2024Avista FERC Form No. 2 - Natural Gas.pdf

THIS FILING IS
Item 1: An Initial(Original)Submission OR ❑ Resubmission No.
FERC FINANCIAL REPORT
FERC FORM No. 2: Annual Report of
Major Natural Gas Companies and
Supplemental Form 3-Q: Quarterly
Financial Report
These reports are mandatory underthe Natural Gas Act,Sections 10(a),and 16
nd 18 CFR Parts 260.1 and 260.300 Failure to report may result in criminal
fines,civil penalties,and other sanctions as provided by law.The Federal
Energy Regulatory Commission does not considerthese reports to be of a
!confidential nature.
FAta
Legal Name of Respondent(Company) Year/Period of Report:
End of.2024/Q4
Corporation
FERC FORM NO.2(02-04)

INSTRUCTIONS FOR FILING FERC FORMS 2, 2-A and 3-Q
GENERAL INFORMATION
I. Purpose
FERC Forms 2,2-A,and 3-Q are designed to collect financial and operational information from natural gas companies subject to the
jurisdiction of the Federal Energy Regulatory Commission.These reports are also considered to be a non-confidential public use forms.
11. Who Must Submit
Each natural gas company whose combined gas transported or stored for a fee exceed 50 million dekatherms in each of the previous
three years must submit FERC Form 2 and 3-Q.
Each natural gas company not meeting the filing threshold for FERC Form 2,but having total gas sales or volume transactions exceeding
200,000 dekatherms in each of the previous three calendar years must submit FERC Form 2-A and 3-Q.
Newly established entities must use projected data to determine whether they must file the FERC Form 3-Q and FERC Form 2 or 2-A.
III. What and Where to Submit
a. Submit FERC Form Nos.2,2-A and 3-Q electronically through the eCollection portal at https://eCollection.ferc.gov,and according to
the specifications in the Form 2,2-A and 3-Q taxonomies..
b. The Corporate Officer Certification must be submitted electronically as part of the FERC Form 2 and 3-Q filings.
c. Submit immediately upon publication,by either eFiling or mailing two(2)copies to the Secretary of the Commission,the latest
Annual Report to Stockholders and any annual financial or statistical report regularly prepared and distributed to bondholders,
security analysts,or industry associations.Do not include monthly and quarterly reports.Indicate by checking the appropriate box
on Form 2,Page 3,List of Schedules,if the reports to stockholders will be submitted or if no annual report to stockholders is
prepared.Unless eFiling the Annual Report to Stockholders,mail these reports to the Secretary of the Commission at:
Secretary of the Commission
Federal Energy Regulatory Commission
888 First Street,NE
Washington,DC 20426
d. For the Annual CPA certification,submit with the original submission of this form,a letter or report(not applicable to respondents
classified as Class C or Class D prior to January 1,1984)prepared in conformity with the current standards of reporting which will:
i. Contain a paragraph attesting to the conformity,in all material respects,of the schedules listed below with the Commission's
applicable Uniform Systems of Accounts(including applicable notes relating thereto and the Chief Accountant's published
accounting releases),and
ii. 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.§§158.10-158.12 for specific
qualifications.)
Reference Reference 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
Filers should state in the letter or report,which,if any,of the pages above do not conform to the Commission's requirements.
Describe the discrepancies that exist
e. Filers are encouraged to file their Annual Report to Stockholders,and the CPA Certification Statement using eFiling.Further
instructions are found on the Commission website at hnps://www ferc gov/ferc-online/ferc-online/freauently-asked uestions-faas-
efilinaferc-online.
f. Federal,State and Local Governments and other authorized users may obtain additional blank copies of FERC Form 2 and 2-A free
of charge from:https•//www ferc gov(ndustries-data/natural-gasrindustry-forms.Copies may also be obtained from the Public
Reference and Files Maintenance Branch,Federal Energy Regulatory Commission,888 First Street,NE.Room 2A,Washington,
DC 20426 or by calling(202).502-8371
Iv. When to Submit:
FERC Forms 2,2-A,and 3-Q must be filed by the dates:
a. FERC Form 2 and 2-A—by April 18th of the following year(18 C.F.R.§§260.1 and 260.2)
b. FERC Form 3-Q--Natural gas companies that file a FERC Form 2 must file the FERC Form 3-Q within 60 days after the reporting
quarter(18 C.F.R.§260.300),and
c. FERC Form 3-Q—Natural gas companies that file a FERC Form 2-A must file the FERC Form 3-Q within 70 days after the

reporting quarter(18 C.F.R.§260.300).
V. Where to Send Comments on Public Reporting Burden.
The public reporting burden forthe Form 2 collection of information is estimated to average 1,671.66 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 Form 2A collection of information is estimated to average
295.66 hours per response.The public reporting burden forthe Form 3-Q collection of information is estimated to average 167 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
I. Prepare all reports in conformity with the Uniform System of Accounts(USofA)(18 C.F.R.Part 201).Interpret all accounting words and
phrases in accordance with the USofA.
Il. Enter in whole numbers(dollars or Dth)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.
III. 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.
IV. For any page(s)that is not applicable to the respondent,indicate whether a schedule has been omitted by entering"NA,""NONE,"or"Not
Applicable"in column(d)on the List of Schedules,page 2.
V. Enter the month,day,and yearfor all dates.Use customary abbreviations.The"Date of Report"included in the header of each page
is to be completed only for resubmissions.
VI. 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.
VII. For any resubmissions,please explain the reason for the resubmission in a footnote to the data field.
VIII. Footnote and further explain accounts or pages as necessary.
IX. Do not make references to reports of previous periods/years or to other reports in lieu of required entries,except as specifically
authorized.
X. 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.
XI. Report all gas volumes in Dth unless the schedule specifically requires the reporting in another unit of measurement.
XII. Schedule specific instructions are found in the applicable taxonomy and on the applicable blank rendered form.
DEFINITIONS
I. Btu per cubic foot—The total heating value,expressed in Btu,produced by the combustion,at constant pressure,of the amount of the gas
which would occupy a volume of 1 cubic foot at a temperature of 60°F if saturated with water vapor and under a pressure equivalent to
that of 30oF,and under standard gravitational force(980.665 cm.per sec)with air of the same temperature and pressure as the gas,when
the products of combustion are cooled to the initial temperature of gas and air when the water formed by combustion is condensed to the
liquid state(called gross heating value or total heating value).
II. Commission Authorization—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.
III. Dekatherm—A unit of heating value equivalent to 10 therms or 1,000,000 Btu.
IV. Respondent—The person,corporation,licensee,agency,authority,or other legal entity or instrumentality on whose behalf the report is
made.
EXCERPTS FROM THE LAW
Natural Gas Act,15 U.S.C.717-717w
"Sec.10(a).Every natural-gas company shall file with the Commission such annual and other periodic or special reports as the Commission
may by rules and regulations or order prescribe as necessary or appropriate to assist the Commission in the proper administration of this act.
The Commission may prescribe the manner and form in which such reports shall be made and require from such natural-gas companies
specific answers to all questions upon which the Commission may need information.The Commission may require that such reports include,
among other things,full information as to assets and liabilities,capitalization,investment and reduction thereof,gross receipts,interest dues
and paid,depreciation,amortization,and other reserves,cost of facilities,costs of maintenance and operation of facilities for the production,
transportation,delivery,use,or sale of natural gas,costs of renewal and replacement of such facilities,transportation,delivery,use and sale of
natural gas..."

"Section 16.The Commission shall have power to perform all and any acts,and to prescribe,issue,make,amend,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 form or forms of all statements
declarations,applications,and reports to be filed with the Commission,the information which they shall contain,and time within they shall be
filed..."
General Penalties
The Commission may assess up to$1 million per day per violation of its rules and regulations.See NGA§22(a),15 U.S.C.§717t-1(a).
FERC FORM NO.2

FERC FORM NO. 2
REPORT OF MAJOR NATURAL GAS COMPANIES
IDENTIFICATION
01 Exact Legal Name of Respondent 02 Year/Period of Report
Avista Corporation End of:2024/Q4
03 Previous Name and Date of Change(if name changed during year)
04 Address of Principal Office at End of Year(Street,City,State,Zip Code)
1411 East Mission Avenue,Spokane,WA 99207
05 Name of Contact Person 06 Title of Contact Person
Ryan L.Krasselt VP,Controller,Prin Acctg Officer
07 Address of Contact Person(Street,City,State,Zip Code)
1411 East Mission Avenue,Spokane,WA 99207
08 Telephone of Contact Person,Including Area 09 This Report is An Original/A Resubmission
10 Date of Report(Mo,Da,Yr)
Code (1)0 An Original
04/18/2025
509-495-2273
(2)El A Resubmission
Annual 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.
11 Name 12 Title
Ryan L.Krasselt VP,Controller,Prin Acctg Officer
13 Signature 14 Date Signed
Ryan L.Krasselt 04/18/2025
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.
FERC FORM No.2(02-04)
Page 1

This report is:
Name of Respondent: (1)21 An Original Date of Report: Year/Period of Report:
Avista Corporation (2) El A Resubmission 04/18/2025 End of:2024/Q4
List of Schedules(Natural Gas Company)
Line Title of Schedule Reference Date Revised Remarks
No. (a) Page No. (c) (d)
(b)
Identification 1 02-04
List of Schedules(Natural Gas Company) 2 REV 12-07
GENERAL CORPORATE INFORMATION AND FINANCIAL
STATEMENTS
i
1 General Information 101 12-96
2 Control Over Respondent 102 12-96
3 Corporations Controlled by Respondent 103 12-96
4 Security Holders and Voting Powers 107 12-96
5 Important Changes During the Year 108 12-96
6 Comparative Balance Sheet REV 06-04
Comparative Balance Sheet(Assets And Other Debits) 110 REV 06-04
Comparative Balance Sheet(Liabilities and Other Credits) 112 REV 06-04
7 Statement of Income for the Year 114 REV 06-04
8 Statement of Accumulated Comprehensive Income and 117 NEW 06-02
Hedging Activities
9 Statement of Retained Earnings for the Year 118 REV 06-04
10 Statement of Cash Flows 120 REV 06-04
11 Notes to Financial Statements 122.1 REV 12-07
BALANCE SHEET SUPPORTING SCHEDULES(Assets and
Other Debits)
12 Summary of Utility Plant and Accumulated Provisions for 200 12-96
Depreciation,Amortization,and Depletion
13 Gas Plant in Service 204 12-96
14 Gas Property and Capacity Leased from Others 212 12-96
15 Gas Property and Capacity Leased to Others 2 33 12-96
16 Gas Plant Held for Future Use 214 12-96
17 Construction Work in Progress-Gas 216 12-96
18 Non-Traditional Rate Treatment Afforded New Projects 217 NEW 12-07
19 General Description of Construction Overhead Procedure 218 REV 12-07
20 Accumulated Provision for Depreciation of Gas Utility Plant 219 12-96
21 Gas Stored 220 REV 04-04
22 Investments 222 12-96
FERC FORM No.2(REV 12-07)
Page 2

List of Schedules(Natural Gas Company)
Line Title of Schedule Reference Date Revised Remarks
Pa
No. (a) - Page No. (c) (d)
23 Investments In Subsidiary Companies 224 12-96
24 Prepayments 230a 12-96
25 Extraordinary Property Losses 230b 12-96
26 Unrecovered Plant And Regulatory Study Costs 230c 12-96
27 Other Regulatory Assets 232 REV 12-07
28 Miscellaneous Deferred Debits 233 12-96
29 Accumulated Deferred Income Taxes 234 REV 12-07
BALANCE SHEET SUPPORTING SCHEDULES(Liabilities
and Other Credits)
30 Capital Stock 250 12-96
Capital Stock Subscribed,Capital Stock Liability for
31 Conversion,Premium on Capital Stock,and Installments 252 12-96
Received on Capital Stock
32 Other Paid-in Capital 253 12-96
33 Discount on Capital Stock 254 12-96
34 Capital Stock Expense 254 12-96
35 Securities Issued Or Assumed And Securities Refunded Or 255.1 12-96
Retired During The Year
36 Long-Term Debt 256 12-96
37 Unamortized Debt Expense,Premium And Discount On Long- 258 12-96
Term Debt
38 Unamortized Loss And Gain On Reacquired Debt 260 12-96
39 Reconciliation of Reported Net Income with Taxable Income for 261 12-96
Federal Income Taxes
40 Taxes Accrued,Prepaid And Charged During Year,Distribution 262 REV 12-07
Of Taxes Charged
41 Miscellaneous Current And Accrued Liabilities 268 12-96
42 Other Deferred Credits 269 12-96
43 Accumulated Deferred Income Taxes-Other Property(Account 274 REV 12-07
282)
44 Accumulated Deferred Income Taxes-Other(Account 283) 276 REV 12-07
45 Other Regulatory Liabilities 278 REV 12-07
INCOME ACCOUNT SUPPORTING SCHEDULES
46 Monthly Quantity&Revenue Data 299 NEW 12-08
47 Gas Operating Revenues 300 REV 12-07
48 Revenues From Transportation Of Gas Of Others Through 302 12-96
Gathering Facilities
FERC FORM No.2(REV 12-07)
Page 2

List of Schedules(Natural Gas Company)
Line Title of Schedule Reference e No Date Revised Remarks
No. (a) Pag . (c) (d)
(b)
49 Revenues From Transportation Of Gas Of Others Through 304 12-96
Transmission Facilities
50 Revenues From Storing Gas Of Others 306 12-96
51 Other Gas Revenues 308 12-96
52 Discounted Rate Services And Negotiated Rate Services 313 NEW 12-07
53 Gas Operation And Maintenance Expenses 317 12-96
54 Exchange And Imbalance Transactions 328 12-96
55 Gas Used In Utility Operations 331 12-96
56 Transmission And Compression Of Gas By Others 332 12-96
57 Other Gas Supply Expenses 334 12-96
58 Miscellaneous General Expenses-Gas 335 12-96
59 Depreciation,Depletion,and Amortization of Gas Plant 12-96
59 Section A.Summary of Depreciation,Depletion,and 336 12-96
Amortization Charges
59 Section B.Factors Used in Estimating Depreciation Charges 338 12-96
60 Particulars Concerning Certain Income Deductions And 340 12-96
Interest Charges Accounts
COMMON SECTION 12-96
61 Regulatory Commission Expenses 350 12-96
62 Employee Pensions And Benefits(Account 926) 352 NEW 12-07
63 Distribution Of Salaries And Wages 354 REVISED
64 Charges For Outside Professional And Other Consultative 357 REVISED
Services
65 Transactions With Associated(Affiliated)Companies 358 NEW 12-07
GAS PLANT STATISTICAL DATA
66 Compressor Stations 508 REV 12-07
67 Gas Storage Projects 512 12-96
67 Gas Storage Projects 513 12-96
68 Transmission Lines 514 12-96
69 Transmission System Peak Deliveries 518 12-96
70 Auxiliary Peaking Facilities 519 12-96
71 Gas Account-Natural Gas 520 REV 01-11
72 Shipper Supplied Gas forthe CurrentQuarter 521 REVISED02-11
73 System Maps 522.1 REV.12-96
74 Footnote Reference
FERC FORM No.2(REV 12-07)

Page 2
List of Schedules(Natural Gas Company)
Line Title of Schedule Reference Date Revised Remarks
No. (a) Page No. (c) (d)
75 Footnote Text
76 Stockholders Reports(check appropriate box)
❑ Four copies will be submitted
❑ No annual report to stockholders is prepared
FERC FORM No.2(REV 12-07)
Page 2

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation (2) ❑A Resubmission 04/18/2025 End of.2024/Q4
General Information
1.Provide name and title of officer having custody of the general corporate books of account and address of office where the general
corporate books are kept,and address of office where any other corporate books of account are kept,if different from that where the general
corporate books are kept.
Ryan L.Krasselt
VP,Controller,Prin Acctg Officer
1411 East Mission Avenue,Spokane,WA 99207
2.Provide the name of the State under the laws of which respondent is incorporated,and date of incorporation.If incorporated under a
special law,give reference to such law.If not incorporated,state that fact and give the type of organization and the date organized.
WA State 3/15/1889
State of Incorporation:WA
Date of Incorporation:03/15/1889
Incorporated Under Special Law:
3.If at any time during the year the property of respondent was held by a receiver or trustee,give(a)name of receiver or trustee,(b)date
such receiver or trustee took possession,(c)the authority by which the receivership or trusteeship was created,and(d)date when
possession by receiver or trustee ceased.
None
(a)Name of Receiver or Trustee Holding Property of the Respondent:None
(b)Date Receiver took Possession of Respondent Property:
(c)Authority by which the Receivership or Trusteeship was created:
(d)Date when possession by receiver or trustee ceased:
4.State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.
Electric service in the states of Washington,Idaho and Montana Natural gas service in the states of Washington,Idaho and Oregon
5.Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for
your previous year's certified financial statements?
(1) ❑ Yes
(2)0 No
FERC FORM No.2(12-96)
Page 101

This report is:
Name of Respondent: (1)Z An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2) ❑A Resubmission
Corporations Controlled by Respondent
Type of Percent
Line Name of Company Controlled Control Kind of Business Voting Stock Footnote Reference
No. (a) (b) (c) awned (e)
(d)
1 Avista Capital,Inc. D Parent to the Company's 100%
subsidiaries
2 Avista Development I Investment in Real Estate 100%
3 Avista Edge,Inc. I Investment in Technology 100%
providing high speed Internet
4 Pentzer Corporation I Parent of Bay Area Mfg and 100%
Penture Venture Holdings
5 Pentzer Venture Holdings II 1 Holding Company-Inactive 100%
6 University Development I Facilitates Property Acquisitions 100%
Company,LLC
7 Avista Capital 11 D Affiliated business trust issued 100%
pref trust Securities
8 Avista Northwest Resources, I Owns an interest in a venture 100%
LLC fund investment
9 Courtyard Office Center,LLC I Inactive 100%
10 Salix,Inc. I Liquified Natural Gas 100%
Operations
11 Alaska Energy and Resources D Parent Co of Alaska Operations 100%
Company(AERC)
12 Alaska Electric Light and Power I Utility Operations in Juneau 100%
Company
13 AJT Mining Properties,Inc. I Inactive mining Co holding 100%
certain properties
14 Snettisham Electric Company I Right to Purchase Snettisham 100%
FERC FORM No.2(12-96)
Page 103

Name of Respondent: This report is: Date of Report: Year/Period of Report:
(1)21 An Original
Avista Corporation (2) ❑ A Resubmission 04/18/2025 End of:2024/Q4
Security Holders and Voting Powers
1. Give the names and addresses of the 10 security holders of the respondent who,at the date of the latest closing of the stock book or
compilation of list of stockholders of the respondent,prior to the end of the year,had the highest voting powers in the respondent,and
state the number of votes that each could cast on that date if a meeting were held.If any such holder held in trust,give in a footnote the
known particulars of the trust(whether voting trust,etc.),duration of trust,and principal holders of beneficiary interests in the trust.If the
company did not close the stock book or did not compile a list of stockholders within one year prior to the end of the year,or if since it
compiled the previous list of stockholders,some other class of security has become vested with voting rights,then show such 10
security holders as of the close of the year.Arrange the names of the security holders in the order of voting power,commencing with
the highest.Show in column(a)the titles of officers and directors included in such list of 10 security holders.
2. If any security other than stock carries voting rights,explain in a supplemental statement how such security became vested with voting
rights and give other important details concerning the voting rights of such security.State whether voting rights are actual or
contingent;if contingent,describe the contingency.
3. If any class or issue of security has any special privileges in the election of directors,trustees or managers,or in the determination of
corporate action by any method,explain briefly in a footnote.
4. Fumish details concerning any options,warrants,or rights outstanding at the end of the year for others to purchase securities of the
respondent or any securities or other assets owned by the respondent,including prices,expiration dates,and other material
information relating to exercise of the options,warrants,or rights.Specify the amount of such securities or assets any officer,director,
associated company,or any of the 10 largest security holders is entitled to purchase.This instruction is inapplicable to convertible
securities or to any securities substantially all of which are outstanding in the hands of the general public where the options,warrants.
2.State the total number of votes cast at the
latest general meeting prior to the end of
1.Give date of the latest closing of the stock year for election of directors of the
book prior to end of year,and,in a footnote, respondent and number of such votes cast 3.Give the date and place of such meeting
state the purpose of such closing: by proxy. 5/1/2024 9:00:00 AM
11/26/2024 Total:
71,383,631
By Proxy:
71,383,631
VOTING SECURITIES
Name(Title)and Address of 4.Number of votes as of(date)-
Line Security Holder 12i3112024
No. (a)
Total Votes Common Stock Preferred Stock Other
(b) (c) (d) (e)
5 TOTAL votes of all voting securities 80,038,880 80,038,880
6 TOTAL number of security holders 5,796 5,796
7 TOTAL votes of security holders 42,782,012 42,782,012
listed below
8 BlackRock Institutional Trust 14,227,474 14,227,474
9 The Vanguard Group 10,209,380 10,209,380
10 State Street Global Advisors(US) 4,972,982 4,972,982
11 PSP Investments 3,576,516 3,576,516
12 Columbia Threadneedle 2,685,796 2,685,796
Investments(UK)
13 Geode Capital Management 1,828,566 1,828,566
14 Dimensional Fund Advisors 1,541,469 1,541,469
15 Westwood Management Corp. 1,278,324 1,278,324
(Texas)
16 Charles Schwab Investment 1,253,280 1,253,280
Management

17 I Invesco Capital Management LLC I 1,208,225 I 1,208,225 I J
FERC FORM No.2(12-96)
Page 107

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of.2024/Q4
(2) El A Resubmission
Important Changes During the Year
Give details concerning the matters indicated below.Make the statements explicit and precise,and numberthem in accordance with the
inquiries.Answer each inquiry.Enter"none"or"not applicable"where applicable.If the answer is given elsewhere in the report,referto the
schedule in which it appears.
1. Changes in and important additions to franchise rights:Describe the actual consideration and state from whom the franchise rights
were acquired.If the franchise rights were acquired without the payment of consideration,state that fact.
2. 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.
3. Purchase or sale of an operating unit or system:Briefly describe the property,and the related transactions,and cite Commission
authorization,if any was required.Give date journal entries called for by Uniform System of Accounts were submitted to the
Commission.
4. 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 conditions.State name of Commission authorizing lease and give
reference to such authorization.
5. Important extension or reduction of transmission or distribution system:State territory added or relinquished and date operations
began or ceased and cite 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.
6. Obligations incurred or assumed by respondent as guarantor for the performance by another of any agreement or obligation,including
ordinary commercial paper maturing on demand or not later than one year after date of issue:State on behalf of whom the obligation
was assumed and amount of the obligation.Cite Commission authorization if any was required.
7. Changes in articles of incorporation or amendments to charter:Explain the nature and purpose of such changes or amendments.
8. State the estimated annual effect and nature of any important wage scale changes during the year.
9. 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.
10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer,
director,security holder,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.
11. Estimated increase or decrease in annual revenues caused by important rate changes:State effective date and approximate amount
of increase or decrease for each revenue classification.State the number of customers affected.
12. Describe fully any changes in officers,directors,major security holders and voting powers of the respondent that may have occurred
during the reporting period.
13. 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.
1. None
2.None
3.None
4.None
5.None
6.Reference is made to Notes 10,11 and 12 of the Notes to Financial Statements
7.None

8. Average annual wage increases were 3.7 percent for non-exempt employees and 3.9 percent for exempt employees,effective February 26,2024.Officers
received average increases of 4.5 percent effective February 12,2024.Bargaining Unit employees annual wage increase is retroactively effective on March
26,2024 in the amount of 5 percent.
9.Reference is made to Note 15 of the Notes to the Financial Statements
10.None
11.
Washington General Rate Cases
2024 General Rate Cases
hi December 2024,the WUTC issued orders related to our multi-year electric and natural gas general rate cases filed with the WUTC in January 2024.
The approved rates within the orders are designed to increase annual electric base revenues by S 12 million(or 2.0 percent),effective January 1,2025(Rate Year 1),and$44 million(or
7.5 percent)for Rate Year 2.The difference in approved rates for Rate Year 1 and those included in our original request ofa$77 million increase is primarily due to a S56 million
decrease in power supply costs compared to those set forth in the original request,and also due to a lower approved return on equity than what was requested.The Rate Year 2 increase
represents the effective increase to customers resulting from the$69 million approved in the order,partially offset by a$25 million decrease due to the expiration ofa separate tariffin
effect during Rate Year 1 to collect remaining Colstrip expenses by December 31,2025(see further discussion below).
The approved rates are also designed to increase annual natural gas base revenues by$14 million(or 11.2 percent),effective January 1,2025,and$4 million(or 2.8 percent)for Rate
Year 2.
The WUTC approved an ROE of9.8 percent,based on a common equity ratio of48.5 percent,and an ROR of 7.32 percent.
The WUTC did not approve our request to modify the ERM under which differences between actual net power supply costs and the amount reflected in base retail customer rates are
tracked.Based on our forecast energy commodity costs in 2025 and 2026,we expect actual net power supply costs to exceed the level included in base rates.We plan to continue to
address how net power supply costs are set in base rates in future regulatory proceedings.
The Commission continued its support for important recovery mechanisms such as wildfire and insurance balancing accounts,and decoupling.
Colstrip Tariff
In 20l9,the Washington State Legislature passed the CETA,which.among other things,requires costs associated with coal-fired generation facilities to be removed from tales no later
than December 31,2025.The WUTC order approving the settlement ofthe 2022 general rate cases,discussed above,required us to establish a tracker for our Colstrip-related costs,
including operating and maintenance expense,depreciation and amortization expense,and a return on rate base.hi October 2024,we filed a cost recovery tariffseeking to recoverthe
costs associated with our ownership of Colstrip in 2025.In the filing,we requested an increase in annual Colstrip tariffrevenues of S19 million-from$24 million in 2024 to S43
million in 2025,effective January 1,2025.In its review,WUTC Staffraised three concerns related to(1)whether forecasted 2025 investments are allowed in rates;(2)whetherthe
capital investment included in the filing will be used and useful for customers prior to the end of2025;and(3)one major capital investment that will not be in service until 2027.In
December 2024,the WUTC allowed our filed tariffto go into effect,but set the rates as subject to refund.The WUTC set the matter for adjudication in 2025,but also ordered us,
WUTC Staff,and other interested parties to meet and resolve the issues.Astatus report is due to the WUTC by March 31,2025.Ifthe parties cannot resolve the concerns of WUTC
Staff,we believe a procedural schedule will be developed and a hearing date set.
Idaho General Rate Cases
2025 General Rate Case
In January 2025,we filed multiyear electric and natural gas general rate cases with the IPUC.If approved,new rates would be effective in September 2025 and September 2026.The
proposed rates are designed to increase annual base electric revenues by$43 million,or 14.0 percent,effective in September2025,and$18 million,or 5.0 percent,effective in
September2026.For natural gas,the proposed rates are designed to increase annual base natural gas revenues by$9 million,or 17.7 percent,effective September2025,and$1
million,or 1.7 percent,effective September 2026.The proposed electric and natural gas revenue increase requests are based on an ROR of 7.68 percent,with a common equity ratio of
50 percent and an ROE of 10.4 percent.Ongoing capital infrastructure investment(including replacement ofwood poles and natural gas distribution pipe,continued investment in the
wildfire resiliency plan,and technology)and increases in operations,maintenance,and power supply costs are the main drivers ofthe proposed increases.The IPUC has up to nine
months to review the general rate case filings and issue a decision.
Oregon General Rate Cases
2024 General Rate Case
In March 2025,we reached an all-party settlement agreement,which has been submitted to the OPUC for its consideration.
Ifapproved,the settlement agreement is designed to increase annual base revenues by$4 million,or 5.0 percent,effective in September2025.The settlement is based on an ROE of
9.5 percent with a common equity ratio of 50 percent and an ROR of 7.22 percent.
To mitigate the overall impact ofthe revenue increases on customers,$5.0 million ofcustomer tax credits will be accelerated and returned to customers over a three-year period.
12. In August 2024,Chief Executive Officer Dennis Vermillion announced he will retire from the Company in the first quarter of 2025.Avista President
and Chief Operating Officer Heather Rosentrater has been appointed CEO by the board of directors,effective January 1,2025.She has also been appointed
to the board of directors,effective January 1,2025.
13.None.
FERC FORM No.2(12-96)
Page 108

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation (2) El A Resubmission 04/18/2025 End of:2024/Q4
Comparative Balance Sheet(Assets And Other Debits)
Line Title of Account Reference Page Current Year End of prior Year End Balance 1231
No. (a) Number Quarter/Year Balance (d)
1 UTILITY PLANT :10 1
2 Utility Plant(101-106,114) 200-201 8,212,758,967 7,852,959,203
3 Construction Work in Progress(107) 200-201 206,589,639 170,812,964
4 TOTAL Utility Plant(Total of lines 2 and 3) 200-201 8,419,348,606 8,023,772,167
5 (Less)Accum.Provision for Depr.,Amort.,Depl. 2,959,941,113 2,796,332,034
(108,111,115)
6 Net Utility Plant(Total of line 4 less 5) 5,459,407,493 5,227,440,133
7 Nuclear Fuel(120.1 thru 120.4,and 120.6) 0 0
8 (Less)Accum.Provision for Amort.,of Nuclear 0 0
Fuel Assemblies(120.5)
9 Nuclear Fuel(Total of line 7 less 8) 0 0
10 Net Utility Plant(Total of lines 6 and 9) 5,459,407,493 5,227,440,133
11 Utility Plant Adjustments(116) 122 0 0
12 Gas Stored-Base Gas(117.1) 220 6,992,076 6,992,076
13 System Balancing Gas(117.2) 220 0 0
Gas Stored in Reservoirs and Pipelines-
14 Noncurrent(117.3) 220 0 0
15 Gas Owed to System Gas(117.4) 220 0 0
16 OTHER PROPERTY AND INVESTMENTS
17 Nonutility Property(121) 22,724,548 22,796,933
18 (Less)Accum.Provision for Depreciation and 114,549 110,345
Amortization(122)
19 Investments in Associated Companies(123) 222-223 11,547,000 11,547,000
20 Investments in Subsidiary Companies(123.1) 224-225 261,742,212 265,210,641
22 Noncurrent Portion of Allowances 0 0
23 Other Investments(124) 222-223 14,094 14,094
24 Sinking Funds(125) 0 0
25 Depreciation Fund(126) 0 0
26 Amortization Fund-Federal(127) 0 0
27 Other Special Funds(128) 21,331,917 15,335,490
28 Long-Term Portion of Derivative Assets(175) 0 0
29 Long-Term Portion of Derivative Assets-Hedges 0 0
(176)
FERC FORM No.2(REV 06-04)
Page 110

