FERC Form

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose
FERC Form No. 1 (FERC Form 1) is an annual regulatory requirement for Major electric utilities, licensees and others (18 C.F.R. § 141.1). FERC Form No. 3-Q ( FERC Form 3-Q) is a quarterly regulatory requirement which supplements the annual financial reporting requirement (18 C.F.R. § 141.400). These reports are designed to collect financial and operational information from electric utilities, licensees and others subject to the jurisdiction of the Federal Energy Regulatory Commission. These reports are also considered to be non-confidential public use forms.
Who Must Submit
Each Major electric utility, licensee, or other, as classified in the Commission’s Uniform System of Accounts Prescribed for Public Utilities, Licensees, and Others Subject To the Provisions of The Federal Power Act (18 C.F.R. Part 101), must submit FERC Form 1 (18 C.F.R. § 141.1), and FERC Form 3-Q (18 C.F.R. § 141.400).
Note: Major means having, in each of the three previous calendar years, sales or transmission service that exceeds one of the following:
1. one million megawatt hours of total annual sales,
2. 100 megawatt hours of annual sales for resale,
3. 500 megawatt hours of annual power exchanges delivered, or
4. 500 megawatt hours of annual wheeling for others (deliveries plus losses).

What and Where to Submit

Submit FERC Form Nos. 1 and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov, and according to the specifications in the Form 1 and 3-Q taxonomies.
The Corporate Officer Certification must be submitted electronically as part of the FERC Forms 1 and 3-Q filings.
Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report to the Secretary of the Commission at:
Secretary
Federal Energy Regulatory Commission 888 First Street, NE
Washington, DC 20426

For the CPA Certification Statement, submit within 30 days after filing the FERC Form 1, a letter or report (not applicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can be either eFiled or mailed to the Secretary of the Commission at the address above.

The CPA Certification Statement should:

Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with the Commission's applicable Uniform System of Accounts (including applicable notes relating thereto and the Chief Accountant's published accounting releases), and

Be signed by independent certified public accountants or an independent licensed public accountant certified or licensed by a regulatory authority of a State or other political subdivision of the U. S. (See 18 C.F.R. §§ 41.10-41.12 for specific qualifications.)

Schedules	Pages
Comparative Balance Sheet	110-113
Statement of Income	114-117
Statement of Retained Earnings	118-119
Statement of Cash Flows	120-121
Notes to Financial Statements	122-123

The following format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained in the letter or report, demand that it be varied. Insert parenthetical phrases only when exceptions are reported.
“In connection with our regular examination of the financial statements of [COMPANY NAME] for the year ended on which we have reported separately under date of [DATE], we have also reviewed schedules [NAME OF SCHEDULES] of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Commission, for conformity in all material respects with the requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for this purpose included such tests of the accounting records and such other auditing procedures as we considered necessary in the circumstances.
Based on our review, in our opinion the accompanying schedules identified in the preceding paragraph (except as noted below) conform in all material respects with the accounting requirements of the Federal Energy Regulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.” The letter or report must state which, if any, of the pages above do not conform to the Commission’s requirements. Describe the discrepancies that exist.
Filers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement using eFiling. Further instructions are found on the Commission’s website at https://www.ferc.gov/ferc-online/ferc-online/frequently-asked-questions-faqs-efilingferc-online.
Federal, State, and Local Governments and other authorized users may obtain additional blank copies of FERC Form 1 and 3-Q free of charge from https://www.ferc.gov/general-information-0/electric-industry-forms.

When to Submit
FERC Forms 1 and 3-Q must be filed by the following schedule:
1. FERC Form 1 for each year ending December 31 must be filed by April 18th of the following year (18 CFR § 141.1), and
2. FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. § 141.400).
Where to Send Comments on Public Reporting Burden.
The public reporting burden for the FERC Form 1 collection of information is estimated to average 1,168 hours per response, including the time for reviewing instructions, searching existing data sources, gathering and maintaining the data-needed, and completing and reviewing the collection of information. The public reporting burden for the FERC Form 3-Q collection of information is estimated to average 168 hours per response.
Send comments regarding these burden estimates or any aspect of these collections of information, including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NE, Washington, DC 20426 (Attention: Information Clearance Officer); and to the Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commission). No person shall be subject to any penalty if any collection of information does not display a valid control number (44 U.S.C. § 3512 (a)).

GENERAL INSTRUCTIONS

Prepare this report in conformity with the Uniform System of Accounts (18 CFR Part 101) (USofA). Interpret all accounting words and phrases in accordance with the USofA.
Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important. The truncating of cents is allowed except on the four basic financial statements where rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on the statements that they support. When applying thresholds to determine significance for reporting purposes, use for balance sheet accounts the balances at the end of the current reporting period, and use for statement of income accounts the current year's year to date amounts.
Complete each question fully and accurately, even if it has been answered in a previous report. Enter the word "None" where it truly and completely states the fact.
For any page(s) that is not applicable to the respondent, omit the page(s) and enter "NA," "NONE," or "Not Applicable" in column (d) on the List of Schedules, pages 2 and 3.
Enter the month, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in the header of each page is to be completed only for resubmissions (see VII. below).
Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing the numbers in parentheses.
For any resubmissions, please explain the reason for the resubmission in a footnote to the data field.
Do not make references to reports of previous periods/years or to other reports in lieu of required entries, except as specifically authorized.
Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be based upon those shown by the report of the previous period/year, or an appropriate explanation given as to why the different figures were used.
Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.

Definitions for statistical classifications used for completing schedules for transmission system reporting are as follows:

FNS - Firm Network Transmission Service for Self. "Firm" means service that can not be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" is Network Transmission Service as described in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservations. "Long-Term" means one year or longer and” firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Reservations" are described in Order No. 888 and the Open Access Transmission Tariff. For all transactions identified as LFP, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and “firm” means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions. For all transactions identified as OLF, provide in a footnote the termination date of the contract defined as the earliest date either buyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Point Transmission Reservations. Use this classification for all firm point-to-point transmission reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions.

OS - Other Transmission Service. Use this classification only for those services which can not be placed in the above-mentioned classifications, such as all other service regardless of the length of the contract and service FERC Form. Describe the type of service in a footnote for each entry.

AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment.

DEFINITIONS

Commission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any other Commission. Name the commission whose authorization was obtained and give date of the authorization.
Respondent -- The person, corporation, licensee, agency, authority, or other Legal entity or instrumentality in whose behalf the report is made.

EXCERPTS FROM THE LAW

Federal Power Act, 16 U.S.C. § 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:

’Corporation' means any corporation, joint-stock company, partnership, association, business trust, organized group of persons, whether incorporated or not, or a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
'Person' means an individual or a corporation;
'Licensee, means any person, State, or municipality Licensed under the provisions of section 4 of this Act, and any assignee or successor in interest thereof;

'municipality means a city, county, irrigation district, drainage district, or other political subdivision or agency of a State competent under the Laws thereof to carry and the business of developing, transmitting, unitizing, or distributing power; ......

"project' means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and structures (including navigation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the primary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful in connection with said unit or any part thereof, and all water rights, rights-of-way, ditches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are necessary or appropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered

'To make investigations and to collect and record data concerning the utilization of the water 'resources of any region to be developed, the water-power industry and its relation to other industries and to interstate or foreign commerce, and concerning the location, capacity, development costs, and relation to markets of power sites; ... to the extent the Commission may deem necessary or useful for the purposes of this Act."

"Sec. 304.

Every Licensee and every public utility shall file with the Commission such annual and other periodic or special* reports as the Commission may by rules and regulations or other prescribe as necessary or appropriate to assist the Commission in the proper administration of this Act. The Commission may prescribe the manner and FERC Form in which such reports shall be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shall include, among other things, full information as to assets and Liabilities, capitalization, net investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other reserves, cost of project and other facilities, cost of maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission otherwise specifies*.10

"Sec. 309.

The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescind such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act. Among other things, such rules and regulations may define accounting, technical, and trade terms used in this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to be filed with the Commission, the information which they shall contain, and the time within which they shall be field..."

GENERAL PENALTIES

The Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA § 316(a) (2005), 16 U.S.C. § 825o(a).

FERC FORM NO.

1/3-Q

REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER

Identification

01 Exact Legal Name of Respondent

NorthWestern Corporation

02 Year/ Period of Report

End of:

2024

03 Previous Name and Date of Change (If name changed during year)

04 Address of Principal Office at End of Period (Street, City, State, Zip Code)

3010 West 69th Street, Sioux Falls, SD 57108

05 Name of Contact Person

Evan VerWey

06 Title of Contact Person

Manager of Financial Reporting

07 Address of Contact Person (Street, City, State, Zip Code)

3010 West 69th Street, Sioux Falls, SD 57108

08 Telephone of Contact Person, Including Area Code

(605)-978-2906

09 This Report is An Original / A Resubmission

(1)

☑ An Original

(2)

☐ A Resubmission

10 Date of Report (Mo, Da, Yr)

06/30/2024

Quarterly Corporate Officer Certification

The undersigned officer certifies that:

I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts.

01 Name

Jeff Berzina

02 Title

Controller

03 Signature

Jeff Berzina

04 Date Signed (Mo, Da, Yr)

08/05/2024

Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction.

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

List of Schedules
Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA".
Line No.	Title of Schedule (a)	Reference Page No. (b)	Remarks (c)
	ScheduleIdentificationAbstract Identification	1
	ScheduleListOfSchedulesAbstract List of Schedules (Electric Utility)	2
1	ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Quarter	108
2	ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet	110
3	ScheduleStatementOfIncomeAbstract Statement of Income for the Quarter	114
4	ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Quarter	118
5	ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows	120
6	ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements	122
7	ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Comp Income, Comp Income, and Hedging Activities	122a
8	ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep	200
9	ScheduleElectricPlantInServiceAndAccumulatedProvisionForDepreciationByFunctionAbstract Electric Plant In Service and Accum Provision For Depr by Function	208
10	ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs	231
11	ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets	232
12	ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities	278
13	ScheduleElectricOperatingRevenuesAbstract Elec Operating Revenues (Individual Schedule Lines 300-301)	300
14	ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1)	302	Not Applicable
15	ScheduleElectricProductionOtherPowerTransmissionRegionalExpensesAbstract Electric Prod, Other Power Supply Exp, Trans and Distrib Exp	324
16	ScheduleElectricCustomerAccountServiceSalesAdministrativeAndGeneralExpensesAbstract Electric Customer Accts, Service, Sales, Admin and General Expenses	325
17	ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others	328
18	ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs	331	Not Applicable
19	ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others	332
20	ScheduleDepreciationDepletionAndAmortizationsAbstract Deprec, Depl and Amort of Elec Plant (403,403.1,404,and 405) (except Amortization of Acquisition Adjustments)	338
21	ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts Included in ISO/RTO Settlement Statements	397	Not Applicable
22	ScheduleMonthlyPeaksAndOutputAbstract Monthly Peak Loads and Energy Output	399
23	ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load	400
24	ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load	400a	Not Applicable

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

IMPORTANT CHANGES DURING THE QUARTER/YEAR
Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears. Changes in and important additions to franchise rights: Describe the actual consideration given therefore and state from whom the franchise rights were acquired. If acquired without the payment of consideration, state that fact. Acquisition of ownership in other companies by reorganization, merger, or consolidation with other companies: Give names of companies involved, particulars concerning the transactions, name of the Commission authorizing the transaction, and reference to Commission authorization. Purchase or sale of an operating unit or system: Give a brief description of the property, and of the transactions relating thereto, and reference to Commission authorization, if any was required. Give date journal entries called for by the Uniform System of Accounts were submitted to the Commission. Important leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective dates, lengths of terms, names of parties, rents, and other condition. State name of Commission authorizing lease and give reference to such authorization. Important extension or reduction of transmission or distribution system: State territory added or relinquished and date operations began or ceased and give reference to Commission authorization, if any was required. State also the approximate number of customers added or lost and approximate annual revenues of each class of service. Each natural gas company must also state major new continuing sources of gas made available to it from purchases, development, purchase contract or otherwise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such arrangements, etc. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance of short-term debt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorization, as appropriate, and the amount of obligation or guarantee. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments. State the estimated annual effect and nature of any important wage scale changes during the year. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings culminated during the year. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director, security holder reported on Pages 104 or 105 of the Annual Report Form No. 1, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a material interest. (Reserved.) If the important changes during the year relating to the respondent company appearing in the annual report to stockholders are applicable in every respect and furnish the data required by Instructions 1 to 11 above, such notes may be included on this page. Describe fully any changes in officers, directors, major security holders and voting powers of the respondent that may have occurred during the reporting period. In the event that the respondent participates in a cash management program(s) and its proprietary capital ratio is less than 30 percent please describe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s). Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.

N/A
Holding Company Reorganization On January 1, 2024, we completed the second and final phase of the holding company reorganization. NorthWestern Corporation contributed the assets and liabilities of its South Dakota and Nebraska regulated utilities to NorthWestern Energy Public Service Corporation, and then distributed its equity interest in NorthWestern Energy Public Service Corporation and certain other subsidiaries to NorthWestern Energy Group, Inc., resulting in NorthWestern Corporation owning and operating the Montana regulated utility and NorthWestern Energy Public Service Corporation owning and operating the Nebraska and South Dakota utilities, each as a direct subsidiary of NorthWestern Energy Group, Inc.
Acquisition of Energy West Montana Assets On July 29, 2024, we entered into an Asset Purchase Agreement with Hope Utilities to acquire its Energy West natural gas utility distribution system and operations serving approximately 33,000 customers located near Great Falls, Cut Bank, and West Yellowstone, Montana for approximately $39.0 million in cash, subject to certain working capital and other agreed upon closing adjustments. The transaction is subject to a number of customary closing conditions, including MPSC approval, and we expect the acquisition to be completed by the end of the first quarter of 2025. Colstrip - Puget Sound Energy Transaction On July 30, 2024, we entered into a definitive agreement (the Agreement) with Puget Sound Energy (Puget) to acquire Puget's 25 percent interest in each of Units 3 and 4 (collectively representing 370 megawatts) at the Colstrip Generating Station for $0. The acquisition would be effective December 31, 2025, subject to the satisfaction of the closing conditions contained within the Agreement. Under terms of the Agreement, we will be responsible for operating costs starting on January 1, 2026; while Puget will retain responsibility for its pre-closing share of environmental and pension liabilities attributed to events or conditions existing prior to the closing of the transaction and for any future decommission and demolition costs associated with the existing facilities that comprise Puget's interest. The Agreement is subject to customary conditions and approvals, including approval from the FERC. Acquisition of Puget's ownership interest, in addition to the previously disclosed acquisition of Avista's 15 percent interest in each of Colstrip Units 3 and 4 (collectively representing 222 megawatts), will result in our ownership of 55 percent of the facility with the ability to guide operating and maintenance investments. This provides capacity to help us meet our obligation to provide reliable and cost effective power to our customers in Montana, while allowing opportunity for us to identify and plan for newer lower or no-carbon technologies in the future.
None
None
See Note 5 "Financing Activities." Debt Issuance: FERC Order ES24-10-000
None
None
See Note 8 "Commitments and Contingencies."
None
None
None
None

