Northwest Pipeline Corporation and the Registrant. Incorporated by reference to Exhibit 10.3 to the Registrant's 1993 Form 10-K.
10.4		Service Agreement (Liquefaction—Storage Gas Service under Rate Schedule SGS-1) dated January 12, 1994, between Northwest Pipeline Corporation and the Registrant. Incorporated by reference to Exhibit 10.4 to the Registrant's 1993 Form 10-K.
10.5		Gas Purchase Agreement dated November 1, 1990, between Mobil Oil Canada and the Registrant. Incorporated by reference to Exhibit 10.6 to the Registrant's Annual Report on Form 10-K for the year ended December 31, 1991.
10.5	.1	Amended dated August 30, 2001, to the Gas Purchase Agreement dated November 1, 1990, between Duke Energy Trading and Marketing, L.L.C. (successor to Mobil Oil Canada)and the Registrant. A PORTION OF THIS AGREEMENT IS SUBJECT TO A REQUEST FOR CONFIDENTIAL TREATMENT.
10.6		Consent to Assignments, Dated June 1, 1997, which assigns from Westcoast Gas Services Inc. (WGSI), to Engage Energy Canada, L.P. (Engage) all the rights and obligations as specified in the contracts contained herein as Exhibit Nos. 10.7, and 10.22. Incorporated by reference to Exhibit 10.6 to the Registrant's Annual Report on Form 10-K for the year ended September 30, 1997 (1997 Form 10-K).

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10.7		Natural Gas Sales Agreement dated November 1, 1998, between Engage Energy US L.P., and the Registrant. Incorporated by reference to Exhibit 10.7 to the Registrant's 1999 Form 10-K.
10.8		Intentionally omitted.
10.9		Intentionally omitted.
10.10		Base Contract for Short-Term Sale and Purchase of Natural Gas dated August 1, 1999, between Kimball Energy Corporation and the Registrant.
10.11		Gas transportation agreement between Pacific Gas Transmission Company and the Registrant dated as of April 30, 1997. Incorporated by reference to Exhibit 10.11 to the Registrant's 1997 10-K.
10.12		Replacement Firm Transportation Agreement dated July 31, 1991, between Northwest Pipeline Corporation and the Registrant. Incorporated by reference to Exhibit 10(1) to the Registrant's registration statement on Form S-2, No. 33-52672 (1992 Form S-2).
10.12	.1	Amendments dated August 20, 1992, November 1, 1992, October 20, 1993, and December 17, 1993, to Replacement Firm Transportation Agreement dated July 31, 1991, between Northwest Pipeline Corporation and the Registrant. Incorporated by reference to Exhibit 10.12.1 to the Registrant's 1993 Form 10-K.
10.13		Firm Transportation Service Agreement dated April 25, 1991, between Pacific Gas Transmission Company and the Registrant (1993 expansion). Incorporated by reference to Exhibit 10(m) to the 1992 Form S-2.
10.14		Firm Transportation Service Agreement dated October 27, 1993, between Pacific Gas Transmission Company and the Registrant. Incorporated by reference to Exhibit 10.14 to the Registrant's 1993 Form 10-K.
10.15		Intentionally omitted.
10.16		Natural gas purchase agreement dated April 26, 2001, between Sempra Energy and the Registrant. A PORTION OF THIS AGREEMENT IS SUBJECT TO A REQUEST FOR CONFIDENTIAL TREATMENT.
10.17		Storage Agreement dated July 23, 1990, between Washington Water Power Company and the Registrant. Incorporated by reference to Exhibit 10(v) to the 1992 Form S-2.
10.17	.1	Second amendment to the agreement for the release of Jackson Prairie Storage Capacity dated as of July 30, 1997, amending the Storage Agreement dated July 23, 1990, between Washington Water Power Company and the Registrant. Incorporated by reference to Exhibit 10.17.1 to the Registrant's 1997 Form 10-K.
10.18		Service Agreement (Firm Redelivery Transportation Agreement under Rate Schedule TF-2 for Cascade's SGS-1) dated January 12, 1994, between Northwest Pipeline Corporation and the Registrant. Incorporated by Reference to Exhibit 10.18 to the Registrant's Annual Report on Form 10-K for the year ended December 31, 1994 (1994 Form 10-K).
10.19		Service Agreement (Firm Redelivery Transportation Agreement under Rate Schedule TF-2 for Cascade's assignment of SGS-1 from WWP) dated January 12, 1994, between Northwest Pipeline Corporation and the Registrant.Incorporated by reference to Exhibit 10.19 to the Registrant's 1994 Form 10-K.