Comparative Balance Sheet(Assets And Other Debits)
Line Title of Account Reference Page Current Year End of prior Year End Balance 12t31
No. (a) Number QuarterNear Balance (d)
(b) (c)
30 TOTAL Other Property and Investments(Total of 317,245,222 314,793,813
lines 17-20,22-29)
31 CURRENT AND ACCRUED ASSETS
32 Cash(131) 2,733,182 11,843,507
33 Special Deposits(132-134) 0 0
34 Working Funds(135) 1,108,576 758,362
35 Temporary Cash Investments(136) 222-223 19,917,239 15,991,036
36 Notes Receivable(141) 0 0
37 Customer Accounts Receivable(142) 189,162,196 199,763,204
38 Other Accounts Receivable(143) 43,278,432 38,651,095
39 (Less)Accum.Provision for Uncollectible 4,804,889 4,905,146
Accounts-Credit(144)
40 Notes Receivable from Associated Companies 29,187,996 20,584,744
(145)
41 Accounts Receivable from Associated 85,106 978,859
Companies(146)
42 Fuel Stock(151) 6,331,080 4,683,150
43 Fuel Stock Expenses Undistributed(152) 0 0
44 Residuals(Elec)and Extracted Products(Gas) 0 0
(153)
45 Plant Materials and Operating Supplies(154) 101,576,700 79,492,528
46 Merchandise(155) 0 0
47 Other Materials and Supplies(156) 0 0
48 Nuclear Materials Held for Sale(157) 0 0
49 Allowances(158.1 and 158.2) 1,175,388 30,071,678
50 (Less)Noncurrent Portion of Allowances 0 0
51 Stores Expense Undistributed(163) 0 0
52 Gas Stored Underground-Current(164.1) 220 10,258,810 -16,271,620
53 Liquefied Natural Gas Stored and Held for 220 0 0
Processing(164.2 thru 164.3)
54 Prepayments(165) 230 29,781,526 50,221,552
55 Advances for Gas(166 thru 167) 0 0
56 Interest and Dividends Receivable(171) 4,053,293 2,627,341
57 Rents Receivable(172) 6,058,492 7,380,742
58 Accrued Utility Revenues(173) 0 0
59 Miscellaneous Current and Accrued Assets(174) 10,090 0
FERC FORM No.2(REV 06-04)
Page 110

Comparative Balance Sheet(Assets And Other Debits)
Line Title of Account Reference Page Current Year End of Prior Year End Balance 12/31
No (a) Number Quarter/Year Balance (d)
(b) (c)
60 Derivative Instrument Assets(175) 11,061,997 11,821,033
61 (Less)Long-Term Portion of Derivative
Instrument Assets(175) 0 0
62 Derivative Instrument Assets-Hedges(176) 0 0
63 (Less)Long-Term Portion of Derivative 0 0
Instrument Assets-Hedges(176)
TOTAL Current and Accrued Assets(Total of
64 lines 32 thru 63) 450,975,214 486,235,305
65 DEFERRED DEBITS
66 Unamortized Debt Expense(181) 21,102,539 21,586,301
67 Extraordinary Property Losses(182.1) 230 0 0
68 Unrecovered Plant and Regulatory Study Costs 230 0 0
(182.2)
69 Other Regulatory Assets(182.3) 232 893,411,579 898,192,107
70 Preliminary Survey and Investigation Charges
(Electric)(183) 0 0
71 Preliminary Survey and Investigation Charges 0 0
(Gas)(183.1 and 183.2)
72 Clearing Accounts(184) 691,571 858,506
73 Temporary Facilities(185) 0 0
74 Miscellaneous Deferred Debits(186) 233 104,072,323 87,517,904
75 Deferred Losses from Disposition of Utility Plant 0 0
(187)
76 Research,Development,and Demonstration 0 0
Expend.(188)
77 Unamortized Loss on Reacquired Debt(189) 5,232,161 5,701,051
78 Accumulated Deferred Income Taxes(190) 234-235 154,122,918 214,152,188
79 Unrecovered Purchased Gas Costs(191) (24,996,804) 51,370,535
80 TOTAL Deferred Debits(Total of lines 66 thru 79) 1,153,636,287 1,279,378,592
81 TOTAL Assets and Other Debits(Total of lines 7,388,256,292 7,314,839,919
10-15,30,64,and 80)
FERC FORM No.2(REV 06-04)
Page 110

FOOTNOTE DATA
U Concept:GasStoredCurrent
Fuel is accounted for within injections and withdrawal accounts.
All gas reported is current working gas.Avista uses the inventory method to report all working gas stored.
FERC FORM No.2(REV 06-04)
Page 110

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation (2) ❑A Resubmission 04/18/2025 End of:2024/Q4
Comparative Balance Sheet(Liabilities and Other Credits)
Line Title of Account Reference Page Current Year End of Prior Year End Balance 12131
No. (a) Number Quarter[Year Balance (d)
(b) (c)
1 PROPRIETARY CAPITAL
2 Common Stock Issued(201) 250-251 1,667,222,874 1,596,986,047
3 Preferred Stock Issued(204) 250-251 0 0
4 Capital Stock Subscribed(202,205) 252 0 0
5 Stock Liability for Conversion(203,206) 252 0 0
6 Premium on Capital Stock(207) 252 0 0
7 Other Paid-In Capital(208-211) 253 (2,732,405) (2,732,405)
8 Installments Received on Capital Stock(212) 252 0 0
9 (Less)Discount on Capital Stock(213) 254 0
10 (Less)Capital Stock Expense(214) 254 (55,172,369) (50,073,294)
11 Retained Earnings(215,215.1,216) 118-119 831,698,463 798,215,179
12 Unappropriated Undistributed Subsidiary 118-119 39,097,599 43,138,900
Earnings(216.1)
13 (Less)Reacquired Capital Stock(217) 250-251 0 0
14 Accumulated Other Comprehensive Income 117 355,480
(219) (357,109)
15 TOTAL Proprietary Capital(Total of lines 2 thru 2,590,814,380 2,485,323,906
14)
16 LONG TERM DEBT
17 Bonds(221) 256-257 2,543,700,000 2,543,700,000
18 (Less)Reacquired Bonds(222) 256-257 0 83,700,000
19 Advances from Associated Companies(223) 256-257 51,547,000 51,547,000
20 Other Long-Term Debt(224) 256-257 0 0
21 Unamortized Premium on Long-Term Debt(225) 258-259 97,717 106,600
22 (Less)Unamortized Discount on Long-Term 258-259 749,866 795,576
Debt-Dr(226)
23 (Less)Current Portion of Long-Term Debt 0 0
24 TOTAL Long-Term Debt(Total of lines 17 thru 23) 2,594,594,851 2,510,858,024
25 OTHER NONCURRENT LIABILITIES
26 Obligations Under Capital Leases-Noncurrent 61,843,479 63,558,661
(227)
27 Accumulated Provision for Property Insurance TO0
(228.1)
FERC FORM No.2(REV 06-04)
Page 112

Comparative Balance Sheet(Liabilities and Other Credits)
Lino Title of Account Reference Page Current Year End of Prior Year End Balance 12131
No. (a) Number Quarter/Year Balance (d)
(b) (c)
28 Accumulated Provision for Injuries and Damages 1,245,000 995,000
(228.2)
Accumulated Provision for Pensions and
29 Benefits(228.3) 74,523,208 89,829,937
30 Accumulated Miscellaneous Operating 0 0
Provisions(228.4)
31 Accumulated Provision for Rate Refunds(229) 447,773 618,329
32 Long-Term Portion of Derivative Instrument 11,967,539 17,902,180
Liabilities
33 Long-Term Portion of Derivative Instrument 0 0
Liabilities-Hedges
34 Asset Retirement Obligations(230) 18,173,105 18,058,399
35 TOTAL Other Noncurrent Liabilities(Total of lines 168,200,104 190,962,506
26 thru 34)
36 CURRENT AND ACCRUED LIABILITIES ,t
37 Current Portion of Long-Term Debt 0 0
38 Notes Payable(231) 342,000,000 349,000,000
39 Accounts Payable(232) 122,286,620 136,101,468
40 Notes Payable to Associated Companies(233) 0 0
41 Accounts Payable to Associated Companies 0 0
(234)
42 Customer Deposits(235) 13,883,447 11,208,693
43 Taxes Accrued(236) 262-263 33,241,269 31,879,207
44 Interest Accrued(237) 22,596,692 22,318,892
45 Dividends Declared(238) 0
46 Matured Long-Term Debt(239) 0 0
47 Matured Interest(240) 0 0
48 Tax Collections Payable(241) 397,222 40,534
49 Miscellaneous Current and Accrued Liabilities 268 75,770,212 99,744,896
(242)
50 Obligations Under Capital Leases-Current(243) 4,519,343 4,490,212
51 Derivative Instrument Liabilities(244) 26,352,702 35,118,959
52 (Less)Long-Term Portion of Derivative 11,967,539 17,902,180
Instrument Liabilities
53 Derivative Instrument Liabilities-Hedges(245) 0 0
54 (Less)Long-Term Portion of Derivative 0 0
Instrument Liabilities-Hedges
FERC FORM No.2(REV 06-04)
Page 112

Comparative Balance Sheet(Liabilities and Other Credits)
Line Title of Account Reference Page Current Year End of prior Year End Balance 12/31
No. (a) Number Quarter/Year Balance (d)
(b) (c)
55 TOTAL Current and Accrued Liabilities(Total of 629,079,968 672,000,681
lines 37 thru 54)
56 DEFERRED CREDITS
57 Customer Advances for Construction(252) 6,506,104 4,436,513
58 Accumulated Deferred Investment Tax Credits 28,097,819 28,233,162
(255)
59 Deferred Gains from Disposition of Utility Plant 0 0
(256)
60 Other Deferred Credits(253) 269 33,705,422 32,918,243
61 Other Regulatory Liabilities(254) 278 452,664,319 479,233,915
62 Unamortized Gain on Reacquired Debt(257) 260 820,535 942,384
63 Accumulated Deferred Income Taxes- 0 0
Accelerated Amortization(281)
64 Accumulated Deferred Income Taxes-Other 657,327,906 653,219,870
Property(282)
65 Accumulated Deferred Income Taxes-Other 226,444,884 256,710,715
(283)
66 TOTAL Deferred Credits(Total of lines 57 thru 1,405,566,989 1,455,694,802
65)
67 TOTAL Liabilities and Other Credits(Total of 7,388,256,292 7,314,839,919
lines 15,24,35,55,and 66)
FERC FORM No.2(REV 06-04)
Page 112

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2) El A Resubmission
Statement of Income
Reference Total Current Year Total Prior Year to Curt&rtt Three Prior Three Months
Line Title of Account Page to Date Balance for Date Balance for Months Ended Ended Quarterly
No. (a) Number Quarter/Year Quarter/Year Quarterly Only No Only No Fourth
(d) Fourth Quarter Quarter
(e) (f)
1 UTILITY OPERATING INCOME
2 Gas Operating Revenues(400) 300-301 1,932,090,931 1,813,140,867
3 Operating Expenses
4 Operation Expenses(401) 317-325 1,151,916,199 1,129,074,478
5 Maintenance Expenses(402) 317-325 86,506,944 86,720,955
6 Depreciation Expense(403) 336-338 199,439,998 194,611,959
7 Depreciation Expense for Asset 336-338 0 0
Retirement Costs(403.1)
8 Amort.&Depl.of Utility Plant 336-338 64,711,332 62,239,993
(404-405)
9 Amortization of Utility Plant Acu. 336-338 0 0
Adjustment(406)
Amort.of Prop.Losses,
10 Unrecovered Plant and Reg. 0 0
Study Costs(407.1)
11 Amortization of Conversion 0 0
Expenses(407.2)
12 Regulatory Debits(407.3) 92,390,929 64,155,411
13 (Less)Regulatory Credits 102,105,265 102,019,225
(407.4)
14 Taxes Other Than Income Taxes 262-263 120,874,933 118,141,439
(408.1)
15 Income Taxes-Federal(409.1) 262-263 8,736,878 2,419,168
16 Income Taxes-Other(409.1) 262-263 1,186,219 895,264
17 Provision of Deferred Income 234-235 58,356,281 36,404,931
Taxes(410.1)
18 (Less)Provision for Deferred 234-235 65,245,950 74,741,597
Income Taxes-Credit(411.1)
19 Investment Tax Credit (135,343) (551,283)
Adjustment-Net(411.4)
20 (Less)Gains from Disposition of 0 0
Utility Plant(411.6)
21 Losses from Disposition of Utility 0 0
Plant(411.7)
22 (Less)Gains from Disposition of 0 0
Allowances(411.8)
FERC FORM No.2(REV 06-04)
Page 114

Statement of Income
Reference Total Current Year Total Prior Year to Current Threa Prior Three Months
Line Title of Account Page to Date Balanco for Date Balanco for Months Ended Ended Quarterly
No. (a) Number Quarter/Year Quarter/Year Quarterly Only No Only No Fourth
(b) (c) (d) Fourth Quarter Quarter
(e) (t?
23 Losses from Disposition of 0 0
Allowances(411.9)
24 Accretion Expense(411.10) 0 0
TOTAL Utility Operating
25 Expenses(Total of lines 4 thru 1,616,633,155 1,517,351,493
24)
26 Net Utility Operating Income 315,457,776 295,789,374
(Total of lines 2 less 25)
28 OTHER INCOME AND
DEDUCTIONS
29 Other Income
30 Nonutilty Operating Income
Revenues From Merchandising,
31 Jobbing and Contract Work 0 0
(415)
(Less)Costs and Expense of
32 Merchandising,Job&Contract 0 0
Work(416)
Revenues From Nonutility
33 11,937 0
Operations(417)
34 (Less)Expenses of Nonutility 13,762,536 7,891,784
Operations(417.1)
35 Nonoperating Rental Income (1,513) (1,034)
(418)
36 Equity in Earnings of Subsidiary 119 1,531,571 4,449,671
Companies(418.1)
37 Interest and Dividend Income 17,033,145 15,537,184
38 Allowance for Other Funds Used 127,811 (39,011)
During Construction(419.1)
39 Miscellaneous Nonoperating 17,486 16,773
Income(421)
40 Gain on Disposition of Property 1,974,406 0
(421.1)
41 TOTAL Other Income(Total of 6,932,307 12,071,799
lines 31 thru 40)
42 Other Income Deductions
43 Loss on Disposition of Property 0 40,896
(421.2)
44 Miscellaneous Amortization 5,617 5,616
(425)
45 Donations(426.1) 340 2,807,938 2,755,476
FERC FORM No.2(REV 06-04)
Page 114

Statement of Income
Reference Total Current Year Total Prior Year to Current Three Prior Three Months'
Line Title of Account Page to Date Balance for Date Balance far Months Ended Ended Quarterly
No. (a) Number Quai'Ior/Year Quarter/Year Quarterly Only No Only No Fourth
(b) (c) (d) Fourth Quarter Quarter
(e) (�
46 Life Insurance(426.2) 2,491,193 2,661,064
47 Penalties(426.3) 41,895 25,450
Expenditures for Certain Civic,
48 Political and Related Activities 1,728,138 1,775,518
(426.4)
49 Other Deductions(426.5) 2,480,852 1,410,301
TOTAL Other Income
50 Deductions(Total of lines 43 thru 340 9,555,633 8,674,321
49)
Taxes Applic.to Other Income
51 and Deductions
52 Taxes Other Than Income Taxes 262-263 2,046,797 462,271
(408.2)
53 Income Taxes-Federal(409.2) 262-263 (4,610,911) (2,079,651)
54 Income Taxes-Other(409.2) 262-263 (151,483) (75,004)
55 Provision for Deferred Income 234-235 7,514,751 3,954,988
Taxes(410.2)
56 (Less)Provision for Deferred 234-235 4,206,684 2,286,595
Income Taxes-Credit(411.2)
57 Investment Tax Credit 0 0
Adjustments-Net(411.5)
58 (Less)Investment Tax Credits
(420)
TOTAL Taxes on Other Income
59 and Deductions(Total of lines 592,470 (23,991)
52-58)
Net Other Income and
60 Deductions(Total of lines 41,50, (3,215,796) 3,421,469
59)
61 INTEREST CHARGES
62 Interest on Long-Term Debt(427) 115,125,685 110,131,468
63 Amortization of Debt Disc.and 258-259 612,619 1,544,188
Expense(428)
64 Amortization of Loss on 1,420,427 1,317,067
Reacquired Debt(428.1)
65 (Less)Amortization of Premium 1 258-259 8,883 8,883
on Debt-Credit(429)
66 (Less)Amortization of Gain on
Reacquired Debt-Credit(429.1)
Interest on Debt to Associated
67 340 2,575,297 2,503,671
Companies(430)
FERC FORM No.2(REV 06-04)
Page 114

Statement of Income I
Reference Total Current Year Total Prior Year to Current Three Prior Three Months
Line Title of Account Page to Date Balance for Date Balance for Months Ended Ended Quarterly
No. (a) Number Quarter/Year Quarter/Year Quarterly Only No Only No Fourth
(b) (c) (d) Fourth Quarter Quarter
(e) (f)
68 Other Interest Expense(431) 340 23,608,892 21,435,607
(Less)Allowance.for Borrowed
69 Funds Used During 11,227,623 8,892,489
Construction-Credit(432)
70 Net Interest Charges(Total of 132,106,414 128,030,629
lines 62 thru 69)
Income Before Extraordinary
71 Items(Total of lines 27,60 and 180,135,566 171,180,214
70)
72 EXTRAORDINARY ITEMS
73 Extraordinary Income(434) 0 0
74 (Less)Extraordinary Deductions
(435)
75 Net Extraordinary Items(Total of 0 0
line 73 less line 74)
76 Income Taxes-Federal and Other 262-263 0 0
(409.3) '
Extraordinary Items after Taxes
77 (line 75 less line 76) 0 0
78 Net
Income(Total of line 71 and 180,135,566 171,180,214
77)
FERC FORM No.2(REV 06-04)
Page 114

Statement of Income
Ll1W."Jf }y etitlR2nt L .Ut°iTi13t Previous Gas1.11 r Current Gas Utility Previous Other Utility Current Other Utility
hire Year to Date(in Year to Date(in Year to Date(in Year to Date(in Year to Date(in Previous Year to
No. dollars) dollars) dollars) dollars) dollars) Date(in dollars)
(g) (h) (i) (f) (k) (I)
H31
2 1,326,892,156 1,193,674,365 605,198,775 619,466,502
4 753,625,794 674,026,748 398,290,405 455,047,730
5 71,891,225 71,447,477 14,615,719 15,273,478
6 153,386,157 149,272,689 46,053,841 45,339,270
7 0 0 0 0
8 49,179,154 46,738,641 15,532,178 15,501,352
9 0 0 0 0
10
11 0 0
12 29,114,169 21,751,021 63,276,760 42,404,390
13 50,294,571 43,048,247 51,810,694 58,970,978
14 83,037,800 79,882,775 37,837,133 38,258,664
15 (11,228,757) (7,715,052) 19.965,635 10,134,220
16 20,284 20,224 1,165,935 875,040
17 45,633,776 29,355,257 12,722,505 7,049,674
18 31,152,894 47,088,945 34,093,056 27,652,652
19 (130,623) (546,563) (4,720) (4,720)
20
21
22
23
24
25 1,093,081,514 974,096,025 523,551,641 543,255,468 0 0
26 233,810,642 219,578,340 81,647,134 76,211,034 0 0
28
29
30
31
32
33
FERC FORM No.2(REV 06-04)
Page 114

Statement of Income
Elec.Utility Current Elec.Utility Previous Gas Utiity Current Gas Utility Previous Other Utility Current Other Utility
Line Year to Date(in Year to Date(in Year to Date(in Year to Date(in Year to Date(in Previous Year to
No. dollars) dollars) dollars) dollars) dollars) Date(in dollars)
(9) (h) (i) (1) (k) (1)
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
i
55
56
57
58
59
60
61 l
62 1 l
63
64
65
FERC FORM No.2(REV 06-04)
Page 114

Statement of Income
Elec.Utility Current Elec.Utility Previous Gas Utiity Current Gas Utility Previous Other Utility Current Other Utility
Line Yearto Date(in Year to Date(in Year to Date(in Year to Date(in Year to Date(in Previous Year to
No. dollars) dollars) dollars) dollars) dollars) Date(in dollars)
(g) ---] (h) (i) (1) (k) 11)
66
67
68
69 I r f
70
71
72
73
74
75
76
77
78
FERC FORM No.2(REV 06-04)
Page 114

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation (2) ❑ A Resubmission 04/18/2025 End of:2024/Q4
Statement of Accumulated Comprehensive Income and Hedging Activities
Other'
Unrealized Other Cash Totals for
Gains and
Minimum Cash Flow each Net Income
Losses on
Pension Foreign Other Flow Hedges category of (Carried Total
Line Item available- Adj strnents liabililty Currency u Hedges [Insert items Forward from Comprehensive
No. (a) Adjustment Hedges interest Footnote Page 114, Income
for-sale net amount (e) recorded in
securities ( ) (d) Rate at Line 1 Line 78) (j)
(b) ((c) Swaps to Accoh) 219 (I)
(f) specify]
(g)
Balance of
1 Account 219 at (2,058,225
Beginning of ) (2,058,225)
Preceding Year
Preceding
Quarter/Yearto
Date
2 Reclassifications
from Account
219 to Net
Income
Preceding
3 Quarter/Yearto 1,701,116 1,701,116
Date Changes in
Fair Value
4 Total(lines 2 and 1,701,116 1,701,116 171,180,214 172,881,330
Balance of
Account 219 at
5 End of (357,109) (357,109)
Preceding
Quarter/Year
Balance of - .
6 Account 219at (357,109) (357,109)
Beginning of
Current Year
Current
Quarter/Year to
Date
7 Reclassifications
from Account
219 to Net
Income
Current
8 Quarter/Yearto 712,589 712,589
Date Changes in
Fair Value
9 Total(lines 7 and 712,589 712,589 180,135,566 180.848,155
Balance of
Account 219 at
10 End of Current 355,480 355,480 ,1
Quarter/Year
FERC FORM No.2(NEW 06-02)
Page 117

This report is: Year/Period of Report:
Name of Respondent: (1)21 An Original Date of Report:
Avista Corporation (2) ❑ A Resubmission 04/18/2025 End of-2024/Q4
Statement of Retained Earnings
Line Item 60ntra'P1 ry &Iffcnt Quarter1Year t S Q%fowdVoryar
No. (a) Account Affected Date Balance to Date Balance
W (c) (d)
UNAPPROPRIATED RETAINED EARNINGS
1 Balance-Beginning of Period 741,321,490 717,509,955
2 Changes(Identify by prescribed retained
earnings accounts)
3 Adjustments to Retained Earnings(Account
439)
3.1 Dividends Received from Subs 5,000,000
4 Adjustments to Retained Earnings Credit(Debit)
6 Balance Transferred from Income(Account 433 178,603,995 166,730,543
less Account 418.1)
7 Appropriations of Retained Earnings(Account
436)
7.1 Excess Earnings (2,537,300) (1,835,879)
8 Appropriations of Retained Earnings Amount
9 Dividends Declared-Preferred Stock(Account
437)
10 Dividends Declared-Preferred Stock Amount
11 Dividends Declared-Common Stock(Account
438)
11.1 Dividends (150,693,583) (141,368,296)
12 Dividends Declared-Common Stock Amount
13 Transfers from Account 216.1,Unappropriated 572,872 285,167
Undistributed Subsidiary Earnings
14 Balance-End of Period(Total of lines 1,4,5,6, 772,267,474 741,321,490
8,10,12,and 13)
15 APPROPRIATED RETAINED EARNINGS
(Account 215)
16 TOTAL Appropriated Retained Earnings 59,430,989 56,893,689
(Account 215)(footnote details)
APPROPRIATED RETAINED EARNINGS-
17 AMORTIZATION RESERVE,FEDERAL
(Account 215.1)
18 TOTAL Appropriated Retained Earnings-
Amortization Reserve,Federal(Account 215.1)
TOTAL Appropriated Retained Earnings
19 (Accounts 215,215.1)(Total of lines of 16 and 59,430,989 56,893,689
18)
20 TOTAL Retained Earnings(Accounts 215, 831,698,463 798,215,179
215.1,216)(Total of lines 14 and 19)
FERC FORM No.2(REV 06-04)
Page 118

Statement of Retained Earnings
Line Item Contra Primary Current Quarter/Year&arto Previous o arteriYear Year
No. (a) Account Affected Date Balance to Date Balance
(b) (c) (d)
21 UNAPPROPRIATED UNDISTRIBUTED
SUBSIDIARY EARNINGS(Account216.1)
Report only on an Annual Basis no Quarterly
22 Balance-Beginning of Year(Debit or Credit) 43,138,900 38,974,396
23 Equity in Earnings for Year(Credit)(Account
418.1) 1,531,571 4,449,671
24 (Less)Dividends Received(Debit) 5,000,000 0
25 Other Changes(Explain) (572,872) (285,167)
25.1 Corporate Costs Allocated to Subsidiaries (572,872) (285,167)
26 1 Balance-End of Year 39,097,599 43,138,900
FERC FORM No.2(REV 06-04)
Page 118

This report is: Year/Period of Report:
Name of Respondent: (1)®An Original Date of Report:
Avista Corporation 04/18/2025
(2) El Resubmission End of:2024/Q4
Statement of Cash Flows
Description(See Instructions for explanation of codes)Current Yearto Date QuarterNcar Previous Year to Date
Line No. (a) (b) QuarterNear
(0;_
1 Net Cash Flow from Operating Activities
2 Net Income(Line 78(c)on page 114) 180,135,566 171,180,214
3 Noncash Charges(Credits)to Income:
4 Depreciation and Depletion 264,151,330 256,851,952
5 Amortization of(Specify)(footnote details)
5.1 Amortization of deferred power and gas costs 104,279,052 7,171,847
5.2 Amortization of debt expense 2,024,163 2,852,372
6 Deferred Income Taxes(Net) (3,581,603) (36,037,425)
7 Investment Tax Credit Adjustments(Net) (135,343) (551,283)
8 Net(Increase)Decrease in Receivables (376,114) 39,845,414
9 Net(Increase)Decrease in Inventory (17,719,292) 4,047,260
10 Net(Increase)Decrease in Allowances Inventory 9,815,601 (30,071,678)
11 Net Increase(Decrease)in Payables and Accrued -(3,490,756) -(50,860,477)
Expenses
12 Net(Increase)Decrease in Other Regulatory Assets (47,639,430) (53,098,758)
13 Net Increase(Decrease)in Other Regulatory Liabilities (7,394,628) 34,302,152
14 (Less)Allowance for Other Funds Used During 8,294,329 6,340,790
Construction
15 (Less)Undistributed Earnings from Subsidiary 1,531,571 4,449,671
Companies
16 Other Adjustments to Cash Flows from Operating
Activities
16.1 Power and natural gas deferrals (2,094,117) (6,119,299)
16.2 Change in special deposits 18,067,069 129,225,987
16.3 Change in other current assets 20,326,234 (26,445,069)
16.4 Non-cash stock compensation 9,195,907 8,441,581
16.5 Loss(Gain)on sale of property and equipment (1,975,266) 40,896
16.6 Other (3,937,118) (3,283,209)
16.7 Allowance for Doubtful Accounts 7,250,703 3,917,172
16.8 Changes in other non-current assets and liabilities 646,854 (13,741,356)
16.9 Cash paid for settlement of interest rate swaps 0 (409,000)
16.10 Cash Received for Settlement of Interest Rate Swaps 4,397,000 7,868,930
FERC FORM No.2(REV 06-04)
Page 120

Statement of Cash Flows
Description(See Instructions for explanation of codes)Current Year to Date Quarter/Year Previous Year to Date
Line No. QuatterfYear
(a) (b) (c)
18 Net Cash Provided by(Used in)Operating Activities 522,119,912 434,337,762
(Total of Lines 2 thru 16)
20 j Cash Flows from Investment Activities:
21 Construction and Acquisition of Plant(including land):
22 Gross Additions to Utility Plant(less nuclear fuel) L(518,461,489) -(490,335,100)
23 Gross Additions to Nuclear Fuel
24 Gross Additions to Common Utility Plant
25 Gross Additions to Nonutility Plant
26 (Less)Allowance for Other Funds Used During
Construction
27 Other Construction and Acquisition of Plant,Investment
Activities
28 Cash Outflows for Plant(Total of lines 22 thru 27) (518,461,489) (490,335,100)
30 Acquisition of Other Noncurrent Assets(d)
31 Proceeds from Disposal of Noncurrent Assets(d) 2,047,651
33 Investments in and Advances to Associated and (7,709,499) (11,411,922)
Subsidiary Companies
34 Contributions and Advances from Associated and
Subsidiary Companies
36 Disposition of Investments in(and Advances to)
Associated and Subsidiary Companies
38 Purchase of Investment Securities(a)
39 Proceeds from Sales of Investment Securities(a)
40 Loan Made or Purchased
41 Collections on Loans
43 Net(Increase)Decrease in Receivables
44 Net(Increase)Decrease in Inventory
45 Net(Increase)Decrease in Allowances Held for
Speculation
46 Net Increase(Decrease)in Payables and Accrued
Expenses
47 Other Adjustments to Cash Flows from Investment
Activities:
47.1 Changes in other property and investments 815,210 1,199,766
47.2 Dividends Received from Subsidiaries 5,000,000 0
49 Net Cash Provided by(Used in)Investing Activities (518,308,127) (500,547,256)
(Total of lines 28 thru 47)
51 Cash Flows from Financing Activities: '
FERC FORM No.2(REV 06-04)
Page 120

Statement of Cash Flows
Description(See instructions for explanation of codes)Current Year to Date QuarterlYear Previous Year to Date
Line No. (a) (b) QuartertYear
(c)
52 Proceeds from Issuance of:
r
53 Proceeds from Issuance of Long-Term Debt(b) 83,700,000 250,000,000
54 Proceeds from Issuance of Preferred Stock
55 Proceeds from Issuance of Common Stock 67,725,000 112,308,131
56 Net Increase in Debt(Long Term Advances)
57 Net Increase in Short-term Debt(c)
59 Cash Provided by Outside Sources(Total of lines 53 thru 151,425,000 362,308,131
58)
61 Payments for Retirement
62 Payments for Retirement of Long-Term Debt(b) (13,500,000)
63 Payments for Retirement of Preferred Stock
64 Payments for Retirement of Common Stock
65 Other Retirements
65.1 Other -(2,741,537) m(4,820,847)
66 Net Decrease in Short-Term Debt(c) (7,000,000) (114,000,000)
67 Other Adjustments to Financing Cash Flows
68 Dividends on Preferred Stock
69 Dividends on Common Stock (150,329,156) (140,922,959)
70 Net Cash Provided by(Used in)Financing Activities (8,645,693) 89,064,325
(Total of lines 59 thru 69)
73 Net Increase(Decrease)in Cash and Cash Equivalents
74 (Total of line 18,49 and 71) (4,833,908) 22,854,831
76 Cash and Cash Equivalents at Beginning of Period 28,592,905 5,738,074
78 Cash and Cash Equivalents at End of Period 23,758,997 28,592,905
FERC FORM No.2(REV 06-04)
Page 120