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlant Utility Plant (101-106, 114)	200	6,567,536,692	7,983,112,655
3	ConstructionWorkInProgress Construction Work in Progress (107)	200	482,148,202	358,401,452
4	UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3)		7,049,684,894	8,341,514,107
5	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115)	200	2,414,500,773	2,874,902,417
6	UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5)		4,635,184,121	5,466,611,690
7	NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1)	202
8	NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2)
9	NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3)
10	SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4)
11	NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6)
12	AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5)	202
13	NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12)
14	UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13)		4,635,184,121	5,466,611,690
15	OtherElectricPlantAdjustments Utility Plant Adjustments (116)		263,806,234	357,585,527
16	GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117)		38,209,486	36,212,426
17	OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS
18	NonutilityProperty Nonutility Property (121)		686,805	686,805
19	AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122)		68,042	67,635
20	InvestmentInAssociatedCompanies Investments in Associated Companies (123)
21	InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1)	224	17,373,060	33,374,273
23	NoncurrentPortionOfAllowances Noncurrent Portion of Allowances	228
24	OtherInvestments Other Investments (124)		13,610,861	13,050,811
25	SinkingFunds Sinking Funds (125)
26	DepreciationFund Depreciation Fund (126)
27	AmortizationFundFederal Amortization Fund - Federal (127)
28	OtherSpecialFunds Other Special Funds (128)
29	SpecialFunds Special Funds (Non Major Only) (129)
30	DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175)
31	DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176)
32	OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31)		31,602,684	47,044,254
33	CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS
34	CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130)
35	Cash Cash (131)		3,605,277	8,740,865
36	SpecialDeposits Special Deposits (132-134)		15,120,601	14,856,653
37	WorkingFunds Working Fund (135)		17,300	22,850
38	TemporaryCashInvestments Temporary Cash Investments (136)
39	NotesReceivable Notes Receivable (141)
40	CustomerAccountsReceivable Customer Accounts Receivable (142)		60,512,993	91,004,512
41	OtherAccountsReceivable Other Accounts Receivable (143)		8,728,635	17,049,224
42	AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144)		2,388,788	2,813,091
43	NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145)
44	AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146)		4,995,480	615,046
45	FuelStock Fuel Stock (151)	227	2,099,910	9,710,818
46	FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152)	227
47	Residuals Residuals (Elec) and Extracted Products (153)	227
48	PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154)	227	75,611,045	85,254,493
49	Merchandise Merchandise (155)	227
50	OtherMaterialsAndSupplies Other Materials and Supplies (156)	227
51	NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157)	202/227
52	AllowanceInventoryAndWithheld Allowances (158.1 and 158.2)	228
53	NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances	228
54	StoresExpenseUndistributed Stores Expense Undistributed (163)	227	285,128
55	GasStoredCurrent Gas Stored Underground - Current (164.1)		5,077,748	18,814,211
56	LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3)
57	Prepayments Prepayments (165)		9,423,941	21,740,289
58	AdvancesForGas Advances for Gas (166-167)
59	InterestAndDividendsReceivable Interest and Dividends Receivable (171)
60	RentsReceivable Rents Receivable (172)		58,942	73,787
61	AccruedUtilityRevenues Accrued Utility Revenues (173)		56,354,796	105,109,956
62	MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174)		1,774,919	876,036
63	DerivativeInstrumentAssets Derivative Instrument Assets (175)
64	DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175)
65	DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176)
66	DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176)
67	CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66)		240,707,671	371,055,649
68	DeferredDebitsAbstract DEFERRED DEBITS
69	UnamortizedDebtExpense Unamortized Debt Expenses (181)		9,854,823	11,096,631
70	ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1)	230a
71	UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2)	230b
72	OtherRegulatoryAssets Other Regulatory Assets (182.3)	232	659,548,733.2	746,025,553
73	PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183)		0	376,264
74	PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1)
75	OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2)
76	ClearingAccounts Clearing Accounts (184)		427,190	2,522
77	TemporaryFacilities Temporary Facilities (185)
78	MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186)	233	1,114,083	11,084,645
79	DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187)
80	ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188)	352
81	UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189)		17,748,864	20,027,942
82	AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190)	234	186,256,057	289,883,014
83	UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191)		11,726,899	3,394,843
84	DeferredDebits Total Deferred Debits (lines 69 through 83)		885,822,269.2	1,081,886,370
85	AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84)		6,095,332,465.2	7,360,395,916

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS)
Line No.	Title of Account (a)	Ref. Page No. (b)	Current Year End of Quarter/Year Balance (c)	Prior Year End Balance 12/31 (d)
1	ProprietaryCapitalAbstract PROPRIETARY CAPITAL
2	CommonStockIssued Common Stock Issued (201)	250	1	1
3	PreferredStockIssued Preferred Stock Issued (204)	250
4	CapitalStockSubscribed Capital Stock Subscribed (202, 205)
5	StockLiabilityForConversion Stock Liability for Conversion (203, 206)
6	PremiumOnCapitalStock Premium on Capital Stock (207)
7	OtherPaidInCapital Other Paid-In Capital (208-211)	253	2,044,252,457	1,981,122,791
8	InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212)	252
9	DiscountOnCapitalStock (Less) Discount on Capital Stock (213)	254
10	CapitalStockExpense (Less) Capital Stock Expense (214)	254b
11	RetainedEarnings Retained Earnings (215, 215.1, 216)	118	298,046,254	810,816,636
12	UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1)	118	2,326,386	1,503,684
13	ReacquiredCapitalStock (Less) Reacquired Capital Stock (217)	250
14	NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218)
15	AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219)	122(a)(b)	5,607,145	5,513,000
16	ProprietaryCapital Total Proprietary Capital (lines 2 through 15)		2,334,365,181	2,784,922,744
17	LongTermDebtAbstract LONG-TERM DEBT
18	Bonds Bonds (221)	256	2,074,660,000	2,479,660,000
19	ReacquiredBonds (Less) Reacquired Bonds (222)	256
20	AdvancesFromAssociatedCompanies Advances from Associated Companies (223)	256
21	OtherLongTermDebt Other Long-Term Debt (224)	256	188,000,000	318,000,000
22	UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225)
23	UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226)			6,538
24	LongTermDebt Total Long-Term Debt (lines 18 through 23)		2,262,660,000	2,797,653,462
25	OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES
26	ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227)		4,152,142	5,996,448
27	AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1)
28	AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2)		4,882,642	6,745,658
29	AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3)		605,218	4,631,028
30	AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4)		30,458,126	50,272,082
31	AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229)
32	LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities
33	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges
34	AssetRetirementObligations Asset Retirement Obligations (230)		35,154,150	41,424,213
35	OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34)		75,252,278	109,069,429
36	CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES
37	NotesPayable Notes Payable (231)
38	AccountsPayable Accounts Payable (232)		79,343,272	131,709,370
39	NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233)
40	AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234)		2,874,699	4,804,188
41	CustomerDeposits Customer Deposits (235)		16,286,302	11,954,099
42	TaxesAccrued Taxes Accrued (236)	262	79,298,747	75,992,477
43	InterestAccrued Interest Accrued (237)		23,626,147	24,775,303
44	DividendsDeclared Dividends Declared (238)
45	MaturedLongTermDebt Matured Long-Term Debt (239)
46	MaturedInterest Matured Interest (240)
47	TaxCollectionsPayable Tax Collections Payable (241)		274,839	1,789,013
48	MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242)		60,767,236	73,408,287
49	ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243)		3,720,120	3,720,377
50	DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244)
51	LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities
52	DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245)
53	LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges
54	CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53)		266,191,362	328,153,114
55	DeferredCreditsAbstract DEFERRED CREDITS
56	CustomerAdvancesForConstruction Customer Advances for Construction (252)		116,301,836	107,470,505
57	AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255)	266	198,504	258,964
58	DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256)
59	OtherDeferredCredits Other Deferred Credits (253)	269	106,256,888	147,334,417
60	OtherRegulatoryLiabilities Other Regulatory Liabilities (254)	278	132,166,353	190,647,029
61	UnamortizedGainOnReacquiredDebt Unamortized Gain on Reacquired Debt (257)
62	AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281)	272
63	AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282)		571,779,664	663,637,584
64	AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283)		230,160,399	231,248,668
65	DeferredCredits Total Deferred Credits (lines 56 through 64)		1,156,863,644	1,340,597,167
66	LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65)		6,095,332,465	7,360,395,916

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

STATEMENT OF INCOME
Quarterly Report in column (c) the current year to date balance. Column (c) equals the total of adding the data in column (g) plus the data in column (i) plus the data in column (k). Report in column (d) similar data for the previous year. This information is reported in the annual filing only. Enter in column (e) the balance for the reporting quarter and in column (f) the balance for the same three month period for the prior year. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in column (k) the quarter to date amounts for other utility function for the current year quarter. Report in column (h) the quarter to date amounts for electric utility function; in column (j) the quarter to date amounts for gas utility, and in column (l) the quarter to date amounts for other utility function for the prior year quarter. If additional columns are needed, place them in a footnote. Annual or Quarterly if applicable Do not report fourth quarter data in columns (e) and (f) Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility column in a similar manner to a utility department. Spread the amount(s) over Lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above. Use page 122 for important notes regarding the statement of income for any account thereof. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid with respect to power or gas purchases. Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting revenues received or costs incurred for power or gas purchases, and a summary of the adjustments made to balance sheet, income, and expense accounts. If any notes appearing in the report to stockholders are applicable to the Statement of Income, such notes may be included at page 122. Enter on page 122 a concise explanation of only those changes in accounting methods made during the year which had an effect on net income, including the basis of allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Line No.	Title of Account (a)	(Ref.) Page No. (b)	Total Current Year to Date Balance for Quarter/Year (c)	Total Prior Year to Date Balance for Quarter/Year (d)	Current 3 Months Ended - Quarterly Only - No 4th Quarter (e)	Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f)	Electric Utility Current Year to Date (in dollars) (g)	Electric Utility Previous Year to Date (in dollars) (h)	Gas Utiity Current Year to Date (in dollars) (i)	Gas Utility Previous Year to Date (in dollars) (j)	Other Utility Current Year to Date (in dollars) (k)	Other Utility Previous Year to Date (in dollars) (l)
1	UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME
2	OperatingRevenues Operating Revenues (400)	300	634,177,713	891,613,624	272,766,522	344,093,402	512,436,822	643,124,407	120,991,859	247,653,944	749,032	835,273
3	OperatingExpensesAbstract Operating Expenses
4	OperationExpense Operation Expenses (401)	320	315,599,179	502,929,658	135,508,573	182,924,276	256,183,402	331,951,648	58,804,460	170,291,746	611,317	686,264
5	MaintenanceExpense Maintenance Expenses (402)	320	23,970,708	29,127,540	13,664,675	15,139,322	20,175,189	24,626,462	3,795,071	4,480,581	448	20,498
6	DepreciationExpense Depreciation Expense (403)	336	74,036,161	90,347,183	37,016,055	44,737,744	62,588,683	74,857,613	11,424,433	15,469,119	23,045	20,451
7	DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1)	336
8	AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405)	336	7,897,866	7,909,363	3,921,291	3,956,407	4,389,066	4,788,102	3,508,800	3,121,261
9	AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406)	336	7,373,942	7,550,886	3,686,971	3,775,443	7,373,942	7,974,138	0	423,253
10	AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11	AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2)
12	RegulatoryDebits Regulatory Debits (407.3)		17,357,451	52,816,415	12,116,854	22,513,988	12,610,110	29,931,275	4,747,341	22,885,140
13	RegulatoryCredits (Less) Regulatory Credits (407.4)		40,928,800	35,576,982	23,860,566	16,910,329	29,764,624	21,390,785	11,164,176	14,186,196
14	TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1)	262	83,228,843	93,402,866	36,153,272	42,245,248	64,303,193	72,309,714	18,901,738	21,064,661	23,912	28,491
15	IncomeTaxesOperatingIncome Income Taxes - Federal (409.1)	262	1,546,839	7,036,411	1,534,613	251,119	2,844,698	1,245,332	1,276,742	5,770,991	21,117	20,088
16	IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1)	262	601,090	9,464,946	839,240	102,912	974,380	7,470,129	366,011	1,987,893	7,279	6,924
17	ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1)	234, 272	61,641,759	48,284,615	29,187,946	21,429,992	47,891,933	40,268,894	13,754,178	8,021,343	4,352	5,622
18	ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1)	234, 272	46,061,194	57,851,456	23,049,212	20,892,123	34,458,726	41,883,325	11,602,468	15,968,132
19	InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4)	266	60,461	50,858	18,565	10,741	60,461	50,858
20	GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6)
21	LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7)
22	GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8)
23	LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9)
24	AccretionExpense Accretion Expense (411.10)
25	UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24)		501,907,525	755,390,587	221,953,441	298,761,020	407,412,629	532,098,339	93,812,130	222,515,154	682,766	777,094
27	NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25)		132,270,188	136,223,037	50,813,081	45,332,382	105,024,193	111,026,068	27,179,729	25,138,790	66,266	58,179
28	OtherIncomeAndDeductionsAbstract Other Income and Deductions
29	OtherIncomeAbstract Other Income
30	NonutilityOperatingIncomeAbstract Nonutilty Operating Income
31	RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415)		245,222	290,844	128,162	137,533
32	CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416)		234,086	115,735	56,834	80,999
33	RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417)		31,623	145,700	146,279	125,340
34	ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1)		112,766	299,213	57,721	169,156
35	NonoperatingRentalIncome Nonoperating Rental Income (418)
36	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1)	119	969,231	251,646	721,300	141,323
37	InterestAndDividendIncome Interest and Dividend Income (419)		17	229,905	9	48,893
38	AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1)		8,951,705	7,810,964	4,851,696	4,096,491
39	MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421)		95,809	53,187	172,187	2,979
40	GainOnDispositionOfProperty Gain on Disposition of Property (421.1)
41	OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40)		7,753,429	7,757,632	3,825,546	4,013,800
42	OtherIncomeDeductionsAbstract Other Income Deductions
43	LossOnDispositionOfProperty Loss on Disposition of Property (421.2)
44	MiscellaneousAmortization Miscellaneous Amortization (425)
45	Donations Donations (426.1)		461,824	492,693	150,773	201,723
46	LifeInsurance Life Insurance (426.2)
47	Penalties Penalties (426.3)		2,269,800	116
48	ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4)		130,848	263,290	37,978	68,781
49	OtherDeductions Other Deductions (426.5)		111,175	67,038	183,601	32,915
50	OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49)		1,788,303	689,061	5,150	237,589
51	TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions
52	TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2)	262	1,386	1,092	840	360
53	IncomeTaxesFederal Income Taxes-Federal (409.2)	262	2,310,548	5,122,373	929,860	1,300,651
54	IncomeTaxesOther Income Taxes-Other (409.2)	262	591,516	81,644	321,157	230,281
55	ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2)	234, 272	1,425	808,487	622	380,914
56	ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2)	234, 272	547	1,195,508	112	493,431
57	InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5)
58	InvestmentTaxCredits (Less) Investment Tax Credits (420)
59	TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58)		2,904,328	4,818,088	1,252,367	1,418,775
60	NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59)		6,637,404	2,250,483	2,568,029	2,357,436
61	InterestChargesAbstract Interest Charges
62	InterestOnLongTermDebt Interest on Long-Term Debt (427)		49,783,488	53,780,235	24,948,092	26,790,229
63	AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428)		601,496	1,308,750	272,170	817,274
64	AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1)		782,951	1,403,102	391,196	699,501
65	AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429)
66	AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1)
67	InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430)
68	OtherInterestExpense Other Interest Expense (431)		2,063,270	3,296,821	1,076,135	1,816,737
69	AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432)		4,046,296	2,970,004	2,193,150	1,557,990
70	NetInterestCharges Net Interest Charges (Total of lines 62 thru 69)		49,184,909	56,818,904	24,494,443	28,565,751
71	IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70)		89,722,683	81,654,616	28,886,667	19,124,067
72	ExtraordinaryItemsAbstract Extraordinary Items
73	ExtraordinaryIncome Extraordinary Income (434)
74	ExtraordinaryDeductions (Less) Extraordinary Deductions (435)
75	NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74)
76	IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3)	262
77	ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76)
78	NetIncomeLoss Net Income (Total of line 71 and 77)		89,722,683	81,654,616	28,886,667	19,124,067