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10.20		Service Agreement (Firm Redelivery Transportation Agreement under rate Schedule TF-2 for Cascade's LS-1) dated January 12, 1994, between Northwest Pipeline Corporation and the Registrant. Incorporated by reference to Exhibit 10.20 to the Registrant's 1994 Form 10-K.
10.21		Gas Purchase Contract dated October 1, 1994, between IGI Resources, Inc. and the Registrant. Incorporated by reference to Exhibit 10.21 to the Registrant's 1994 Form 10-K.
10.21	.1	Amended Exhibit A, effective October 1, 2001, to Gas Purchase Contract dated October 1, 1994, between IGI Resources, Inc. and the Registrant. A PORTION OF THIS AGREEMENT IS SUBJECT TO A REQUEST FOR CONFIDENTIAL TREATMENT.
10.21	.2	Amended Exhibit A, effective October 1, 2002, to Gas Purchase Contract dated October 1, 1994, between IGI Resources, Inc. and the Registrant. A PORTION OF THIS AGREEMENT IS SUBJECT TO A REQUEST FOR CONFIDENTIAL TREATMENT.
10.21	.3	Amended Exhibit A, effective October 1, 2003, to Gas Purchase Contract dated October 1, 1994, between IGI Resources, Inc. and the Registrant. A PORTION OF THIS AGREEMENT IS SUBJECT TO A REQUEST FOR CONFIDENTIAL TREATMENT.
10.22		Amended and restated Natural Gas Sales Agreement dated August 17, 1994, between Westcoast Gas Services, Inc. and the Registrant Incorporated by reference to Exhibit 10.22 to the Registrant's 1994 Form 10-K.
10.22	.1	Amendment dated November 20, 2001, to Amended and restated Natural Gas Sales Agreement dated August 17, 1994, between Engage Energy Canada L.P. and Registrant. A PORTION OF THIS AGREEMENT IS SUBJECT TO A REQUEST FOR CONFIDENTIAL TREATMENT.
10.23		Firm Transportation Service Agreement dated November 4, 1994, between Pacific Gas Transmission and the Registrant, effective November 1, 1995. Incorporated by reference to Exhibit 10.23 to the Registrant's 1994 Form 10-K.
10.24		Firm Transportation Agreement dated August 1, 1994, between Northwest Pipeline Corporation and the Registrant. Incorporated by reference to Exhibit 10.24 to the Registrant's 1994 Form 10-K.
10.25		Prearranged Permanent Capacity Release of Firm Natural Gas Transportation Agreements dated November 30, 1993 between Tenaska Gas Co., Tenaska Washington Partners, L.P. and the Registrant. Incorporated by reference to Exhibit 10.25 to the Registrant's 1994 Form 10-K.
10.26		Agreement for Peak Gas Supply Service dated August 1, 1992, between Tenaska Gas Co., Tenaska Washington Partners, L.P., and the Registrant. Incorporated by reference to Exhibit 10.26 to the Registrant's 1994 Form 10-K.
10.27		Intentionally omitted.
10.28		Intentionally omitted.
10.29		1991 Director Stock Award Plan of the Registrant.* Incorporated by reference to Exhibit 10(n) to the 1992 Form S-2.
10.30		Executive Supplemental Retirement Income Plan of the Registrant and Supplemental Benefit Trust as amended and restated as of May 1, 1989, as amended by Amendment No. 1 dated July 1, 1991.* Incorporated by reference to Exhibit 10(o) to the 1992 Form S-2.

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10.31		Form of employment agreement between the Registrant and W. Brian Matsuyama, and each other executive officer of the Registrant. * Incorporated by reference to Exhibit 10(p) to the 1992 Form S-2.
10.32		Intentionally omitted.
10.33		Agreement for Jackson Prairie Storage Service, dated October 7, 1999, between Engage Energy Canada, L.P. and the Registrant. A PORTION OF THIS AGREEMENT IS SUBJECT TO A REQUEST FOR CONFIDENTIAL TREATMENT. Incorporated by reference to Exhibit 10.33 to the Registrant's 1999 Form 10-K.
12.		Statement regarding computation of ratio of earnings to fixed charges and preferred dividend requirements.
21.		A list of the Registrant's subsidiaries is omitted because the subsidiaries considered in the aggregate as a single subsidiary do not constitute a significant subsidiary.
23.		Consent of Deloitte & Touche LLP to the incorporation of their report in the Registrant's registration statements.

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*

Management contract or compensatory plan or arrangement.

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QuickLinks

CASCADE NATURAL GAS CORPORATION Annual Report to the Securities and Exchange Commission on Form 10-K For the Fiscal Year Ended September 30, 2001 Table of Contents
Part I

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

Part II

Item 5. Market for Registrant's Common Equity and Related Stockholder Matters

Item 6. Selected Financial Data

Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations
Item 7A. Quantitative and Qualitative Disclosures About Market Risk

Item 8. Financial Statements and Supplementary Data

CASCADE NATURAL GAS CORPORATION CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME
CASCADE NATURAL GAS CORPORATION CONSOLIDATED BALANCE SHEETS
CASCADE NATURAL GAS CORPORATION CONSOLIDATED STATEMENTS OF COMMON SHAREHOLDERS' EQUITY
CASCADE NATURAL GAS CORPORATION CONSOLIDATED STATEMENTS OF CASH FLOWS
Notes to Consolidated Financial Statements

SCHEDULE II

CASCADE NATURAL GAS CORPORATION VALUATION AND QUALIFYING ACCOUNTS (Thousands of Dollars)

Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure

PART III

Item 10. Directors and Executive Officers of the Registrant
Item 11. Executive Compensation
Item 12. Security Ownership of Certain Beneficial Owners and Management
Item 13. Certain Relationships and Related Transactions

PART IV

Item 14. Exhibits, Financial Statement Schedules, and Reports on Form 8-K

SIGNATURES
INDEX TO EXHIBITS