This report is: Year/Period of Report:
Name of Respondent: (1)®An Original Date of Report:
Avista Corporation 04/18/2025 End of:2024/04
(2) ❑A Resubmission
FOOTNOTE DATA
Ja)Concept:NetlncreaseDecreaselnPayablesAndAccruedExpensesOperatingActivities
Kash paid(received)during the period for:
Income taxes:$7,555,015
Interest:$135,301,539
U Concept:GrossAdditionsToUtilityPlantLessNuclearFuellnvestingActivities
Additions to PPE in Accounts Payable:$22,779,844
Lc)Concept:Othe rReti rementsOfBa I a nces I mpacti ng Cash F lowsFromFi n anci ngActiviti es
(Debt Issuance costs(1,156,533);Minimum tax withholdings(1,585,004)
Concept:NetlncreaseDecreaselnPayablesAndAccruedExpensesOperatingActivities
Cash paid(received)during the period for:
Income taxes:$(1,439,727)
Interest:$125,249,194
Le)Concept:GrossAdditionsToUtilityPlantLessNuclearFuellnvestingActivities
Additions to PPE in Accounts Payable:$33,691,044
ko Concept:OtherRetirementsOfBalancesImpacting Cash FlowsFromFinancingActivities
Debt Issuance costs(3,323,740);Nfmimwn tax withholdings(1,497,107)
FERC FORM No.2(REV 06-04)
Page 120

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2) El A Resubmission
Notes to Financial Statements
1. Provide important disclosures regarding the Balance Sheet,Statement of Income for the Year,Statement of Retained Earnings for the
Year,and Statement of Cash Flow,or any account thereof.Classify the disclosures according to each financial statement,providing a
subheading for each statement except where a disclosure is applicable to more than one statement.The disclosures must be on the
same subject matters and in the same level of detail that would be required if the respondent issued general purpose financial
statements to the public or shareholders.
2. Furnish details as to any significant contingent assets or liabilities existing at year end,and briefly explain any action initiated by the
Internal Revenue Service involving possible assessment of additional income taxes of material amount,or a claim for refund of income
taxes of a material amount initiated by the utility.Also,briefly explain any dividends in arrears on cumulative preferred stock.
3. Furnish details on the respondent's pension plans,post-retirement benefits other than pensions(PBOP)plans,and post-employment
benefit plans as required by instruction no.1 and,in addition,disclose for each individual plan the current year's cash contributions.
Furnish details on the accounting for the plans and any changes in the method of accounting for them.Include details on the
accounting for transition obligations or assets,gains or losses,the amounts deferred and the expected recovery periods.Also,
disclose any current year's plan or trust curtailments,terminations,transfers,or reversions of assets.Entities that participate in
multiemployer postretirement benefit plans(e.g.parent company sponsored pension plans)disclose in addition to the required
disclosures for the consolidated plan,(1)the amount of cost recognized in the respondent's financial statements for each plan for the
period presented,and(2)the basis for determining the respondent's share of the total plan costs.
4. Furnish details on the respondent's asset retirement obligations(ARO)as required by instruction no.1 and,in addition,disclose the
amounts recovered through rates to settle such obligations.Identify any mechanism or account in which recovered funds are being
placed(i.e.trust funds,insurance policies,surety bonds).Furnish details on the accounting for the asset retirement obligations and
any changes in the measurement or method of accounting for the obligations.Include details on the accounting for settlement of the
obligations and any gains or losses expected or incurred on the settlement.
5. Provide a list of all environmental credits received during the reporting period.
6. Provide a summary of revenues and expenses for each tracked cost and special surcharge.
7. Where Account 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 item.See General Instruction 17 of the Uniform System of Accounts.
8. Explain concisely any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
9. Disclose details on any significant financial changes during the reporting year to the respondent or the respondent's consolidated
group that directly affect the respondent's gas pipeline operations,including:sales,transfers or mergers of affiliates,investments in
new partnerships,sales of gas pipeline facilities or the sale of ownership interests in the gas pipeline to limited partnerships,
investments in related industries(i.e.,production,gathering),major pipeline investments,acquisitions by the parent corporation(s),and
distributions of capital.
10. Explain concisely unsettled rate proceedings where a contingency exists such that the company may need to refund a material
amount to the utility's customers or that the utility may receive a material refund with respect to power or gas purchases.State for each
year affected the gross revenues or costs to which the contingency relates and the tax effects and explain the major factors that affect
the rights of the utility to retain such revenues or to recover amounts paid with respect to power and gas purchases.
11. Explain concisely 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 summarize the adjustments made to balance sheet,
income,and expense accounts.
12. Explain concisely only those significant 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 approximate dollar effect of
such changes.
13. 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.
14. 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.
15. 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 FINANCIAL STATEMENTS
NOTE 1.SUMMARYOF SIGNIFICANT ACCOUNTING POLICIES
Nature ofBusiuess
Avista Corp.(the Company)is primarily an electric and natural gas utility with certain otherbusiness ventures.Avista Corp.provides electric distribution and transmission,and
natural gas distribution services in parts ofeastem Washington and northern Idaho.Avista Corp.also provides natural gas distribution service in parts ofnortheastem and southwestern
Oregon.Avista Corp.has electric generating facilities in Washington,Idaho,Oregon and Montana.Avista Corp.also supplies electricity to a small number ofeustomers in Montana.
Alaska Electric and Resource Company(AERC)is a wholly-owned subsidiary ofAvista Corp.The primary subsidiary ofAERC is Alaska Energy Light and Power(AEL&P),which
comprises Avista Corp.'s regulated utility operations in Alaska.
Avista Capital,a wholly owned non-regulated subsidiary ofAvista Corp.,is the parent company ofthe subsidiary companies except AERC(and its subsidiaries).
Basis of Reporting
The financial statements include the assets,liabilities,revenues and expenses of the Company and have been prepared in accordance with the accounting requirements of the Federal
Energy Regulation Commission(FERC)as set forth in its applicable Uniform System ofAccounls and published accounting releases,which is a comprehensive basis ofaccounting
other than accounting principles generally accepted in the United States ofAmerica(GAAP).As required by the FERC,the Company accounts for its investment in majority owned

subsidiaries as required by GAAP,The accompanying financial statements include the Company's proportionate share ofutility plant and related operations associated with its
interests in jointly owned plants.In addition,under the requirements ofthe FERC,there are differences from GAAPin the presentation of(1)current portion oflong-term debt,(2)
assets and liabilities for cost ofremoval assets,(3)assets held for sale,(4)regulatory assets and liabilities,(5)deferred income taxes associated with accounts other than utility
property,plant and equipment,(6)comprehensive income,(7)unamortized debt issuance costs,(8)operating revenues and resource costs associated with settled energy contracts that
are"booked out",(9)non-service portion ofpension and other postretirement benefit costs,(10)emissions allowance inventory and liabilities,and(11)leases.
Use of Estimates
The preparation ofthe financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported for assets and liabilities
and the disclosure ofcontingent assets and liabilities at the date ofthe financial statements and the reported amounts ofrevenues and expenses during the reporting period.Significant
estimates include:
determining the market value ofenergy commodity derivative assets and liabilities,
pension and otherpostretirement benefit plan obligations,
contingent liabilities,
obligations under the Climate Commitment Act(CCA),
goodwill impairment testing,
recoverability ofregulatory assets,and
unbilled revenues.
Changes in these estimates and assumptions are considered reasonably possible and may have a material effect on the financial statements and thus actual results could differ from the
amounts reported and disclosed herein.
System ofAccounts
The accounting records ofthe Company's utility operations are maintained in accordance with the uniform system of accounts prescribed by the FERC and adopted by the state
regulatory commissions in Washington,Idaho,Montana and Oregon.
Regulation
The Company is subject to state regulation in Washington,Idaho,Montana,Oregon and Alaska.The Company is subject to federal regulation primarily by the FERC,as well as
various other federal agencies with regulatory oversight ofparticular aspects ofits operations.
Depreciation
For utility operations,depreciation expense is estimated by a method ofdepreciation accounting utilizing composite rates for utility plant.Such rates are designed to provide for
retirements ofproperties at the expiration oftheir service lives.For utility operations,the ratio ofdepreciation provisions to average depreciable property was as follows for the years
ended December 31:
2024 2023 2022
Avista Corp. 3.45% 3.52% 3.50%
The average service lives for the following broad categories ofutility plant in service are(in years):
Electric thermal/other production 27
Hydroelectric production 81
Electric transmission 44
Electric distribution 42
Natural gas distribution property 44
Other shorter-lived general plant 8
Allowance for Funds Used During Construction(AFUDC)
AFUDC represents the cost ofboth the debt and equity funds used to finance utility plant additions during the construction period.As prescribed by regulatory authorities,AFUDC is
capitalized as a part ofthe cost ofutility plant.The debt component ofAFUDC is credited against total interest expense in the Statements oflncome in the line item"capitalized
interest."The equity component ofAFUDC is included in the Statements oflncome in the line item"other income-net."The Company is permitted,under established regulatory rate
practices,to recover the capitalized AFUDC,and a reasonable return thereon,through its inclusion in rate base and the provision for depreciation afterthe related utility plant is
placed in service.Cash inflow related to AFUDC does not occur until the related utility plant is placed in service and included in rate base.
The Washington Utilities and Transportation Commission(WUCC)and the Idaho Public Utilities Commission(IPUC)have authorized Avista Corp.to calculate AFUDC using its
allowed rate ofretum on rate base.To the extent amounts calculated using this rate exceed the AFUDC amounts calculated using the FERC formula,Avista Corp.capitalizes the
excess as a regulatory asset.The regulatory asset associated with plant in service is amortized over the average useful life ofAvista Corp.'s utility plant which is approximately 30
years.The regulatory asset associated with construction work in progress is not amortized until the plant is placed in service.
The effective AFUDC rate was the following forthe years ended December31:
2024 2023
Avista Corp. 7.03% 7.03%
Income Taxes
Deferred income tax assets represent future income tax deductions the Company expects to utilize in future tax returns to reduce taxable income.Deferred income tax liabilities
represent future taxable income the Company expects to recognize in future tax returns.Deferred tax assets and liabilities arise when there are temporary differences resulting from
differing treatment ofitems for tax and accounting purposes.Adeferred income tax asset or liability is determined based on the enacted tax rates that will be in effect when the
temporary differences between the financial statement carrying amounts and tax basis of existing assets and liabilities are expected to be reported in the Company's income tax returns.
The effect on deferred income taxes from a change in tax rates is recognized in income in the period that includes the enactment date unless a regulatory order specifies deferral ofthe
effect ofthe change in tax rates over a longerperiod of time.The Company establishes a valuation allowance when it is more likely than not that all,ora portion,ofa deferred tax
asset will not be realized.Deferred income tax assets and liabilities and regulatory assets and liabilities are established for income tax benefits flowed through to customers.
The Company has elected to account for transferable tax credits as a component ofthe income tax provision.The Company recognizes the benefit ofproduction tax credits as a
reduction of income tax expense in the period the credit is generated,which corresponds to the period the energy production occurs.The Company applies the deferral method of
accounting for investment tax credits(ITCs).Underthis method,ITCs are amortized as a reduction to income tax expense overthe estimated useful lives ofthe underlying property
that gave rise to the credit.
The Company's largest deferred income tax item is the difference between the book and tax basis ofutility plant.This item results from the temporary difference on depreciation
expense.In early tax years,this item is recorded as a deferred income tax liability that will eventually reverse and become subject to income tax in later tax years.
The Company did not incurpenallies on income tax positions in 2024 or2023.The Company would recognize interest accrued related to income tax positions as interest expense or
interest income and penalties incurrcd as otheropewting expense.
Stock-Based Compensation
The Company issues three types ofstock-based compensation awards-restricted shares,market-based awards and performance-based awards.Compensation cost relating to share-
based payment transactions is recognized in the Company's financial statements based on the fair value ofthe equity instruments issued and recorded over the requisite service period.
The Company recorded stock-based compensation expense(included in other operating expenses)and income tax benefits in the Statements of Income ofthe following amounts for
the years ended December 31(dollars in millions):
2024 2023
Stock-based compensation expense $8 $7

Income tax benefits 2 2
Restricted share awards vest in equal thirds each year over 3 years and are payable in Avista Corp.common stock at the end of each year ifthe service condition is met.Restricted
stock is valued at the close of market ofthe Company's common stock on the grant date.
Total Shareholder Return(TSR)awards are market-based awards and Cumulative Earnings Per Share(CEPS)awards we performance awards.Both types of awards vest after a period of
3 years and are payable in cash or Avista Corp.common stock at the and ofthe three-yettrperiod.The method of settlement is at the discretion ofthe Company and historically the
Company has settled these awards through issuance ofAvista Corp.common stock and intends to continue this practice.Both types ofawards entitle the recipients to dividend
equivalent rights,are subject to forfeiture under certain circumstances,and arc subject to meeting specific market orperformance conditions.Based on the level of attainment ofthe
market or performance conditions,the amount ofcash paid or common stock Issued will range from 0 to 200 percent ofthe initial awards granted.Dividend equivalent rights are
accumulated and paid out only on shares that have vested and have met the market and performance conditions.
The Company accounts forboth the TSR awards and CEPS awards as equity awards and compensation cost for these awards is recognized over the requisite service period,provided
the requisite service period is rendered.For TSR awards,if the market condition is not met at the end ofthe three-year service period,there will be no change in the cumulative amount
ofcompensation cost recognized,since the awards arc still considered vested even though the market metric was not met.For CEPS awards,at the end ofthe three-yearservice period,
ifthe internal performance metric of cumulative earnings per share is not met,all compensation cost forthese awards is reversed as these awards are not considered vested.
The fair value ofeach TSR award is estimated on the date ofgrant using a statistical model incorporating the probability ofineeting the market targets based on historical returns
relative to a peer group.CEPS awards are valued at the close ofmarket ofthe Company's common stock on the grant date.
The following table summarizes the number of grants,vested and unvested shares,earned shares(based on market metrics),and other pertinent information related to the Company's
stock compensation awards for the years ended December31
2024 2023
Restricted Shares
Shares granted during the year 82,433 76,806
Shares vested during the year 75,107 75,007
Unvested shares at end ofyear 158,464 152,140
Unrecognized compensation expense at end ofyear
(in millions) $3 $3
TSR Awards
TSR shares granted during the year 45,739 34,912
TSR shares vested during the year 64,640 61,456
TSR shares earned based on market metrics 35,552 44,863
Unvested TSR shares at end ofyear 77,530 96,915
Unrecognized compensation expense at end ofyear
(in millions) $2 $2
CEPS Awards
CEPS shares granted during the year 137,161 104,685
CEPS shares vested during the year 64,640 61,456
CEPS shares earned based on performance metrics 29,088 33,801
Unvested CEPS shares at end ofyear 232,486 161,235
Unrecognized compensation expense at end ofyear
(in millions) $3 $2
Outstanding restricted,TSR and CEPS share awards include a dividend component paid in cash.Aliability forthe dividends payable related to these awards is accrued es dividends
are announced throughout the life ofthe award.As of December 31,2024 and 2023,the Company had recognized a liability of$3 million and$2 million,respectively,related to the
dividend equivalents payable on the outstanding and unvested share grants.
Cash and Cash Equivalents
For the purposes ofthe Statements of Cash Flows,the Company considers all temporary investments with a maturity ofthree months or less when purchased to be cash equivalents.
Accounts Receivable and Allowance for Doubtful Accounts
The Company maintains an allowance for doubtful accounts to provide for estimated and potential losses on accounts receivable.The Company determines the allowance forutility
and other customer accounts receivable based on historical write-offs as compared to accounts receivable and operating revenues.Additionally,the Company establishes specific
allowances for certain individual accounts.
The Company has received grants from various government agencies to assist customers with their energy bills.The Company received these grant funds and applied them to
customer accounts,reducing accounts receivable balances.These grants totaled$10 million in 2024 and$2 million in 2023.
Utility Plant in Service
The cost ofadditions to utility plant in service,including AFUDC and replacements ofunits ofproperty and improvements,is capitalized.The cost ofdepreciable units ofproperty
retired plus the cost ofremoval less salvage is charged to accumulated depreciation.
Asset Retirement Obligations(ARO)
The Company records the fair value ofa liability for an ARO in the period in which it is incurred.When the liability is initially recorded,the associated costs ofthe ARO are
capitalized as part ofthe carrying amount ofthe related long-lived asset.The liability is accreted to its present value each period and the related capitalized costs are depreciated over
the useful life ofthe related asset.In addition,ifthctc are changes in the estimated timing or estimated costs ofthe AROr,adjustments are recorded during the period new information
becomes available as an increase or decrease to the liability,with the offset recorded to the related long-lived asset.Upon retirement ofthe asset,the Company either settles the ARO
for its recorded amount or recognizes a regulatory asset or liability for the difference,which will be surchargedtmllmded to customers through the ratemaking process.The Company
records regulatory assets and liabilities for the difference between asset retirement costs currently recovered in rates and AROs recorded since asset retirement costs are recovered
through rates charged to customers(see Note 11 for further discussion ofthe Company's AROs).
Derivative Assets and Liabilities
Derivatives are recorded as either assets or liabilities on the Balance Sheets measured at estimated fair value.
The WUTC and the IPUC issued accounting orders authorizing Avista Corp.to offset energy commodity derivative assets or liabilities with a regulatory asset or liability.This
accounting treatment is intended to defer the recognition ofmnrk-to-morkct gains and losses on energy commodity transactions until the period ofdelivery.Realized benefits and
costs result in adjustments to retail rates through Purchase Gas Adjustments(PGAs),the Energy Recovery Mechanism(ERM)in Washington,the Power Cost Adjustment(PCA)
mechanism in Idaho,and periodic general rate cases.The resulting regulatory assets associated with energy commodity derivative instruments ate probable of recovery through future
rates.
Substantially all forward contracts to purchase or sell power and natural gas are recorded as derivative assets or liabilities at estimated fair value with an offsetting regulatory asset or
liability.Contracts not considered derivatives are accounted for on the accrual basis until they are settled or realized unless there is a decline in the fair value ofthe contract
determined to be other-than-temporary.
For interest rate swap derivatives,Avista Corp.records all mad:-to-market gains and losses in each accounting period as assets and liabilities,as well as offsetting regulatory assets and
liabilities,such that there is no income statement impact.The interest rate swap derivatives ate risk management tools similar to energy commodity derivatives.Upon settlement of
interest rate swap derivatives,the mgulatory asset or liability is amortized as a component of intetst expense over the term ofthe associated debt.The Company records an offset of
interest rate swap derivative assets and liabilities with regulatory assets and liabilities,based on the priorpractice of the commissions to provide recovery through the ratemaking
process.
The Company has multiple master netting agreements with a variety ofentities allowing for cross-commodity netting ofderivative agreements with the same counterparty(i.e.power
derivatives can be netted with natural gas derivatives).In addition,some master netting agreements allow for the netting ofcommodity derivatives and interest rate swap derivatives
for the same counterparty.The Company does not have agreements which allow for cross-affiliate netting among multiple affiliated legal entities.The Company nets all derivative
instruments when allowed by the agreement for presentation in the Balance Sheets.
Fair Value Measurements

Fair value represents the price that would be received when selling an asset or paid to transfer a liability(an exit price)in an orderly transaction between market participants at the
measurement date.Energy commodity derivative assets and liabilities,deferred compensation assets,as well as derivatives related to interest rate swaps and foreign currency
exchange contracts,are reported at estimated fair value on the Balance Sheets.See Note 13 forthe Company's fair value disclosures.
Regulatory Deferred Charges and Credits
The Company prepares its financial statements in accordance with regulatory accounting practices because:
rates for regulated services are established by or subject to approval by independent third-party regulators,
the regulated rates are designed to recoverthe cost ofproviding the regulated services,and
in view ofdemand forthe regulated services and the level ofcompetition,it is reasonable to assume that rates can be charged to and collected from
customers at levels that will recover costs.
Regulatory accounting practieett require certain coatsand/or obligations(such as incurred powerand natural gas costs not currently reflected in rates,but expected to be recovered or
refunded in the future),to be reflected as deferred cha%es or credits on the Balance Sheets.These costs and/or obligations are not reflected in the Statements oflncome until the period
during which matching revenues are recognized.The Company also has decoupling revenue deferrals.See Note 2 for discussion on decoupling revenue deferrals.
Ifat some point in the future the Company determines it no longer meets the criteria for continued application ofregulatory accounting practices for all or a portion of its regulated
operations,the Company could be:
required to write offits regulatory assets,and
precluded from the future deferral of costs or decoupled revenues not recovered through rates at the time such amounts are incurred,even ifthe Company
expected to recover these amounts from customers in the future.
Unamordzed Debt Expense
Unamortized debt expense includes debt issuance costs that are amortized over the life ofthe related debt.
Unamortized Debt Repurchase Costs
Forthe Company's Washington regulatory jurisdiction and for any debt repurchases beginning in 2007 in all jurisdictions,premiums and discounts paid to repurchase debt are
amortized overthe remaining life ofthe original debt repurchased or,ifnew debt is issued in connection with the repurchase,these amounts are amortized overthe life ofthe new debt.
In the Company's other regulatory jurisdictions,premiums or discounts paid to repurchase debt prior to 2007 are being amortized over the average remaining maturity ofoutstanding
debt when no new debt was issued in connection with the debt repurchase.The premium and discount costs are recovered orretumed to customers through retail rates as a component
of interest expense.
Appropriated Retained Earnings
In accordance with the hydroelectric licensing requirements ofsection 10(d)ofthe Federal Power Act(FPA),the Company maintains an appropriated retained earnings account for
earnings in excess ofthe specified rate ofretum on the Company's investment in the licenses for its various hydroelectric projects.Per section 10(d)ofthe FPA,the Company must
maintain these excess eaniirigs in au appropriated retained earnings account until the termination ofthe licensing agreements or apply them to reduce the net investment in the
licenses ofthe hydroelectric projects at the discretion ofthe FERC.The Company calculates the earnings in excess ofthe specified rate ofretum on an annual basis,usually during the
second quarter.
The appropriated retained earnings amounts included in retained earnings were as follows as ofDecember3l(dollars in millions):
2024 2023
Appropriated retained earnings $59 $57
Contingencies
The Company has unresolved regulatory,legal and tax issues which have inherently uncertain outcomes.The Company accrues a loss contingency ifit is probable that a liability has
been incurred and the amount ofthe loss or impairment can be reasonably estimated.The Company also discloses loss contingencies that do not meet these conditions for accrual,if
there is a reasonable possibility that a material loss may be incurred.As ofDecember 31,2024,the Company has not recorded significant amounts related to unresolved
contingencies.See Note 15 for further discussion ofthe Company's commitments and contingencies.
Equity in Earnings(Losses)of Subsidiaries
The Company records all the earnings(losses)from its subsidiaries under the equity method.The Company had the following equity in earnings(losses)of its subsidiaries forthe
years ended December 31(dollars in millions):
2024 2023
Avista Capital $ (6) $ (4)
AERC g g
Total equity in earnings of subsidiary companies $ 2 $ 4
Subsequent Events
Management has evaluated the impact of events occurring after December 31,2024 up to February 25,2025,the date that Avista Corp.'s GAAP financial statements were issued and
has updated such evaluation for disclosure purposes through the date ofthis filing.These financial statements include all necessary adjustments and disclosures resulting from these
evaluations.
NOTE 2.REVENUE
The core principle ofthe revenue recognition model is that an entity should identify the various performance obligations in a contract,allocate the transaction price among the
performance obligations and recognize revenue when(or as)the entity satisfies each performance obligation.
Utility Revenues
Revenue from Contracts with Customers
General
The majority ofAvista Corp.'s revenue is from rate-regulated sales of electricity and natural gas to retail customers,which has two performance obligations,(1)having service
available for a specified period(typically a month at a time)and(2)the delivery ofenergy to customers.The total energy price generally has a fixed component(basic charge)related
to having service available and a usage-based component,related to the delivery and consumption ofenergy.The commodity is sold and/ordelivered to and consumed by the
customer simultaneously,and the provisions ofthe relevant utility commission authorization determine the charges the Company may bill the customer.Since all revenue recognition
criteria are met upon the delivery ofenergy to customers,revenue is recognized immediately.
In addition,the sale of electricity and natural gas is governed by the various state utility commissions,which set rates,charges,terms and conditions ofservice,and prices.
Collectively,these rates,charges,terms and conditions are included in a"tariff,"which governs all aspects ofthe provision ofregulated services.Tariffs are only permitted to be
changed through a rate-setting process involving an independent,third-party regulator empowered by statute to establish rates that bind customers.Thus,all regulated sales by the
Company are conducted subject to the regulator-approved tariff.
Tariffsales involve the current provision ofcommodity service(electricity and/or natural gas)to customers fora price that generally has a basic charge and a usage-based component.
Tariffrates also include certain pass-through costs to customers such as natural gas costs,retail revenue credits and other miscellaneous regulatory items that do not impact net income,
but can cause total revenue to fluctuate significantly up or down compared to previous periods.The commodity is sold and/or delivered to and consumed by the customer

simultaneously,and the provisions ofthe relevant tariff determine the charges the Company may bill the customer,payment due date,and other pertinent rights and obligations of
both parties.Generally,tariffsales do not involve a written contract.Since all revenue recognition criteria are met upon the delivery ofenergy to customers,revenue is recognized at
that time.
Unhilled Revenue from Contracts with Customers
The determination ofthe volume ofenergy sales to individual customers is based on the reading oftheirmeters,which occurs on a systematic basis throughout the month(once per
month for each individual customer).At the end ofeach calendarmonth,the amount ofenergy delivered to customers since the date ofthe last meterreading is estimated and the
corresponding unbilled revenue is estimated and recorded.The Company's estimate ofunbilled revenue is based on:
the number of customers,
tariffrates,
meter reading dates,
actual native load for electricity,
actual throughput for natural gas,and
electric line losses and natural gas system losses.
Any difference between actual and estimated revenue is recorded in the following month when the meter reading and customer billing occurs.
Accounts receivable includes unbilled energy revenues ofthe following amounts as of December 31(dollars in millions):
2024 2023
Unbilled accounts receivable $ 72 $ 76
Non-Derivative Wholesale Contracts
The Company has certain wholesale contracts that are not accounted for as derivatives and are considered revenue from contracts with customers.Revenue is recognized as energy is
delivered to the customer or the service is available for a specified period of time,consistent with the discussion ofrate regulated sales above.
Alternative Revenue Programs(Decoupling)
Alternative revenue programs are contracts between an entity and a regulator of utilities,not a contract between an entity and a customer.GAAP requires the presentation ofrevenue
arising from alternative revenue programs separately from revenues arising from contracts with customers on the Statements of Income.The Company's decoupling mechanisms(also
known as a FCAin Idaho)qualify as alternative revenue programs.Decoupling revenue deferrals are recognized in the Statements of Income during the period they occur(i.e.during
the period ofrevenue shortfall orexcess due to fluctuations in customerusage),subject to certain limitations,and a regulatory asset or liability is established which will be surcharged
orrebated to customers in future periods.GAAP requires that loran alternative revenue program like decoupling,the revenue must be expected to be collected from customers within
24 months ofthe deferral to qualify for recognition in the Statements of Income.Amounts included in the Company's decoupling program that are not expected to be collected from
customers within 24 months are not recorded in the financial statements until the period in which revenue recognition criteria are met.The amounts expected to be collected from
customers within 24 months represents an estimate made by the Company on an ongoing basis due to it being based on the volumes ofelectric and natural gas sold to customers on a
go-forward basis.
The Company records alternative program revenues under the gross method,which is to amortize the decoupling regulatory asset/liability to the alternative revenue program line item
on the Statements of Income as it is collected from or refunded to customers.The cash passing between the Company and the customers is presented in revenue from contracts with
customers since it is a portion ofthe overall tariffpaid by customers.This method results in a gross-up to both revenue from contracts with customers and revenue from alternative
revenue programs,but has a net zero impact on total revenue.Depending on whether the previous deferral balance being amortized was a regulatory asset or regulatory liability,and
depending on the size and direction ofthe current year deferral of surcharges and/or rebates to customers,it could result in negative alternative revenue program revenue during the
year.
Derivative Revenue
Most wholesale electric and natural gas transactions(including both physical and financial transactions),and the sale of fuel are considered derivatives,which are disclosed separately
from revenue from contracts with customers.Revenue is recognized for these items upon the settlement/expiration ofthe derivative contract.Derivative revenue includes transactions
entered into and settled within the same month.
Other Utility Revenue
Other utility revenue includes rent,sales ofmaterials,late fees and other charges that do not represent contracts with customers.This revenue is excluded from revenue from contracts
with customers,as this revenue does not represent items where a customer is a party that has contracted with the Company to obtain goods or services that are an output ofthe
Company's ordinary activities in exchange for consideration.As such,these revenues are presented separately from revenue from contracts with customers.
Other Considerations for Utility Revenues
Gross Versus Net Presentation
Utility-related taxes collected from customers(primarily state excise taxes and city utility taxes)are imposed on Avista Corp.as opposed to being imposed on customers;therefore,
Avista Corp.is the taxpayer and records these transactions on a gross basis in revenue from contracts with customers and operating expense(taxes otherthan income taxes).
Utility-related taxes included in revenue from contracts with customers were as follows for the years ended December 31(dollars in millions):
2024 2023
Utility-related taxes $81 $75
Significant Judgments and Unsatisfied Performance Obligations
The only significant judgments involving revenue recognition are estimates surrounding unbilled revenue and receivables from contracts with customers and estimates surrounding
the amount of decoupling revenues that will be collected from customers within 24 months(discussed above).
The Company has certain capacity arrangements,where the Company has a contractual obligation to provide either electric ornatural gas capacity to its customers for a fixed fee.
Most ofthese arrangements are paid for in arrears by the customers and do not result in deferred revenue and only result in receivables from the customers.The Company has one
capacity agreement where the customer makes payments throughout the year.As of December 31,2024,the Company estimates it had unsatisfied capacity performance obligations of
$2 million,which will be recognized as revenue in future periods as the capacity is provided to the customers.These performance obligations are not reflected in the financial
statements,as the Company has not received payment for these services.
NOTE 3.LEASES
The core principle of lease accounting is that an entity should recognize the ROU assets and liabilities from leases on the balance sheet and depreciate or amortize the asset and
liability overthe term ofthe lease,as well as provide disclosure to enable users ofthe financial statements to assess the amount,timing,and uncertainty of cash flows from leases.For
regulatory reporting,the FERC provided prescribed accounts for the ROU assets and liabilities,with the ROU assets being included in utility plant(FERC account 101)and the lease
liabilities being included in capital lease obligations(FERC account 227).These accounts are different than the accounts allowed for in GAAPreporting,which results in a
FERC/GAAP difference.
Significant Judgments and Assurnptions
The Company determines ifan arrangement is a lease,as well as its classification,at its inception.