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

STATEMENT OF RETAINED EARNINGS
Do not report Lines 49-53 on the quarterly report. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account affected in column (b). State the purpose and amount for each reservation or appropriation of retained earnings. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order. Show dividends for each class and series of capital stock. Show separately the State and Federal income tax effect of items shown for Account 439, Adjustments to Retained Earnings. Explain in a footnote the basis for determining the amount reserved or appropriated. If such reservation or appropriation is to be recurrent, state the number and annual amounts to be reserved or appropriated as well as the totals eventually to be accumulated. If any notes appearing in the report to stockholders are applicable to this statement, attach them at page 122.
Line No.	Item (a)	Contra Primary Account Affected (b)	Current Quarter/Year Year to Date Balance (c)	Previous Quarter/Year Year to Date Balance (d)
	UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216)
1	UnappropriatedRetainedEarnings Balance-Beginning of Period		810,816,636	769,493,168
2	ChangesAbstract Changes
3	AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439)
4	AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit
4.1	AdjustmentsToRetainedEarningsCredit
9	AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439)
10	AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit
10.1	AdjustmentsToRetainedEarningsDebit Holding Company Reorganization		570,525,446
15	AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439)		570,525,446
16	BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1)		90,691,914	195,412,909
17	AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436)
22	AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436)
23	DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437)
29	DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437)
30	DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438)
30.1	DividendsDeclaredCommonStock Common Stock Dividend		32,936,850	154,089,441
36	DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438)		32,936,850	154,089,441
37	TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings
38	UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37)		298,046,254	810,816,636
39	AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215)
45	AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215)
	AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1)
46	AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1)
47	AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46)
48	RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1)		298,046,254	810,816,636
	UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly)
49	UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit)
50	EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1)
51	DividendsReceived (Less) Dividends Received (Debit)
52	ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year
53	UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52)

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

STATEMENT OF CASH FLOWS
Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify separately such items as investments, fixed assets, intangibles, etc. Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet. Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income taxes paid. Investing Activities: Include at Other (line 31) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Line No.	Description (See Instructions No.1 for explanation of codes) (a)	Current Year to Date Quarter/Year (b)	Previous Year to Date Quarter/Year (c)
1	NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities
2	NetIncomeLoss Net Income (Line 78(c) on page 117)	89,722,683	81,654,616
3	NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income:
4	DepreciationAndDepletion Depreciation and Depletion	74,036,161	90,347,183
5	NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details)
5.1	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Amortization of	15,271,808	15,460,249
5.2	NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other Non-cash charges to net income-net	(a) 4,765,913	6,660,255
8	DeferredIncomeTaxesNet Deferred Income Taxes (Net)	15,581,443	9,953,862
9	InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net)	60,461	50,858
10	NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables	19,724,896	48,975,867
11	NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory	440,876	458,487
12	NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory
13	NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses	2,555,611	64,685,396
14	NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets	426,195	18,127,659
15	NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities	22,920,002	1,967,432
16	AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction	8,951,705	7,810,964
17	UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies	969,231	251,646
18	OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote):
18.1	OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription Other	(b) 4,118,071	114,602,459
22	NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21)	193,946,578	296,004,773
24	CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities:
25	ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land):
26	GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel)	228,762,750	263,076,313
27	GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel
28	GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant	4,058,662	8,068,541
29	GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant
30	AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction	8,951,705	7,810,964
31	OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote):
34	CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33)	223,869,707	263,333,890
36	AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d)
37	ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d)
39	InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies
40	ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies
41	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to)
42	DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies
44	PurchaseOfInvestmentSecurities Purchase of Investment Securities (a)
45	ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a)
46	LoansMadeOrPurchased Loans Made or Purchased
47	CollectionsOnLoans Collections on Loans
49	NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables
50	NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory
51	NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation
52	NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses
53	OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote):
53.1	OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription Investment in Equity Securities		5,538,861
57	CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55)	223,869,707	268,872,751
59	CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities:
60	ProceedsFromIssuanceAbstract Proceeds from Issuance of:
61	ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b)	175,000,000	300,000,000
62	ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock
63	ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock		10,802,005
64	OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote):
64.1	OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription Treasury Stock Activity		414,049
66	NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c)
67	OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote):
67.1	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other		92,403
67.2	DescriptionForOtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Cash contribution from NorthWestern Energy Group, Inc.	60,000,000
70	CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69)	235,000,000	311,123,651
72	PaymentsForRetirementAbstract Payments for Retirement of:
73	PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b)	100,000,000
74	PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock
75	PaymentsForRetirementOfCommonStockFinancingActivities Common Stock
76	OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote):
76.1	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Debt Financing Costs	764,045	2,758,826
76.2	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Line of Credit (Repayments) Borrowings, Net	76,000,000	259,000,000
76.3	DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities Distribution of Cash to NorthWestern Energy Public Service Corporation	253,166
78	NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c)
80	DividendsOnPreferredStock Dividends on Preferred Stock
81	DividendsOnCommonStock Dividends on Common Stock	32,936,850	76,085,340
83	CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81)	25,045,939	26,720,515
85	NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents
86	NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83)	4,877,190	411,507
88	CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period	23,620,368	20,814,526
90	CashAndCashEquivalents Cash and Cash Equivalents at End of Period	(c) 18,743,178	21,226,033

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: NoncashAdjustmentsToCashFlowsFromOperatingActivities

	6/30/2024	6/30/2023
Other Noncash Charges to Income, Net:
Amortization of debt issue costs, discount, and deferred hedge gain	1,630,741	2,205,048
Other noncash losses (gains)	5,507	(412,591)
Stock based compensation costs	3,129,665	4,867,798
	4,765,913	6,660,255

(b) Concept: OtherAdjustmentsToCashFlowsFromOperatingActivities

	6/30/2024	6/30/2023
Other Assets and Liabilities, Net:
Net change - other current assets	916,681	2,274,065
Net change - accrued utility revenues	27,739,453	52,919,200
Net change - deferred debits	(8,473,907)	72,629,689
Net change - deferred credits	(8,221,976)	(2,925,300)
Net change - noncurrent liabilities	(7,842,180)	(10,295,195)
	4,118,071	114,602,459

	6/30/2024	12/31/2023	6/30/2023	12/31/2022
Cash (131)	3,605,277	8,029,111	6,104,366	8,029,111
Working Funds (135)	17,300	23,450	22,850	23,450
Other Special Deposits (134)	15,120,601	12,761,965	15,098,817	12,761,965
Total	18,743,178	20,814,526	21,226,033	20,814,526

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

NOTES TO FINANCIAL STATEMENTS

Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Reference is made to Notes to Financial Statements included in the NorthWestern Corporation's Annual FERC Form 1 Report)

(Unaudited)

(1) Nature of Operations and Basis of Consolidation

NorthWestern Corporation (NW Corp), doing business as NorthWestern Energy, provides electricity and/or natural gas to approximately 617,600 customers in Montana and Yellowstone National Park. We have generated and distributed electricity and distributed natural gas in Montana since 2002.

The preparation of financial statements in conformity with accounting requirements of the Federal Energy Regulatory Commission (FERC) as set forth in its applicable Uniform System of Accounts requires us to make estimates and assumptions that may affect the reported amounts of assets, liabilities, revenues and expenses during the reporting period. Actual results could differ from those estimates. The unaudited Financial Statements reflect all adjustments (which unless otherwise noted are normal and recurring in nature) that are, in our opinion, necessary to fairly present our financial position, results of operations and cash flows. The actual results for the interim periods are not necessarily indicative of the operating results to be expected for a full year or for other interim periods. Events occurring subsequent to June 30, 2024 have been evaluated as to their potential impact to the Financial Statements through the date of issuance.

The Financial Statements included herein have been prepared by NorthWestern, without audit, pursuant to the rules and regulations of the FERC as set forth in its applicable Uniform System of Accounts. Certain information and footnote disclosures normally included in financial statements prepared in accordance with the accounting requirements of the FERC as set forth in its applicable Uniform System of Accounts and published accounting releases have been condensed or omitted pursuant to such rules and regulations; however, we believe that the condensed disclosures provided are adequate to make the information presented not misleading. We recommend that these Financial Statements be read in conjunction with the audited financial statements and related footnotes included in the Annual FERC Form 1 Report for the year ended December 31, 2023.

Financial Statement Presentation

The financial statements are presented on the basis of the accounting requirements of the FERC as set forth in its applicable Uniform System of Accounts and published accounting releases, which is a comprehensive basis of accounting other than accounting principles generally accepted in the United States of America (GAAP). This report differs from GAAP due to FERC requiring the presentation of subsidiaries on the equity method of accounting, which differs from Accounting Standards Codification (ASC) 810, Consolidation. ASC 810 requires that all majority-owned subsidiaries be consolidated (see Note 4). The other significant differences consist of the following:

• Earnings per share and footnotes for revenue from contracts with customers, and segment and related information, are not presented;

• Removal and decommissioning costs of generation, transmission and distribution assets are reflected in the Balance Sheets as a component of accumulated depreciation of $438.5 million and $523.7 million as of June 30, 2024 and December 31, 2023, respectively, in accordance with regulatory treatment as compared to regulatory liabilities for GAAP purposes;

• Goodwill is reflected in the Balance Sheets as a utility plant adjustments of $263.8 million as of June 30, 2024 and $357.6 as of December 31, 2023, respectively, in accordance with regulatory treatment, as compared to goodwill for GAAP purposes;

• The write-down of plant values associated with the 2002 acquisition of the Montana operations is reflected in the Balance Sheets as a component of accumulated depreciation of $147.6 million for June 30, 2024 and December 31, 2023, respectively, in accordance with regulatory treatment as compared to plant for GAAP purposes;

• The current portion of gas stored underground is reflected in the Balance Sheets as current and accrued assets, as compared to inventory for GAAP purposes;

• Operating lease right of use assets are classified in the Balance Sheets as capital leases in accordance with regulatory treatment, as compared to non-current assets for GAAP purposes;

• Operating lease liabilities are reflected as current and long term obligations under capital leases in the Balance Sheets, as compared to accrued expenses and long term liabilities for GAAP purposes;

• Unamortized debt expense is classified in the Balance Sheets as deferred debits in accordance with regulatory treatment, as compared to long-term debt for GAAP purposes;

• Current and long-term debt is classified in the Balance Sheets as all long-term debt in accordance with regulatory treatment, while current and long-term debt are presented separately for GAAP reporting;

• The current portion of the provision for injuries and damages and the expected insurance proceeds receivable related to the provision for injuries and damages are reported as a current liability for GAAP purposes, as compared to a non-current liability for FERC purposes;

• Accumulated deferred tax assets and liabilities are classified in the Balance Sheets as gross non-current deferred debits and credits, respectively, while GAAP presentation reflects a net non-current deferred tax liability;

• Stranded tax effects associated with the Tax Cuts and Jobs Act are included in accumulated other comprehensive income (AOCI) in accordance with regulatory treatment, while included in retained earnings for GAAP purposes;

• Uncertain tax positions related to temporary differences are classified in the Balance Sheets within the deferred tax accounts in accordance with regulatory treatment, as compared to other noncurrent liabilities for GAAP purposes. In addition, interest related to uncertain tax positions is recognized in interest expense in accordance with regulatory treatment, as compared to income tax expense for GAAP purposes;

• Net periodic benefit costs and net periodic postretirement benefit costs are reflected in operating expense for FERC purposes, as compared to the GAAP presentation, which reflects the current service costs component of the net periodic benefit costs in operating expenses and the other components outside of income from operations. In addition, only the service cost component of net periodic benefit cost is eligible for capitalization for GAAP purposes, as compared to the total net periodic benefit costs for FERC purposes;

• Regulatory assets and liabilities are reflected in the Balance Sheets as non-current items, while current and non-current amounts are presented separately for GAAP;

• Unbilled revenue is reflected in the Balance Sheets as Accrued utility revenue in accordance with regulatory treatment, as compared to Accounts receivable, net for GAAP purposes;

• Implementation costs associated with cloud computing arrangements are reflected as Miscellaneous Intangible Plant in accordance with regulatory treatment, as compared to Other current assets for GAAP purposes. Additionally, these cash outflows are presented within investing activities cash outflows in the Statement of Cash Flows in accordance with regulatory treatment, as compared to operating activities cash outflows for GAAP purposes; and

• GAAP revenue differs from FERC revenue primarily due to the equity method of accounting as discussed above, netting of electric purchases and sales for resale in revenue for the GAAP presentation as compared to a gross presentation for FERC purposes (with the exception of those transactions in a regional transmission organization (RTO)), the netting of RTO transmission transactions for the GAAP presentation as compared to a gross presentation for FERC purposes, and the classification of regulatory amortizations in revenue for GAAP purposes as compared to expense for FERC purposes.

The following table reconciles GAAP revenues to FERC revenues by segment for the three months ended 2023 and 2022 (in millions):

	Three Months Ended June 30, 2024
	Total	Electric	Natural Gas	Other

GAAP Revenues	$ 260.9	$ 217.5	$ 43.4	$ —
Revenue from equity investments	(0.6)	—	(0.6)	—
Grossing revenues / power purchases	5.5	5.5	—	—
Regulatory amortizations	7.4	11.4	(4.0)	—
Other	(0.4)	(0.1)	(0.6)	0.3
FERC Revenues	$ 272.8	$ 234.3	$ 38.2	$ 0.3

	Three Months Ended June 30, 2023
	Total	Electric	Natural Gas	Other

GAAP Revenues	$ 290.6	$ 229.3	$ 61.3	$ —
Revenue from equity investments	(0.8)	—	(0.8)	—
Grossing revenues / power purchases	15.4	15.4	—	—
Regulatory amortizations	40.7	37.0	3.7	—
Other	(1.8)	1.6)	(0.4)	0.2
FERC Revenues	$ 344.1	$ 280.1	$ 63.8	$ 0.2

	Six Months Ended June 30, 2024
	Total	Electric	Natural Gas	Other

GAAP Revenues	$ 643.6	$ 512.0	$ 131.6	$ —
Revenue from equity investments	(1.3)	—	(1.3)	—
Grossing revenues / power purchases	21.1	21.1	—	—
Regulatory amortizations	(31.7)	(23.6)	(8.1)	—
Other	2.5	2.9	(1.2)	0.8
FERC Revenues	$ 634.2	$ 512.4	$ 121.0	$ 0.8

	Six Months Ended June 30, 2023
	Total	Electric	Natural Gas	Other

GAAP Revenues	$ 745.1	$ 524.6	$ 220.5	$ —
Revenue from equity investments	(1.5)	—	(1.5)	—
Grossing revenues / power purchases	48.2	48.2	—	—
Regulatory amortizations	93.3	63.4	29.9	—
Other	6.5	6.9	(1.2)	0.8
FERC Revenues	$ 891.6	$ 643.1	$ 247.7	$ 0.8

Holding Company Reorganization

On January 1, 2024, we completed the second and final phase of our holding company reorganization. NW Corp contributed the assets and liabilities of its South Dakota and Nebraska regulated utilities to NWE Public Service, and then distributed its equity interest in NWE Public Service and certain other subsidiaries to NorthWestern Energy Group, resulting in NW Corp owning and operating the Montana regulated utility and NWE Public Service owning and operating the Nebraska and South Dakota utilities, each as a direct subsidiary of NorthWestern Energy Group. This holding company reorganization was approved by the FERC on November 29, 2022, in Docket No. EC22-72-000.

The below table represents the net assets distributed to NWE Public Service as well as the net assets of certain other non-regulated subsidiaries to NorthWestern Energy Group, Inc.:

		January 1,
		2024

ASSETS

Net Utility Plant		$ 979,240,425
Utility Plant Adjustment - Goodwill (116)		93,779,293
Other Property and Investments		15,050,992
Current and Accrued Assets		79,841,412
Deferred Debits		207,845,600
Total assets		1,375,757,722


LIABILITIES
Long-Term Debt		534,000,000
Other Noncurrent Liabilities		24,674,976
Current and Accrued Liabilities		54,485,980
Deferred Credits		189,842,020
Total liabilities		803,002,976

Net Assets		572,754,746

Goodwill

We completed our annual utility plant adjustment impairment test as of April 1, 2024, and no impairment was identified. We calculate the fair value of our reporting units by considering various factors, including valuation studies based primarily on a discounted cash flow analysis, with published industry valuations and market data as supporting information. Key assumptions in the determination of fair value include the use of an appropriate discount rate and estimated future cash flows. In estimating cash flows, we incorporate expected long-term growth rates in our service territory, regulatory stability, and commodity prices (where appropriate), as well as other factors that affect our revenue, expense and capital expenditure projections.