ROU assets represent the Company's right to use an underlying asset for the lease term,and lease liabilities represent the Company's obligation to make lease payments.Operating
lease ROU assets and lease liabilities are recognized at the commencement date ofthe agreement based on the present value oflease payments over the lease term.As most ofthe
Company's leases do not provide an implicit rate,the Company uses its incremental borrowing rate based on the information available at the commencement date to determine the
present value oflease payments.The implicit rate is used when it is readily determinable.The operating lease ROU assets also includes lease payments made and exclude lease
incentives,if any,that accrue to the benefit ofthe lessee.
Lease terns may include options to extend or terminate the lease when it is reasonably certain the Company will exercise that option.Lease expense is recognized on a straight-line
basis over the lease term.The difference between lease expense and cash paid for leased assets is recognized as a regulatory asset or regulatory liability.
Description ofLeases
Operating Leases
The Company's most significant operating lease is with the State of Montana associated with submerged land around the Company's hydroelectric facilities in the Clark Fork River
basin,which expires in 2046.The terms ofthis lease are subject to adjustment-depending on the outcome of ongoing litigation between the State of Montana and NorthWestem.In
addition,the State of Montana and Avista Corp,were engaged in litigation regarding lease terms,including how much money,ifany,the State of Montana should return to Avista
Corp-;however,that litigation was dismissed as premature pending the outcome ofthe ongoing litigation between the State of Montana and NorthWestem.Any reduction in future
lease payments orthe return to Avista Corp.ofamounts previously paid will be included in the future ratemaking process.
In addition to the lease with the State of Montana,the Company has other operating leases for land associated with its utility operations,as well as communication sites which support
network and radio communications within its service territory.The Company's leases have remaining terms of 1 to 69 years.Most oftbe Company's leases include options to extend
the lease term for periods of 5 to 50 years.Options are exercised at the Company's discretion.
Certain ofthe Company's lease agreements include rental payments which are periodically adjusted over the term ofthe agreement based on the consumerprice index.The Company's
lease agreements do not include material residual value guarantees or material restrictive covenants.
In March 2023,the Company entered into an agreement with Rathdmm Power,LLC amending and restating a PPAfor the output ofthe Lancaster Plant.The restated PPA meets the
accounting definition ofa lease,and all payments are variable in nature,based on capacity,usage,or performance ofthe plant.Therefore,there is no lease obligation or corresponding
ROU asset recorded by the Company related to this agreement.The variable lease costs related to this agreement are included in resource costs on the Statements ofhlcome.
Avista Corp.does not record leases with a term of 12 months or less in the Balance Sheets.Total short-term lease costs for 2024 are immaterial.
Operating Lease Balances in the Financial Statements
The components oflease expense were as follows for the year ended December 31(dollars in millions):
2024 2023 2022
Operating lease cost:
Fixed lease cost(Other operating expenses) $5 $5 $5
Variable lease cost(Other operating expenses and Resource costs) 31 25 2
Total operating lease cost $36 $30 $7
Supplemental cash flow information related to leases was as follows for the year ended December 31(dollars in millions):
2024 2023
Cash paid for amounts included in the measurement oflease liabilities:
Operating cash outflows:
Operating lease payments $5 $5
Supplemental balance sheet information related to leases was as follows for December 31(dollars in millions):
December 31. December 31,
2024 2023
Operating Leases
Operating lease ROUassets(Otherproperty and investments-net
and other noncurrent assets) $66 $68
Other current liabilities $4 $4
Other oon-currentliabilities and deferred credits 62 64
Total operating lease liabilities $66 $68
Weighted Average Remaining Lease Term
Operating leases 21 years 22 years
Weighted Average Discount Rate
Operating leases 4.30 % 4.29 %
Maturities oflease liabilities(including principal and interest)were as follows as of December 31,2024(dollars in millions):
Operating Leases
2025 S 5
2026 5
2027 5
2028 5
2029 5
Thereafter 79
Total lease payments $ 104
Less:imputed interest (38
Total $66
NOTE 4.DERIVATIVES AND RISK MANAGEMENT
Energy Commodity Derivatives
Avista Corp.is exposed to market risks relating to changes in electricity and natural gas commodity prices and certain other fuel prices.Market risk is,in general,the risk of
fluctuation in the market price ofthe commodity being traded and is influenced primarily by supply and demand.Market risk includes the fluctuation in the market price of associated
derivative commodity instruments.Avista Corp.utilizes derivative instruments,such as forwards,futures,swap derivatives and options to manage the various risks relating to these
commodity price exposures.Avista Corp.has an energy resources risk policy and control procedures to manage these risks.
As part ofAvista Corp.'s resource procurement and management operations in the electric business,Avista Corp.engages in an ongoing process ofreseurce optimization,which
involves the economic selection from available energy resources to serve Avista Corp.'s load obligations and the use of these resources to capture available economic value through
wholesale market transactions.These include sales and purchases ofelectric capacity and energy,fuel forelectric generation,and derivative contracts related to capacity,energy and
fuel.Such transactions are part ofthe process ofmatching resources with load obligations and hedging a portion ofthe related financial risks.These transactions range from terms of
intra-hour up to multiple years.
As part ofits resource procurement and management ofits natural gas business,Avista Corp.makes continuing projections ofits natural gas loads and assesses available natural gas

resources including natural gas storage availability.Natural gas resource planning typically includes peak requirements,low and average monthly requirements and delivery
constraints from natural gas supply locations to Avista Corp:s distribution system.However,daily variations in natural gas demand can be significantly different than monthly
demand projections.Based on these projections,Avista Corp.plans and executes a series oftransactions to hedge a portion ofits projected natural gas requirements through forward
market transactions and derivative instruments.These transactions may extend as much as three natural gas operating years(November through October)into the future.Avista Corp.
also leaves a significant portion of its natural gas supply requirements unhedged for purchase in short-term and spot markets.
Avista Corp.plans for sufficient natural gas delivery capacity to serve its retail customers fora theoretical peak day event.Avista Corp.generally has more pipeline and storage
capacity than what is needed during periods other than a peak day.Avista Corp.optimizes its natural gas resources by using market opportunities to generate economic value that
mitigates the fixed costs.Avista Corp.also optimizes its natural gas storage capacity by purchasing and storing natural gas when prices are traditionally lower,typically in the summer,
and withdrawing during higher priced months,typically during the winter.Howeve0 ifmarket conditions and prices indicate that Avista Corp.should buy or sell natural gas at other
times during the year;Avista Corp,engages in optimization transactions to capture value in the marketplace.Natural gas optimization activities include,but are not limited to,
wholesale market sales ofsutplYsnatural gas supplies,purchases and sales ofnatural gas to optimize use ofpipeline and storage capacity,and participation in the transportation
capacity release market.
The following table presents the underlying energy commodity derivative volumes as ofDecember 31,2024 expected to be delivered in each respective year(in thousands ofMWhs
and mmBTUs):
Purchases Sales
Electric Derivatives Gas Derivatives Electric Derivatives Gas Derivatives
Physical(1) Financial(1) Physical(1) Financial(1) Physical(1) Financial(1) Physical (1) Financial(1)
Year MWh MWh mmBTUs mmBTUs MWh MWh mmBTUs mmBTUs
2025 7 — 27,993 39,483 427 420 1,8 97 1,963
2026 — — 17,560 13,175 — — — —
2027 — — 7,555 2,.50 — —As ofDecember 31,2024,there are no expected deliveries ofenergy commodity derivatives after2027.
The following table presents the underlying energy commodity derivative volumes as ofDecember 31,2023 that were expected to be delivered in each respective year(in thousands
ofMWhs and mmBTUs):
Purchases Sales
Electric Derivatives Gas Derivatives Electric Derivatives Gas Derivatives
Physical(1) Financial(1) Physical(1) Financial(1) Physical(1) Financial(1) Physical(1) Financial(1)
Year MWh MWh mmBTUs mmBTUs MWh MWh mmBTUs mmBTUs
2024 9 — 22,747 74,596 472 510 1,723 12,038
2025 — — 12,505 19,590 11 96 1,115 1,125
2026 — - 5,570 3,940 -- - - -
As ofDecember 31,2023,there were no expected deliveries ofenergy commodity derivatives after 2026.
(1)Physical transactions represent commodity transactions in which Avista Corp.will take or make delivery ofeither electricity or natural gas;financial transactions represent
derivative instruments with delivery of cash in the amount ofthe benefit or cost but with no physical delivery ofthe commodity,such as futures,swap derivatives,options,or
forward contracts.
The electric and natural gas derivative Contracts above will be included in either power supply costs ornatural gas supply costs during the period they are scheduled to be delivered
and will be included in the various deferral and recovery mechanisms(ERM,PCA,and PGAs),or in the general rate case process,and are expected to be recovered through retail rates
from customers.
Foreign Currency Exchange Derivatives
Asignificant portion ofAvista Corp.'s natural gas supply(including fuel for power generation)is obtained from Canadian sources.Most ofthose transactions are executed in U.S.
dollars,which avoids foreign currency risk.Aportion of Avista Corp:s short-term natural gets transactions and long-term Canadian transportation contracts are committed based on
Canadian currency prices.The short term natural gas transactions are settled within 60 days with U.S.dollars.Avista Corp.hedges a portion ofthe foreign currency risk by purchasing
Canadian currency exchange derivatives when such commodity transactions are initiated.The foreign currency exchange derivatives and the unhedged foreign currency risk have not
had a material effect on Avista Corp:s financial condition,results of operations or cash flows and these differences in cost related to currency fluctuations are included with natural gas
supply costs for ratemaking.
The following table summarizes the foreign currency exchange derivatives outstanding as ofDecember 31(dollars in millions):
2024 2023
Number of contracts 22 S
Notional amount(in United States dollars) $2 $—
Notional amount(in Canadian dollars) 2 —
Interest Rafe Snvap Derivatives
Avista Corp.is affected by fluctuating interest rates related to a portion of its existing debt,and future borrowing requirements.Avista Corp.may hedge a portion of its interest rate risk
with financial derivative instruments,including interest rate swap derivatives.These interest rate swap derivatives are considered economic hedges against fluctuations in future cash
flows associated with anticipated debt issuances.
The following table summarizes the unsettled interest rate swap derivatives outstanding as ofthe balance sheet date indicated below(dollars in millions):
Mandatory Cash
Balance Sheet Date Number of Contracts Notional Amount Settlement Date
December 31,2024 1 $ 10 2025
December 31,2023 2 $ 20 2024
1 10 2025
The fairvalue ofoutmanding interest rate swap derivatives can vary significantly from period to period depending on the total notional amount ofswap derivatives outstanding and
fluctuations in market interest rates compared to the interest rates fixed by the swaps.Avista Corp.is required to make cash payments to settle the interest rate swap derivatives when
the fixed rates are higher than prevailing market rates at the date ofsettlement.Conversely,Avista Corp.receives cash to settle its interest rate swap derivatives when prevailing market
rates at the time ofsettlement exceed the fixed swap rates.
Summary ofOursranding Derivative Instruments
The amounts recorded on the Balance Sheets as ofDecember 31,2024 and December 31,2023 reflect the offsetting ofderivative assets and liabilities where a legal right ofoffset
exists.
The following table presents the fair values and locations ofderivative instruments recorded on the Balance Sheets as ofDecember 31,2024(dollars in millions):
Fair Value
Net Asset
(Liability)
Gross Gross Collateral on Balance
Derivative and Balance Sheet Location Asset Liability Netting Sheet
Interest rate swap derivatives
Derivative instrument assets current $ 1 $ — $ — $ 1
Energy commodity derivatives
Derivative instrument assets current 10 — — 10
Derivative instrument liabilities current 11 (48) 23 (14)
Long-term portion ofderivative liabilities 2 (16) 1 (13)
Total derivative instruments recorded on the
balance sheet S 24 $ (64) $ 24 $ (16)

The following table presents the fair values and locations of derivative instruments recorded on the Balance Sheets as ofDecember 31,2023(dollars in millions):
Fair\slue
Net Asset
(Liability)
Gross Gross Collateral on Balance
Derivative and Balance Sheet Location Asset Liability Netting Sheet
Interest rate swap derivatives
Derivative instrument assets current $4 $_ $_ $4
Energy commodity derivatives
Derivative instrument assets current 9 — — 9
Derivative instrument liabilities current 20 (79 ) 42 (17
Long-term portion ofderivative liabilities 3 (21 ) (18 )
Total derivative instruments recorded on the
balance sheet S 36 S(100 ) $4422 $(22
Exposure to Demands for Collateral
Avista Corp.'s derivative contracts often require collateral(in the form ofcash or letters ofcredit)or othercredit enhancements,or reductions or terminations of a portion ofthe
contract through cash settlement.In the event ofchanges in market prices ora downgrade in Avista Corp.'s credit ratings or other established credit criteria,additional collateral may
be required.In periods ofprice volatility,the level of exposure can change significantly.As a result,sudden and significant demands may be made against Avista Corp.'s credit
laeilities and cash.Avista Corp.actively monitors the exposure to possible collateral calls and takes steps to mitigate capital requirements.
The following table presents collateral outstanding related to its derivative instruments as ofDecember 31(dollars in millions):
Energy commodity derivatives 2024 2023
Cash collateral posted S 24 S 43
Letters ofcredit outstanding 12 20
There was no collateral or letters of credit outstanding related to interest rate swap derivatives as ofDecember 31,2024 and December 31,2023.
Certain ofAvista Corp.'s derivative instruments contain provisions requiring Avista Corp.to maintain an"Investment grade"credit rating from the majoreredit rating agencies.If
AvistaCorygi credit ratings were to fall below"investment grade,'it would be in violation ofthese provisions,and the counterparties to the derivative instruments could request
immediate payment or demand immediate and ongoing collateralization on derivative instruments in net liability positions.
The following table presents the aggregate ftirvalue ofall derivative instruments with credit-risk-related contingent features in a liability position and the amount ofadditional
collateral Avista Corp.could be required to post as ofDecember 31(dollars in millions):
Energy commodity derivatives 2024
Liabilities with credit-risk-related contingent features $ 33
Additional collateral to post 22
NOTE 5.JOINTLYOWNED ELECTRIC FACILITIES
The Company has a 15 percent ownership interest in Units 3 and 4 ofColstrip,and provides financing for its ownership interest in the project.In January 2023,the Company entered
into an agreement to transferits ownership in Colstrip Units 3 and 4 to Northwestern on December 31,2025.The Company will retain responsibility for remediation obligations in
existence at the time the transaction closes.See further discussion of the transaction within Note 15.
Pursuant to the ownership and operating agreements among the co-owners.the Company's share ofrelated fuel costs as well as operating expenses forplant in service are included in
the corresponding accounts in the Statements oflncome.The Company's share ofutility plant in service for Colstrip and accumulated depreciation(inclusive ofthe ARO assets and
accumulated amortization)were as follows as of December 31(dollars in millions):
Utility plant in service $ 2024 401 $ 2023 394
Accumulated depreciation
(355) (334)
See Note 6 for further discussion ofAROs.
While the obligations and liabilities with respect to Colstrip are to be shared among the co-owners on a pro-rata basis,many ofthe environmental liabilities are joint and several under
the law,so that if any co-owner failed to pay its share of such liability,the other co-owners(or any one of them)could be required to pay the defaulting co-owner's share(or the entire
liability).
NOTE 6.ASSET RETIREMENT OBLIGATIONS
The Company has recorded liabilities for future AROs to:
restore coal ash containment ponds and coal holding areas at Colstrip,
cap a landfill at the Kettle Falls Plant,and
remove plant and restore the land at the Coyote Springs 2 site at the termination ofthe land lease.
Due to an inability to estimate a range of settlement dates,the Company cannot estimate a liability for the:
removal and disposal of certain transmission and distribution assets,and
abandonment and decommissioning of certain hydroelectric generation and natural gas storage facilities.
In 2015,the EPAissued a final rule regarding CCRs.Colstrip produeesthis byproduct.The CCR rule has been the subject ofongoing litigation.In August 2018,the D.C.Circuit
struck down provisions ofthe rule.The rule includes technical requirements for CCR landfills and surface impoundments.The Colstrip owners developed a multi-year compliance
plan to address the CCR requirements and existing state obligations.
In April 2024 and January 2025,the EPA issued additional final rules building on the 2015 regulations and regulating CCR management units at active and inactive powerplants.
The Colstrip owners are performing analyses to determine whether any potential changes to the existing remediation efforts are required.Based on the results of these analyses to date,
the Company believes there will not be a material change to the asset retirement obligation forColstrip related to these final rules.
The actual asset retirement costs related to the CCR rule requirements may vary substantially from the estimates used to record the ARO due to the uncertainty and evolving nature of
the compliance strategies that will be used and the availability ofdata used to estimate costs,such as the quantity ofcoal ash present at certain sites and the volume of fill that will be
needed to cap and cover certain impoundments.The Company updates its estimates as new information becomes available.The Company expects to seek recovery ofcosts related to
complying with the CCR rile through the ratemaking process.
In addition to the above,under a 2018 Administrative Order on Consent and ongoing negotiations with the Montana Department orEcological Quality,the owners ofColstrip are
required to provide financial assurance,primarily in the form of surety bonds,to secure each owner's pro-rata shareorvarious anticipated closure and remediation ofthe ash pondsond
coal holding areas.The amount of financial assurance required ofeach owner may,like the ARO,vary substantially due to the uncertainty and evolving nature ofanticipaled closure
and remediation activities,and as those activities are completed over time.
The following table documents the changes in the Company's asset retirement obligation during the years ended December3l(dollars in millions):
2024 2023
Asset retirement obligation at beginning ofyear $ 18 $ 16
Liabilities incurred _ 2
Liabilities settled (1)
Accretion expense I ._
Asset retirement obligation at end ofyear $ 18 $ 18

NOTE 7.PENSION PLANS AND OTHER POSTRETIREMENT BENEFIT PLANS
The Company has a defined benefit pension plan covering the majority ofregular full-time non-union employees at Avista Corp.hired prior to January 1,2014 and regular full-time
union employees that were hired prior to January 1,2024.Employees eligible for the plan continue to accrue benefits.Individual benefits under this plan are based upon the
employee's years of service,date of hire and average compensation as specified in the plan.Non-union employees hired on or after January 1,2014 and union employees hired on or
after January 1,2024 participate in a defined contribution 401(k)plan in lieu ofa defined benefit pension plan.The Company's funding policy is to contribute at least the minimum
amounts required to be funded under the Employee Retirement Income Security Act,but not more than the maximum amounts currently deductible for income tax purposes.The
Company contributed$10 million in cash each year to the pension plan in 2024 and 2023.The Company expects to contribute$10 million in cash to the pension plan in 2025.
In 2022,the defined benefit pension plan lump sum payments exceeded the annual service and interest costs for the plan.This resulted in a partial settlement ofthe plan,and the
Company recorded a settlement loss of$12 million for the previously unrecognized losses in 2022.This loss was deferred as a regulatory asset and is being amortized over 12 years in
accordance with regulatory accounting orders.
In 2024,the Company offered pension participants an election to leave the pension plan for an alternative defined contribution 401(k)plan.In April 2024,it was determined that due
to the number ofparticipaniselecting to leave the pension plan,as well as the insulting decrease in expected future service,this event resulted in a curtailment ofthe pension plan,
and an associated gain ofSI million for the reduction in the benefit obligation.This gain was offset against the unrecognized net actuarial loss(and recorded within a regulatory
ass").The cunailment triggered a remeasurement ofpension plan.The remcasurement did not have a material impact on the Company's financial condition or results ofopemtions.
The Company has a SERPproviding additional pension benefits to certain executive officers and certain key employees ofthe Company.The SERPpmvides benefits to individuals
whose benefits under the defined benefit pension plan are reduced due to the application of Section 415 ofthe Internal Revenue Code of 1986 and the deferral of salary under deferred
compensation plans.The liability and expense forthis plan are included as pension benefits in the tables included in this Note.
The Company expects benefit payments underthe pension plan and the SERPwill total(dollars in millions):
Total 2030-
2025 2026 2027 2028 2029 2034
Expected benefit payments $ 44 $ 45 $ 45 $ 46 $ 46 $ 242
The expected long-term rate ofretum on plan assets is based on past performance and economic forecasts for the types ofinvestments held by the plan.In selecting a discount rate,the
Company considers yield rates for highly rated corporate bond portfolios with maturities similar to that ofthe expected term ofpension benefits.
The Company provides cennin health care and life insurance benefits for eligible retired employees hired prior to January I,2014.The Company accrues the estimated cost of
postretimmienl benefit obligations during the years employees provide services.The liability and expense ofthis plan are included as other postretirement benefits.Non-union
employees hired on or after January 1,2014,will have access to the retiree medical plan upon retirement;however;Avista Corp.will no longer provide a contribution toward their
medical premium.
The Company has a Health Reimbursement Arrangement(HRA)to provide employees with tax-advantaged funds to pay for allowable medical expenses upon retirement.The amount
earned by the employee is fixed on the retirement date based on the employee's years of service and the ending salary.The liability and expense ofthe HRA are included as other
postretirement benefits.
The Company provides death benefits to beneficiaries of executive officers who die during their term ofoffice or after retirement.Underthe plan,an executive officers designated
beneficiary will receive a payment equal to twice the executive officers annual base salary at the time ofdeath(or ifdeath occurs after retirement,a payment equal to twice the
executive officer's total annual pension benefit).The liability and expense forthis plan are included as otherpostretirement benefits.
The Company expects benefit payments under other postretirement benefit plans will total(dollars in millions):
Total 2030-
2025 2026 2027 2028 2029 2034
Expected benefit payments $ 7 $ 7 S 7 $ 7 $ 7 $ 38
The Company expects to contribute$7 million to other postretirement benefit plans in 2025.The Company uses a December 31 measurement date for its pension and other
postretirement benefit plans.
The following tables set forth the pension and other postretirement benefit plan disclosures as of December 31,2024 and 2023 and the components ofnet periodic benefit costs for
the years ended December 31,2024 and 2023(dollars in millions):
Other Post-
Pension Benefits retirement Benefits
2024 2023 2024 2023
Change in benefit obligation:
Benefit obligation as ofbeginning ofyear $ 585 S 558 $ 122 $ 116
Service cost 16 14 3 2
Interest cost 34 33 7 7
Actuarial(gain)/loss(1) 2 21 (9) 4
Benefits paid (36) (41) (6) (7)
Curtailments (1) — —
Benefit obligation as ofend ofyear(2) S 600 $ 585 S 117 S 122
Change in plan assets:
Fair value ofplan assets as ofbeginning ofyear S 590 $ 541 S 58 S 49
Actual return on plan assets 42 79 9 9
Employer contributions 10 10 Benefits paid (34) (40) —
Fair value ofplan assets as ofend ofyear(2) $ 608 $ 590 $ 67 $ 58
Funded status $ 8 $ 5 $ (50) $ (64)
Amounts recognized in the Balance Sheets:
Non-current assets $ 35 $ 33 $ - $
Current liabilities (2) (2) (1) (1)
Non-current liabilities (25) (26) (49) (63)
Net amount recognized S 8 S 5 $ (50) $ (64)
Accumulated pension benefit obligation(2) $ 522 $ 514
Accumulated postretirement benefit obligation:
For retirees $ 67 S 68
For fully eligible employees $ 16 S 16
For other participants $ 34 S 38
Included in accumulated other comprehensive loss(income)(net of tax):
Unrecognized prior service cost(credit) $ 3 $ 4 S — S (1)
Unrecognized net actuarial loss 70 69 2 13
Total 73 73 2 12
Less regulatory asset (73) (72) (2) (13)
Accumulated other comprehensive loss for unfunded benefit
obligation for pensions and other postretirement benefit plans $— S — $ (1)
(I)The change in the pension benefit obligation related to actuarial loss is primarily related to changes in demographic experience,partially offset by financial assumption changes.
(2)As ofDecember3l,2024,the SERPhad a projected benefit obligation of$27 million and an accumulated benefit obligation of$26 million,with no plan assets.
Other Post-
Pension 11"e6ts retirement Benefits
2024 2023 2024 2023
Weighted-average assumptions as of December 31:
Discount rate for benefit obligation 6.13% 5.86% 6.09% 5.83%
Discount rate for annual expense 5.86% 6.10% 5.83% 6.10%

Expected long-tern return on plan assets 7.80% 8.30% 6.70% 7.20%
Rate ofcompensation increase 5.19% 4.87%
Medical cost trend pre-age 65-initial 6.50% 6.50%
Medical cost trend pre-age 65-ultimate 5.00% 5.00%
Ultimate medical cost trend yearpre-age 65 2031 2030
Medical cost trend post-age 65-initial 6.50% 6.50%
Medical cost trend post-age 65-ultimate 5.00% 5.00%
Ultimate medical cost trend year postage 65 2031 2030
Pension Benefits Other Post-retirement Benefits
2024 2023 2024 2023
Components of net periodic benefit cost
Service cost(1) $ 16 $ 14 $ 3 $ 2
Interest cost 34 33 7 7
Expected return on plan assets (45) (44) (4) (3)
Amortization ofprior service cost(credit) — 1 (1) (1)
Net loss recognition 2 5 — —
Settlement loss(2)
Net periodic benefit cost $ 7 S 9 $ 5 S 5
(1)Total service cost in the table above is recorded to the same accounts as labor expense.Labor and benefits expense is recorded to various projects based on whether the work is a
capital project or an operating expense.Approximately 45 percent ofall labor and benefits is capitalized to utility property and 55 percent is expensed to utility other operating
expenses.
(2)The settlement loss was deferred as a regulatory asset and is being amortized over 12 years in accordance with regulatory accounting orders.
Pension costs other than service costs are presented in the Statements oflncome in the line item"Other income-net."
Plan Assets
TheRnance Committee ofthe Board of Directors approves investment policies,objectives and strategies that seek an appropriate return for the pension plan and other postretirement
benofttplans and reviews and approves changes to the investment and funding policies.
The Company has contracted with investment consultants who are responsible for monitoring the individual investment managers.The investment managers'performance and related
individual fund performance is periodically reviewed by an internal benefits committee and by the Finance Committee to monitor compl iance with investment policy objectives and
strategies.
Pension plan assets are invested in mutual funds,and trusts and partnerships that hold marketable debt and equity securities and mal estate.In seeking to obtain a return that aligns
with the funded status ofthe pension plan,the investment consultant recommends allocation percentages by asset classes.These recommendations am reviewed by the internal
benefits committee,which then recommends their adoption by the Finance Committee.The Finance Committee has established target investment allocation percentages by asset
classes and investment ranges for each asset class of55 percent in equity securities,40 percent in debt securities,and 5 percent in real estate.The target investment allocation
percentages are typically the midpoint ofthe established range.
The fairvalue ofpension plan assets invested in debt and equity securities was based primarily on fairvalue(market prices).The fair value of investment securities traded on a
national securities exchange is determined based on the reported last sales price;securities traded in the over-thc-counter market am valued at the last reported bid price.Investment
securities forwhich market prices am not readily available or for which market prices do not represent the value at the time ofpricing,the investment manager estimates fairvalue
based upon other inputs(including valuations of securities comparable in coupon,rating,maturity and industry).
Pension plan and other postretirement plan assets with fairvalues are measured using net asset value(NAV)are excluded from the fairvalue hierarchy and included as reconciling
items in the tables below.
The plan's investments in common/collective trusts have redemption limitations that permit quarterly redemptions following notice requirements of45 to 60 days.Most ofthe plan's
investments in closely held investments and partnership interests have redemption limitations ranging from bi-monthly to semi-annually following redemption notice requirements of
60 to 90 days.
The following table discloses by level within the fair value hierarchy(see Note 13 for a description ofthe fair value hierarchy)ofthe pension plan's assets measured and reported as of
December 31,2024 at fairvalue(dollars in millions):
Leven Level Level Total
Cash equivalents $ — $ 8 $ — S 8
Fixed income securities:
U.S.government issues — 37 — 37
Corporate issues — 213 — 213
International issues — 33 — 33
Municipal issues — 11 — 11
Mutual funds:
U.S.equity securities 160 —
l60
International equity securities 63 — — 63
Plan assets measured at NAV(not subject to hierarchy
disclosure)
Common/collective trusts:real estate — — 24
Partnership/closely held investments:
International equity securities — — 52
Real estate _
— 7
Total S 223 S 302 $ $ 608
The following table discloses by level within the fairvalue hierarchy(see Note 13 fora description ofthe fairvalue hierarchy)ofthe pension plan's assets measured and reported as of
December 31,2023 at fairvalue(dollars in millions):
Leven Level 2 Level Total
Cash equivalents $ _ S 7 $ — $ 7
Fixed income securities:
U.S.government issues — 19 19
Corporate issues — 175 __ 175
International issues — 27 27
Municipal issues — 14 14
Mutual funds:
U.S.equity securities 170 — — 170
International equity securities 75 75
Plan assets measured at NAV(not subject to hierarchy
disclosure)
Common/collective trusts:real estate 25
Partnership/closely held investments:
International equity securities -. -. 71
Real estate
Total S 245 S 242 $ $ 590
The fair value ofotherpostretirement plan assets invested in debt and equity securities was based primarily on market prices.The fair value ofinvestment securities traded on a
national securities exchange is determined based on the last reported sales price;securities traded in the over-the-counter market are valued at the last reported bid price.For
investment securities for which market prices are not readily available,the investment manager determines fair value based upon other inputs(including valuations ofsecurities

comparable in coupon,rating,maturity and industry).The target asset allocation was 60 percent equity securities and 40 percent debt securities in both 2024 and 2023.
The fair value ofotherpostretimment plan assets was determined to be$67 million as ofDecember 31,2024 and$58 million as ofDecember 31,2023.The assets consist ofa
balanced index mutual fund,which is a single mutual fund that includes a percentage of U.S.equity and fixed income securities and international equity and fixed income securities.
This mutual fund is classified as Level 1 in the fir value hierarchy(see Note 18 for a description ofthe fair value hierarchy).
40I(k)Plans and Executive Deferral Plan
Avista Corp.has a salary deferral 401(k)plan that is a defined contribution plan and covers substantially all employees.Employees can make contributions to their respective
accounts in the plans on a pre-tax basis up to the maximum amount permitted by law.The Company matches a portion ofthe salary deferred by each participant according to the
schedule in the respective plan.
Employer matching contributions were as follows for the years ended December 31(dollars in millions):
2024 2023
Employer401(k)matching contributions $ 16 $ 15
The Company has an Executive Deferral Plan.This plan allows executive officers and other key employees the opportunity to deferuntil the earlier oftheir retirement,termination,
disability or death,up to 75 percent of theirbase salary and/orup to 100 percent of their incentive payments.Deferred compensation funds are held by the Company in a Rabbi Trust.
There were deferred compensation assets corresponding deferred compensation liabilities on the Balance Sheets ofthe following amounts as ofDecember3l(dollars in millions):
2024 2023
Deferred compensation assets and liabilities $ 9 $ 8
NOTE 8.ACCOUNTING FOR INCOME TAXES .�-
Income Tax Expense
Areconciliation of federal income taxes derived from the statutory federal tax rate of 21 percent applied to income before income taxes is as follows for the years ended December 31
(dollars in millions):
2024 2023
Federal income taxes at statutory rates $ 38 21.0% $ 27 21.0%
Increase(decrease)in tax resulting from:
Tax effect ofregulatory treatment ofutility
plant differences (12) (6.6) (12) (9.2)
State income tax expense 1 0.5 1 0.5
Flow through related to deduction ofineters
and mixed service casts(1) (23) (12.6) (48) (36.7)
Tax credits (1) (0.6) (2) (1.6)
Other (2) (0.9) (2) (1.6)
Total income tax expense(benefit) $ 1 0.8% S (36) (27.6)%
(1)The Company's general rate cases included approval ofbase rate increases,offset by tax customer credits.As the tax customer credits are returned to customers,this results in
a decrease to income tax expense due to flowing through the benefits related to meters and mixed service costs.Once these tax customer credits have been applied to
customers and are exhausted,income tax expense will increase.
The realization ofdeferred income tax assets is dependent upon the ability to generate taxable income in future periods.The Company evaluated available evidence supporting the
realization ofits deferred income tax assets and determined it is more likely than not that deferred income tax assets will be realized.
As of December 31,2024,the Company had S 19 million of state tax credit carryforwards.Ofthe total amount,the Company believes that it is more likely than not that it will only be
able to utilize S 11 million ofthe state tax credits.As such,the Company has recorded a valuation allowance of$8 million against the state tax credit carryforwards and reflected the
net amount of$11 million as an asset as of December 31,2024.State tax credits expire from 2025 to 2038.
Status oflnternal Revenue Service(IRS)and State Examinations
The Company and its eligible subsidiaries file consolidated federal income tax returns.All tax years after2020 are open loran IRS tax examination.The IRS is reviewing tax year
2019.
The Company files state income tax returns in certain jurisdictions,including Idaho,Oregon,Montana and Alaska.Subsidiaries are charged or credited with the tax effects of their
operations on a stand-alone basis.
All tax years after 2020 are open for examination in Idaho,Oregon,Montana and Alaska.
The Company believes open tax years for federal or state income taxes will not result in adjustments that would be significant to the financial statements.
NOTE 9.ENERGYPURCHASE CONTRACTS
Avista Corp.has contracts forthe purchase offuel for thermal generation,natural gas forresale and various agreements forthe purchase or exchange ofelectric energy with other
entities.The remaining term ofthe contracts range from one month to twenty-five years.
Total expenses for power purchased,natural gas purchased,fuel forgeneration and other fuel costs,which are included in utility resource costs in the Statements oflncome,were as
follows forthe years ended December 31(dollars in millions):
2024 2023
Utility power resources S 548 $ 607
The following table details Avista Corp.'s future contractual commitments forpower resources(including transmission contracts)and natural gas resources(including transportation
contracts)(dollars in millions):
2025 2026 2027 2028 2029 Thereafter Total
Power resources $ 333 S 311 $ 285 $ 263 $ 264 $ 2,570 S 4,026
Natural gas resources 108 81 64 55 50 249 607
Total $ 441 $ 392 $ 349 S 318 $ 314 $ 2,819 $ 4,633
These energy purchase contracts were entered into as part of Avista Corp:s obligation to serve its retail electric and natural gas customers'energy requirements,including contracts
entered into for resource optimization.These costs are recovered either through base retail rates or adjustments to retail rates as part ofthe power and natural gas cost deferral and
recovery mechanisms.
The future contractual commitments forpower resources include fixed contractual amounts related to the Company's contracts with Public Utility Districts(PUDs)to purchase portions
ofthe output of certain generating facilities.Although Avista Corp.has no investment in the PUD generating facilities,the conlroeloobligate Avista Corp.to pay certain minimum
amounts whether or not the facilities are operating.The cost ofpower obtained under the contracts,including payments made when a Areility is not operating,is included in utility
resource costs in the Statements of Income.The contractual amounts included above consist of Avista Corp:s share ofexisting debt service cost and its proportionate share ofthe
variable operating expenses ofthese projects.The minimum amounts payable under these contracts are based in part on the proportionate share ofthe debt service requirements ofthe
PUD's revenue bonds for which the Company is indirectly responsible.The Company's total future debt service obligation associated with the revenue bonds outstanding at
December 31,2024(principal and interest)was$267 million.
In addition,Avista Corp.has operating agreements,settlements and other contractual obligations related to its generating facilities and transmission and distribution services.The
expenses associated with these agreements are reflected as other operating expenses in the Statements oflncome.The following table details future contractual commitments under
these agreements(dollars in millions):

2025 2026 2027 2028 2029 Thereafter Total
Contractual obligations $ 3T $ 40 $ 18 $ 18 $ 9 $ 165 $ 289
NOTE 10.SHORr-TERM BORROWINGS
Lines ofCmdil
Avista Corp.has a committed line ofcredit in the total amount of$S00 million with an expiration date of June 2028.The Company has the option to extend for two additional one
yearperiods(subject to customary conditions).The committed line ofcredit is secured by non-transferable first mortgage bonds ofthe Company issued to the agent bank that would
only become due and payable in the event,and then only to the extent,that the Company defaults on its obligations undertbe committed line ofcredit-
Balances outstanding and interest rates on borrowings(excluding letters ofcredit)underthe Company's revolving committed line ofcredit were as follows as ofDecember3I(dollars
in millions):
2024 2023
Balance outstanding at end ofperiod $ 342 $ 349
Letters ofcredit balance outstanding at end ofperiod 5 5
Average interest rate at end ofperiod 5.52% 6.46%
As of December 31,2024 and 2023,the borrowings outstanding under Avista Carp:s committed lines ofcredit were classified as short-term borrowings on the Balance Sheets.
Letter of Credit Facility
In December2022,the Company entered into a continuing letter ofcredit agreement in the aggregate amount of$50 million.Eitherparty may terminate the agreement at any time.
The Company had$12 million and$20 million in letters ofcredit outstanding under this agreement as of December 31,2024 and December 31,2023,respectively.Letters ofcredit
are not reflected on the Balance Sheets.Ifa letter ofcredit were drawn upon by the holder,we would have an immediate obligation to reimburse the bank that issued that letter.
Covenants and Default Previsions
The short-term borrowing agreements contain customary covenants and default provisions,including a change in control(as defined in the agreements).The events ofdefault under
each ofthe credit facilities also include a cross default from other indebtedness(as defined)and in some cases other obligations.Most ofthe short-term borrowing agreements also
include a covenant which does not permit the ratio of"consolidated total debt"to"consolidated total capitalization"ofAvista Corp.to be greater than 65 percent at any time.As of
December 31,2024,the Company complied with this covenant.
NOTE 11.BONDS
The following details long-term debt outstanding as of December 31(dollars in millions):
Maturity Interest
Year Description Rate 2024 2023
Avista Corp.Secured Long-Term Debt
2028 Secured Medium-Term Notes 6.37% $ 25 $ 25
2032 Secured Pollution Control Bonds(1) 3.88% 67 67
2034 Secured Pollution Control Bonds(1) 3.88% 17 17
2035 First Mortgage Bonds 6.25% 150 150
2037 First Mortgage Bonds 5.70% 150 150
2040 First Mortgage Bonds 5.55% 35 35
2041 First Mortgage Bonds 4.45% 85 85
2044 First Mortgage Bonds 4.11% 60 60
2045 First Mortgage Bonds 4.37% 100 100
2047 First Mortgage Bonds 423% 80 80
2047 First Mortgage Bonds 3.91% 90 90
2048 First Mortgage Bonds 4.35% 375 375
2049 First Mortgage Bonds 3.43% 180 180
2050 First Mortgage Bonds 3.07% 165 165
2051 First Mortgage Bonds 3.54% 175 175
2051 First Mortgage Bonds 2.90% 140 140
2052 First Mortgage Bonds 4.00% 400 400
2053 First Mortgage Bonds 5 66% 250 250
Total Avista Corp.secured long-term debt 2,544 2,544
Secured Pollution Control Bonds held by Avista
Corporation(1) — (84)
Total long-term debt $ 2,544 $ 2,460
(1)in April 2024,the Company remarketed the City ofForsyth,Montane Pollution Control Revenue Refunding Bonds.The bonds ate not subject to ordinary optional redemption.
The bonds are secured by equal principal amounts ornon-transferable first mortgage bonds ofthe Company.Avista Corp.had purchased the Forsyth bonds upon original
issuance in Deccmber20lO and held the bonds until market conditions were favorable for remarketing the bonds to unaffiliated investors.In connection with the pricing of
the Forsyth bonds,the Company cash-settled hvo interest rate swap derivatives(notional aggregate amount ofS20 million)and received a net amount ofS4 million.See note
8 for a discussion of interest rate swap derivatives.
The following table details future long-term debt maturities including advances from associated affiliates(see Note 12)(dollars in millions):
2025 2026 2027 2028 2029 Thereafter Total
Debt maturities $ $ — $ — $ 25 $ — $ 2,571 $ 2,596
Substantially all of Avista Corp.'s owned properties are subject to the lien oftheir respective mortgage indentures.Under the Mortgages and Deeds of Trust(Mortgages)securing their
first mortgage bands(including secured medium-term notes),Avista Corp.may issue additional first mortgage bonds undertheir specific mortgage in an aggregate principal amount
equal to the sum of:
66-2/3 percent ofthe cost or fair value to the Company(whichever is lower)ofproperty additions ofthat entity which have not previously been made the basis ofany
application under that entity's Mortgage,or
an equal principal amount ofretired first mortgage bonds ofthat entity which have not previously been made the basis ofany application under that entity's Mortgage,or
deposit of cash.
Avista Corp.may not individually issue any additional first mortgage bonds(with certain exceptions in the case ofbonds issued on the basis ofretired bonds)unless the particular
entity issuing the bonds has"net earnings"(as defined in that entity's Mortgage)for any period of 12 consecutive calendar months out ofthe preceding 18 calendar months that were
at least twice the annual interest requirements on all mortgage securities at the time outstanding,including the first mortgage bonds to be issued,and on all indebtedness ofpriorrank.
As ofDecember 31,2024,property additions and retired bonds would have allowed,and the net earnings test would not have prohibited,the issuance of$1.5 billion by Avista Corp.
in an aggregate principal amount ofadditional first mortgage bonds,at an assumed interest rate of 8 percent.
NOTE 12.ADVANCES FROM ASSOCIATED COMPANIES
In 1997,the Company issued Floating Rate Junior Subordinated Deferrable Interest Debentures,Series B,with a principal amount of$52 million to Avista Capital li,an affiliated
business trust formed by the Company.Avista Capital II issued$50 million of Preferred Trust Securities.The distribution rate on the Preferred Trust Securities is three-month CME
Term SOFR plus 1.137 percent.
The distribution rates paid were as follows during the years ended December 31:
2024 2023
Law distribution rate 5.64% 5.64%

High distribution rate 6.51% 6.55%
Distribution rate at the end ofthe year 5.64% 6.51%
Concurrent with the issuance ofthe Preferred Trust Securities,Avista Capital II issued S2 million ofCornmon Trust Securities to the Company.These Preferred Trust Securities may be
redeemed at the option of Avista Capital 11 at any time and mature on June 1,2037.In December2000,the Company purchased S 10 million ofthese Preferred Trust Securities.
The Company owns 100 percent of Avista Capital II and has solely and unconditionally guaranteed the payment ofdistributions on,and redemption price and liquidation amount for,
the Preferred Trust Securities to the extent Avista Capital II has funds available forsuch payments from the respective debt securities.Upon maturity or prior redemption ofsuch debt
securities,the Preferred Trust Securities will be mandatorily redeemed.
NOTE 13.FAIR VALUE
The carrying values ofcash and cash equivalents,special deposits,accounts and notes receivable,accounts payable and notes payable as shown on the Balance Sheets are reasonable
estimates oftheir fairvalues.The carrying values ofbonds and advances from associated companies as shown on the Balance Sheets may be different from the estimated fair value.See
below for the estimated fair value of bonds and advances from associated companies.
The fairvalue hierarchy prioritizes the inputs used to measure fairvalue.The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or
liabilities(Level 1 measurements)and the lowest priority to fairvalues derived from unobservable inputs(Level 3 measurements).
The three levels ofthe fairvalue hierarchy are defined as follows:
Level 1-Quoted prices are available in active markets for identical assets orliabilities.Active markets are those in which transactions forthe asset or liability occur with
sufficient frequency and volume to provide pricing information on an ongoing basis.
Level 2-Pricing inputs are otherthan quoted prices in active markets included in Level 1,but which are either directly or indirectly observable as ofthe reporting date.Level 2
includes financial instruments valued using models or othervaluation methodologies.These models are primarily industry-standard models that considervarious assumptions,
including quoted forward prices for commodities,time value,volatility factors,and current market and contractual prices forthe underlying instruments,as well as otherrelevant
economic measures.Substantially all of these assumptions are observable in the marketplace throughout the full term ofthe instrument,can be derived from observable data or are
supported by observable levels at which transactions are executed in the marketplace.
Level -Pricing inputs include significant inputs generally unobservable from objective sources.These inputs may be used with internally developed methodologies that result
in management's best estimate offair value.
Financial asselsand liabilities are classified in their entirety based on the lowest level ofinput that is significant to the fair value measurement.The Company's assessment ofthe
significance ofs particularinput to the fairvalue measurement requires judgment and may affect the valuation offairvalue assets and liabilities and theirplacement within the fair
value hierarchy levels.The determination ofthe fair values incorporates various factors that include not only the credit standing ofthe counterparties involved and the impact of
credit enhancements(such as cash deposits and letters of credit),but also the impact of Avista Corp:s nonperformance risk on its liabilities.
The following table sets forth the carrying value and estimated fairvalue ofthe Company's financial instruments not reported at estimated fairvalue on the Balance Sheets as of
December 31(dollars in millions):
202J 2031
Carrying Estimated Carrying Estimated
Woe Fair value value Farr value
Bonds(Level 2) S 1,100 $ 938 $ 1,100 $ 969
Bonds(Level 3) 1,444 1,089 1,360 1,089
Advances from associated companies(Level 3) 52 47 52 46
These estimates offair value oflong-term debt and long-term debt to affiliated trusts were primarily based on available market information,which generally consists ofestimated
market prices from third party brokers for debt with similar risk and terms.The price ranges obtained from the third party brokers consisted ofmarket prices of 57.68 to 105.474 percent
ofthe principal amount,where 100.00 represents the carrying value recorded on the Balance Sheets.Level 2long-term debt represents publicly issued bonds with quoted market
prices;however,due to their limited trading activity,they are classified as Level 2 because brokers must generate quotes and make estimates ifthere is no trading activity near a period
end.Level 3 long-term debt consists ofprivate placement bonds and debt to affiliated trusts,which typically have no secondary trading activity.Fairvalues in Level 3 are estimated
based on market prices from third party brokers using secondary market quotes for debt with similar risk and terms to generate quotes for Avista Corp.bonds.
The following table discloses by level within the fairvalue hierarchy the Company's assets and liabilities measured and reported on the Balance Sheets as of December 31,2024 at
fair value on a recurring basis(dollars in millions):
Counterparty
and Cash
Collateral
Level) Leve12 Level Netting(I) Total
December 31,2024
Assets:
Energy commodity derivatives(2) S - $ 23 $ - $ (13) S 10
Interest rate swap derivatives - 1 - - 1
Deferred compensation assets:
Mutual Funds:
Fixed income securities 2 - - - -
Equity securities 7 - -
Total S 9 $ 24 S - $ (13) $ 20
Liabilities:
Energy commodity derivatives(2) $ -- S 61 $ 3 S (37) S 27
Total $ - $ 61 $ 3 S (37) S 27
The following table discloses by level within the fair value hierarchy the Company's assets and liabilities measured and reported on the Balance Sheets as of December 31,2023 at
fair value on a recurring basis(dollars in millions):
Counterparty
and Cash
Collateral
LevelI Level Leve113 Netting(I) Total
December 31,2023
Assets:
Energy commodity derivatives(2) S - $ 31 S - S (23) S 8
Interest rate swap derivatives - 4 - -- 4
Deferred compensation assets:
Mutual Funds:
Fixed income securities I - - - 1
Equity securities 7 - '- -- 7
Total $ 8 $ 35 S - $ (23) $ 20
Liabilities:
Energy commodity derivatives(2) $ - S 92 S 8 $ (65) $ 35
Total $ - $ 92 $ 8 $ (65) $ 35
(I)The Company is permitted to net derivative assets and derivative liabilities with the same counterparty when a legally enforceable master netting agreement exists.In addition,the
Company nets derivative assets and derivative liabilities against payables and receivables for cash collateral held or placed with these same counterparties.
(2)The Level 3 energy commodity derivative balances are associated with a natural gas exchange agreement.
The difference between the amount ofderivative assets and liabilities disclosed in respective levels in the table above and the amount ofderivative assets and liabilities disclosed on
the Balance Sheets is due to netting arrangements with certain counterparties.See Note 4 for additional discussion ofderivative netting.

To establish fair value for energy commodity derivatives,the Company uses quoted market prices and forward price curves to estimate the fait value ofenergy commodity derivative
instruments included in Level 2.Electric derivative valuations are performed using market quotes,adjusted for periods in between quotable periods.Natural gas derivative valuations
arc estimated using New York Mercantile Exchange pricing for similar instruments,adjusted for basin differences,using market quotes.Where observable inputs are available for
substantially the full term ofthe contract,the derivative asset or liability is included in Level 2.
To establish fair values for interest rate swap derivatives,the Company uses forward market curves for interest rates for the term ofthe swaps and discounts the cash flows back to
present value using an appropriate discount rate.The discount rate is calculated by third party brokers according to the terms ofthe swap derivatives and evaluated by the Company
forreasonabicness,with consideration given to the potential non-performance risk by the Company.Future cash flows ofthe interest rate swap derivatives are equal to the fixed
interest rate in the swap compared to the floating market interest rate multiplied by the notional amount foreach period.
Deferred compensation assets and liabilities represent funds held by the Company in a Rabbi Trust foran executive deferral plan.These funds consist ofactively traded equity and
bond funds with quoted prices in active markets.
Level Fair Value
Natural Gas Exchange Agreement
For the natural gas commodity exchange agreement,the Company uses the same Level 2 market quotes described above;however,the Company also estimates the purchase and sales
volumes(within con tmetual limits)as well as the timing ofthose transactions_Changing the liming ofvolume estimates changes the timing ofpurchases and sales,impacting which
brokered quote is used.Because the brokered quotes can vary significantly from period to period,the unobservable estimates ofthe timing and volume oftransactions can have a
significant impact on the calculated fair value.The Company currently estimates volumes and timing oftransactions based on a most likely scenario using historical data.Historically,
the timing and volume oftransactions are not highly correlated with market prices and market volatility.
As of December 31,2024,expected remaining transactions under the agreement were sales.The contract expires in April 2025.
The following table presents the quantitative information which was used to estimate the fairvalues ofthe Level 3 assets and liabilities above as ofDecember 31,2024(dollars in
millions,except mmBTU amounts):
Fair value(Net)at
December 31,2024 \9Iuauon Technique _ Unobservable Input Range
Natural gas exchange $ (3) Internally derived Forward sales prices $2.28-$4.57/mmBTU
weighted average $3.18 Weighted Average
cost ofgas
Sales volumes 280,000-600,000 mmBTUs
The valuation methods,significant inputs and resulting fairvalues described above were developed by the Company and are reviewed on at least a quarterly basis to ensure they
provide a reasonable estimate offairvalue each reporting period.
The following table presents activity for assets and liabilities measured at fair value using significant unobservable inputs(Level 3)for the years ended December 31(dollars in
millions):
Natural Gas Exchange
Agreement(1)
2024:
Balance as of January 1,2024 $ (8)
Total gains or(losses)(realized/unrealized):
Included in regulatory assets
Ending balance as of December31,2024 $ (3)
2023:
Balance as ofJanuary 1,2023 $ (18)
Total gains or(losses)(realized/unrealized):
Included in regulatory assets 10
Ending balance as ofDecember 31,2023 $ (8)
(1)There were no purchases,issuances or transfers from other categories ofderivatives instruments during the periods presented in the table above.
NOTE 14.COMMON STOCK
The payment ofdividends on common stock could be limited by:
certain covenants applicable to preferred stock(when outstanding)contained in the Company's Restated Articles of Incorporation,as amended(currently there
are no preferred shares outstanding),
certain covenants applicable to the Company's outstanding long-term debt and committed line of credit agreements,
the hydroelectric licensing requirements ofsection I0(d)ofthe FPA(seeNote 1),and
certain requirements underthe Oregon Public Utility Commission(OPUC)approval ofthe AERC acquisition in 2014.The OPUC's AERC acquisition order
requires Avista Corp.to maintain a capital structure ofno less than 40 percent common equity(inclusive of short-term debt).This limitation may be revised upon request
by the Company with approval from the OPUC.
The requirements ofthe OPUC approval ofthe AERC acquisition are the most restrictive.Under the OPUC restriction,the amount available for dividends at December 31,2024 was
$326 million.
The Company has 10 million authorized shares ofpreferred stock.The Company did not have preferred stock outstanding as of December 31,2024 and 2023.
Common Stock Issuances
The Company issued common stock for total net proceeds of$68 million in 2024.Most ofthese issuances were made through sales agency agreements underwhich the Company may
offerand sell new shares ofcommon stock from time to time through its sales agents.In 2024,1.8 million shares were issued under these agreements.
NOTE 15.COMMITMENTS AND CONTINGENCIES
In the course ofits business,the Company becomes involved in various claims,controversies,disputes and other contingent matters,including the items described in this Nate.Some
of these claims,controversies,disputes and other contingent matters involve litigation or other contested proceedings.For all such matters,the Company will vigorously protect and
defend its interests and pursue its rights.However,no assurance can be given as to the ultimate outcome ofany matter because litigation and other contested proceedings are subject to
numerous uncertainties.Formatters affecting Avista Corp.'s,the Company intends to seek,to the extent appropriate,recovery of incurred costs through the ratemaking process.
Climate Commitment Act
The CCArequires the Company to submit greenhouse gas emission reports to the Washington State Department of Ecology(Ecology)annually for its electric and natural gas entities.
The CCAthen requires the Company to contract with a third-party verifier to audit the emissions data in the emissions reports.In August 2024,the Company's third-party verifier
submitted to Ecology its verification report on the Company's 2023 emissions report.The verification report was issued with an adverse emissions data verification statement.hi
Scptember2024,in the absence ofs positive verification statement.Ecology assigned an emission level(AEL)to Avista Corp,based on information submitted by the Company's
third-party verifier.In late October 2024.the Company resubmitted a revised emissions report to the third-party verifier and Ecology.In Novcmber2024.the third-party verifier issued
a revised 2023 emissions report with a positive verification statement.In December 2024 Ecology issued a revised AEL for the 2023 emissions reporting year that was in line with the
Company's estimates.
Collective Bargaining Agreements
The Company's collective bargaining agreement with the IBEW represents 36 percent ofall Avista Corp.'s employees.The Company's largest represented group,representing
approximately 90 percent of Avista Corp.'s bargaining unit employees in Washington and Idaho.are covered under a four year agreement which expires in March 2025.The Company
and the IBEW began negotiations on a new collective bargaining agreement in the fiml quarter of2 025.
Boyds Fire(State of Washington Department of Natural Resources a Avista)
In August 2019,the Company was served with a complaint,captioned"State of Washington Department of Natural Resources v.Avista Corporation,"seeking recovery of up to$4.4
million for fire suppression and investigation costs and related expenses incurred in connection with a wildfire that occurred in Ferry County,Washington,in August 2018.
Specifically,the complaint alleges the fire,which became known as the"Boyds Fire,"was caused by a dead ponderosa pine tree falling into an overhead distribution line,and that

Avista Corp.,along with its independent vegetation management contractors Asplundh Tree Company and CN Utility Consulting,were negligent in failing to identify and remove the
tree before it came into contact with the line.Avista Corp.disputes that it was negligent in failing to identify and remove the tree in question.Additional lawsuits were subsequently
filed by private landowners seeking$0.8 million in property damages as well as potential non-economic damages,and holders of insurance subrogation claims seeking recovery Of
$1.8 million in insurance proceeds purportedly paid to their insureds.
The lawsuits were filed in the Superior Court ofFerry County,Washington,and is scheduled for trial on July 7,2025.The Company continues to vigorously defend itself in the
litigation.However,at this time the Company is unable to predict the likelihood ofan adverse outcome or estimate a range ofpotential loss in the event of such an outcome.
Labor Day 2020 Windstorm/Babb Road Fire
In September 2 020,asevere windstorm occurred in eastern Washington and northern Naho.The extreme weather event resulted in customer outages and multiple wildfires in the
region,including the Babb Road Fire,which occurred near the town of Malden,Washington.The Babb Road Fire covered approximately 15,000 acres and destroyed approximately
220 structures.There are no reports ofpersonal injury or death resulting from the fire.
In May 2021 the Company learned the Washington Department ofNatural Resources(DNR)had completed its investigation and issued a report on the Babb Road Fire.
The DNR report concluded,among other things,that
the fire was ignited when a branch ofa multi-dominant Ponderosa Pine tree was broken offby the wind and fell on an Avista Corp.distribution line;
the tree was located approximately 30 feet from the center of Avista Corp:s distribution line and approximately 20 feet beyond Avista Corp.'s right-of-way;
the tree showed some evidence of insect damage,a small area of scarring where a lateral branch/leader(LBL)had broken off in the past,and some past signs of
Gall Rust disease.
The DNR report concluded that:"because ofthe unusual configuration ofthe tree,and its proximity to the powerline,a closer inspection was warranted.Anearer inspection ofthe tree
should have revealed the cut LBL ends and its previous failure,and necessitated determination ofthe failure potential ofthe adjacent LBL,implicated in starting the Babb Road Fire."
The DNR report acknowledged that,other than the multi-dominant nature ofthe tree,the conditions mentioned above would not have been easily visible without close-up inspection
of,or cutting into,the tree.The report also acknowledged that,while the presence of multiple tops would have been visible from the nearby roadway,the tree did not fail at a v-fork
due to the presence ofmultiple tops.The Company contends that applicable inspection standards did not require a closer inspection ofthe otherwise healthy tree,nor was the
Company negligent with respect to its maintenance,inspection or vegetation management practices.
Eleven lawsuits have been filed in connection with the Babb Road fire.Asplundh Tree Company and CN Utility Consulting,which both perform vegetation management services as
independent contractors to the Company,are also named as defendants in each ofthe lawsuits.The lawsuits include six subrogation actions filed by 51 insurance companies seeking
to recover approximately S21 million purportedly paid to insureds to date,and five actionson behalfof 128 individual plaintiffs.One ofthe private plaintiffactions was originally
filed as a class action lawsuit,but has since been amended to assert direct claims on behalfof 10 individual plaintiffs.In the course ofdiscovery,approximately 80 private plaintiffs
have provided information about their alleged damages.Based on information received to date,the 80 private plaintiffs claim damages ofappremimately S60 million.S21 million of
this claim is alleged noneconomic damages(i.e.emotional distress).The Company does not believe noneconomic damages are applicable in this case and will vigorously dispute
such claims.Approximately$6 million ofprivate plaintiffs'claimed damages have been covered by insurance or other forms ofreimbursement.
All proceedings,except for one action filed on September 1,2023 on behalfof three individual plaintiffs(the"Widman Action")have been consolidated in the Superior Court of
Spokane County Washington underthe lead action Blakeley v.Avista Corporation et al.,and variously assert causes ofaction fornegligence,private nuisance,and trespass(the
"Blakeley Proceeding").
In November2023,all parties to the Blakeley Proceeding agreed to a stipulated order which was presented to and entered by the Superior Court of Spokane County,Washington.The
order consolidates the Blakeley Proceeding fortrial(in addition to discovery and pro-trial proceedings)and bifurcates the trial into liability and damages phases,such that the initial
trial in the case will focus solely on whether the defendants are legally responsible for the Babb Road Fire.Atrial date on the liability phase is currently set for May 5,2025,but may
be continued given the current status of discovery.The Widman Action is set for trial on October 6,2025,
In addition,the stipulated order relating to the Blakeley Proceeding memorializes the plaintiffs'agreement to voluntarily dismiss all claims asserting inverse condemnation as a theory
ofliability,without prejudice to theirability to seek permission from the Court to refile those claims at a later date if they can showgood cause to do so.The Widman Action does not
include claims for inverse condemnation.The parties to the Blakeley Proceeding agreed to a preliminary mediation no lalerthan 60 days priorto the liability trial,and,ifthere is a
trial following that mediation and ifthe jury returns a verdict in the plaintiffs'favor in the liability trial,a second mediation within 90 days following the verdict focusing on damages.
The preliminary mediation is scheduled forthe first quarter of2025.Finally,the plaintiffs agreed to complete a damages questionnaire identifying all claimed damages being sought
in connection with the litigation.
Based on the facts and circumstances available to the Company through February 25,2025.the date through which the Company has evaluated the impacts ofevents occurring after
December3l,2024 as indicated under"Subsequent Events",the Company was unable to predict the likelihood ofan adverse outcome or estimate a range ofpotential loss in the event
ofsuch an outcome,and did not record an accrual for losses.Subsequent to February 25,2025,the Company has engaged in mediation discussions with the plaintiffs.Any
information associated with the Babb Road fire arising subsequent to February 25,2025 will be considered in a future period.
Orofino Fire
In August 2023.a fire subsequently referred to as the"Hospital Fire"started in windy conditions near Orofino,Idaho,burning 53 acres and seven primary residences,as well as several
outbuildings.The Idaho Department oft.ands investigated and has issued a report in which it concluded the fire was caused by an electrical fault igniting three separate spots which
then spread uphill.The Company has a distribution line in the area near the ignition point.The Company has to date found no evidence suggesting negligence on its part.Except for
two minor claims for damage to personal property which were resolved,the Company has not,al this time,received any claims in connection with the fire.The Company will
vigorously defend itselfin the event any additional claims are asserted;however at this time,it is unable to estimate the likelihood ofan adverse outcome nor the amount or range of a
potential loss in the event ofan adverse outcome.
Colstrip
Colsirip Owners Arbitration and Litigation
Colstrip Units 3 and 4 are owned by the Company,PacifiCorp,Portland General Electric(POE),and Puget Sound Energy(PSE)(collectively,the"Western CO.Owners'),as well as
NorthWestem and Talen Montana,LLC(Talen),as tenants in common under an Ownership and Operating Agreement,dated May 6,1981,as amended(O&O Agreement),in the
percentages set forth below:
Co-Owner Usti 3 Uoll 4
Avista 15% 15"�
PacifiCorp 10% 10%
PGE 20% 20%
PSE 25% 25%
NorthWestem — 30%
Talen 30% —
Colstrip Units 1 and 2,owned by PSE and Talen,were shut down in 2020 and are in the process of being decommissioned.The co-owners of Units 3 and 4 also own undivided
interests in facilities common to both Units 3 and 4,as well as in certain facilities common to all four Colstrip units.
The Washington Clean Energy Transformation Act(CETA),among other things,imposes deadlines by which each electric utility must eliminate from its electricity rates in
Washington the costs and benefits associated with coal-fired resources,such as Colstrip.The practical impact of CETAis electricity from such resources,including Colstrip,may no
longer be delivered to Washington retail customers after 2025.
Agreement Between Avista and North Western
In January 2023,the Company entered into an agreement with NorthWestem under which,subject to the terms and conditions specified in the agreement,the Company will transfer its
15 percent ownership in Colstrip Units 3 and 4 to NorthWestem.There is no monetary exchange included in the transaction.The transaction is scheduled to close on December 31,
2025 or such other date as the parties mutually agree upon.
Under the agreement,the Company will remain obligated through the close oflhc transaction to pay its share of(i)operating expenses,(ii)capital expenditures,but not in excess of
the portion allocable pro rasa to the portion of useful life(through 2030)expired through the close ofthe transaction,and(iii)site remediation expenses except certain costs relating
to post closing activities.in addition,the Company would enter into an agreement under which it would retain its voting rights with respect to decisions relating to remediation.
The Company will retain its Colstrip transmission system assets,which are excluded from the transaction.
The transaction is subject to the satisfaction ofcustomary closing conditions.Although the agreement was also contingent upon NorthWestem's ability to enter into a new coal supply
agreement by December 31,2024,NorthWestem has since waived that contingency.
The Company does not expect this transaction to have a direct material impact on its financial results.