(2) Regulatory Matters

Montana Rate Review

On July 10, 2024, we filed a Montana electric and natural gas rate review with the Montana Public Service Commission (MPSC). The filing requests a base rate annual revenue increase of $156.5 million ($69.4 million net with Property Tax and Power Cost and Credit Adjustment Mechanism (PCCAM) tracker adjustments) for electric and $28.6 million for natural gas. Our request is based on a return on equity of 10.80 percent with a capital structure including 46.81 percent equity, and forecasted 2024 electric and natural gas rate base of $3.45 billion and $731.9 million, respectively. The electric rate base investment includes the 175-megawatt natural gas-fired Yellowstone County Generating Station ("YCGS"), which is expected to be in service during the third quarter of 2024. We requested interim base rates to be effective October 1, 2024.

(3) Income Taxes

We compute income tax expense for each quarter based on the estimated annual effective tax rate for the year, adjusted for certain discrete items. Our effective tax rate typically differs from the federal statutory tax rate due to the regulatory impact of flowing through the federal and state tax benefit of repairs deductions, state tax benefit of accelerated tax depreciation deductions (including bonus depreciation when applicable) and production tax credits. The regulatory accounting treatment of these deductions requires immediate income recognition for temporary tax differences of this type, which is referred to as the flow-through method. When the flow-through method of accounting for temporary differences is reflected in regulated revenues, we record deferred income taxes and establish related regulatory assets and liabilities.

The following table summarizes the differences between our effective tax rate and the federal statutory rate (in thousands):

	Three Months Ended June 30,
	2024		2023
Income before income taxes	$ 33,885		$ 20,922

Income tax calculated at federal statutory rate	7,116	21.0 %	4,394	21.0 %

Permanent or flow-through adjustments:
State income tax, net of federal provisions	507	1.5	273	1.3
Flow-through repairs deductions	(2,503)	(7.4)	(1,708)	(8.2)
Production tax credits	(349)	(1.0)	(1,147)	(5.5)
Amortization of excess deferred income tax	—	—	(233)	(1.1)
Plant and depreciation flow-through items	502	1.5	201	1.0
Other, net	(275)	(0.8)	17	0.1
	(2,118)	(6.2)	(2,597)	(12.4)

Income tax expense	$ 4,998	15.0 %	$ 1,797	8.6 %

	Six Months Ended June 30,
	2024		2023
Income before income taxes	$ 105,998		$ 93,356

Income tax calculated at federal statutory rate	22,260	21.0 %	$ 19,605	21.0 %

Permanent or flow through adjustments:
State income, net of federal provisions	1,563	0.6	1,232	1.3
Flow-through repairs deductions	(8,072)	(8.3)	(7,553)	(8.1)
Production tax credits	(1,080)	(4.5)	(4,346)	(4.7)
Amortization of excess deferred income tax	—	—	(1,032)	(1.1)
Reduction to previously claimed alternative minimum tax credit	—	—	3,186	3.4
Plant and depreciation flow through items	2,778	3.7	889	1.0
Share-based compensation	—	—	388	0.4
Other, net	(1,174)	0.8	(668)	(0.7)
	(5,985)	(7.9)	(7,904)	(8.5)

Income tax expense	$ 16,275	13.1 %	$ 11,701	12.5 %

Uncertain Tax Positions

We recognize tax positions that meet the more-likely-than-not threshold as the largest amount of tax benefit that is greater than 50 percent likely of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. We had unrecognized tax benefits of approximately $3.3 million as of June 30, 2024, including approximately $1.5 million that, if recognized, would impact our effective tax rate.

Our policy is to recognize interest related to uncertain tax positions in income tax expense. As of June 30, 2024, we have accrued $1.2 million for the payment of interest on the Balance Sheets.

Tax years 2020 and forward remain subject to examination by the Internal Revenue Service and state taxing authorities.

(4) Equity Investments

The following table presents our equity investments reflected in the investments in subsidiary companies on the Balance Sheets (in thousands):

	June 30, 2023	December 31, 2023
Havre Pipeline Company, LLC	$ 12,460	$ 13,163
Canadian Montana Pipeline Corporation	4,913	5,182
NorthWestern Energy Solutions, Inc.	—	11,797
NorthWestern Services, LLC	—	2,135
Risk Partners Assurance, Ltd.	—	1,097
Total Investments in Subsidiary Companies	$ 17,373	$ 33,374

(5) Financing Activities

On March 28, 2024, NW Corp issued and sold $175.0 million aggregate principal amount of Montana First Mortgage Bonds at a fixed interest rate of 5.56 percent maturing on March 28, 2031. These bonds were issued in transactions exempt from the registration requirements of the Securities Act of 1933. Proceeds were used to redeem NW Corp's $100.0 million of Montana First Mortgage Bonds due this year and for other general utility purposes. The bonds are secured by NW Corp's electric and natural gas assets associated with its Montana utility operations.

(6) Related Party Transactions

Accounts receivable from and payables to associated companies primarily include intercompany billings for direct charges, overhead, and income tax obligations.

The following table reflects our accounts receivable from and accounts payable to associated companies (in thousands):

	June 30, 2024	December 31, 2023
Accounts Receivable from Associated Companies:
Northwestern Public Services Corporation	$ 2,252	$ —
Havre Pipeline Company, LLC	2,743	591
NorthWestern Energy Solutions, Inc.	—	112
Risk Partners Assurance, Ltd.	—	(88)
	$ 4,995	$ 615

Accounts Payable to Associated Companies:
Canadian Montana Pipeline Corporation	$ 2,576	$ 2,516
NorthWestern Energy Group, Inc.	288	206
NorthWestern Energy Solutions	11	2,082
NorthWestern Services, LLC	—	2,082
	$ 2,875	$ 4,804

(7) Employee Benefit Plans

We sponsor and/or contribute to pension and postretirement health care and life insurance benefit plans for eligible employees. Net periodic benefit cost (credit) for our pension and other postretirement plans consists of the following (in thousands):

	Pension Benefits		Other Postretirement Benefits
	Three Months Ended June 30,		Three Months Ended June 30,
	2024	2023	2024	2023
Components of Net Periodic Benefit Cost (Credit)
Service cost	$ 1,264	$ 1,422	$ 61	$ 79
Interest cost	5,183	6,482	108	161
Expected return on plan assets	(5,651)	(6,671)	(321)	(273)
Amortization of prior service credit	—	—	—	29
Recognized actuarial loss (gain)	6	(3)	—	5
Net periodic benefit cost (credit)	$ 802	$ 1,230	$ (152)	$ 1

	Pension Benefits		Other Postretirement Benefits
	Six Months Ended June 30,		Six Months Ended June 30,
	2024	2023	2024	2023
Components of Net Periodic Benefit Cost (Credit)
Service cost	$ 2,550	$ 2,916	$ 126	$ 166
Interest cost	10,363	13,047	228	337
Expected return on plan assets	(11,293)	(13,357)	(640)	(548)
Amortization of prior service credit	—	—	—	58
Recognized actuarial loss (gain)	17	137	—	36
Net periodic benefit cost (credit)	$ 1,637	$ 2,743	$ (286)	$ 49

We contributed $2.6 million to our pension plans during the six months ended June 30, 2024. We expect to contribute an additional $7.4 million to our pension plans during the remainder of 2024.

(8) Commitments and Contingencies

ENVIRONMENTAL LIABILITIES AND REGULATION

Except as set forth below, the circumstances set forth in 9 - Commitments and Contingencies to the financial statements included in our Annual FERC Form 1 Report appropriately represent, in all material respects, the current status of our environmental liabilities and regulation.

Environmental Protection Agency (EPA) Rules

On April 25, 2024, the EPA released final rules related to GHG emission standards (GHG Rules) for existing coal-fired facilities and new coal and natural gas-fired facilities as well as final rules strengthening the MATS requirements (MATS Rules). Compliance with the rules will require expensive upgrades at Colstrip Units 3 and 4 with proposed compliance dates that may not be achievable and / or require technology that is unproven, resulting in significant impacts to costs of the facilities. The final MATS and GHG Rules require compliance as early as 2027 and 2032, respectively.

Previous efforts by the EPA were met with extensive litigation, and this time is no different. We, along with many other utilities, electric cooperatives, organizations, and states, have petitioned for judicial review of the GHG and MATS Rules with the U.S. Court of Appeals for the D.C. Circuit. We have further requested the court stay the implementation of the Rules pending review on the merits, but that judicial relief is discretionary. Briefing is underway for the requests to stay the MATS Rules. On July 19, 2024, the D.C. Circuit denied all consolidated motions to stay the GHG Rules, concluding the petitioners had not shown likelihood of success on the merits and irreparable harm from the GHG Rules' imposition. However, the court ordered the litigation parties to submit a proposed briefing schedule to ensure the case is argued and the GHG Rule is reviewed on the merits as soon as possible. If the MATS Rules and GHG Rules are implemented, it would result in additional material compliance costs. We will continue working with federal and state regulatory authorities, other utilities, and stakeholders to seek relief from the MATS or GHG regulations that, in our view, disproportionately impact customers in our region.

These GHG Rules and MATS Rules as well as future additional environmental requirements - federal or state - could cause us to incur material costs of compliance, increase our costs of procuring electricity, decrease transmission revenue and impact cost recovery. Technology to efficiently capture, remove and/or sequester such GHG emissions or hazardous air pollutants may not be available within a timeframe consistent with the implementation of any such requirements.

LEGAL PROCEEDINGS

State of Montana - Riverbed Rents

On April 1, 2016, the State of Montana (State) filed a complaint on remand (the State’s Complaint) with the Montana First Judicial District Court (State District Court), naming us, along with Talen Montana, LLC (Talen) as defendants. The State claimed it owns the riverbeds underlying 10 of our, and formerly Talen’s, hydroelectric facilities (dams, along with reservoirs and tailraces) on the Missouri, Madison and Clark Fork Rivers, and seeks rents for Talen’s and our use and occupancy of such lands. The facilities at issue include the Hebgen, Madison, Hauser, Holter, Black Eagle, Rainbow, Cochrane, Ryan, and Morony facilities on the Missouri and Madison Rivers and the Thompson Falls facility on the Clark Fork River. We acquired these facilities from Talen in November 2014.

The litigation has a long prior history in state and federal court, including before the United States Supreme Court, as detailed in Note 19 - Commitments and Contingencies to the financial statements included in our Annual FERC Form 1 Report. On April 20, 2016, we removed the case from State District Court to the United States District Court for the District of Montana (Federal District Court). On August 1, 2018, the Federal District Court granted our and Talen’s motions to dismiss the State’s Complaint as it pertains to the navigability of the riverbeds associated with four of our hydroelectric facilities near Great Falls. A bench trial before the Federal District Court commenced January 4, 2022, and concluded on January 18, 2022, which addressed the issue of navigability concerning our other six facilities. On August 25, 2023, the Federal District Court issued its Findings of Fact, Conclusions of Law, and Order (the "Order"), which found all but one of the segments of the riverbeds in dispute not navigable, and thus not owned by the State of Montana. The one segment found navigable, and thus owned by the State, was the segment on which the Black Eagle development was located. The State filed a motion to pursue an interlocutory appeal of the Order, and on January 2, 2024, the Federal District Court certified the Order for appeal to the 9th Circuit Court of Appeals. Briefing in the appeal is underway. Damages were bifurcated by agreement and will be tried separately for the Black Eagle segment, and any other segments found navigable, should the State prevail on appeal.

We dispute the State’s claims and intend to continue to vigorously defend the lawsuit. If the Federal District Court calculates damages as the State District Court did in 2008, we do not anticipate the resulting annual rent for the Black Eagle segment would have a material impact to our financial position or results of operations. We anticipate that any obligation to pay the State rent for use and occupancy of the riverbeds would be recoverable in rates from customers, although there can be no assurances that the Montana Public Service Commission (MPSC) would approve any such recovery.

Colstrip Arbitration

The remaining depreciable life of our investment in Colstrip Unit 4 is through 2042. The six owners of Colstrip Units 3 and 4 currently share the operating costs pursuant to the terms of an Ownership and Operation Agreement (O&O Agreement). However, several of the owners are mandated by Washington and Oregon law to eliminate coal-fired resources in 2025 and 2029, respectively.

As a result of the mandate, the owners have disagreed on various operational funding decisions, including whether closure requires each owner’s consent under the O&O Agreement. On March 12, 2021, we initiated an arbitration under the O&O Agreement (the “Arbitration”), to resolve the issues of whether closure requires each owner's consent and to clarify each owner's obligations to continue to fund operations until all joint owners agree on closure. The owners previously agreed to stay the Arbitration in an effort to work out a global resolution to the dispute, but that stay has now expired. The parties were not able to agree to continue the stay, and are presently in the process of retaining an arbitrator and are proceeding with the Arbitration.

Colstrip Coal Dust Litigation

On December 14, 2020, a claim was filed against Talen in the Montana Sixteenth Judicial District Court, Rosebud County, Cause No. CV-20-58. Talen is one of the co-owners of Colstrip Unit 3, and the operator of Units 3 and 4. The plaintiffs allege they have suffered adverse effects from coal dust generated during operations associated with Colstrip. On August 26, 2021, the claim was amended to add in excess of 100 plaintiffs; though the number of plaintiffs has since decreased to 57. It also added NorthWestern, the other owners of Colstrip, and Westmoreland Rosebud Mining LLC, as defendants. Plaintiffs are seeking economic damages, costs and disbursements, punitive damages, attorneys’ fees, and an injunction prohibiting defendants from allowing coal dust to blow onto plaintiffs’ properties. Since this lawsuit remains in its discovery stages, we are unable to predict outcomes. We continue to evaluate a range of reasonably possible losses.

Yellowstone County Generating Station Air Permit

On October 21, 2021, the Montana Environmental Information Center and the Sierra Club filed a lawsuit in Montana State District Court, against the Montana Department of Environmental Quality (MDEQ) and NorthWestern, alleging that the environmental analysis conducted by MDEQ prior to issuance of the Yellowstone County Generating Station's air quality construction permit was inadequate. On April 4, 2023, the Montana District Court issued an order finding MDEQ's environmental analysis was deficient in not addressing exterior lighting and greenhouse gases and remanded it back to MDEQ to address the deficiencies and vacated the air quality permit pending that remand. As a result of the vacatur of the permit, we paused construction. On June 8, 2023, the Montana District Court granted our motion to stay the order vacating the air quality permit pending the outcome of our appeal to the Montana Supreme Court. Oral argument was held May 15, 2024. We recommenced construction in June 2023 and expect the plant to be in service during the third quarter of 2024. The ultimate resolution of the lawsuit challenging the Yellowstone County Generating Station air quality permit could impact our ability to operate the facility.

During the litigation of the air permit, Montana House Bill 971 was signed into law, preventing the MDEQ from, except under certain exceptions, evaluating greenhouse gas emissions and corresponding impacts to the climate in environmental reviews of large projects such as coal mines and power plants. On August 4, 2023, the Montana First Judicial District Court in Held v. State of Montana, a separate case by Montana youths alleging climate damages, issued its order finding House Bill 971 unconstitutional delaying the issuance of the revised Yellowstone County Generating Station's air permit. The Montana Supreme Court granted NorthWestern permission to participate as amicus in the Held appeal. The Montana Supreme Court heard oral argument on the Held appeal on July 10, 2024.

Other Legal Proceedings

We are also subject to various other legal proceedings, governmental audits and claims that arise in the ordinary course of business. In our opinion, the amount of ultimate liability with respect to these other actions will not materially affect our financial position, results of operations, or cash flows.