Agreement Between PSE and Northwestern
In July 2024,PSE entered into an agreement with NorthWestem under which,PSE will transfer its 25 percent ownership in Col strip Units 3 and 4 to NorthWestem.There is no
monetary exchange included in the transaction.The transaction is scheduled to close on December 31,2025.
Burnett et al.v.Talen et al.
Multiple property owners initiated a legal proceeding(titled Burnett et al.v.7a1eri er al.)in the Montana District Court for Rosebud County against Tolen,PSE,Paei6Corp,PGE,
Avista Corp.,NorthWestem,and Westmoreland Rosebud Mining.The plaintiffs allege a failure to contain coal dust in connection with the operation ofColstrip,and seek unspecified
damages.The Colstrip owners reached a settlement with one ofthe litigants,Richard Bumett,loran amount ofless than 50.1 million.The settlement does not involve or implicate the
claims ofany other litigants.The Company will vigorously defend itselfin the litigation,but at this time is unable to predict the outcome,nor an amount orrange ofpotential impact
in the event ofan outcome adverse to the Company's interests.
Westmoreland Mine Permits
Two lawsuits have been commenced by the Montana Environmental Information Center and others,challenging certain permits relating to the operation ofthe Westmoreland
Rosebud Mine,which provides coal to Colstrip.In the first,the Montana District Court for Rosebud County issued an order vacating a permit for one area ofthe mine,which decision
was subsequently upheld by the Montana Supreme Court.In the second,the Montana Federal District Court vacated a decision by the federal Office of Surface Mining Reclamation
and Enforcement,a branch ofthe United States Department ofthe Interior;approving expansion ofthe mine into a new area,pending furtheranalysis ofpotential environmental
impact.An initial appeal ofthat decision to the Ninth Circuit was dismissed forleck ofjurisdiction,pending further proceedings before the Department ofthe Interior.Avista Corp.is
not a party to either ofthese proceedings,but continues to monitor the progress ofboth issues and assess the impact,ifany,ofthe proceedings on Westmoreland's ability to meet its
contractual coal supply obligations.
Rathdrum,Idaho Natural Gas Incident
In October 2021,there was an incident in Rathdrum,Idaho involving the Company's natural gas infrastructure.The incident occurred after a third party damaged those facilities
during excavation work.The incident resulted in a fire which destroyed one residence and resulted in minor injuries to the occupants.In January 2023,the Company was served with a
lawsuit filed in the District Court of Kootenai County,Idaho by one property owner;seeking unspecified dtlttt cL In February 2024,the Company received a second lawsuit filed by
the owners ofthe adjacent property,seeking damages forpersonal injury and emotional distress from having witnessed the incident.The Company will vigorously defend itselfin the
legal proceedings;however,at this time the Company is unable to predict the likelihood ofan adverse outcome or estimate a range ofpotential loss in the event ofsuch an outcome.
Complaint of Consumers for Independent Regional Transmission Planning for All FERC�furisdietional Transmission Facilities at 100kV and Ahave
In December 2024,the Company received notice ofa complaint fled with the FERC by Consumers for independent Regional Transmission Planning against all FERC-jurisdictional
Transmission providers with local planning tariffs utilizing facilities at 100 kV and above,which includes the Company.The complaint alleges that the local transmission planning
process allows individual transmission owners to plan FERC jurisdictional transmission facilities without regard to whether that planning is the more efficient or cost-effective project
for the interconnected grid and cost effective for customers.The Company intends to vigorously defend itselfin this action;however,at this time the Company is unable to predict the
likelihood ofan adverse outcome or estimate a range ofpotential loss in the event ofsuch an outcome.
Other Contingencies
In the normal course ofbusiness,the Company has various other legal claims and contingent matters outstanding.The Company believes any ultimate liability arising from these
actions will not have a material impact on its financial condition,results ofoperations or cash flows.It is possible a change could occur in the Company's estimates ofthe probability
oramount ofa liability being incurred.Such a change,should it occur,could be significant.
The Company routinely assesses,based on studies,expert analysis and legal reviews,its contingencies,obligations and commitments forremediation ofcontaminated sites,including
assessments ofranges and probabilities ofrecoveries from other responsible parties who eitherhave orhave not agreed to a settlement as well as recoveries from insurance tamers.The
Company's policy is to accrue and charge to current expense identified exposures related to environmental remediation sites based on estimates ofinvestigation,cleanup and
monitoring costs to be incurred.
The Company has potential liabilities under the Endangered Species Act and similar state statutes for species offish,plants and wildlife that have eitheralready been added to the
endangered species list,listed as"threatened"orpetitioned forlisting.Thus far,measures adopted and implemented have had minimal impact on the Company.However;the Company
will continue to seek recovery,through the ratemaking process,of all operating and capitalized costs related to these issues.
Under the federal licenses forits hydroelectric projects,the Company is obligated to protect its property rights,including water rights.In addition,the Company holds additional non-
hydro waterrights.The States of Montana and Idaho are each conducting general adjudications ofwater rights in areas that include the Company's facilities in these states.Claims
within the Clark Fork River basin and the Spokane Riverbasin could adversely affect the energy production of the Company's hydroelectric facilities.The Company is and will
continue to be a participant in the adjudication processes.The complexity ofsuch adjudications makes each unlikely to be concluded in the foreseeable future.As such,it is not
possible for the Company to estimate the impact ofany outcome at this time.The Company Ail]continue to seek recovery,through the ratemaking process,of all costs related to this
issue.
NOTE 16.REGULATORYMATTERS
Power Cost Deferrals and Recovery Mechanisms
Deferred power supply costs are recorded as a deferred charge or liability on the Balance Sheets for future prudence review and recovery or rebate through retail rates.The power
supply costs deferred include certain differences between actual net power supply costs incurred by Avista Corp.and the costs included in base retail rates.This difference in net power
supply costs primarily results from changes in:
short-temi wholesale market prices and sales and purchase volumes,
the level,availability and optimization ofhydroelectric generation,
the level and availability ofthermal generation(including changes in fuel prices),
retail loads,and
sales of surplus transmission capacity.
In Washington,the ERM allows Avista Corp.to periodically increase or decrease electric rates Aith WUTC approval to reflect changes in power supply costs.The ERM is an
accounting method used to track certain differences between actual power supply costs,net of wholesale sales and sales of fuel,and the amount included in base retail rates for
Washington customers.Under the ERM,the Company defers these differences(over the$4 million deadband and sharing bands)for future surcharge or rebate to customers.
The following is a summary ofthe ERM:
Deferred for
Future
Surcharge or Expense or
Rebate Benefit
Annual Power Supply Cog Wriability to Customers to the Company
within+/-$0 to$4 million(deadband) 00/ 100%
higher by$4 million to S10 million 50% 50%
lowerby$4 million to$10 million 75% 25%
higher or lower by over$10 million 90% 10%
Total net deferred power costs under the ERM were assets of$36 million as of December 31,2024 and$38 million as of December 31,2023.The deferred power cost assets represent
amounts due from customers,and deferred power cost liabilities represent amounts due to customers.
Pursuant to WUTC requirements,should the cumulative deferral balance exceed$30 million in the rebate or surcharge direction,the Company must make a filing with the WUTC to
adjust eustomermles to eilherretum the balance to customers orrecover/he balance from customers.Avista Corp.makes an annual filing on,orbefore,April 1 ofeach year to provide
the opportunity for the WUTC staffand other interested panics to review the prudence of,and audit,the ERM deferred powercost transactions for the prior calendaryean In June
2023.the Company received approval from the WUTC fora rate surcharge to customers over a two-year period,effective July 1,2023.
Avista Corp.has a PCAmechanism in Idaho allowing for the modification ofelectric rates on October 1 ofeach yearwith IPUC approval.Under the PCAmechanism,Avista Corp.
defers 90 percent ofthe difference between certain actual net powersupply expenses and the amount included in base retail rates for its Idaho customers.The October 1 rate
adjustments recoverorrobate power costs deferred during the preceding July-June twelve-month period.Total net power supply costs deferred underthe PCAmechanism were
liabilities of$15 million as of December 31,2024 and assets of$8 million as of December 31,2023.Deferred power cost assets represent amounts due from customers and liabilities
represent amounts due to customers.
Natural Gas Cost Deferrals and Recovery Mechanisms
Avista Corp.files a PGA in all three states it serves to adjust natural gas rates for.1)estimated commodity and pipeline transportation costs to serve natural gas customers for the

coming year,and 2)the difference between actual and estimated commodity and transportation costs for the prior year.In Oregon,the Company absorbs(cost or benefit)10 percent of
the difference between actual and projected natural gas costs included in base retail rates for supply that is not hedged.Total net deferred natural gas costs were a liability of$25
million as of December 31,2024 and an asset of$52 million as of December 31,2023.Asset balances represent amounts due from customers and liabilities represent amounts due to
customers.
Decoupling and Earnings Sharing Mechanisms
Decoupling(also known as an FCAin Idaho)is a mechanism designed to sever the link between a utility's revenues and consumers'energy usage.In each ofAvista Corp:s
jurisdictions,Avista Corp.'s electric and natural gas revenues are adjusted so as to be based on the numberofeustomers in certain customer rate classes and assumed"normal"kilowatt
hour and themt sales,rather than being based on actual kilowatt hour and therm sales.The difference between revenues based on the number of customers and"normal"sales and
revenues based on actual usage is deferred and either surcharged or rebated to customers beginning in the following year.Only residential and certain commercial customer classes are
included in decoupling mechanisms.
Washington Decoupling and Earnings Sharing
In Washington,the WUTC approved the Company's decoupling mechanisms for electric and natural gas through December2026.
Electric and natural gas decoupling surcharge rate adjustments to customers are limited to a 3 percent increase on an annual basis,with remaining surcharge balance carried forward for
recovery in a future period.There is no limit on the level ofrebate rate adjustments.New customers added after a test period are not decoupled until included in a future test period.
The decoupling mechanisms each include an after-the-fact earnings test.At the end ofeach calendaryear,separate electric and natural gas earnings calculations are made forthe
calendar yearjust ended.These earnings tests reflect actual decoupled revenues,normalized power supply costs and other normalizing adjustments.Through the 2022 general rate
taus,the Company modified its earnings test so that if the Company cams more than 0.5 percent higher than the rate ofretum authorized by the WUTC in the multi-yearrate plan,the
Company would defer these excess revenues and laterretum them to customers.
Idaho FCA and Earnings Sharing Mechanisms
In Idaho,the IPUC approved the implementation ofFCAs for electric and natural gas through March 31,2025.Apending application would extend the mechanism through August
31,2029.
Oregon Decoupling Mechanism
In Oregon,the Company has a decoupling mechanism for natural gas.An earnings review is conducted on an annual basis.In the annual earnings review,ifthe Company cams more
than 100 basis points above its allowed return on equity,one-third ofthe earnings above the 100 basis points would be deferred and later retumed to customers.The earnings review is
separate from the decoupling mechanism and was in place prior to decoupling.
Cumulative Decoupling and Earnings Sharing Mechanism Balances
As of December 31,2024 and December 31,2023,the Company had the following cumulative balances outstanding related to decoupling and earnings sharing mechanisms in its
various jurisdictions(dollars in millions):
December 31, December 31,
2024 2023
Washington
Decoupling surcharge(rebate) $ 18 $ (3)
Idaho
Decoupling surcharge(rebate) $ 1 $ (8)
Provision for earnings sharing rebate — (1)
Oregon
Decoupling surcharge(rebate) $ 1 $ (4)
NOTE 17.NOTES RECEIVABLE FROM ASSOCIATED COMPANIES
Avista Capital may borrow up to$80 million from Avista Corp.to cover subsidiary cash needs in accordance with board-approved limits.Avista Capital pays interest on the
outstanding amount at a rate at least equal to the Alternate Base Rate as defined in the Avista Corp.credit facility agreement,which is estimated at the Prime rate.This rate will be reset
when the Agent bank on the Avista Corp.credit facility agreement changes the Prime rate orthe margin.
As of December 31,2024,the Company had a note receivable balance from Avista Capital of$29 million with an applicable interest rate of7.5 percent.
FERC FORM No.2(REV 12-07)
Page 122.1

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Summary of Utility Plant and Accumulated Provisions for Depreciation,Amortization and Depletion
- - - - _
Total Company For
Use Current Elegy G >3!as A ptscify) Common
1 UTILITY PLANT
2 In Service
3 Plant in Service(Classified) 8.137,295,369 5,594,245,021 1,776,159,609 766,890,739
4 Property Under Capital Leases 65,812,604 65.812,604
5 Plant Purchased or Sold
6 Completed Construction not
Classified
7 Experimental Plant Unclassified
8 TORTA)Utility Plant(Total of lines 3 8,203,107,973 5,594,245,021 1,776,159,609 832,703,343
9 Leased to Others
10 Held for Future Use 9,399,810 8,669,209 180,896 549,705
11 Construction Work in Progress 206,589,639 184,887,514 5,603,100 16,099,025
12 Acquisition Adjustments 251,184 251,184
13 TOTAL Utility Plant(Total of lines 8 8,419,348,606 5,788,052,928 1,781,943,605 849,352,073
thru 12)
Accumulated Provisions for
14 Depreciation,Amortization,& 2,959,941,113 2,086,904,096 547,115,726 325,921,291
Depletion
15 Net
Utility Plant(Total of lines 13 and 5,459,407,493 j3,701, 8,832 1,234,827.879 523,430,782
14)
DETAIL OF ACCUMULATED
16 PROVISIONS FOR
DEPRECIATION,AMORTIZATION
AND DEPLETION
17 In Service:
18 Depreciation 2,717,635,837 2,038,316,809 545,577,268 133,741,760
Amortization and Depletion of
19 Producing Natural Gas Land and
Land Rights
20 Amortization of Underground
Storage Land and Land Rights
21 Amortization of Other Utility Plant 242,305,276 48,587,287 1,538,458 192,179,531
22 TOTAL In Service(Total of lines 18 2,959,941,113 2,086,904,096 547,115,726 325,921,291
thru 21)
23 Leased to Others
24 Depreciation
25 Amortization and Depletion
26 TOTAL Leased to Others(Total of
lines 24 and 25)
27 Held for Future Use
28 Depreciation
29 Amortization
FERC FORM No.2(12-96)
Page 200

Summary of Utility Plant and Accumulated Provisions for Depreciation,Amortization and Depletion
Total Company For
Line Item the Current Electric Gas Other(Specify) Common
No. (a) QUarter[Year (c) (d) (e) (f)
(b)
30 TOTAL Held for Future Use(Total of
lines 28 and 29)
31 Abandonment of Leases(Natural
Gas)
32 Amortization of Plant Acquisition
Adjustment
TOTAL Accum.Provisions(Should
33 agree with line 14 above)(Total of 2,959,941,113 2,086,904,096 547,115,726 325,921,291
lines 22,26,30,31,and 32)
FERC FORM No.2(12-96)
Page 200

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Gas Plant in Service(Accounts 101,102,103,and 106)
Line Account Balance at Additions Retirements Adjustments Transfers Balance at End
No. (a) Beginning of Year (c) (d) (a) (f) of Year
(g)
1 INTANGIBLE PLANT
2 301Organization
3 302 Franchise and Consents
4 303 MiscellaneouslntangiblePlant 4,082,783 52,280 53,811 4,081,252
5 Total Intangible Plant(Total of lines 4,082,783 52,280 53,811 4,081,252
2 thru 4)
6 PRODUCTION PLANT
7 Natural Gas Production and
Gathering Plant
8 325.1 Producing Lands
9 325.2 Producing Leaseholds
10 325.3 Gas Rights
11 325A Rights-of-Way
12 325.5 Other Land and Land Rights
13 326 Gas Well Structures
14 327 Field Compressor Station
Structures
15 328 Field Measuring and
Regulating Station Structures
16 329 Other Structures
17 330 Producing Gas Wells-Well
Construction
18 331 Producing Gas Wells-Well
Equipment
19 332 Field Lines
20 333 Field Compressor Station
Equipment
21 334 Field Measuring and
Regulating Station Equipment
22 335 Drilling and Cleaning
Equipment
23 336 Purification Equipment 0
24 337 Other Equipment
25 338 Unsuccessful Exploration and
Development Costs
339 Asset Retirement Costs for
26 Natural Gas Production and
Gathering Plant
27 Total Production and Gathering 0
Plant(Total of lines 8 thru 26)
28 PRODUCTS EXTRACTION
PLANT
�29 340 Land and Land Rights
FERC FORM No.2(12-96)
Page 204

Gas Plant in Service(Accounts 101,102,103,and 106)
Balanco at Balance at End
Line Account Additions Retirements Adjustments Transfers of Year
No. (a) Beginning (c) (d) (e) (f)
30 341 Structures and Improvements
342 Extraction and Refining
31 Equipment
32 343 Pipe Lines
33 344 Extracted Products Storage
Equipment
34 345 Compressor Equipment
35 346 Gas Measuring and
Regulating Equipment
36 347 Other equipment
37 348 Asset Retirement Costs for
Products Extraction Plant
38 Total Products Extraction Plant
(Total of lines 29 thru 37)
39 Total Natural Gas Production Plant 0
(Total of lines 27 and 38)
Manufactured Gas Production
40 Plant(Submit supplementary 59,924 59,924
information in a footnote)
41 Total Production Plant(Total of 59,924 0 59,924
lines 39 and 40)
42 NATURAL GAS STORAGE AND
PROCESSING PLANT
43 Underground storage plant
44 350.1 Land 1,313,516 240,467 1,553,983
45 350.2 Rights-of--Way 66,742 66,742
46 351 Structures and Improvements 3,423,118 483,738 3,906,856
47 352 Wells 19,777,733 483,737 20.261,470
48 352.1 Storage Leaseholds and
Rights
49 352.2 Reservoirs 1,667.492 1,667.492
50 352.3
s.3 Non-recoverable Natural 5,810,311 5,810,311
51 353 Lines 2,229,534 2,229,534
52 354 Compressor Station 19,041,089 483,738 19,524,827
Equipment
53 355 Measuring and Regulating 2,565,405 483,738 3,049,143
Equipment
54 356 Purification Equipment 560,248 560,248
55 357 Other Equipment 3,556,857 483,737 4,040,594
56 358 Asset Retirement Costs for
Underground Storage Plant
57 Total Underground Storage Plant 60,012,045 2,659,155 62,671,200
(Total of lines 44 thru 56)
58 Other Storage Plant
59 360 Land and Land Rights
FERC FORM No.2(12-96)
Page 204

Gas Plant in Service(Accounts 101,102,103,and 106)
"d , Retirements Adjustments Transfers Balance at End'
(d) (e) of year
ME (9)
60 361 Structures and Improvements
61 362 Gas Holders
62 363 Purification Equipment
63 363.1 Liquefaction Equipment
64 363.2 Vaporizing Equipment
65 363.3 Compressor Equipment
363.4 Measuring and Regulating
66 Equipment
67 363.5 Other Equipment
68 363.6 Asset Retirement Costs for
Other Storage Plant
69 Total Other Storage Plant(Total of
lines 58 thru 68)
70 Base Load Liquefied Natural Gas
Tenninaling and Processing Plant
71 364.1 Land and Land Rights
72 364.2 Structures and
Improvements
73 364.3 LNG Processing Terminal
Equipment
74 364.4 LNG Transportation
Equipment
75 364.5 Measuring and Regulating
Equipment
76 364.6 Compressor Station
Equipment
77 364.7 Communications Equipment
78 364.8 Other Equipment
79 364.9 Asset Retirement Costs for
Base Load Liquefied Natural Gas
Total Base Load Liquified Natural
80 Gas,Terminating and Processing
Plant(Total of lines 71 thru 79)
Total Nafl Gas Storage and
81 Processing Plant(Total of lines 57, 60,012,045 2,659,155 62,671,200
69,and 80)
82 TRANSMISSION PLANT
83 365.1 Land and Land Rights
84 365 2 Rights-of-Way
85 366 Structures and Improvements
86 367 Mains
87 368 Compressor Station
Equipment
88 369 Measuring and Regulating
Station Equipment
89 370 Communication Equipment
FERC FORM No.2(12-96)
Page 204

Gas Plant in Service(Accounts 101,102,103,and 106)
B&atance at Add(tiuns R�:tiramonts Adj i unonts Transk•Ts Baianco at Eno
Beginning of Year (c) ( ) of Year
(b) (g)
90 371 Other Equipment
91 372 Asset Retirement Costs for
Transmission Plant
92 Total Transmission Plant(Total of
line 81 thru 91)
93 DISTRIBUTION PLANT
94 374 Land and Land Rights 1,699,421 66,281 1,765,702
95 375 Structures and Improvements 2,376,694 146,722 13,961 2,509,455
96 376 Mains 812,692,887 44,377,630 537,575 856,532,942
97 377 Compressor Station
Equipment
98 378 Measuring and Regulating 14,581,168 260,312 77,198 14,764,282
Station Equipment-General
379 Measuring and Regulating
99 Station Equipment-City Gate 10,398,548 2,264,772 75,212 12,588,108
100 380 Services 505,275,682 23,185,548 228,436 528,232,794
101 381 Meters 193,042,710 17,365,696 2,932.103 207,476,303
102 382 Meter Installations
103 383 House Regulators
104 384 House Regulator Installations
105 385 Industrial Measuring and 6,913,457 436,938 81.183 7,269,212
Regulating Station Equipment
106 386 Other Property on Customers'
Premises
107 387 Other Equipment 601 601
108 388 Asset Retirement Costs for
Distribution Plant
109 Total Distribution Plant(Total of 1,546,981,168 88,103,899 3,945,668 1,631,139,399
lines 94 thru 108)
110 GENERALPLANT
111 389 Land and Land Rights 3,916,534 3,916,534
112 390 Structures and Improvements 29,508,518 1,814,596 78,968 31,244,146
113 391 Office Furniture and 415,897 229,503 186,394
Equipment
114 392 Transportation Equipment 20,937,531 2,965,421 834,844 42,691 23,110,799
115 393 Stores Equipment 243,144 39,805 8,500 274,449
116 394 Tools,Shop,and Garage 11,067,366 766,748 119,556 11,714,558
Equipment
117 395 Laboratory Equipment 456,354 456,354
118 396 Power Operated Equipment 4,298,891 1,105,014 134,995 5,268,910
119 397 Communication Equipment 1,874,962 182,736 31,989 2,025,709
120 398 Miscellaneous Equipment 9,981 9,981
121 S20btotal(Total of lines 111 thru 72,729,178 6,874,320 1,438,355 42,691 78,207,834
FERC FORM No.2(12-96)
Page 204

Gas Plant in Service(Accounts 101,102,103,and 106)
Balanco at Balance at
Line Account Additions Retirements Adjustments Transfers
No. Beginning of Year of Year
(0) (b) l�) (d) (e) (� (g)
122 399 Other Tangible Property
123 399.1 Asset Retirement Costs for
General Plant
124 Total General Plant(Total of lines 72,729,178 6.874,320 1,438,355 42,691 78,207,834
121,122,and 123)
125 Total(Accounts 101 and 106) 1,683,865,098 97,689,654 5,437,834 42,691 1,776,159,609
126 Gas Plant Purchased(See
Instruction 8)
127 (Less)Gas Plant Sold(See
Instruction 8)
128 Experimental gas plant
unclassified
129 Total Gas Plant In Service(Total of 1,683,865,098 97,689,654 5,437,834 42,691 1,776,159,609
lines 125 thru 128)
FERC FORM No.2(12-96)
Page 204

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)El AResubmission
Gas Plant Held for Future Use(Account 105)
ate
tine Description and Location of Properly O�ig riaffyfncfnded In this 6iia Expected to be Used in Balance at End of Year
No. (a) Account Utility Service (d1
(b) (c) —
1 Gas Distribution Mains and Services,Spokane,WA 03/01/2000 12/31/2026 180,896
45 Total 180,896
FERC FORM No.2(12-96)
Page 214

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Construction Work in Progress-Gas(Account 107)
Line Description of Project Construction work in progress•Gas
P j (Account 107) Estimated Additional Cost of Project
No. (a) (b) (c)
1 Gas Reinforce-Minor Blanket 1,589,225 2,095,000
2 Gas Revenue Blanket 1,402,881 2,777,969
3 Minor Projects under$1,000,000 2,610,994 7,719,505
45 TOTAL 5,603.100 12,592,474
FERC FORM No.2(12-96)
Page 216

report is:
Name of Respondent: (1)sr This repo po Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)❑A Resubmission
General Description of Construction Overhead Procedure
Capitalization Cost Rate
Line Title Amount Entity Name Ration Percentage
Rate Indicator
en
(a) (b) (c) (percent) en (fl
(d)
1.Components of Formula(Derived from actual book balances and actual cost rates):
(1)Average Short-Term Debt 205,442,000
s
(2)Short-Term Interest 6.5%
D 48.5626984 d
(3)Long-Term Debt 2,500,000,000 % 4.98%
(4)Preferred Stock P 0% P
(5)Common Equity c 2,442,542,115 47A5% 0 9.4%
(6)Total Capitaization 5,147,984,115 96%
(7)Average Construction Work in w -
Progress Balance 205,442,000
2.Gross Rate for Borrowed Funds s(S/W)+d[(D!(D+P+C))(1-(S/W))] 6.5%
3.Rate for Other Funds[1-(S/W)][p(P/(D+P+C))+c(C/(D+P+C))]- 0%
.Weighted Average Rate Actually Used for the Year:
(a)Rate for Borrowed Funds- 6.5%
(b)Rate for Other Funds- 0
FERC FORM No.2(REV 12-07)
Page 218

This report is:
Name of Respondent: (1)V An Original Date of Report: Year/Period of Report:
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
Accumulated Provision for Depreciation of Gas Utility Plant(Account 108)
Line -T-- Item' Total(c+d+e) Gas Plant in Service Gas Plant held for Future Gas Plant Leased to
No. (a) (b) (c) Use Others
(d) (e)
Section A.BALANCES AND CHANGES
DURING YEAR
1 Balance Beginning of Year 512,558,995 512,558,995 0 0
2 Depreciation Provisions for Year,Charged
to
3 (403)Depreciation Expense 46,053,841 46,053,841
4 (403.1)Depreciation Expense for Asset 0
Retirement Costs
5 (413)Expense of Gas Plant Leased to
Others
6 Transportation Expenses-Clearing 739,468 739,468
7 Other Clearing Accounts
8 Other Clearing(Specify)(footnote details):
9.1
9.2
9.3
9.4
9.5
10 TOTAL Deprec.Prov.for Year(Total of 46,793,309 46,793,309 0 0
lines 3 thru 8)
11 Net Charges for Plant Retired:
12 Book Cost of Plant Retired (5,384,023) (5,384,023)
13 Cost of Removal 0 0
14 Salvage(Credit) 425,037 425,037
15 TOTAL Net Chrgs for Plant Ret.(Total of
lines 12 thru 14) (4,958,986) (4,958,986) 0 0
16 Other Debit or Credit Items(Describe in
footnote details)
17.1 RWIP (2,036,972) (2,036,972)
17.2 DJ 105 APx Accrual 5,219 5,219
17.3 TransferAmount (25,904) (25,904)
17.4 GL Depreciation for Common Allocated (6,758,393) (6,758,393)
18 Book Cost of Asset Retirement Costs
19 Balance End of Year(Total of lines 1,10,15,16 and 18) 545,577,268 545,577,268 0 0
Section B.BALANCES AT END OF YEAR
ACCORDING TO FUNCTIONAL
CLASSIFICATIONS
21 Productions-Manufactured Gas
22 Production and Gathering-Natural Gas
23 Products Extraction-Natural Gas
FERC FORM No.2(12-96)
Page 219

Accumulated Provision for Depreciation of Gas Utility Plant(Account 108)
Line ftem Total(c+d+e) Gas Plant In Service Gas Plant held for Future Gas Plant Luasud to
Use Others
No. (a) (b) (c)
24 Underground Gas Storage 22,684,769 22,684,769
25 Other Storage Plant
26 Base Load LNG Terminaling and
Processing Plant
27 Transmission
28 Distribution 492,606,353 492,606,353
29 General 30,286,146 30,286,146
30 TOTAL(Total of lines 21 thru 29) 545,577,268 545,577,268 0 0
FERC FORM No.2(12-96)
Page 219

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
Gas Stored(Accounts 117.1,117.2,117.3,117A,164.1,164.2,and 164.3)
Line Descri Lion Noncurrent p (Account 117.1) (Account 117.2) (Account 117.4)
No. (a) (b) (c) 1 7 ) (e)
1 Balance at Beginning of Year 6,992,076 0 0 0
2 Gas Delivered to Storage
3 Gas Withdrawn from Storage
4 Other Debits and Credits
5 Balance at End of Year 6,992,076 0 0 0
6 Dth 1,253.060
7 Amount Per Dth 5.58
FERC FORM No.2(REV 04-04)
Page 220

Gas Stored(Accounts 117.1,117.2,117.3,117.4,164.1,164.2,and 164.3)
Line Current(Account 164.1) LNG(Account 164.2) LNG(Account 164.3) Total
No. (g) (h) (i)
1 -16,271,620 0 23,263,696
2 7,785,790 7,785,790
3 13,798,600 13,798,600
4
5 10,258,810 0 17,250,886
6 7,825,035 9,078,095
7 1.31 1•9
FERC FORM No.2(REV 04-04)
Page 220

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
FOOTNOTE DATA
La)Concept:GasStoredCurrent
Fuel is accounted for within injections and withdrawal accounts.
All gas reported is currentworking gas.Avista uses the inveniory method to report all working gas stored.
FERC FORM No.2(REV 04-04)
Page 220

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of.2024/Q4
(2)El A Resubmission
Investments(Account 123,124,and 136)
Saft C04 Cost at
Beginning of End of Year(If
Yoar(If book book cost is
cost is different different from Gain or
from cost to Purchases or Sales or No.of cost to Loss from
Description of Date Date Additions other PrtncipalShares Revenues
Line respondent respondent, Investment
Investment Acquired Matured During the Dispositions Amount at End for Year
No. (a) (c) (d) Year During Year (h) of Year (k)(b) give cost to give cost to Disposed
roSpondent in a �_ respondent in of
footnote and (f) (g) () a footnote (0
explain and explain
difference) differonce)
1 InvestmentCapita 11,547,000 7
11,547,000
Avista Capital II
Total Investment J6
2 in Associated 11,547,000 0 0 11,547,000 0 0
Companies
Other Investment-
1 Coli Cash 40,758,010 3,997,488 44,755,498
Valuation
2 Other Investment- (40,758,010) 3,997,488 (44,755,498)
Coli Borrowings
3 Otherinvestment- 14,094 a
WZN Loans
4 Total Other 14.094 3,997,488 3,997,488
Investments
jj
1 Temporary Cash 15,991,036 3,926,203 Investments2 Total Temporary 15,991,0360
Cash Investments
4 Total lnvestments
FERC FORM No.2(12-96)
Page 222

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2) A Resubmission
04/18/2025 End of:2024/Q4
❑
Investments in Subsidiary Companies(Account 123.1)
Gain or
Amount of Equity in Revenues Amountof Loss from for Year
Line Description of Investment Date Acquired Date of Maturity In at Subsidiary Investment at Investment
No. (a) (b) (c) Beginning of Year eamingsforYear (f) End of Year Disposed
(d) (e) (9) of
(h)
1 Investment in Avista Capital 256,138,971 256,138,971
2 Investment in AERC 89,816,380 89,816,380
3 AERC-Equity in 29,809,944 8,253,337 5,000,000 33,063,281
Earnings
4 Avista Capital-Equity in
Earnings (110,554,654) (6,721,766) (117,276,420)
40 TOTAL Cost of Account Total 123.1$ 265,210,641 1,531,571 5,000,000 261,742,212
FERC FORM No.2(12-96)
Page 224

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)El A Resubmission
Prepayments(Acct 165),Extraordinary Property Losses(Acct 182.1),Unrecovered Plant and Regulatory Study Costs(Acct 182.2)
Line No. (a) (b)
PREPAYMENTS(ACCOUNT 165)
1 Prepaid Insurance 975,396
2 Prepaid Rents 4,824
3 Prepaid Taxes 4,001,236
4 Prepaid Interest
5 Miscellaneous Prepayments 24,800,070
6 TOTAL 29,781,526
FERC FORM No.2(12-96)
Page 230a

This report is:
Name of Respondent: (1)0 An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Other Regulatory Assets(Account 182.3)
Description and Purpose of Other Balance at Beginning
Line Regulatory Assets Amortization Period Regulatory Citation Current Quarter/Year Debits
No. (a) (b) (c) (d) (e)
u
1 WA Excess Nat Gas Line Extension 2,583,244 0
Allowance
2 Reg Asset Post Ret Liabilility 112,462,393 1,008,986
L0
3 Regulatory Asset FAS 109 Utility 78,172,454 638,386
Plant
u
4 Regulatory Asset FAS 109 DSIT 2,681,673 399,532
Non Plant
u
5 Regulatory Asset Lake CDA
36,692,352 0
Settlement-Varies
Ln
6 Reg Assets-Decoupling Surcharges 2,435,722 29,867,538
is
7 Reg Asset-Colstrip 19,428,968 7,424,361
u
8 Regulatory Asset FAS 143 Asset 2,298,569 139.782
Retirement Obligation
u
9
Regulatory Asset Workers Comp 1,930,165 535.342
m
10 Interest Rate Swap Asset 179,488,399 74,909
u
11 DSM Asset 10,257,486 31,617,768
f➢
12 Deferred ITC 3,602,106 13
13 Regulatory Asset MDM System 29,345,159 0
L^
14 Regulatory Asset BPA Residential 1,550,215 1,311,195
Exchange
u
15 Regulatory Asset FISERV 170,311 0
im
16 Regulatory Asset AFUDC(PIS,WIP) 59,066,092 39,475,508
&Equity DFIT
17 Regulatory Asset ID PCA Deferral 7,627,491 0
Ll�
18 Existing Meters/ERTS Retirement
17,635,170 0
Def
u
19 Regulatory Asset Colstrip
750,000 0
Community Fund
u
20 Regulatory Asset COVID-19 657,789 280,301
lll
21 Regulatory Asset Energy Imbalance 582,599 0
Market
u
22 Regulatory Asset-Wildfire
23,737,455 8,506,283
Resiliency&Balancing
L
23 Deferral for CS2&Colstrip(O&M, 2,018,257 3,250,141
Excess Depr)
FERC FORM No.2(REV 12-07)
Page 232

Other Regulatory Assets(Account 182.3)
Balance atBeginIOng
Amortization Period Regulatory Citation CntQuertere�r Debits:
(b) (c) (d) e
u
Regulatory Asset Tax Basis Flow
24 through 145,169,206 7,349,256
25 Regulatory Asset Commodity MTM 69,139,449 177,234,474
ST&LT
26 Regulatory Asset Energy 1,301,000 264,081
Affordability Act
u
27 Reg Asset-Insurance Balancing 288,789 11,461,312
Acct
28
594,833 609,466
Reg Asset-Energy Efficiency
29
1,915,416 2,212,454
Deferred Regulatory Fees
30 Regulatory Asset Pension 10,841,956 0
Settlement Deferral
31
Reg Asset-CCA 46,022,329 33,285,653
32 WA ERM Deferral 25,478,297 17,504,772
33
1,613,960 51,076
Reg Asset-MT Riverbed Escrow Int
34 cm 511,800 0
Reg Asset-Depreciation
35
Reg Asset-PPA Interest Deferral 0 383,630
u
36 0 2,926,457
Reg Liab-Tax Customer Credit
37
Misc Reg Asset 141,003 185,974
40 TOTAL 398,192,107 377,998,650
FERC FORM No.2(REV 12-07)
Page 232

Other Regulatory Assets(Account 182.3)
Written off DuringLine Written off During Period Amount Written off During Period Amount
o. Quarte Charged r/Year
ed Account Recovered Deemed Unrecoverable Balance at End of Current QuarterlYear
N
No. (� (g) (h) (i)
1 407 1,550,391 1,032,853 f
2 228 11,386,178 102,085,201
3 283 5,280,347 73,530,493
4 283 724,394 2,356,811
5 407 1,116,805 35,575,547
6 456,495 25,632,120 6,671,140
7 407 1,547,703 25,305,626
8 0 2,438,351
9 242 560,236 1,905,271
10 242 7,230,381 172,332,927
11 0 41,875,254
12 283,410 102,352 3,499,767
13 407 3,035,706 26,309,453
14 407 2,449,182 412,228
15 407 170,311 0
16 Various 38,914,609 59,626,991
17 557 7,627,491 0
18 407 1,824,328 15,810.842
19 407 750,000 0
20 407 674,974 263,116
21 407 349.559 233,040
22 407 9,768,051 22,475,687
23 407 1,397,496 3,870,902
24 282,283 2,870,669 149,647,793
25 244,175 205,809,844 40,564,079
26 182 1,565,081 0
27 407 681,480 11,068,621
28 242 778,348 425,951
29 407 86,100 4,041,770
30 407 985,632 9,856,324
31 407 29,660,212 49,647,770
32 557 17,607,876 25,375,193
33 0 1,665,036
34 407 511,800 0
35 0 383,630
36 0 2,926,457
37 407 129,522 197,455
40 382,779,178 0 893,411,579
FERC FORM No.2(REV 12-07)
Page 232

FOOTNOTE DATA
La)Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Residential Schedule 101 customers who receive a natural gas line extension 85 part of conversion to natural gas from another fuel source.Amort fora period of 3 years on the excess
allowance exceeding the cost ofthe line extension.
Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Recognition ofthe overfunded and underfunded status of a defined benefit post retirement plan based on ASC 715 for financial reporting,
Lc)Concept:DescdpbonAndPurposeOfOtherRegulatoryAssets
Deferted lax flow through balance on utility plant.Amortization occurs over book life ofrespective utility plant assets.
U Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Deferred tax flow through balance on utility planL Amortization occurs overbook life of respective utility plant assets.
Ue Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
WA Docket UE-080416,ID Order AVU-E-08-01.Amortization thru 2059.
ko Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
eeoupling revenue deferrals are recognized during the period they occur,subject to certain limitations.Revenue is expected to be collected within 24 months ofthe deferral.
1q1 Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
For WA Elec,amort period is 33.75yrs as per Order 09,dockets UE-190334,UG-190335,UE-190222(Consolidated).For ID Elec,amort is for 34.75yrs as per Order 34276,AVU-E-
18-03,Amor ends in 2054 for both jurisdictions.
U Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Reg assets related to deferred ARO expenses for Kettle Falls and Coyote Springs thermal plants.The expenses will not be collected from customers until actual work is performed.
1i1 Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Quarterly adjustments to workers comp reserve for current unpaid claims.
Concept:DescdpbonAndPurposeOfOtherRegulatoryAssets
Settled swaps are amortized over the life ofthe associated debt.
Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Amortization period varies depending on timing of transactions.
LI)Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Amortization period varies depending on underlying transactions.
(m)Concept:DescriptionAndPurposeOfOtherRegulatoryAssets
A Docket Nos UE-180418,UG-180419.
(n)Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Avista is a participant in the Residential Exchange Program with Bonneville Power Administration.Customers served under Schedules 1,12,22,32,and 48 are given a rate adjustment
based on Schedule 59 for WA and Id.Amort is based on customer usage.
U Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
iD Order No 33494,Docket Nos.AVU-E-16-01 and Stipulation and Settlement Docket No AVU-E-19-04.
W Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Deferring the difference between FERC formula and State approved AFUDC rates from 2010 to present.
Concept:Descr ptionAndPurposeOfOtherRegulatoryAssets
WA Docket No UE-002066 and M Order No 28648.
jr)Concept:DescriptionAndPurposeOfOtherRegulatoryAssets
WA Order 09 in Dockets UE-190334,UE-190222.Deferral of customer portion for future rate recovery.The funds are set aside to help the Colstrip community transition away from
economic activity related to coal-fired generation.
Lsj Concept:DescrtptionAndPurposeOfOtherRegulatoryAssets
Deferral of COVID-19 costs as per ID PUC Order No 34718,OR PUC Order No 20401,Docket UM 2069 and WA UTC Order No.01,Dockets UE-200407 and UG-200408.
ft)Concept:DescriptionAndPurposeOfOtherRegulatoryAssets
ID PUC Order No 34606.Deferral of costs related to Avista's entry in the Energy Imbalance Market in March 2022.
Ju)Concept:Desch ptionAnd Pu rposeOfOtherReg u latoryAssets
Deferral of O&M wildfire expenses as per Idaho PUC Order 34883 and WA Dockets UE-200900,UG-200901,and UE-200894.
"v)Concept:DescriptionAndPurposeOfOtherRegulatoryAssets
WA Order 09,Docket Nos,UE-190334,UG-190335,UE-190222.
W Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
%VA Order 01,Dockets UE-200895 and UG-200896,ID Case Nos.AVU-E-20-12 and AVU-G-20-07 Order No.34906,and OR Docket No UM 2124 Order No 21-131-Accounting
method change for federal income tax expense associated with Industry Director Directive No.5 mixed service costs for meters.
W Concept:DescriptionAndPurposeOfOtherRegulatoryAssets
WA Docket No UE-002066 and ID Order No 28648.

�y)Concept:DescdpbonAndPurposeOfOtherRegulatoryAssets
Deferral of costs associated with Oregon House Bill 2475.
Uz)Concept:DescdpbonAndPurposeOfOtherRegulatoryAssets
o defer costs above or below the baseline in accordance with Order No 10/04 Docket Nos UE-220053.UE-210854,and UG-220054.
as Concept:DescdpbonAndPurposeOfOtherRegulatoryAssets
o defer costs of compliance for CPP(OR-UM 2254)and CCA(WA-Doc.UG-220803)in relation to energy efficiency programs to reduce GHG for natural gas customers.
ab Concept:DescrtptionAndPurposeOfOtherRegulatoryAssets
R Docket No UG415/Advice No.21-06-G.Amortization of amounts deferred previously in Order No.20-254 in UG 395.WA Docket No UE-220892 and UG-220893 Order 01.
ac Concept:Desc6ptionAndPurposeOfOtherRegulatoryAssets
To defer expected impacts associated with the occurrence of pension events and amortization over 12 years-ID Case Nos.AVU-E-22-16 and AVU-G-22-08,WA DocketNos UE-
220898 and UG-220899,and OR UM 2267.
(ad.)Concept:DescdpbonAndPurposeOfOtherRegulatoryAssets
o defer costs of compliance with the Climate Commitment Act in accordance with WAC 480-100-203(3)and WAC 480-90-203(3).WA Docket No UG-220803.
Lae)Concept:DescdptionAndPurposeOfOtherRegulatoryAssets
Washington Energy Recovery Mechanism
Jaf)Concept:DescdpbonAndPurposeOfOtherRegulatoryAssets
Deferral for the Montana Riverbed land lease agreement escrow release provisions following Avista.and State of Montana Agreement on an updated balance owed.
Lag)Concept:DescdpbonAndPurposeOfOtherRegulatoryAssets
Difference between depreciation rates in GRC verses effective date based on ID Order 35909 Dockets AVU-E-23-01 and AVU-G-23-01.
ah Concept:Descr ptonAndPurposeOfOtherRegulatoryAssets
Accrued interest on power purchase agreements in connection with the clean energy action plan M RCW 80.28.410.
LaQ Concept:DescdptionAndPurposeOFOtherRegulatoryAssets
(Deferral and Amortization resulting from the approval of flow through tax treatment for IDD#5 and meters basis adjustments.
W Concept:DescdpbonAndPurposeOfOtherRegulatoryAssets
Grouped minor items.
FERC FORM No.2(REV 12-07)
Page 232

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2) A Resubmission
0411 8/2 0 2 5 End of:2024/04
❑
Miscellaneous Deferred Debits(Account 186)
Description of Miscellaneous Deferred Balance at Beginning of Credits Account
Line Debits Amortization Period Year Debits Charged
No. (a) (b) (c) (d) (e)
1 Reg Asset-Battery Storage 3,422,093
2 Plant Alloc of Clearing Journal 6,207,998 5,038,606
3 Reg Asset-ERM 12,160,663 VAR
4 WA REC Deferral 412,639 557
5 Reg Asset-DecouplingDeferred 9,112,109 9.988,171
6 Reg Asset-COVID 19 Deferral 11,484,555 0
7 Reg Asset-CEIP 1,033,207 1,811,891
8 Reg Asset-Williams Outage 10,297,716 VAR
9 Misc Deferred Debits-Pension 33,003,989 2,395,079
10 Nez Perce Settlement 103,561 557
11 City of Post Falls Lease Pay 126,851 VAR
12 Post Falls HED Project 63 101,121 VAR
13 DCL Inter Study 3 DsnConst 0 372,096
14 ENEL Studies for TSR 0 100,421
15 Network Future State 0 254,378
16 Misc.Deferred Debits<$100,000 51,402 J JVAR
39 Miscellaneous Work in Progress
_�:M
40 TOTAL 87,517,904 19,960,642
FERC FORM No.2(12-96)
Page 233

Miscellaneous Deferred Debits(Account 186)
Line No. Credits Amount Blatat1h6�9 @hd of Year
1 0 3,422,093
2 11,246,604
3 1,654,718 10,505,945
4 412.639 0
5 19,100,280
6 11,484,555
7 2,845,098
8 646,170 9,651,546
9 35,399,068
10 5,188 98,373
11 126,851 0
12 101,121 0
13 372,096
14 100,421
15 254,378
16 459,536 (408,134)
39
40 3,406,223 104,072,323
FERC FORM No.2(12-96)
Page 233

Name of Respondent: This report is:
P Date of Report: Year/Period of Report:
(1)®An Original
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
Accumulated Deferred Income Taxes(Account 190)
Changes Changes Changes Changes
Balance at During Year During Year,During YearDuring Year Adjustments Adjustments Adjustments Adjustments
Account Amounts Amounts Amounts Amounts Balance at
Line Beginning of Debits Debits Credits Credits No. Subdivisions Year Debited to Credited to Debited to Credited to Account No. Amount Account No. Amount End of Year
(a) (b) Account Account Account Account (g) (l�) (� (1) (k)
410.1 411.1 410.2 4112
(c) (d) (e) (i)
1 Account 190
2 Electric 724'041,518
4,418.866 19,505,827 (6,576,161) 148,722 19,754 254.3 34,721 58,173,189
3 Gas (435,661) (2,228,207) 0 11,218 254.3 1,255 22,258,935
4 Other(Define) -105,691,804 25,138,175 (258,553) 6,832,190 4,507,550 254.3 4.279,642 73,690,794
5 Total(Total of 214,152,188 44,208,341 (9,062,921) 6,980,912 4,538,522 4,315,618 154,122,918
lines 2 thru 4)
6 Other
(Specify)
TOTAL
7 Account 190 214,152,188 44,208,341
(Total of lines (9,062,921) 6,980,912 4,538,522 4,315,618 154,122,918
5 thru 6)
8 Classification
of TOTAL
9 Federal 214,152,188 44,208,341 (9,062,921) 6,980,912 4,538,522 4,315,618 154,122,918
Income Tax
10 State Income
Tax
11 Locallncome
Tax
FERC FORM No.2(REV 12-07)
Page 234

Name of Respondent: This report is: Date of Report: Year/Period of Report:
(1)0 An Original
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
FOOTNOTE DATA
"Concept:AccumuIated Deferred lncomeTaxes
Beg.Balance End.Balance
Pension,Medical,and SERP 34,671,763 31,876,832
Federal lncomeTaxCarryforwards 27,406,304 1,202,010
State lncomeTaxCarryforwards 17,952,286 21,234,188
Derivative Instruments 16,269,451 10,631,115
Compensation and Payroll 6,986,432 7,010,014
Plant Excess Deferred Gross Up 3,951,713 3,340,097
Other Common Deferred Tax Assets (1,546,146) (1,603,462)
Total 105,691,803 73,690,794
FERC FORM No.2(REV 12-07)
Page 234

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Capital Stock(Accounts 201 and 204)
Outstanding per
Bal.Sheet(total Hold by Held by Held by Held by
Numberof Paror amt outstanding RespondentRespondentRespondentResponden
Class and Series of Shares Stated Call Price without As As in Sinking In Sinking
No. Stock Exchange Year
Line Stock and Name of Authorized by Value per at End of reduction for A Sheet Outstanding per Reacquired Reacquired and Other and Other
Charter Share amts held by Amount Stock(Acct Stock(Acct Funds Funds
(a) (b) (c) (d) respondent) (� 217)Shares 217)Cost Shares Amount
Shares (g) (h) (i) (j)
(e)
1 Common Stock
(Account201)
2 No Par Value 200.000,000 80,039,000 1,667,222,874
3 Restricted Shares 158,464 5,958,729
4
5 Total 200,000,000 80,039,000 1,667,222,874
6 Preferred Stock
(Account204)
3t1i� -
7 Cumulative ��10001000
8
9
10 Total 10,000,01 0
11 Total
FERC FORM No.2(12-96)
Page 250

This report is: Year/Period of Report
Name of Respondent: (1)®An Original Date of Report:
Avista Corporation 04/18/2025
(2)El Resubmission End of:2024/04
Other Paid-In Capital(Accounts 208-211)
ount
1 Donations Received from Stockholders(Account 208)
2 Beginning Balance Amount
3 Increases(Decreases)from Sales of Donations Received from Stockholders
4 Ending Balance Amount
5 Reduction in Par or Stated Value of Capital Stock(Account 209)
6 Beginning Balance Amount
7 Increases(Decreases)Due to Reductions in Par or Stated Value of Capital Stock
8 Ending Balance Amount
9 Gain or Resale or Cancellation of Reacquired Capital Stock(Account 210)
10 Beginning Balance Amount
11 Increases(Decreases)from Gain or Resale or Cancellation of Reacquired Capital Stock
12 Ending Balance Amount
13 Miscellaneous Paid-In Capital(Account211)
14 Beginning Balance Amount (2,732,405)
15 Increases(Decreases)Due to Miscellaneous Paid-In Capital
16 Ending Balance Amount (2,732,405)
17 Other Paid in Capital
18 Beginning Balance Amount
19 Increases(Decreases)in Other Paid-In Capital
20 Ending Balance Amount
40 Total (2,732.405)
FERC FORM No.2(12-96)
Page 253

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Securities Issued or Assumed and Securities Refunded or Retired During the Year
1. Furnish a supplemental statement briefly describing security financing and refinancing transactions during the year and the accounting for the securities,
discounts,premiums,expenses,and related gains or losses.Identify as to Commission authorization numbers and dates.
2. Provide details showing the full accounting for the total principal amount,par value,or stated value of each class and series of security issued,assumed,
retired,or refunded and the accounting for premiums,discounts,expenses,and gains or losses relating to the securities.Set forth the facts ofthe accounting
clearly with regard to redemption premiums,unamortized discounts,expenses,and gain or losses relating to securities retired or refunded,including the
accounting for such amounts carried in the respondent's accounts at the date ofthe refunding or refinancing transactions with respectto securities previously
refunded or retired.
3. Include in the identification of each class and series ofsecurity,as appropriate,the interest or dividend rate,nominal date of issuance,maturity date,
aggregate principal amount,par value orstated value,and number of shares.Give also the issuance of redemption price and name ofthe principal
underwriting firm through which the security transactions were consummated
4. Where the accounting for amounts relating to securities refunded or retired is other than that specified in General Instruction 17 ofthe Uniform System of
Accounts,cite the Commission authorization for the different accounting and state the accounting method.
5. For securities assumed,give the name ofthe company for which the liability on the securities was assumed as well as details ofthe transactions whereby
the respondent undertook to pay obligations of another company.If any unamortized discount,premiums,expenses,and gains or losses were taken over
onto the respondent's books,furnish details ofthese amounts with amounts relating to refunded securities clearly earmarked.
In April 2024,the Company remarketed the City of Forsyth,Montana Pollution Control Revenue Refunding Bonds.The bonds are not subject to ordinary optional redemption.The bonds are
secured by equal principal amounts of non-transferable first mortgage bonds ofthe Company.Avista Corp.had purchased the Forsyth bonds upon original issuance in December 2010 and
held the bonds until market conditions were favorable for remarketingthe bonds to unaffiliated investors.In connection with the pricing ofthe Forsyth bonds,the Company cash-settled two
interest rate swap derivatives(notional aggregate amount of$20 million)and received a net amount of$4 million.
The new issuance is based on the following state commission orders:
1. Order of the Washington Utilities and Transportation Commission in Docket No.240011 entered January 25,2024.
2. Order of the Idaho Public Utilities Commission,Order No.36079 entered February 1,2024.
3. Order of the Public Utility Commission of Oregon,Order No.24-016,entered January 23,2024.
4. Order of the Public Service Commission of the State of Montana,Default Order No.4535.
The Company issued common stock for total net proceeds of$68 million in 2024.Most of these issuances were made through sales agency agreements under which the Company may offer
and sell new shares of common stock from time to time through its sales agents.In 2024,1.8 million shares were issued under these agreements.
FERC FORM No.2(12-96)
Page 255.1

This report is:
Name of Respondent: (1) An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)❑A Resubmission
Long-Term Debt(Accounts 221,222,223,and 224)
OuLstanding(Total amount
lig ttfon and Narate of outstanding without Interost for Year
nge Nominal DateaP Date of Mahrrity reduction for amts held by Rate(in o)
(b (c) r-.5pondent) (a)
(d)
1 Bonds(Account221)
2 FMBS-SERIES C-6.37%DUE 06/18/2028 06/19/1998 06/19/2028 25,000,000 6.37%
3 FMBS-6.25%DUE 12-01-35 11/17/2005 12/01/2035 150,000,000 6.25%
4 FMBS-5.70%DUE 07-01-2037 12/15/2006 07/01/2037 150,000,000 5.7%
5 5.55%SERIES DUE 12-20-2040 12/20/2010 12/20/2040 35,000,000 5.55%
6 4.11%SERIES DUE 12-1-2044 12/18/2014 12/01/2044 60,000,000 4.11%
7 4.37%SERIES DUE 12-1-2045 12/16/2015 12/01/2045 100,000,000 4.37%
8 4.23%SERIES DUE 11-29-2047 11/30/2012 11/29/2047 80,000,000 4.23%
9 3.91%SERIES DUE 12-1-2047 12/14/2017 12/01/2047 90,000,000 3.91%
10 4.35%SERIES DUE 6-1-2048 05/22/2018 06/01/2048 375,000,000 4.35%
11 3.43%SERIES DUE 12-1-2049 11/26/2019 12/01/2049 180,000,000 3A3%
12 3.07%SERIES DUE 9-1-2050 09/30/2020 09/30/2050 165,000,000 3.07%
13 2.90%SERIES DUE 10/01/2051 09/28/2021 10/01/2051 140,000,000 2.9%
14 3.54%SERIES DUE 2051 12/15/2016 12/O1/2051 175,000,000 3.54%
15 4.00%SERIES DUE4/1/2052 03/17/2022 04/01/2052 400,000,000 4%
16 5.66%SERIES DUE 04-01-2053 03/29/2023 04/01/2053 250,000,000 5.66%
17 COLSTRIP 2010A PCRBs DUE 2032 04/01/2024 10/01/2032 66,700,000 3.875%
18 COLSTRIP 2010B PCRBs DUE 2034 04/01/2024 03/01/2034 17.000,000 3.875%
19 4.45%series due 12-14-2041 12/14/2011 12/14/2041 85,000,000 4.45%
20 Subtotal 2,543,700,000
21 Reacquired Bonds(Account 222)
22
23
24
25
26
27
28
29
30 Subtotal 0
31 Advances from Associated Companies
(Account 223)
32 ADVANCE ASSOCIATED-AVISTA CAPITAL II 06/03/1997 06/01/2037 51,547,000
(TOPRS)
33 Subtotal 51,547,000
r-
34 Other Long Term Debt(Account 224)
FERC FORM No.2(12-96)
Page 256

Long-Term Debt(Accounts 221,222,223,and 224)
Outstanding(Total amount
Class and Series of Obligation and Name of outstanding without Interest for Year
Line Stock Exchange Nominal Date of Issue Date of Maturity o
No. 9 (b) (c) reduction for amts held by Rate(in /n)
(a) respondent) (e)
_ (d)
35
36
37
38
39
40
41
42
36 Subtotal 0
40 TOTAL 2.595,247,000
FERC FORM No.2(12-96)
Page 256

Long-Tenn Debt(Accounts 221,222,223,and 224)
Line interest for Year Amount Held by Respondent Reacquired Held by Respondent Sinking and Redemption Price per$100 at End
Bonds(Acct 222) Other Funds of Year
No. (9) (h) (i)
1
2 1,592.500
3 9,375,000
4 8,550,000
5 1,942,500
6 2,466.000
7 4,370,000
8 3,384,000
9 3,519,000
10 16,312,500
11 6,174,000
12 5,065,500
13 4,060,000
14 6,195,000
15 16,000,000
16 14,150.000
17 1,292,313
18 329,375
19 3,782,500
3E
20 108,560,188 0
21 AL AWL A
22
23
24
25
26
27
28
29
30 0
31
32 2,575,297
33 2,575,297 0
34
35
36
37
38
FERC FORM No.2(12-96)
Page 256

Long-Term Debt(Accounts 221,222,223,and 224)
Line Interest for Year Amount Held by Respondent Reacquired Held by Respondent Sinking and Redemption Price per$100 at End
No. M Bonds(Acct 222) Other Funds of Year
(9) (h) (i)
39
40
41
42 '
36
40 111,135.485 0 0
FERC FORM No.2(12-96)
Page 256