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year		535,470		1,434,774	7,675,908		5,705,664
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income		335,123			226,065		109,058
3	Preceding Quarter/Year to Date Changes in Fair Value				1,846			1,846
4	Total (lines 2 and 3)		335,123		1,846	226,065		110,904	81,654,616	81,543,712
5	Balance of Account 219 at End of Preceding Quarter/Year		200,347		1,432,928	7,449,843		5,816,568
6	Balance of Account 219 at Beginning of Current Year		273,619		1,437,159	7,223,778		5,513,000
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income		318,221			226,065		92,156
8	Current Quarter/Year to Date Changes in Fair Value				1,989			1,989
9	Total (lines 7 and 8)		318,221		1,989	226,065		94,145	89,722,683	89,628,538
10	Balance of Account 219 at End of Current Quarter/Year		44,602		1,435,170	6,997,713		5,607,145

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	5,861,338,176	4,464,265,983	1,198,186,637	(a) 1,547,776			197,337,780
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	40,889,244				(b) 40,209,537	(c) 679,707
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified	4,798,750	4,798,750
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	5,907,026,170	4,469,064,733	1,198,186,637	1,547,776	40,209,537	679,707	197,337,780
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	4,191,929	4,162,063	29,866
11	ConstructionWorkInProgress Construction Work in Progress	482,148,202	429,715,333	24,256,704				28,176,165
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	656,318,593	656,318,593
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	7,049,684,894	5,559,260,722	1,222,473,207	1,547,776	40,209,537	679,707	225,513,945
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	2,414,500,773	1,875,141,635	442,392,360	1,150,318	36,188,563	0	59,627,897
15	UtilityPlantNet Net Utility Plant (13 less 14)	4,635,184,121	3,684,119,087	780,080,847	397,458	4,020,974	679,707	165,886,048
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	2,118,140,236	1,659,970,310	381,045,392	1,150,318	36,188,563		39,785,653
19	AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights	53,945,449		53,945,449
20	AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights
21	AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant	56,080,855	28,837,092	7,401,519				19,842,244
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	2,228,166,540	1,688,807,402	442,392,360	1,150,318	36,188,563	0	59,627,897
23	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others
24	DepreciationUtilityPlantLeasedToOthers Depreciation
25	AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion
26	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25)
27	DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use
28	DepreciationUtilityPlantHeldForFutureUse Depreciation
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment	186,334,233	186,334,233
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	2,414,500,773	1,875,141,635	442,392,360	1,150,318	36,188,563	0	59,627,897

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: UtilityPlantInServiceClassified

This column represents regulated propane.

(b) Concept: UtilityPlantInServicePropertyUnderCapitalLeases

This column represents the write-down of plant values associated with the 2002 acquisition of Montana Power and the reduction from fair value to regulated basis associated with the transfer of Colstrip Unit 4 to the regulated utility in 2009.

This column represents an electric default supply capacity and energy sales agreement classified as a capital lease.

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

Electric Plant In Service and Accum Provision For Depr by Function
Report below the original cost of plant in service by function. In addition to Account 101, include Account 102, and Account 106. Report in column (b) the original cost of plant in service and in column(c) the accumulated provision for depreciation and amortization by function.
Line No.	Item (a)	Plant in Service Balance at End of Quarter (b)	Accumulated Depreciation And Amortization Balance at End of Quarter (c)
1	Intangible Plant	39,165,366	13,875,902
2	Steam Production Plant	139,123,168	37,104,887
3	Nuclear Production Plant
4	Hydraulic Production - Conventional	642,945,768	138,705,984
5	Hydraulic Production - Pumped Storage
6	Other Production	287,486,288	82,304,836
7	Transmission	1,187,632,109	440,631,920
8	Distribution	2,008,259,110	875,629,170
9	Regional Transmission and Market Operation
10	General	164,452,924	100,554,703
11	TOTAL (Total of lines 1 through 10)	4,469,064,733	1,688,807,402

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
2	FAC Studies	8,647	253		253
3	SIS Studies	107,673	253	260,466	253
4	Line Interconnection Studies	54,114	253		253
20	Total	170,434		260,466
21	Generation Studies
22	FAC Studies	170,792	253	142,768	253
23	SIS Studies	31,035	253	200,000	253
24	FEA Studies	75,594	253	92,656	253
25	Optional Studies	791	253	10,000	253
39	Total	278,212		445,424
40	Grand Total	448,646		705,890

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	Flow-through Income Taxes (Montana)	493,200,421	4,832,685			498,033,106
2	Excess Deferred Income Taxes (Montana)	42,841,302	0	410.1	787,432	42,053,870
3	Basin Creek Capital Lease (Montana)	3,472,237	0		300,655	3,171,582
4	BPA Residential Exchange Program (Montana) - Docket 2018.8.49 Order 7630; Annual Amortization	1,343,979	1,282,242	254	1,651,683	974,538
5	Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization	0	8,228,782		8,228,782	0
6	FAS 106 (Montana) - Docket 93.6.24 and Docket 2009.9.129	6,795,313	58,400		89,005	6,764,708
7	FAS 112 (Montana) - Docket 93.6.24 and Docket 2009.9.129	3,687,034	0		0	3,687,034
8	Compensated Absences (Montana) - Docket 97.11.219	12,177,086	637,503		0	12,814,589
9	Pension Plan (Montana)	72,157,797	0		1,697,914	70,459,883
10	Montana Consumer Counsel Tax (Montana) - Docket 2018.10.67 - Order 7637	0	21,192		13,802	7,390
11	Montana Public Service Commission (Montana) - Docket 2017.9.78 - Order 7568	2,742,692	256,311		289,815	2,709,188
12	Montana Wildfire Mitigation	4,008,666	3,933,039		0	7,941,705
13	Asset Retirement Obligation (Montana)	10,495,503	435,637		0	10,931,140
44	TOTAL	652,922,030	19,685,791		13,059,088	659,548,733.2

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	Excess Deferred Income Taxes (Montana)	115,882,899		948,477	0	114,934,422
2	Deferred Gas Storage Sales (Montana) - Docket D2001.1.1; Amortization 2001 - 2039	6,520,299	(2)407	105,129	0	6,415,170
3	Montana Public Service Commission Consumer Counsel Taxes (Montana) - Dockets 2017.9.78 and 2018.10.67	13,803	Various	13,803	0	0
4	CTC QF Over/Under Collections (Montana) - Docket 97.9.90 and Docket 2001.1.15; Annual Amortization	1,141,232		27,315	0	1,113,917
5	Property Tax Tracker (Montana) - Docket 2017.11.86 - Order 7580a; Annual Amortization	19,409,125		9,876,300	0	9,532,825
6	Natural Gas Regulatory Deferrals (Montana)	240,084		99,205	29,140	170,019
41	TOTAL	143,207,442		11,070,229	29,140	132,166,353

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	203,391,716	244,759,620	582,407	1,769,755
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	204,969,570	245,123,883	749,757	1,902,554
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	22,950,505	45,715,036	77,873	362,085
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	7,487,963	9,533,596	6,298	18,618
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities		412,533		3,492
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales	468,162	557,113	1,579	1,841
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	439,267,916	546,101,781	1,417,914	4,058,345
11	SalesForResaleAbstract (447) Sales for Resale	21,147,523	44,958,820	563,427	440,142
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	460,415,439	591,060,601	1,981,341	4,498,487
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds	4,597	8,836
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	460,420,036	591,051,765	1,981,341	4,498,487
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts		205,122
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	88,442	91,220
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	2,211,373	2,053,222
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(a) 8,166,484	12,403,041
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	41,550,487	37,320,037
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
26	OtherOperatingRevenues TOTAL Other Operating Revenues	52,016,786	52,072,642
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	512,436,822	643,124,407
Line12, column (b) includes $ of unbilled revenues.
Line12, column (d) includes MWH relating to unbilled revenues

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

FOOTNOTE DATA

(a) Concept: OtherElectricRevenue

	YTD Q2 2024
Other Electric Revenue (456)
Ancillary Services:
Scheduling, System Control and Dispatch	$978,443
Regulation and Frequency Response	606,821
Energy Imbalance	4,693,789
Other Transmission Revenue	72,391
Low Income Housing	1,771,965
Steam Sales	-
Sale of Materials	7,349
Miscellaneous	35,726
Total	$8,166,484

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.	Description of Service (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

ELECTRIC PRODUCTION, OTHER POWER SUPPLY EXPENSES, TRANSMISSION AND DISTRIBUTION EXPENSES

Report Electric production, other power supply expenses, transmission, regional market, and distribution expenses through the reporting period.
Line No.	Account (a)	Year to Date Quarter (b)
1	PowerProductionExpensesAbstract 1. POWER PRODUCTION AND OTHER SUPPLY EXPENSES
2	SteamPowerGenerationOperationsExpense Steam Power Generation - Operation (500-509)	16,194,641
3	SteamPowerGenerationMaintenanceExpense Steam Power Generation – Maintenance (510-515)	5,413,681
4	PowerProductionExpensesSteamPower Total Power Production Expenses - Steam Power	21,608,322
5	NuclearPowerGenerationOperationsExpense Nuclear Power Generation – Operation (517-525)
6	NuclearPowerGenerationMaintenanceExpense Nuclear Power Generation – Maintenance (528-532)
7	PowerProductionExpensesNuclearPower Total Power Production Expenses - Nuclear Power
8	HydraulicPowerGenerationOperationsExpense Hydraulic Power Generation – Operation (535-540.1)	6,284,488
9	HydraulicPowerGenerationMaintenanceExpense Hydraulic Power Generation – Maintenance (541-545.1)	1,103,538
10	PowerProductionExpensesHydraulicPower Total Power Production Expenses - Hydraulic Power	7,388,026
11	RentsOtherPowerGeneration Other Power Generation – Operation (546-550.1)	11,234,412
12	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration Other Power Generation – Maintenance (551-554.1)	1,129,142
13	MaintenanceOfMiscellaneousOtherPowerGenerationPlant Total Power Production Expenses - Other Power	12,363,554
14	OtherPowerSuplyExpensesAbstract Other Power Supply Expenses
15	PurchasedPower (555) Purchased Power	150,162,630
15.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations
16	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching
17	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	6,327,741
18	OtherPowerSupplyExpense Total Other Power Supply Expenses (line 15-17)	143,834,889
19	PowerProductionExpenses Total Power Production Expenses (Total of lines 4, 7, 10, 13 and 18)	185,194,791
20	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
21	TransmissionExpensesOperationAbstract Transmission Operation Expenses
22	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	1,867,239
24	LoadDispatchReliability (561.1) Load Dispatch-Reliability	465,143
25	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System	436,260
26	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling	512,197
27	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services
28	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development
29	TransmissionServiceStudies (561.6) Transmission Service Studies
30	GenerationInterconnectionStudies (561.7) Generation Interconnection Studies
31	ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services
32	StationExpensesTransmissionExpense (562) Station Expenses	1,007,957
32.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
33	OverheadLineExpense (563) Overhead Lines Expenses	544,723
34	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses
35	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	3,372,393
36	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	61,263
37	RentsTransmissionElectricExpense (567) Rents	661,041
38	OperationSuppliesAndExpensesTransmissionExpense (567.1) Operation Supplies and Expenses (Non-Major)
39	TransmissionOperationExpense TOTAL Transmission Operation Expenses (Lines 22 - 38)	8,928,216
40	TransmissionMaintenanceAbstract Transmission Maintenance Expenses
41	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	220,098
42	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	13,922
43	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware	1,008,986
44	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	1,446
45	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment
46	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
47	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	416,185
47.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
48	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	579,233
49	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines
50	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant
51	MaintenanceOfTransmissionPlant (574) Maintenance of Transmission Plant
52	TransmissionMaintenanceExpenseElectric TOTAL Transmission Maintenance Expenses (Lines 41 – 51)	2,239,870
53	TransmissionExpenses Total Transmission Expenses (Lines 39 and 52)	11,168,086
54	RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES
55	RegionalMarketExpensesOperationAbstract Regional Market Operation Expenses
56	OperationSupervision (575.1) Operation Supervision
57	DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation
58	TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation
59	CapacityMarketAdministration (575.4) Capacity Market Facilitation
60	AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation
61	MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance
62	MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services
63	RegionalMarketOperationExpense Regional Market Operation Expenses (Lines 55 - 62)
64	RegionalMarketExpensesMaintenanceAbstract Regional Market Maintenance Expenses
65	MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements
66	MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware
67	MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software
68	MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment
69	MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant
70	RegionalMarketMaintenanceExpense Regional Market Maintenance Expenses (Lines 65-69)
71	RegionalMarketExpenses TOTAL Regional Control and Market Operation Expenses (Lines 63,70)
72	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
73	DistributionOperationExpensesElectric Distribution Operation Expenses (580-589)	7,363,492
74	DistributionMaintenanceExpenseElectric Distribution Maintenance Expenses (590-598)	7,889,687
75	DistributionExpenses Total Distribution Expenses (Lines 73 and 74)	15,253,179

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

Electric Customer Accts, Service, Sales, Admin and General Expenses
Report the amount of expenses for customer accounts, service, sales, and administrative and general expenses year to date.
Line No.	Account (a)	Year to Date Quarter (b)
-	CustomerAccountsExpensesOperationsAbstract Operation
1	CustomerAccountExpenses (901-905) Customer Accounts Expenses	5,379,685
2	CustomerServiceAndInformationExpenses (907-910) Customer Service and Information Expenses	1,388,877
3	SalesExpenses (911-917) Sales Expenses	185,173
4	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
5	AdministrativeAndGeneralExpensesOperationAbstract Operation
6	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	15,292,598
7	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	8,896,005
8	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit	3,011,160
9	OutsideServicesEmployed (923) Outside Services Employed	3,620,126
10	PropertyInsurance (924) Property Insurance	2,435,984
11	InjuriesAndDamages (925) Injuries and Damages	6,384,579
12	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	11,857,776
13	FranchiseRequirements (927) Franchise Requirements
14	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	1,901,074
15	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.
16	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	173,029
17	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	7,576,117
18	RentsAdministrativeAndGeneralExpense (931) Rents	263,401
19	AdministrativeAndGeneralOperationExpense TOTAL Operation (Total of lines 6 thru 18)	55,389,529
20	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
21	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	2,399,271
22	AdministrativeAndGeneralExpenses TOTAL Administrative and General Expenses (Total of lines 19 and 21)	57,788,800

Name of Respondent:

NorthWestern Corporation

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

06/30/2024

Year/Period of Report

End of:

2024

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")
Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c). Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c). In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain. Report in column (i) and (j) the total megawatthours received and delivered. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively. Footnote entries and provide explanations following all required data.
									TRANSFER OF ENERGY		REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS
Line No.	PaymentByCompanyOrPublicAuthority Payment By (Company of Public Authority) (Footnote Affiliation) (a)	TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName Energy Received From (Company of Public Authority) (Footnote Affiliation) (b)	TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c)	StatisticalClassificationCode Statistical Classification (d)	RateScheduleTariffNumber Ferc Rate Schedule of Tariff Number (e)	TransmissionPointOfReceipt Point of Receipt (Substation or Other Designation) (f)	TransmissionPointOfDelivery Point of Delivery (Substation or Other Designation) (g)	BillingDemand Billing Demand (MW) (h)	TransmissionOfElectricityForOthersEnergyReceived Megawatt Hours Received (i)	TransmissionOfElectricityForOthersEnergyDelivered Megawatt Hours Delivered (j)	Demand Charges ($) (k)	Energy Charges ($) (l)	Other Charges ($) (m)	RevenuesFromTransmissionOfElectricityForOthers Total Revenues ($) (k+l+m) (n)
1	Ash Grove Cement	Energy Keepers Inc.	Ash Grove Cement	FNO	Montana OATT	Kerr	Clancy, MT	7	9,670	9,670	59,194			59,194
2	Aspen Air U.S., LLC	Talen Energy	Aspen Air Corporation	FNO	Montana OATT	Colstrip	Billings, MT	11	12,722	12,722	66,663			66,663
3	Barretts Minerals, Inc.	Energy Keepers inc.	Barretts Minerals, Inc.	FNO	Montana OATT	Kerr	Dillon, MT	6	6,766	6,766	34,133			34,133
4	Beartooth Electric Cooperative, Inc.	WAPA & Energy Keepers Inc.	Beartooth Electric Cooperative, Inc.	FNO	Montana OATT	Fort Peck & Kerr	Various in Montana	18	20,111	20,111	161,283			161,283
5	Benefis Health Systems	Energy Keepers inc.	Benefis Health Systems	FNO	Montana OATT	Kerr	Various in Montana	7	7,782	7,782	53,718			53,718
6	Big Horn County Electric Coop. Inc.	WAPA	Big Horn County Electric Coop. Inc.	FNO	Montana OATT	Various & Great Falls	Various in Montana	18	15,309	15,309	128,007			128,007
7	Bonneville Power Administration	BPA	Bonneville Power Administration	FNO	Montana OATT	BPAT.NWMT	Various in Montana	185	211,373	211,373	1,563,972			1,563,972
8	Basin Electric Power Cooperative	Morgan Stanley, WAPA, Talen Energy	Basin Electric Power Cooperative	FNO	Montana OATT	Various in Montana	Various NWMT & WAUW	181	206,809	206,809	1,484,982			1,484,982
9	Basin Electric Power Cooperative	Basin Electric & WAPA	Basin Electric Power Cooperative	FNO	Montana OATT	BPAT.NWMT & Great Falls	Various NWMT & WAUW	15	18,401	18,401	130,374			130,374
10	CHS, Inc.	Morgan Stanley	CHS, Inc.	FNO	Montana OATT	MATL.NWMT	Various in Montana	58	93,218	93,218	501,799			501,799
11	City of Great Falls	Energy Keepers Inc.	City of Great Falls	FNO	Montana OATT	Kerr	Various in Montana	6	4,242	4,242	28,759			28,759
12	Talen Montana, LLC	Avista Energy	Colstrip Steam Electric Station	FNO	Montana OATT	Colstrip	Nichols Pump Sub	10	4,140	4,140	37,869			37,869
13	Atlas Power, LLC	Portland General Electric	Atlas Power, LLC	FNO	Montana OATT	Colstrip	Butte, MT	75	147,445	147,445	464,132			464,132
14	Phillips 66 Company	Shell Energy	Phillips 66 Company	FNO	Montana OATT	BPAT.NWMT	Various in Montana	70	119,721	119,721	643,804			643,804
15	Par Montana, LLC	Talen Energy	Par Montana, LLC	FNO	Montana OATT	Colstrip	Billings, MT	35	58,626	58,626	339,577			339,577
16	General Mills Operations, LLC	Talen Energy	General Mills Operations, LLC	FNO	Montana OATT	Colstrip	Great Falls, MT	4	5,073	5,073	27,887			27,887
17	Great Falls Public Schools	Energy Keepers Inc.	Great Falls Public Schools	FNO	Montana OATT	Kerr	Great Falls, MT	3	2,586	2,586	15,646			15,646
18	GCC Three Forks, LLC	Energy Keepers Inc., GCC Three Forks	GCC Three Forks, LLC	FNO	Montana OATT	Kerr & GCC	Three Forks, MT	8	5,418	5,418	47,798			47,798
19	Magris Talc USA, Inc.	Energy Keepers Inc.	Magris Talc USA, Inc.	FNO	Montana OATT	Kerr	Three Forks, MT	6	7,245	7,245	38,116			38,116
20	DFA Dairy Brands Fluid, LLC	Talen Energy	DFA Dairy Brands Fluid, LLC	FNO	Montana OATT	Colstrip	Various in Montana	1	1,376	1,376	8,593			8,593
21	Calumet Refining, LLC	Talen Energy	Calumet Montana Refining Company, Inc.	FNO	Montana OATT	Colstrip	Great Falls, MT	25	39,118	39,118	197,999			197,999
22	Montana Resources	Energy Keepers, Inc.	Montana Resources	FNO	Montana OATT	BPAT.NWMT & Kerr	Butte, MT	50	91,315	91,315	496,542			496,542
23	REC Silicon Company	Shell Energy	REC Silicon Company	FNO	Montana OATT	BPAT.NWMT	Butte, MT	117	151,359	151,359	808,254			808,254
24	Roseburg Forest Products Company	Shell Energy	Roseburg Forest Products Company	FNO	Montana OATT	BPAT.NWMT	Missoula, MT	8	9,031	9,031	61,215			61,215
25	Sibanye-Stillwater	Various	Stillwater Mining Company	FNO	Montana OATT	As Available	Various in Montana	46	72,196	72,196	399,293			399,293
26	Town of Philipsburg	Town of Philipsburg	Town of Philipsburg	FNO	Montana OATT	Philipsburg Substation	Philipsburg, MT	0	0	0	0			0
27	Western Area Power Administration	WAPA	Western Area Power Administration	FNO	Montana OATT	Crossover	Various NWMT & WAUW	4	2	2	7,530			7,530
28	Montana State University - Bozeman	WAPA	Montana State University - Bozeman	FNO	Montana OATT	Fort Peck West	Great Falls, MT	4	4,286	4,286	25,577			25,577
29	Western Area Power Administration	WAPA	Malmstrom Air Force Base	FNO	Montana OATT	Fort Peck West	Great Falls, MT	4	7,039	7,039	41,645			41,645
30	Altop Energy Trading LLC	PPW	WAPA	NF	MONTANA OATT	YTP	CROSSOVER	0	402	402	0	2,180		2,180
31	Altop Energy Trading LLC	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	YTP	0	20	20	0	124		124
32	Avista Corporation	AVA	AVA	NF	MONTANA OATT	COLSTRIP	AVAT.NWMT	0	1,408	1,408	0	7,853		7,853
33	Avista Corporation	AVA	AVA	SFP	MONTANA OATT	COLSTRIP	AVAT.NWMT	0	480	480	0	2,980		2,980
34	Avista Corporation	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	COLSTRIP	0	1,604	1,604	0	9,056		9,056
35	Avista Corporation	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	NWMT.SYSTEM	0	897	897	0	5,165		5,165
36	Avista Corporation	AVA	NWMT	SFP	MONTANA OATT	AVAT.NWMT	NWMT.SYSTEM	0	1,368	1,368	0	7,790		7,790
37	Basin Electric Power Cooperative	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	NWMT.SYSTEM	0	30	30	0	186		186
38	Basin Electric Power Cooperative	BPAT	WAPA	NF	MONTANA OATT	BPAT.NWMT	GREATFALLS	0	435	435	0	2,701		2,701
39	Basin Electric Power Cooperative	NWMT	BPAT	NF	MONTANA OATT	MATL.NWMT	BPAT.NWMT	0	234	234	0	1,453		1,453
40	Basin Electric Power Cooperative	NWMT	PACE	SFP	MONTANA OATT	KERR	YTP	0	2,400	2,400	0	14,900		14,900
41	Basin Electric Power Cooperative	NWMT	WAUW	NF	MONTANA OATT	MATL.NWMT	GREATFALLS	0	30	30	0	186		186
42	Basin Electric Power Cooperative	PPW	WAPA	NF	MONTANA OATT	YTP	CROSSOVER	0	228	228	0	1,416		1,416
43	Basin Electric Power Cooperative	PPW	WAPA	SFP	MONTANA OATT	YTP	CROSSOVER	0	48	48	0	260		260
44	Basin Electric Power Cooperative	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	YTP	0	30	30	0	163		163
45	Basin Electric Power Cooperative	WAPA	WAPA	LFP	MONTANA OATT	CROSSOVER	GREATFALLS	31	67,704	67,704	384,387	0		384,387
46	Bonneville Power Administration	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	NWMT.SYSTEM	0	753	753	0	4,676		4,676
47	Bonneville Power Administration	BPAT	PPW	NF	MONTANA OATT	BPAT.NWMT	BRDY	0	10	10	0	54		54
48	Bonneville Power Administration	BPAT	WAPA	NF	MONTANA OATT	BPAT.NWMT	GREATFALLS	0	138	138	0	748		748
49	CP Energy Marketing (US) Inc.	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	12,081	12,081	0	66,048		66,048
50	CP Energy Marketing (US) Inc.	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	NWMT.SYSTEM	0	496	496	0	2,717		2,717
51	CP Energy Marketing (US) Inc.	NWMT	BPAT	NF	MONTANA OATT	MATL.NWMT	BPAT.NWMT	0	640	640	0	3,587		3,587
52	CP Energy Marketing (US) Inc.	NWMT	NWMT	NF	MONTANA OATT	COLSTRIP	MATL.NWMT	0	60	60	0	325		325
53	CP Energy Marketing (US) Inc.	NWMT	NWMT	NF	MONTANA OATT	COLSTRIP	NWMT.SYSTEM	0	3	3	0	16		16
54	CP Energy Marketing (US) Inc.	NWMT	NWMT	NF	MONTANA OATT	MATL.NWMT	NWMT.SYSTEM	0	89	89	0	482		482
55	CP Energy Marketing (US) Inc.	WAPA	NWMT	NF	MONTANA OATT	CROSSOVER	NWMT.SYSTEM	0	4	4	0	22		22
56	CP Energy Marketing (US) Inc.	WAUW	NWMT	NF	MONTANA OATT	CROSSOVER	MATL.NWMT	0	60	60	0	325		325
57	Cycle Power Partners, LLC	NWMT	PACE	NF	MONTANA OATT	HORSESHOE	BRDY	0	12	12	0	65		65
58	Cycle Power Partners, LLC	NWMT	PACE	NF	MONTANA OATT	HORSESHOE	JEFF	0	5,303	5,303	0	28,742		28,742
59	Dynasty Power Inc.	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	18,004	18,004	0	97,740		97,740
60	Dynasty Power Inc.	BPAT	NWMT	SFP	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	5,208	5,208	0	28,210		28,210
61	Dynasty Power Inc.	BPAT	PPW	NF	MONTANA OATT	BPAT.NWMT	YTP	0	172	172	0	1,068		1,068
62	Dynasty Power Inc.	BPAT	WAPA	NF	MONTANA OATT	BPAT.NWMT	CROSSOVER	0	98	98	0	569		569
63	Dynasty Power Inc.	NWMT	BPAT	NF	MONTANA OATT	MATL.NWMT	BPAT.NWMT	0	1,483	1,483	0	8,038		8,038
64	Dynasty Power Inc.	NWMT	WAUW	NF	MONTANA OATT	NWMTIMBALANC	CROSSOVER	0	4	4	0	22		22
65	Dynasty Power Inc.	PACE	NWMT	NF	MONTANA OATT	YTP	COLSTRIP	0	43	43	0	233		233
66	Dynasty Power Inc.	PACE	NWMT	NF	MONTANA OATT	YTP	MATL.NWMT	0	1,515	1,515	0	8,211		8,211
67	Dynasty Power Inc.	PPW	BPAT	NF	MONTANA OATT	BRDY	BPAT.NWMT	0	442	442	0	2,396		2,396
68	Dynasty Power Inc.	PPW	BPAT	NF	MONTANA OATT	YTP	BPAT.NWMT	0	918	918	0	4,976		4,976
69	Dynasty Power Inc.	PPW	WAPA	NF	MONTANA OATT	YTP	CROSSOVER	0	11,249	11,249	0	62,226		62,226
70	Dynasty Power Inc.	WAPA	BPAT	NF	MONTANA OATT	CROSSOVER	BPAT.NWMT	0	177	177	0	959		959
71	Dynasty Power Inc.	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	BRDY	0	84	84	0	455		455
72	Dynasty Power Inc.	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	YTP	0	175	175	0	949		949
73	Dynasty Power Inc.	WAUW	NWMT	NF	MONTANA OATT	CROSSOVER	MATL.NWMT	0	305	305	0	1,653		1,653
74	EDF Trading North America, LLC	AVA	AVA	NF	MONTANA OATT	COLSTRIP	AVAT.NWMT	0	616	616	0	3,339		3,339
75	EDF Trading North America, LLC	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	COLSTRIP	0	8	8	0	43		43
76	EDF Trading North America, LLC	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	GTFALLSNWMT	0	8	8	0	43		43
77	EDF Trading North America, LLC	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	NWMT.SYSTEM	0	45	45	0	244		244
78	EDF Trading North America, LLC	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	COLSTRIP	0	256	256	0	1,403		1,403
79	EDF Trading North America, LLC	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	GTFALLSNWMT	0	200	200	0	1,084		1,084
80	EDF Trading North America, LLC	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	NWMT.SYSTEM	0	1,529	1,529	0	8,287		8,287
81	EDF Trading North America, LLC	NWMT	AVA	NF	MONTANA OATT	COLSTRIP	AVAT.NWMT	0	164	164	0	952		952
82	EDF Trading North America, LLC	NWMT	BPAT	NF	MONTANA OATT	COLSTRIP	BPAT.NWMT	0	10,075	10,075	0	56,775		56,775
83	EDF Trading North America, LLC	NWMT	NWMT	NF	MONTANA OATT	COLSTRIP	COLSTRIP	0	1,730	1,730	0	9,921		9,921
84	EDF Trading North America, LLC	NWMT	NWMT	NF	MONTANA OATT	COLSTRIP	MATL.NWMT	0	1,325	1,325	0	7,182		7,182
85	EDF Trading North America, LLC	NWMT	NWMT	NF	MONTANA OATT	COLSTRIP	NWMT.SYSTEM	0	38	38	0	206		206
86	EDF Trading North America, LLC	NWMT	NWMT	NF	MONTANA OATT	MATL.NWMT	GTFALLSNWMT	0	8	8	0	43		43
87	EDF Trading North America, LLC	NWMT	NWMT	NF	MONTANA OATT	MATL.NWMT	NWMT.SYSTEM	0	6	6	0	33		33
88	EDF Trading North America, LLC	NWMT	NWMT	NF	MONTANA OATT	TFALLS	COLSTRIP	0	368	368	0	2,045		2,045
89	EDF Trading North America, LLC	NWMT	NWMT	SFP	MONTANA OATT	COLSTRIP	COLSTRIP	0	96	96	0	596		596
90	EDF Trading North America, LLC	NWMT	PPW	NF	MONTANA OATT	COLSTRIP	BRDY	0	593	593	0	3,333		3,333
91	EDF Trading North America, LLC	NWMT	PPW	NF	MONTANA OATT	COLSTRIP	YTP	0	175	175	0	1,068		1,068
92	EDF Trading North America, LLC	NWMT	PPW	SFP	MONTANA OATT	COLSTRIP	JEFF	0	17,975	17,975	0	113,225		113,225
93	EDF Trading North America, LLC	PACE	NWMT	NF	MONTANA OATT	BRDY	COLSTRIP	0	266	266	0	1,652		1,652
94	EDF Trading North America, LLC	PPW	NWMT	NF	MONTANA OATT	BRDY	NWMT.SYSTEM	0	240	240	0	1,301		1,301
95	Energy Keepers Inc.	AVA	PPW	SFP	MONTANA OATT	AVAT.NWMT	JEFF	0	1,200	1,200	0	7,450		7,450
96	Energy Keepers Inc.	NWMT	AVA	NF	MONTANA OATT	KERR	AVAT.NWMT	0	1,681	1,681	0	10,222		10,222
97	Energy Keepers Inc.	NWMT	AVA	SFP	MONTANA OATT	KERR	AVAT.NWMT	0	3,465	3,465	0	20,655		20,655
98	Energy Keepers Inc.	NWMT	BPAT	LFP	MONTANA OATT	KERR	BPAT.NWMT	40	87,360	87,360	495,983	0		495,983
99	Energy Keepers Inc.	NWMT	BPAT	SFP	MONTANA OATT	KERR	KERR.MVP	0	8,732	8,732	0	49,596		49,596
100	Energy Keepers Inc.	NWMT	NWMT	SFP	MONTANA OATT	MATL.NWMT	NWMT.SYSTEM	0	7,190	7,190	0	45,290		45,290
101	Energy Keepers Inc.	NWMT	PACE	LFP	MONTANA OATT	KERR	ANTE	8	17,975	17,975	113,219	0		113,219
102	Energy Keepers Inc.	NWMT	PACE	LFP	MONTANA OATT	KERR	BRDY	33	73,250	73,250	393,542	0		393,542
103	Energy Keepers Inc.	NWMT	PACE	NF	MONTANA OATT	JUDITHGAP	BRDY	0	480	480	0	2,980		2,980
104	Energy Keepers Inc.	NWMT	PACE	NF	MONTANA OATT	KERR	BRDY	0	1,128	1,128	0	7,003		7,003
105	Energy Keepers Inc.	NWMT	PACE	SFP	MONTANA OATT	KERR	JEFF	0	2,832	2,832	0	17,240		17,240
106	Energy Keepers Inc.	NWMT	PPW	NF	MONTANA OATT	COLSTRIP	BRDY	0	905	905	0	5,712		5,712
107	Energy Keepers Inc.	PACE	NWMT	SFP	MONTANA OATT	JEFF	COLSTRIP	0	600	600	0	3,250		3,250
108	Guzman Energy, LLC	AVA	PPW	NF	MONTANA OATT	AVAT.NWMT	YTP	0	5	5	0	31		31
109	Guzman Energy, LLC	BPAT	AVA	NF	MONTANA OATT	BPAT.NWMT	AVAT.NWMT	0	252	252	0	1,366		1,366
110	Guzman Energy, LLC	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	NWMT.SYSTEM	0	47	47	0	292		292
111	Guzman Energy, LLC	BPAT	PPW	NF	MONTANA OATT	BPAT.NWMT	YTP	0	487	487	0	3,001		3,001
112	Guzman Energy, LLC	PPW	AVA	NF	MONTANA OATT	YTP	AVAT.NWMT	0	1,869	1,869	0	10,125		10,125
113	Guzman Energy, LLC	PPW	BPAT	NF	MONTANA OATT	YTP	BPAT.NWMT	0	1,860	1,860	0	10,076		10,076
114	Guzman Energy, LLC	PPW	WAPA	NF	MONTANA OATT	YTP	CROSSOVER	0	1,237	1,237	0	7,501		7,501
115	Guzman Energy, LLC	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	YTP	0	2,316	2,316	0	13,547		13,547
116	Heartland Generation Ltd	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	150	150	0	932		932
117	Idaho Power Company	PACE	NWMT	NF	MONTANA OATT	JEFF	MLCK	0	368	368	0	1,995		1,995
118	Macquarie Energy, LLC	NWMT	AVA	NF	MONTANA OATT	BGI	AVAT.NWMT	0	4,280	4,280	0	23,184		23,184
119	Macquarie Energy, LLC	NWMT	AVA	NF	MONTANA OATT	MATL.NWMT	AVAT.NWMT	0	2,289	2,289	0	12,422		12,422
120	Macquarie Energy, LLC	NWMT	AVA	NF	MONTANA OATT	TFALLS	AVAT.NWMT	0	2,593	2,593	0	14,048		14,048
121	Macquarie Energy, LLC	NWMT	AVA	SFP	MONTANA OATT	TFALLS	AVAT.NWMT	0	528	528	0	2,860		2,860
122	Macquarie Energy, LLC	NWMT	BPAT	NF	MONTANA OATT	MATL.NWMT	BPAT.NWMT	0	119	119	0	645		645
123	Macquarie Energy, LLC	NWMT	BPAT	NF	MONTANA OATT	TFALLS	BPAT.NWMT	0	341	341	0	1,848		1,848
124	Macquarie Energy, LLC	NWMT	PACE	NF	MONTANA OATT	TFALLS	BRDY	0	48	48	0	260		260
125	Macquarie Energy, LLC	PPW	AVA	NF	MONTANA OATT	BRDY	AVAT.NWMT	0	480	480	0	2,602		2,602
126	Macquarie Energy, LLC	PPW	AVA	NF	MONTANA OATT	YTP	AVAT.NWMT	0	400	400	0	2,168		2,168
127	Macquarie Energy, LLC	PPW	AVA	SFP	MONTANA OATT	BRDY	AVAT.NWMT	0	6,489	6,489	0	35,415		35,415
128	MAG Energy Solutions	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	MATL.NWMT	0	48	48	0	260		260
129	MAG Energy Solutions	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	261	261	0	1,415		1,415
130	MAG Energy Solutions	NWMT	PACE	NF	MONTANA OATT	MATL.NWMT	BRDY	0	112	112	0	696		696
131	MAG Energy Solutions	PACE	NWMT	NF	MONTANA OATT	BRDY	MATL.NWMT	0	78	78	0	423		423
132	MAG Energy Solutions	PACE	NWMT	NF	MONTANA OATT	YTP	MATL.NWMT	0	279	279	0	1,512		1,512
133	Morgan Stanley Capital Group, Inc.	AVA	AVA	NF	MONTANA OATT	COLSTRIP	AVAT.NWMT	0	25	25	0	136		136
134	Morgan Stanley Capital Group, Inc.	AVA	GWA	NF	MONTANA OATT	AVAT.NWMT	GLWND1	0	20	20	0	108		108
135	Morgan Stanley Capital Group, Inc.	AVA	GWA	NF	MONTANA OATT	AVAT.NWMT	GLWND2	0	12	12	0	75		75
136	Morgan Stanley Capital Group, Inc.	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	MATL.NWMT	0	8,815	8,815	0	51,250		51,250
137	Morgan Stanley Capital Group, Inc.	BPAT	GWA	NF	MONTANA OATT	BPAT.NWMT	GLWND1	0	620	620	0	3,752		3,752
138	Morgan Stanley Capital Group, Inc.	BPAT	GWA	NF	MONTANA OATT	BPAT.NWMT	GLWND2	0	277	277	0	1,588		1,588
139	Morgan Stanley Capital Group, Inc.	BPAT	GWA	SFP	MONTANA OATT	BPAT.NWMT	GLWND1	0	144	144	0	780		780
140	Morgan Stanley Capital Group, Inc.	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	66,368	66,368	0	373,692		373,692
141	Morgan Stanley Capital Group, Inc.	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	NWMT.SYSTEM	0	11	11	0	60		60
142	Morgan Stanley Capital Group, Inc.	BPAT	NWMT	SFP	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	52,602	52,602	0	280,405		280,405
143	Morgan Stanley Capital Group, Inc.	BPAT	PPW	NF	MONTANA OATT	BPAT.NWMT	BRDY	0	180	180	0	1,118		1,118
144	Morgan Stanley Capital Group, Inc.	BPAT	WAPA	NF	MONTANA OATT	BPAT.NWMT	CROSSOVER	0	4	4	0	25		25
145	Morgan Stanley Capital Group, Inc.	GWA	AVA	NF	MONTANA OATT	GLWND1	AVAT.NWMT	0	54,719	54,719	0	306,621		306,621
146	Morgan Stanley Capital Group, Inc.	GWA	AVA	NF	MONTANA OATT	GLWND2	AVAT.NWMT	0	30,849	30,849	0	171,529		171,529
147	Morgan Stanley Capital Group, Inc.	GWA	BPAT	NF	MONTANA OATT	GLWND1	BPAT.NWMT	0	42,119	42,119	0	239,166		239,166
148	Morgan Stanley Capital Group, Inc.	GWA	BPAT	NF	MONTANA OATT	GLWND2	BPAT.NWMT	0	28,102	28,102	0	159,525		159,525
149	Morgan Stanley Capital Group, Inc.	GWA	NWMT	NF	MONTANA OATT	GLWND1	MATL.NWMT	0	4,980	4,980	0	28,927		28,927
150	Morgan Stanley Capital Group, Inc.	GWA	NWMT	NF	MONTANA OATT	GLWND2	MATL.NWMT	0	921	921	0	5,498		5,498
151	Morgan Stanley Capital Group, Inc.	GWA	NWMT	NF	MONTANA OATT	GLWND2	NWMT.SYSTEM	0	13,104	13,104	0	74,394		74,394
152	Morgan Stanley Capital Group, Inc.	GWA	PPW	NF	MONTANA OATT	GLWND1	BRDY	0	277	277	0	1,694		1,694
153	Morgan Stanley Capital Group, Inc.	GWA	PPW	NF	MONTANA OATT	GLWND2	BRDY	0	120	120	0	745		745
154	Morgan Stanley Capital Group, Inc.	NWMT	AVA	NF	MONTANA OATT	HARDIN	AVAT.NWMT	0	22	22	0	119		119
155	Morgan Stanley Capital Group, Inc.	NWMT	AVA	NF	MONTANA OATT	MATL.NWMT	AVAT.NWMT	0	85,811	85,811	0	479,270		479,270
156	Morgan Stanley Capital Group, Inc.	NWMT	BPAT	NF	MONTANA OATT	COLSTRIP	BPAT.NWMT	0	173	173	0	938		938
157	Morgan Stanley Capital Group, Inc.	NWMT	BPAT	NF	MONTANA OATT	HARDIN	BPAT.NWMT	0	26	26	0	141		141
158	Morgan Stanley Capital Group, Inc.	NWMT	BPAT	NF	MONTANA OATT	MATL.NWMT	BPAT.NWMT	0	76,715	76,715	0	436,593		436,593
159	Morgan Stanley Capital Group, Inc.	NWMT	GWA	NF	MONTANA OATT	COLSTRIP	GLWND1	0	25	25	0	155		155
160	Morgan Stanley Capital Group, Inc.	NWMT	GWA	NF	MONTANA OATT	MATL.NWMT	GLWND1	0	425	425	0	2,479		2,479
161	Morgan Stanley Capital Group, Inc.	NWMT	GWA	NF	MONTANA OATT	MATL.NWMT	GLWND2	0	86	86	0	466		466
162	Morgan Stanley Capital Group, Inc.	NWMT	NWMT	NF	MONTANA OATT	COLSTRIP	MATL.NWMT	0	2,000	2,000	0	12,311		12,311
163	Morgan Stanley Capital Group, Inc.	NWMT	NWMT	NF	MONTANA OATT	HARDIN	MATL.NWMT	0	31	31	0	168		168
164	Morgan Stanley Capital Group, Inc.	NWMT	NWMT	NF	MONTANA OATT	KERR	MATL.NWMT	0	4,775	4,775	0	29,801		29,801
165	Morgan Stanley Capital Group, Inc.	NWMT	NWMT	NF	MONTANA OATT	NWMTIMBALANC	MATL.NWMT	0	8	8	0	43		43
166	Morgan Stanley Capital Group, Inc.	NWMT	NWMT	SFP	MONTANA OATT	COLSTRIP	MATL.NWMT	0	2,665	2,665	0	14,490		14,490
167	Morgan Stanley Capital Group, Inc.	NWMT	NWMT	SFP	MONTANA OATT	CROOKEDFALLS	MATL.NWMT	0	11,400	11,400	0	70,775		70,775
168	Morgan Stanley Capital Group, Inc.	NWMT	NWMT	SFP	MONTANA OATT	HARDIN	MATL.NWMT	0	889	889	0	4,843		4,843
169	Morgan Stanley Capital Group, Inc.	NWMT	PACE	NF	MONTANA OATT	MATL.NWMT	BRDY	0	1,210	1,210	0	7,504		7,504
170	Morgan Stanley Capital Group, Inc.	NWMT	PACE	NF	MONTANA OATT	MATL.NWMT	JEFF	0	75	75	0	407		407
171	Morgan Stanley Capital Group, Inc.	PACE	NWMT	NF	MONTANA OATT	BRDY	MATL.NWMT	0	1,167	1,167	0	6,345		6,345
172	Morgan Stanley Capital Group, Inc.	WAPA	AVA	NF	MONTANA OATT	GREATFALLS	AVAT.NWMT	0	7,374	7,374	0	40,981		40,981
173	Morgan Stanley Capital Group, Inc.	WAPA	BPAT	NF	MONTANA OATT	GREATFALLS	BPAT.NWMT	0	1,455	1,455	0	8,283		8,283
174	Morgan Stanley Capital Group, Inc.	WAPA	PPW	NF	MONTANA OATT	GREATFALLS	BRDY	0	25	25	0	136		136
175	Morgan Stanley Capital Group, Inc.	WAUW	NWMT	NF	MONTANA OATT	GREATFALLS	MATL.NWMT	0	4,451	4,451	0	24,649		24,649
176	Morgan Stanley Capital Group, Inc.	WAUW	NWMT	SFP	MONTANA OATT	GREATFALLS	MATL.NWMT	0	600	600	0	3,725		3,725
177	Naturener Power Watch, LLC	GWA	GWA	SFP	MONTANA OATT	GLWND1	GLWND2	0	10,920	10,920	0	61,995		61,995
178	PacifiCorp	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	COLSTRIP	0	646	646	0	3,621		3,621
179	PacifiCorp	NWMT	BPAT	NF	MONTANA OATT	NWMTIMBALANC	BPAT.NWMT	0	50	50	0	271		271
180	PacifiCorp	PACE	NWMT	NF	MONTANA OATT	YTP	COLSTRIP	0	9	9	0	55		55
181	PacifiCorp	PPW	NWMT	NF	MONTANA OATT	MLCK	JEFF	0	212	212	0	1,317		1,317
182	Phillips 66 Energy Trading, LLC	PPW	AVA	SFP	MONTANA OATT	BRDY	AVAT.NWMT	0	107,391	107,391	0	620,281		620,281
183	Portland General Electric Company	AVA	AVA	NF	MONTANA OATT	COLSTRIP	AVAT.NWMT	0	600	600	0	3,252		3,252
184	Portland General Electric Company	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	COLSTRIP	0	16	16	0	99		99
185	Portland General Electric Company	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	COLSTRIP	0	2,183	2,183	0	12,228		12,228
186	Portland General Electric Company	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	600	600	0	3,252		3,252
187	Portland General Electric Company	NWMT	BPAT	LFP	MONTANA OATT	CLEARWATER	BPAT.NWMT	300	655,200	655,200	3,719,875	0		3,719,875
188	Portland General Electric Company	NWMT	BPAT	NF	MONTANA OATT	COLSTRIP	BPAT.NWMT	0	30	30	0	186		186
189	Portland General Electric Company	NWMT	NWMT	NF	MONTANA OATT	COLSTRIP	COLSTRIP	0	25	25	0	155		155
190	Portland General Electric Company	NWMT	NWMT	NF	MONTANA OATT	COLSTRIP	MATL.NWMT	0	1,975	1,975	0	10,728		10,728
191	Powerex Corporation	AVA	BPAT	NF	MONTANA OATT	AVAT.NWMT	BPAT.NWMT	0	68	68	0	369		369
192	Powerex Corporation	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	MATL.NWMT	0	34	34	0	184		184
193	Powerex Corporation	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	5,028	5,028	0	27,252		27,252
194	Powerex Corporation	BPAT	PPW	LFP	MONTANA OATT	BPAT.NWMT	BRDY	84	183,959	183,959	1,055,587	0		1,055,587
195	Powerex Corporation	BPAT	PPW	LFP	MONTANA OATT	BPAT.NWMT	JEFF	0	71	71	0	0		0
196	Powerex Corporation	BPAT	PPW	NF	MONTANA OATT	BPAT.NWMT	YTP	0	1,083	1,083	0	6,522		6,522
197	Powerex Corporation	BPAT	WAPA	NF	MONTANA OATT	BPAT.NWMT	CROSSOVER	0	197	197	0	1,223		1,223
198	Powerex Corporation	NWMT	AVA	NF	MONTANA OATT	MATL.NWMT	AVAT.NWMT	0	149	149	0	808		808
199	Powerex Corporation	NWMT	PACE	NF	MONTANA OATT	MATL.NWMT	BRDY	0	54	54	0	293		293
200	Powerex Corporation	PPW	AVA	NF	MONTANA OATT	JEFF	AVAT.NWMT	0	162	162	0	878		878
201	Powerex Corporation	PPW	AVA	NF	MONTANA OATT	YTP	AVAT.NWMT	0	276	276	0	1,496		1,496
202	Powerex Corporation	PPW	BPAT	NF	MONTANA OATT	BRDY	BPAT.NWMT	0	50	50	0	311		311
203	Powerex Corporation	PPW	BPAT	NF	MONTANA OATT	JEFF	BPAT.NWMT	0	83	83	0	450		450
204	Powerex Corporation	PPW	BPAT	NF	MONTANA OATT	YTP	BPAT.NWMT	0	180	180	0	1,094		1,094
205	Powerex Corporation	PPW	PPW	NF	MONTANA OATT	YTP	BRDY	0	4	4	0	22		22
206	Powerex Corporation	WAPA	AVA	NF	MONTANA OATT	CROSSOVER	AVAT.NWMT	0	88	88	0	477		477
207	Powerex Corporation	WAPA	BPAT	NF	MONTANA OATT	CROSSOVER	BPAT.NWMT	0	1,356	1,356	0	7,811		7,811
208	Powerex Corporation	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	YTP	0	82	82	0	444		444
209	Public Service Company of Colorado	PPW	WAPA	NF	MONTANA OATT	YTP	CROSSOVER	0	933	933	0	5,386		5,386
210	Puget Sound Energy Marketing	AVA	AVA	NF	MONTANA OATT	COLSTRIP	AVAT.NWMT	0	1	1	0	6		6
211	Puget Sound Energy Marketing	AVA	AVA	SFP	MONTANA OATT	COLSTRIP	AVAT.NWMT	0	2,400	2,400	0	13,000		13,000
212	Puget Sound Energy Marketing	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	COLSTRIP	0	353	353	0	2,192		2,192
213	Puget Sound Energy Marketing	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	COLSTRIP	0	2,524	2,524	0	14,048		14,048
214	Puget Sound Energy Marketing	NWMT	BPAT	NF	MONTANA OATT	COLSTRIP	BPAT.NWMT	0	2,160	2,160	0	12,385		12,385
215	Puget Sound Energy Marketing	NWMT	PPW	NF	MONTANA OATT	COLSTRIP	YTP	0	2	2	0	12		12
216	Rainbow Electric Marketing Corp.	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	741	741	0	4,016		4,016
217	Rainbow Electric Marketing Corp.	BPAT	PPW	NF	MONTANA OATT	BPAT.NWMT	YTP	0	229	229	0	1,241		1,241
218	Rainbow Electric Marketing Corp.	BPAT	WAPA	NF	MONTANA OATT	BPAT.NWMT	CROSSOVER	0	122	122	0	758		758
219	Rainbow Electric Marketing Corp.	NWMT	WAUW	NF	MONTANA OATT	MATL.NWMT	CROSSOVER	0	422	422	0	2,621		2,621
220	Rainbow Electric Marketing Corp.	PACE	NWMT	NF	MONTANA OATT	BRDY	MATL.NWMT	0	60	60	0	325		325
221	Rainbow Electric Marketing Corp.	PACE	NWMT	NF	MONTANA OATT	YTP	MATL.NWMT	0	592	592	0	3,209		3,209
222	Rainbow Electric Marketing Corp.	PPW	AVA	NF	MONTANA OATT	JEFF	AVAT.NWMT	0	692	692	0	3,751		3,751
223	Rainbow Electric Marketing Corp.	PPW	AVA	NF	MONTANA OATT	YTP	AVAT.NWMT	0	15	15	0	81		81
224	Rainbow Electric Marketing Corp.	PPW	BPAT	NF	MONTANA OATT	JEFF	BPAT.NWMT	0	1,457	1,457	0	7,897		7,897
225	Rainbow Electric Marketing Corp.	PPW	BPAT	NF	MONTANA OATT	YTP	BPAT.NWMT	0	2,527	2,527	0	13,696		13,696
226	Rainbow Electric Marketing Corp.	PPW	WAPA	NF	MONTANA OATT	YTP	CROSSOVER	0	6,829	6,829	0	37,013		37,013
227	Rainbow Electric Marketing Corp.	PPW	WAPA	SFP	MONTANA OATT	YTP	CROSSOVER	0	2,808	2,808	0	15,210		15,210
228	Rainbow Electric Marketing Corp.	WAPA	BPAT	NF	MONTANA OATT	CROSSOVER	BPAT.NWMT	0	200	200	0	1,084		1,084
229	Rainbow Electric Marketing Corp.	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	YTP	0	965	965	0	5,230		5,230
230	Rainbow Electric Marketing Corp.	WAUW	NWMT	NF	MONTANA OATT	CROSSOVER	MATL.NWMT	0	2,137	2,137	0	11,899		11,899
231	Shell Energy North America	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	8,802	8,802	0	48,624		48,624
232	Shell Energy North America	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	NWMT.SYSTEM	0	30	30	0	163		163
233	Shell Energy North America	BPAT	NWMT	SFP	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	912	912	0	4,940		4,940
234	Shell Energy North America	BPAT	WAPA	NF	MONTANA OATT	BPAT.NWMT	CROSSOVER	0	2,946	2,946	0	17,361		17,361
235	Shell Energy North America	PPW	WAPA	NF	MONTANA OATT	BRDY	CROSSOVER	0	11	11	0	60		60
236	Shell Energy North America	WAPA	BPAT	NF	MONTANA OATT	CROSSOVER	BPAT.NWMT	0	141	141	0	782		782
237	TEC Energy Inc.	AVA	NWMT	NF	MONTANA OATT	AVAT.NWMT	MATL.NWMT	0	1,150	1,150	0	6,720		6,720
238	TEC Energy Inc.	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	45	45	0	244		244
239	TEC Energy Inc.	PACE	NWMT	NF	MONTANA OATT	BRDY	MATL.NWMT	0	1,575	1,575	0	8,777		8,777
240	TEC Energy Inc.	PPW	WAPA	NF	MONTANA OATT	BRDY	CROSSOVER	0	10	10	0	54		54
241	The Energy Authority	AVA	BPAT	NF	MONTANA OATT	AVAT.NWMT	BPAT.NWMT	0	1	1	0	6		6
242	The Energy Authority	BPAT	NWMT	NF	MONTANA OATT	BPAT.NWMT	MATL.NWMT	0	1,433	1,433	0	7,885		7,885
243	The Energy Authority	BPAT	PPW	NF	MONTANA OATT	BPAT.NWMT	BRDY	0	201	201	0	1,090		1,090
244	The Energy Authority	BPAT	PPW	NF	MONTANA OATT	BPAT.NWMT	YTP	0	296	296	0	1,838		1,838
245	The Energy Authority	BPAT	WAPA	NF	MONTANA OATT	BPAT.NWMT	CROSSOVER	0	1,203	1,203	0	6,632		6,632
246	The Energy Authority	PPW	AVA	NF	MONTANA OATT	BRDY	AVAT.NWMT	0	1	1	0	6		6
247	The Energy Authority	PPW	PPW	NF	MONTANA OATT	MLCK	BRDY	0	1	1	0	6		6
248	The Energy Authority	PPW	WAPA	NF	MONTANA OATT	YTP	CROSSOVER	0	727	727	0	3,940		3,940
249	The Energy Authority	WAPA	BPAT	NF	MONTANA OATT	CROSSOVER	BPAT.NWMT	0	1,410	1,410	0	8,630		8,630
250	The Energy Authority	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	BRDY	0	175	175	0	949		949
251	The Energy Authority	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	YTP	0	519	519	0	3,050		3,050
252	Transalta Energy Marketing (US) Inc.	AVA	PPW	NF	MONTANA OATT	AVAT.NWMT	BRDY	0	11	11	0	68		68
253	Transalta Energy Marketing (US) Inc.	BPAT	PPW	NF	MONTANA OATT	BPAT.NWMT	YTP	0	1,147	1,147	0	6,699		6,699
254	Transalta Energy Marketing (US) Inc.	BPAT	WAPA	NF	MONTANA OATT	BPAT.NWMT	CROSSOVER	0	3,024	3,024	0	17,953		17,953
255	Transalta Energy Marketing (US) Inc.	BPAT	WAPA	SFP	MONTANA OATT	BPAT.NWMT	CROSSOVER	0	360	360	0	2,235		2,235
256	Transalta Energy Marketing (US) Inc.	PPW	BPAT	NF	MONTANA OATT	YTP	BPAT.NWMT	0	4,438	4,438	0	24,054		24,054
257	Transalta Energy Marketing (US) Inc.	PPW	WAPA	NF	MONTANA OATT	BRDY	CROSSOVER	0	576	576	0	3,577		3,577
258	Transalta Energy Marketing (US) Inc.	PPW	WAPA	NF	MONTANA OATT	YTP	CROSSOVER	0	510	510	0	2,764		2,764
259	Transalta Energy Marketing (US) Inc.	WAPA	AVA	NF	MONTANA OATT	CROSSOVER	AVAT.NWMT	0	130	130	0	705		705
260	Transalta Energy Marketing (US) Inc.	WAPA	BPAT	NF	MONTANA OATT	CROSSOVER	BPAT.NWMT	0	2,457	2,457	0	13,528		13,528
261	Transalta Energy Marketing (US) Inc.	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	BRDY	0	218	218	0	1,314		1,314
262	Transalta Energy Marketing (US) Inc.	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	YTP	0	596	596	0	3,453		3,453
263	Western Area Power Administration	NWMT	NWMT	NF	MONTANA OATT	CANYONFERRY	NWMT.SYSTEM	0	1,488	1,488	0	7,870		7,870
264	Western Area Power Administration	NWMT	NWMT	SFP	MONTANA OATT	CANYONFERRY	NWMT.SYSTEM	0	1,438	1,438	0	9,058		9,058
265	Western Area Power Administration	NWMT	WAPA	NF	MONTANA OATT	CANYONFERRY	CROSSOVER	0	12	12	0	65		65
266	Western Area Power Administration	NWMT	WAPA	NF	MONTANA OATT	CANYONFERRY	GREATFALLS	0	56	56	0	304		304
267	Western Area Power Administration	NWMT	WAPA	SFP	MONTANA OATT	CANYONFERRY	CROSSOVER	0	78,837	78,837	0	447,429		447,429
268	Western Area Power Administration	NWMT	WAPA	SFP	MONTANA OATT	CANYONFERRY	GREATFALLS	0	72	72	0	390		390
269	Western Area Power Administration	PPW	WAPA	SFP	MONTANA OATT	YTP	CROSSOVER	0	99,039	99,039	0	574,637		574,637
270	Western Area Power Administration	WAPA	PPW	NF	MONTANA OATT	CROSSOVER	YTP	0	1,680	1,680	0	10,227		10,227
271	Western Area Power Administration	WAPA	PPW	SFP	MONTANA OATT	CROSSOVER	YTP	0	69,840	69,840	0	395,370		395,370
272	Western Area Power Administration	WAPA	WAPA	NF	MONTANA OATT	GREATFALLS	CROSSOVER	0	43,680	43,680	0	247,980		247,980
273	Western Area Power Administration	WAUW	NWMT	SFP	MONTANA OATT	GREATFALLS	GTFALLSNWMT	0	4,368	4,368	0	24,798		24,798
274	Rounding							1	1	1	2	3		1
35	TOTAL							1,479	3,580,872	3,580,872	14,036,956	6,596,798	0	20,633,754

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	Vigilante Elec Coop	OLF	6,588	6,588	12,600			12,600
2	Bonneville Power Administration	OLF					(a) 942,159	942,159
3	Southwest Power Pool	FNS	23,527	23,527	424,010			424,010
4	Supply:
5	Avista	NF	325	325		2,728		2,728
6	Bonneville Power Administration	NF	110,555	110,555		311,893		311,893
7	Idaho Power Company	NF	4,919	4,919		23,868		23,868
8	Snohomish County PUD	NF	621	621		863		863
9	Seattle City Light	NF	2,904	2,904		5,082		5,082
10	Rounding					1		1
	TOTAL		149,439	149,439	436,610	344,433	942,159	1,723,202

Deprec, Depl and Amort of Elec Plant (403,403.1,404,and 405) (except Amortization of Acquisition Adjustments)
Report the year to date amounts of depreciation expense, asset retirement cost depreciation, depletion and amortization, except amortization of acquisition adjustments for the accounts indicated and classified according to the plant functional groups described.
Line No.	FunctionalClassificationAxis Functional Classification (a)	DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b)	DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c)	AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d)	AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e)	DepreciationAndAmortization Total (f)
1	Intangible Plant			1,526,612		1,526,612
2	Steam Production Plant	2,217,362				2,217,362
3	Nuclear Production Plant
4	Hydraulic Production Plant-Conventional	5,874,454				5,874,454
5	Hydraulic Production Plant-Pumped Storage
6	Other Production Plant	5,649,634		160		5,649,794
7	Transmission Plant	14,113,371		290,071		14,403,442
8	Distribution Plant	29,587,006		17,171		29,604,177
9	General Plant	3,193,472				3,193,472
10	Common Plant-Electric	1,953,384		2,555,052		4,508,436
11	TOTAL	62,588,683	0	4,389,066	0	66,977,749

Monthly Peak Loads and Energy Output
Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the required information for each non- integrated system. Report in column (b) by month the system’s output in Megawatt hours for each month. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales. Report in column (d) by month the system’s monthly maximum megawatt load (60 minute integration) associated with the system. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).
Line No.	MonthAxis Month (a)	Total Monthly Energy (MWH) (b)	Monthly Non-Requirements Sales for Resale & Associated Losses (c)	MonthlyPeakLoad Monthly Peak Megawatts (See Instr. 4) (d)	DayOfMonthlyPeak Monthly Peak Day of Month (e)	HourOfMonthlyPeak Monthly Peak Hour (f)
	NAME OF SYSTEM: Montana Operations
1	January
2	February
3	March
4	Total for Quarter 1
5	April	615,357	88,866	2,086	19	9
6	May	580,952	68,679	2,038	8	10
7	June	636,182	88,484	2,331	23	19
8	Total for Quarter 2	1,832,491	246,029
9	July
10	August
11	September
12	Total for Quarter 3
41	Total




FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature

TRANSMISSION OF ELECTRICITY BY ISO/RTOs
Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a). In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided. In column (d) report the revenue amounts as shown on bills or vouchers. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.	Payment Received by (Transmission Owner Name) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Total Revenue by Rate Schedule or Tariff (d)	Total Revenue (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40	TOTAL

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.	Description of Item(s) (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	Energy
2	Net Purchases (Account 555)
2.1	Net Purchases (Account 555.1)
3	Net Sales (Account 447)
4	Transmission Rights
5	Ancillary Services
6	Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL

MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Firm Network Service for Self (e)	Firm Network Service for Others (f)	Long-Term Firm Point-to-point Reservations (g)	Other Long-Term Firm Service (h)	Short-Term Firm Point-to-point Reservation (i)	Other Service (j)
	NAME OF SYSTEM: Montana Operations
1	January	2,183	13	18	1,036	774	575	0	2,209	0
2	February	1,832	15	19	1,022	713	575	0	475	0
3	March	1,731	21	21	1,009	653	575	0	1,148	0
4	Total for Quarter 1				3,067	2,140	1,725	0	3,832	0
5	April	1,582	19	9	1,002	672	504	0	1,840	0
6	May	1,534	8	10	1,001	629	504	0	2,050	0
7	June	1,827	23	19	999	684	504	0	3,080	0
8	Total for Quarter 2				3,002	1,985	1,512	0	6,970	0
9	July
10	August
11	September
12	Total for Quarter 3
13	October
14	November
15	December
16	Total for Quarter 4
17	Total				6,069	4,125	3,237	0	10,802	0

Monthly ISO/RTO Transmission System Peak Load
Report the monthly peak load on the respondent's transmission system. If the Respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Column (c) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (i) by month the system’s transmission usage by classification. Amounts reported as Through and Out Service in Column (g) are to be excluded from those amounts reported in Columns (e) and (f). Amounts reported in Column (j) for Total Usage is the sum of Columns (h) and (i).
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Import into ISO/RTO (e)	Exports from ISO/RTO (f)	Through and Out Service (g)	Network Service Usage (h)	Point-to-Point Service Usage (i)	Total Usage (j)
	NAME OF SYSTEM: Enter System
1	January
2	February
3	March
4	Total for Quarter 1
5	April
6	May
7	June
8	Total for Quarter 2
9	July
10	August
11	September
12	Total for Quarter 3
13	October
14	November
15	December
16	Total for Quarter 4
17	Total Year to Date/Year

FERC FINANCIAL REPORT FERC FORM No. 1: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report

INSTRUCTIONS FOR FILING FERC FORM NOS. 1 and 3-Q

GENERAL INFORMATION

Purpose

Who Must Submit

What and Where to Submit

When to Submit

Where to Send Comments on Public Reporting Burden.

GENERAL INSTRUCTIONS

EXCERPTS FROM THE LAW

GENERAL PENALTIES

FERC FINANCIAL REPORT
FERC FORM No. 1: Annual Report of
Major Electric Utilities, Licensees
and Others and Supplemental
Form 3-Q: Quarterly Financial Report