This report is:
Date of Repo
Name of Respondent: (1)®An Original Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)❑A Resubmission
Unamortized Debt Expense,Premium and Discount on Long-Term Debt(Accounts 181,225,226)
-- Totatexpaf�sa=Pend- akrrn; .
Line Oosiynatton of Long-lemi Deft Discount;or Data
Princfpol Amorint of Debt Amorti-vitlon Porlod Date Amortization Period D
Issued From To
No. (a) (b) tssuaneo Costs (d) (e)
1 Unamortized Debt Expense(Account 181)
2 ADVANCE ASSOC IATED-AVISTA 51,547,000 1,296,086 06/03/1997 06/01/2037
CAPITAL II(TOPRS)
3 FMBS-SERIES C-6.37%DUE 25,000,000 158,304 06/19/1998 06/19/2028
O6/18/2028
4 FMBS-6.25%DUE 12-01-35 150,000,000 2,180,435 11/17/2005 12/01/2035
5 FMBS-5.70%DUE 07-01-2037 150,000.000 4,924,304 12/15/2006 07/01/2037
6 5.55%SERIES DUE 12-20-2040 35,000,000 258,834 12/20/2010 12/20/2040
7 4.45%SERIES DUE 12-14-2041 85,000,000 692,833 12/14/2011 12/14/2041
8 SHORT-TERM CREDIT FACILITY 0 16,353,003 12/14/2011 06/08/2028
9 4.23%SERIES DUE 11-29-2047 80,000,000 730,832 11/30/2012 11/29/2047
10 4.11%SERIES DUE 12-1-2044 60,000,000 428,205 12/18/2014 12/01/2044
11 4.37%SERIES DUE 12-1-2045 100,000,000 590,761 12/16/2015 12/01/2045
12 3.54%SERIES DUE 2051 175,000,000 1,042,569 12/15/2016 12/01/2051
13 3.91%SERIES DUE 12-1-2047 90,000,000 552,539 12/14/2017 12/01/2047
14 4.35%SERIES DUE 6-1-2048 375,000,000 4,625,198 06/01/2018 06/01/2048
15 3.43%SERIES DUE 12-1-2049 180,000,000 1,108,340 12/01/2019 12/01/2049
16 3.07%SERIES DUE 9-1-2050 165,000,000 1,074,990 09/30/2020 09/30/2050
17 2.90%SERIES DUE 10/01/2051 140,000,000 1,083,452 09/28/2021 10/01/2051
18 4.00%SERIES DUE4-1-2052 400,000,000 4,723,993 03/17/2022 04/01/2052
19 5.66%SERIES DUE 04-01-2053 250,000,000 1,444,302 03/29/2023 04/01/2053
20 COLSTRIP 2010A PCRBs DUE 2032 66,700,000 965,638 04/01/2024 10/01/2032
21 COLSTRIP 2010B PCRBs DUE 2034 17,000,000 264,090 04/01/2024 03/01/2034
22 DEBT STRATEGIES 0 56,760 08/01/2005 08/01/2035
23 Rathrum2005 0 71,647 09/30/2005 12/01/2035
24 Premium on Long-Term Debt(Account 225)
25 FMBS-6.25%DUE 12-01-35 150,000,000 2,180,435 11/17/2005 12/01/2035
26 Discount on Long-Term Debt(Account 226)
27 FMBS-6.25%DUE 12-01-35 150,000,000 2,180,435 11/17/2005 12/01/2035
28 FMBS-5.70%DUE 07-01-2037 150,000,000 4,924,304 12/15/2006 07/01/2037
29 4.35%SERIES DUE 6-1-2048 375,000,000 4,625,198 06/01/2018 06/01/2048
30 4.00%SERIES DUE4-1-2052 400,000,000 4,723,993 03/17/2022 04/01/2052
FERC FORM No.2(12-96)
Page 258

Unamortized Debt Expense,Premium and Discount on Long-Term Debt(Accounts 181,225,226)
Line Balance at Beginning of Ycar Debits During Year AMC, ffabn0e dt W'Ofyow, lil
1
2 189,200 14,015 175,185
3 23,745 5,277 18,468
4 724,530 60,377 664,153
5 2,088,747 153,773 1,934,974
6 146,677 8,628 138.049
7 415,871 23,104 392,767
8 3,225,563 709,357 2,516,206
9 499,526 20,886 478,640
10 299,925 14,282 285,643
11 433,433 19,702 413,731
12 834,227 29,794 804,433
13 442,140 18,423 423,717
14 3,458,745 141,174 3,317,571
15 957,905 36,843 921,062
16 1,007,566 37,666 969,900
17 1,004,308 36,083 968,225
18 4,314,601 152,280 4,162,321
19 1,408.944 48,032 1,360,912
20 65,260 885,077 65,261 885,076
21 16,633 245,148 16,633 245,148
22 333 29 304
23 28,422 2,368 26,054
24
25 106,600 8,883 ==97,717
26
27 252,898 21,075 231,823
28 98,599 7,259 91,340
29 308,456 12,590 295,866
30 135,623 4,786 130,837
FERC FORM No.2(12-96)
Page 258

report is:e This rpo
Name of Respondent: Th Th po Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)❑A Resubmission
Unamortized Loss and Gain on Reacquired Debt(Accounts 189,257)
Principal ofT>e5t — Balance at Balance at
Line Designation of Long Torm Debt Data of Mpturety' pate Reacquired Net Gain or Loss
Reacquired Beginning of Yoar End of Year
No. (a) (b) (c) (d) (e) (f) (9)
1 Unamortized Loss(Account 189)
2 Misc Debt Repurchases 1 05/10/1993 0 4,695,395 28,297 22,009
3 ADVANCE ASSOCIATED- 06/01/2037 12/18/2000 10,000,000 0 0 0
AVISTA CAPITAL II(ToPRS)
4 Misc 2002 Repurchase 12/31/2002 10,000,000 121,847 11,157 8,309
5 Misc 2003 Repurchase 12/31/2003 25,330,000 684,726 33,059 24,794
6 Misc 2005 R epurchase 12/31/2005 26,000,000 1,700,371 356,995 321,990
7 Misc 2008 Repurchase 12/31/2008 0 (43,132) (139)
8 COLSTRIP 2010APCRBs DUE 03/01/2032 12/14/2010 66,700,000 3,709,174 1,375.065 1,219,398
2032
9 COLSTRIP 2010E PCRBs DUE 03/01/2034 12/14/2010 17.000,000 1,916,297 842,019 759,526
2034
10 5.55%SERIES DUE 12-20-2040 12/20/2040 12/20/2010 30,000,000 5,263,822 2,982,834 2,807,372
11 4.23%SERIES DUE 11-29-2047 11/29/2047 06/28/2012 4,100,000 105,020 71,764 68,763
12 Unamortized Gain(Account 257)
13 Misc Debt Repurchases 1 05/10/1993 0 0 0 0
14 ADVANCE ASSOCIATED- 06/01/2037 12/18/2000 10,000,000 (1,769,125) 654,780 605,976
AVISTA CAPITAL II(ToPRS)
15 Misc 2002 Repurchase 12/31/2002 10,000,000 (2,350,000) 215,183 160,243
16 Misc 2003 Repurchase 12/31/2003 25,330,000 (1,000,000) 72,421 54.316
17 Misc 2005 Repurchase 12/31/2005 26.000,000 0 0 0
18 Misc 2008 Repurchase 12/31/2008 0 0 0 0
19 COLSTRIP 2010A PCRBs DUE 03/01/2032 12/14/2010 66,700,000 0 0 0
2032
20 COLSTRIP 2010B PCRBs DUE 03/01/2034 12/14/2010 17,000,000 0 0 0
2034
21 5.55%SERIES DUE 12-20-2040 12/20/2040 12/20/2010 30,000,000 0 0 0
22 4.23%SERIES DUE 11-29-2047 11/29/2047 06/28/2012 4,100,000 0 0 0
FERC FORM No.2(12-96)
Page 260

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
Reconciliation of Reported Net Income with Taxable Income for Federal Income Taxes
- — �e Amount
(a) (b)
1 Net Income for the Year(Page 114) 180,135,566
2 Reconciling Items for the Year
3
4 Taxable Income Not Reported on Books
5 Contributions in Aid of Construction 14,886,504
6 Other 36,294,996
8 Total
51,181,500
9 Deductions Recorded on Books Not Deducted for Return
10 Book Depreciation 273,381,876
11 Federal Income Tax Expense 287,918
12 State Income Tax Expense (31,149)
13 Subsidiary Overheads 725,157
14 Other 146.643,628
13 Total 421,007,430
14 Income Recorded on Books Not Included in Return
15 Subsidiary Earnings 1,531,571
16 Other
34,892,415
18 Total
36,423,986
19 Deductions on Return Not Charged Against Book Income
20 Tax Depreciation 248,402,156
21 Plant Basis Adjustment 101,845,755
22 Other 167.349,813
26 Total
517,597,724
27 Federal Tax Net Income 98,302,786
28 Show Computation of Tax:
29 Federal Tax at 21% 20,643,585
30 Business Credits Utilized (17,264,409)
31 Prior Year True Ups 746,791
32 Total Federal Current Tax Expense 4,125.967
FERC FORM No.2(12-96)
Page 261

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)0 A Resubmission
Taxes Accrued,Prepaid and Charged During Year,Distribution of Taxes Charged(Show utility dept where applicable and acct charged)
- ----- - - -- -- ----- _ Bafanoleat
Line Kind efTlk*o Instruction 5) Type of Tax Tax Jurisdiction Tax Year Bog.ofY
(d) Taxes
Accnied
-(e)
1 Income Tax Federal Tax 2020
2 Income Tax Federal Tax 2023
3 Income Tax Federal Tax 2024
4 Subtotal Federal Tax 0
5 Property Tax Property Tax WA 2023 14,233,320
6 Property Tax Property Tax WA 2024
7 Property Tax Property Tax ID 2023 2,048,214
8 Property Tax Property Tax ID 2024
9 Property Tax Property Tax MT 2023 3,675,530
10 Property Tax Property Tax MT 2024
11 Property Tax Property Tax OR 2023
12 Property Tax Property Tax OR 2024
13 Subtotal Property Tax 19,957,064
14 Excise Tax Excise Tax WA 2018
15 Excise Tax Excise Tax WA 2019
16 Excise Tax Excise Tax WA 2020
17 Excise Tax Excise Tax WA 2021
18 Excise Tax Excise Tax WA 2023 3,960.799
19 Excise Tax Excise Tax WA 2024
20 Corp Activities Tax-CAT Excise Tax OR 2023
21 Corp Activities Tax-CAT Excise Tax OR 2024
22 Subtotal Excise Tax 3,960,799
23 Natural Gas Use Tax Sales And Use Tax WA 2023 5,824
24 Natural Gas Use Tax Sales And Use Tax WA 2024
25 Use Tax Sales And Use Tax WA 2018
26 Use Tax Sales And Use Tax WA 2019
27 Use Tax Sales And Use Tax WA 2020
28 Use Tax Sales And Use Tax WA 2021
29 Use Tax Sales And Use Tax WA 2023 241,889
30 Use Tax Sales And Use Tax WA 2024
31 Use Tax Sales And Use Tax ID 2023 52,694
32 Use Tax Sales And Use Tax ID 2024
33 Subtotal Sales And Use Tax 300,407
34 Municipal Occupation Tax Local Tax WA 2023 3,823,700
35 Municipal Occupation Tax Local Tax f WA 2024
FERC FORM No.2(REV 12-07)
Page 262

Taxes Accrued,Prepaid and Charged During Year,Distribution of Taxes Charged(Show utility dept where applicable and acct charged)
Balance at
Line Kind of Tax(See Instruction 5) Type of Tax Tax Jurisdiction Tax Year Beg.of Year
No. (a) (b) (c) (d) Taxes
Accrued
(e)
36 Subtotal Local Tax 3,823,700
37 KWH Tax Other Taxes ID 2023 22,224
38 KWH Tax Other Taxes ID 2024
39 KWH Tax Other Taxes MT 2023 219,378
40 KWH Tax Other Taxes MT 2024
41 WA Renewable Energy Credits Other Taxes WA 2024
42 Subtotal Other Taxes 241,602
43 Income Tax State Tax ID 2023
44 Income Tax State Tax ID 2024
45 Income Tax State Tax MT 2023
46 Income Tax State Tax MT 2024
47 Income Tax State Tax OR 2023
48 Income Tax State Tax OR 2024
49 Income Tax State Tax Misc 2024
50 Subtotal State Tax 0
51 Payroll Taxes Payroll Tax ID 2023 3,747
52 Payroll Taxes Payroll Tax ID 2024
53 Payroll Taxes Payroll Tax MT 2023 239
54 Payroll Taxes Payroll Tax MT 2024
55 Payroll Taxes Payroll Tax OR 2023 10,829
56 Payroll Taxes Payroll Tax OR 2024
57 Payroll Taxes Payroll Tax WA 2023 (125,238)
58 Payroll Taxes Payroll Tax WA 2024
59 Payroll Taxes Payroll Tax MISC 2023 720
60 Payroll Taxes Payroll Tax MISC 2024
61 Payroll Taxes Payroll Tax FED 2023 1,052,854
62 Payroll Taxes Payroll Tax FED 2024
63 Subtotal Payroll Tax 943,151
64 Franchise Tax Franchise Tax ID 2023 1,372,780
65 Franchise Tax Franchise Tax ID 2024
66 Franchise Tax Franchise Tax OR 2023 1,279,644
67 Franchise Tax Franchise Tax OR 2024
68 Subtotal Franchise Tax 2,652,424
69 Consumer Council Fee Other License And Fees Tax MT 2023 10
70 Consumer Council Fee Other License And Fees Tax MT 2024
71 Public Commission Fee Other License And Fees Tax MT 2023 50
r772 Public Commission Fee Other License And Fees Tax MT 2024
FERC FORM No.2(REV 12-07)
Page 262

Taxes Accrued,Prepaid and Charged During Year,Distribution of Taxes Charged(Show utility dept where applicable and acct charged) 7
Balance at
Line Kind of Tax(See Instruction 5) Type of Tax Tax Jurisdiction Tax Year Beg.of Year
No. (a) (b) (c) (d) Taxes
Accrued
(e)
73 Subtotal Other License And
60
Fees Tax
40 Total 31,879,207
FERC FORM No.2(REV f 2-07)
Page 262

Taxes Accrued,Prepaid and Charged During Year,Distribution of Taxes Charged(Show utility dept where applicable and acct charged)
Balance at Beg.of Year Balance at End of Year Taxei
Line Prepaid Taxes Taxes Charged During Year Taxes Paid During Year Adjustments
No. p (g) (h) (i) Accrued(Account 236)
(f) U)
1 (847,386) (847,386) 0
2 746,790 1,271,415 524,625 0
3 3,226,894 7,201,000 3,974,106 0
4 0 3,973,684 7,625,029 3,651,345 0
5 (452,595) 13,780,724 (1) 0
6 14,250,327 1 14.250,328
7 (634,704) 1,413,509 (1) 0
8 2,579,148 651,106 1,928,042
9 309.549 3,985.078 (1) 0
10 6,514.446 3,273.648 1 3,240,799
11 4,233,606 4,233,606 0
12 4,001,392 8,002,628 0
13 4,233,606 30,801,169 31,106,693 (1) 19,419,169
14 164.708 164,708
15 1,789,049 1,789,049
16 169,866 169,866
17 (64,551)
(64,551)
18 105,993 4,066,792 0
19 37,934,731 33,751,857 4,182,874
20 85,864 100,276 14,412 0
21 1,000,000 1,000,000 0
22 0 41,185,660 38,918,925 14,412 6,241,946
23 4,039 9,864 1 0
24 122,674 122,590 84
25 (174,420)
(174,420)
26 (381,322)
(381,322)
27 (625,368)
(625,368)
28 (335,436) (335,436)
29 (4,416) 237,473 0
30 2,860.132 2,253,199 606.933
31 52,693 (1) 0
32 235,387 181,737 1 53,651
33 0 1,701,270 2,857,556 1 (855,878)
34 (10,824) 3,812,877 1 0
35 31,779,742 27,647,417 4,132,325
36 0 31,768,918 31,460,294 1 4,132,325
37 103 22,368 41 0
38 342,367 324,109 (40) 18,218
FERC FORM No.2(REV 12-07)
Page 262

Taxes Accrued,Prepaid and Charged During Year,Distribution of Taxes Charged(Show utility dept where applicable and acct charged)
Line Balance at Beg.of Year Taxes Charged During Year Taxes Paid During Year Adjustments Balance at End of Year Taxes
Prepaid Taxes Accrued(Account 236)
39 (4) 219,374 0
40 923,826 704,269 219,557
41 622,440 622,440 0
42 0 1,888,732 1,892,560 1 237.775
43 10 0 (10) 0
44 120 100 (20) 0
45 0
46 50 50 0
47 0
48 100,000 100,000 0
49 975 975 0
50 0 101,155 101,125 (30) 0
51 2,117 (1,630) 0
52 79,756 59,365 20,391
53 239 0
54 5,153 5,019 134
55 (10,829) 0
56 69,682 58,417 11,265
57 125,238 0
58 1,147,321 627,177 520,144
59 (720) 0
60 1,994 1,944 50
61 (170,384) 1,012 (881,458) 0
62 17,943,947 17,943,947 769,400 769.400
63 0 19.077,469 18,699,237 1 1.321,384
64 9 1,372,789 0
65 6,101,860 4,818,900 1,282,960
66 1,376 1,281,022 2 0
67 5,035,862 3.574,329 (1) 1,461,532
68 0 11,139,107 11,047,040 1 2,744,492
69
8 (2) 0
70 40 32 2 10
71 50 0
72 240 195 1 46
73 0 280 285 1 56
40 4,233,606 141.637,444 143,708,744 3,665,732 33,241,269
FERC FORM No.2(REV 12-07)
Page 262

Taxes Accrued,Prepaid and Charged During Year,Distribution of Taxes Charged(Show utility dept where applicable and acct charged)
Balance at End of Year Electric Account 408.1, Other Income and
( Other Utility Dept.(Account
Lino Prepaid Taxes(Included in Gas(Account 408.1.409.1) Deductions(Account 4082,
No. Acct 165) 409.1) (m) 4081,409.1) 409.2)
(k) (I) (n)
- (o)
1
2 2,744,271 (1,799,539) (197,942)
3 (13,973,028) 21,765,174
(4,565,252)
4 0 (11,228.757) 19,965,635 0 (4,763,194)
5 (386,070) (61,587) (4,938)
6 10,703,475 3,409,944 136,908
7 421 (635,125)
8 1,487,340 1,075,376 16,432
9 309,549
10 6,514,446
11 1,690,104 2,543,502
12 4,001.236 1,609,146 2,392,246
13 4,001,236 21,928,411 8,724,356 0 148,402
14 87,897 72,631 4,180
15 89.686 74,140 1.548,680
16 87,688 77,388 4,790
17 (30,537) (40,441) 6,427
18 96,368 (2,918) 12,543
19 27,135,228 10,603,613 195,890
20 85,864
21 1,000,000
22 0 27,466,330 11,870.277 0 1,772,510
23 4,039
24 3,253
25
26
27
28
29
30
31
32
33 0 7,292 0 0 0
34 (9,469) (1,355)
35 22,389,328 9,390,414
36 0 22,379,859 9,389,059 0 0
37 103
38 342,367
FERC FORM No.2(REV 12-07)
Page 262

Taxes Accrued,Prepaid and Charged During Year,Distribution of Taxes Charged(Show utility dept where applicable and acct charged)
Balanco at End of Year Other Income and
400.1)
Electric(Account 406.1, Other Utility Dept (Account Account4682,
Line Prepaid Taxes(Included In Gas(Account 408.1, Deductions
408.1,409.1)409.1) (No. Acc 4092)t 165) (t) (m) (n)
(k) (o)
39 (4)
40 923,826
41
42 0 J 1,266,292 0 0 0
43 9 1
44 102 18
45
46 50
47
48 20,000 80,000
49 123 52 800
50 0 20,284 80.071 0 800
51
52 24,096 8,469 526
53
54 1,557 547 34
55
56 21,053 7,399 460
57
58 346,634 121,829 7,572
59
60 602 212 13
61 (51,477) (18,092) (1,125)
62 I 5,421,312 1,905,393 118,428
63 0 5,763,777 2,025,757 0 125,908
64 50 (41)
65 4,225,509 1,876,351
66 1,376
87 5,035,862
68 0 4,225,559 6,913,548 0 0
69
70 40
71
72 240
73 0 280 0 0 0
40 4,001.236 71,829,327 58,968,703 0 (2,715,574)
FERC FORM No.2(REV 12-07)
Page 262

Taxes Accrued,Prepaid and Charged During Year,Distribution of Taxes Charged(Show utility dept where applicable and acct charged)
Line Extraordinary Items(Account Other Utility Opn.Income Adjustment to Ret.Earnings Other State/local Income
No 409.3) (Account 408.1,409.1) (Account 439) Tax Rate
(p) (4) (r) (s) (t)
1
2
3
4 0 0 0 0
5
6
7
8
9
10
11
12
13 0 0 0 0
14
15 76,543
16
17
18
19
20
21
22 0 0 0 76,543
23
24 119,421
25 (174.420)
26 (381,322)
27 (625,368)
28 (335,436)
29 (4,416)
30 2,860,132
31
32 235,387
33 0 0 0 1,693,978
34
35
36 0 0 0 0
37
38
FERC FORM No.2(REV 12-07)
Page 262

Taxes Accrued,Prepaid and Charged During Year,Distribution of Taxes Charged(Show utility dept where applicable and acct charged)
Line Extraordinary Items(Account Other UtilTty din.Income Adjustmentto ki Earnings Other State/local Income
4D9.3) (Account 408.1,409.t) (Account 439) Tax R.,te
No. (p) (a) W {s) (t)
39
40
41 622,440
42 0 0 0 622,440
43
44
45
46
47
48
49
50 0 0 0 0
51
52 46,665
53
54 3,015
55
56 40,770
57
58 671,286
59
60 1,167
61 (99,690)
62 10,498,814
63 0 0 0 11,162,027
64
65
66
67
68 0 0 0 0
69
70
71
72
73 0 0 0 0
40 0 0 0 13,554,988
FERC FORM No.2(REV 12-07)
Page 262

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Miscellaneous Current and Accrued Liabilities(Account 242)
Line No. Item Balance at End of Year
(a) (b)
1 MISC LIAB-PAID TIME OFF 31,439,660
2 CURRENT PORTION-BENEFIT LIAB 14,904,284
3 CUSTOMER ACCOUNTS 11,938.489
4 MISC LIAB-MT LEASE PAYMENTS 6,095,000
5 ACCTSPAY-SOFTWARELICENSES-ST 2,470,815
6 MISC LIAB-MARGIN CALL DEPOSIT 2,755,001
7 MISC LIAB-FOREST USE PERMITS 1,921,536
8 WORKERS COMP LIABILITY 1,905,271
9 MISC LIAB-FERC ADMIN FEE ACC 795,692
10 MISC LIAB-SUAJPMORGAN CHASE 615,871
11 MISC LIABILITY-MISC NON-MON PWR EXCHANGE 270,698
12 MISC LIAB UNDER$250k 657,895
45 Total
75,770,212
FERC FORM No.2(12-96)
Page 268

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)EJ A Resubmission
Other Deferred Credits(Account 253)
Leto pescrlpUon of COW Doterrad CreditsBahwW at Beginning Debit Contra Debit Amount Credits
No. of Yenr Account (d) (e)
(b) (c)
LM
1 Deferred Gas Exchange 1,406,250 495 5,625,000 5,625,000 1,406,250
2 Bills Pole Rentals 666,361 454 1,680,627 1,748,552 734,286
3 Defer Comp Active Execs 7,793,908 128 494,678 2,081,070 9,380,300
4 Unbilled Revenue 4,654.027 908 49,864,716 55,527,842 10,317,153
5 uDecoupling Deferred Credits 8,466,683 182,456,495 8,466,683 0
6 Reg Liability-COVID-19 Deferral 7,749,100 407,236 214,234 823.589 8,358,455
7 WA REC Deferrals 186,431,557 2,810,569 3,950,992 1,140,423
8 Misc.Deferred Credits 6,920 407,186 400,554 471,777 78,143
9 Timber Harvest 226,796 226,796
10 OtherDerfCr-FISERV 870,702 903 316,667 304,298 858,333
11
AcctsPay-SoftwareLicenses-LT 1,077,496 242 1,098,874 1,226,661 1,205,283
45 TOTAL 32,918,243 70,972,602 71,759,781 33,705,422
FERC FORM No.2(12-96)
Page 269

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
FOOTNOTE DATA
jai Concept:Descri ptionOfOtherDeferredCred its
FortisBC and Avista exchange volumes of gas on a firm delivery basis during different time periods.Amortization is recorded monthly every year.This contract ends Apri12025.
Concept:DescdptionOfOtherDeferredCredits
Decoupling revenue deferrals are recognized during the period they occur,subject to certain limitations.Revenue is expected to be collected within 24 months of the deferral.
LQ Concept:DescriptionOfOtherDeferredCredits
Deferral of COVID-19 costs as per Idaho PUC Order No.34718,Oregon PUC Order No.20-401,Docket UM 2069 and WA UTC Order No.01,Dockets UE-200407 and UG-
200408.
U Concept:DescdptionOFOtherDeferredCredits
WA Docket UE-190334,Schedule 98.
jet Concept:Descri ptionOfOtherDeferred Credits
Other Deferred Credit-Fisery
Mf Concept:Descri ptionOfOtherDeferredCred its
Deferred Liability for Software Licenses
FERC FORM No.2(12-96)
Page 269

Name of Respondent: This report is: Date of Report: Year/Period of Report:
(1)®An Original
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
Accumulated Deferred Income Taxes-Other Property(Account 282)
Changes
Ghansr_s Changes During p �n , - -
ng
Balance at
During Year During Ycar Year
Year Adjustments Adjustments AdjustmentsAdjustments galnnce at
Account Amounts Amounts Amounts
Line Boyinniny of Amounts Debits Debits Credits Credits End of Year
(a)
Subdivisions Debited to Credite Debited to d to Credited
No. Year AccounbNo. Amount Account No. Amount
(b) Account Account Account to (g) (h) (i) (k)
410.1 411.1 Account
()2
(c) (d) 4 411.2
1 Account 282
2 Electric 439,198,735 460,906 0 182.3 656,968 440,316,609
3 Gas 157,037,181 2,421,002 0 182.3 2,881,115 162,339,298
4 Other(Define) 56,983,954 (1,523.849) 1,245,646 182.3 457,540 54,671,999
5 Total(Total of 653,219,870 1,358,059 1,245,646 3,995,623 657,327,906
lines 2 thru 4)
6 Other(Specify) 0 0
TOTAL
7 Account282 653,219,870 1,358,059 1,245,646 3,995,623 657,327,906
(Total of lines 5
thru 6)
8 Classification
of TOTAL
9 Federal 653,219,870 1,358,059 1,245,646 3,995,623 657,327,906
Income Tax
10 State Income 0 0
Tax
11 Local Income 0 0
Tax
FERC FORM No.2(REV 12-07)
Page 274

Name of Respondent: This report is:
P Date of Report: Year/Period of Report:
(1)®An Original
Avista Corporation (2)El Resubmission 04/18/2025 End of:20241 Q4
Accumulated Deferred Income Taxes-Other(Account 283)
Changes Changes Changes Changes
During Year (k)
During Year During During Year
Account Amounts Amounts
Subdivisions
Balance at Debited to Credited to Year Adjustments Adjustments Adjustments Adjustments Amounts Balance at
Credited to
Line Beginning of Amounts Debits Debits Credits Credits End of Year
( )
No. Year Debited to Account No. Amount Account No. Amount
(a) b Account Account Account (g) (h) (i) (J)
410.1 411.1 Account 411.2
(
(c) (d) 4 )2 (f)
1 Account283
2 Electric 50,155,679 5,782,822 5,360,201 136,648 (198,277) 182/254 182,499 51,095,724
3 Gas 22,133,532 (609,090) 21.009,561 328,400 (133,561) 182/254 765,866 1,742,708
4 Other(Define) 184,421,504 3,052,828 3,129,109 68,781 182/254 10,807,552 173,606,452
5 Total(Total of 256,710.715 8,226,560 29,498,871 533,829 (331,838) 948,365 10,807,552 226,444.884
lines 2 thru 4)
6 Other
(Specify)
TOTAL
7 Account283 256,710.715 8,226,560 29,498,871 533,829 (331.838) 948,365 10,807,552 226,444,884
(Total of lines
5 thru 6)
8 Classification
of TOTAL
9 Federal 256,710,715 8,226,560 29,498,871 533,829 (331,838) 948,365 10,807,552 226,444,884
Income Tax
10 State Income
Tax
11 Local Income
Tax
FERC FORM No.2(REV 12-07)
Page 276

This report is:
Name of Respondent: Th Th®An Original Date of Report: Year/Pedod of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)❑A Resubmission
Other Regulatory Liabilities(Account 254)
Written off -- - -
6at3nce at during Written off Outing Win off During Balance at
Description and Purpose of Period Amount End of
Une Beginning of Current QuarteriPeriod Period Amount Credits
Oihr-r Regulatory Lfabilltfes Deemed Non- Current
No. (a) QuarterNeir Account Refunded (fl
b) Credited ld) Refundable Quartcrffear
( (a) (g)
(c)
1 Idaho Investment Tax Credit 7,105,476 190 8,287 4,320,338 11,417,527
2 Interest Rate Swaps 23,751,628 175,427 3,908,282 4,397,000 24,240,346
3 Nez Perce 440,276 557 22,008 0 418,268
4 Idaho Earnings Test 572,475 407 343,485 0 228,990
5 u 17,998,342 495,182 20,977,937 8,424,296 5,444,701
Decoupling Rebate
6 Ldl 7,204,302 190 204,794 27 6,999,535
Deferred Federal ITC-Varies
7 u 301,619,229 190,282 297,908,665 283,963,634 287,674,198
Plant Excess Deferred
8 DSM Tariff Rider 4,987.044 182,$31, 7,260,923 4,079.552 1,805,673
9 Low Income Energy Assistance 5,734,024 242,908 11,038,765 10,259,367 4,954,626
u
10 RegLiability-ORTaxStrategy 569,566 407 481,897 11,201 98.870
Deferral
Ll
11 Reg Liability-Tax Reform 139,305 407 95,175 5.320 49.450
Amortization
m
12 Reg Liability-Energy Efficiency 714,598 232 514,282 7,673 207,989
Assistance
u
13 Reg Liability-COVID-19 2,807,374 407 1,843,711 512,139 1,475,802
Deferral
L
14 Reg Liability-Tax Customer 56,253,863 410,190 31,804,782 10.525,190 34,974,271
Credit
u
15 CS2 Insurance Proceeds 867,237 0 76,656 943,893
Deferral
16 kj 11,238,054 190,143 1,162,690 33,802 10.109,166
Misc.Regulatory Liabilities
17 Reg Liability-CCA
37,231,122 407 15,496,504 22,064,809 43,799,427
18 Depreciation Regulatory Liability 0 0 2,732,550 2,732,550
19 Idaho PCA Deferral 0 557,419 10,976,381 25,888,417 14,912,036
20 Battery Storage ITC 0 190 7,933 184,934 177,001
45 Total 479,233,915 404,056,501 0 377,486,905 452,664,319
FERC FORM No.2(REV 12-07)
Page 278

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
FOOTNOTE DATA
1W Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
Not amortized.
Lb)Concept:Descri ptionAnd P urposeOfOtherRegul atoryLiabi lit es
Mark-to-Market gains and losses for interest rate swap derivatives.Upon settlement,amortization or Regulatory Assets and Liabilities as a component of interest
expense over the term of the associated debt.
Lc)Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
Decoupling rebates are recognized during the penod they occur,subject to certain limitations.Rebates are returned to customers within 24 months of the deferral.
Ld.)Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
Noxon ITC-65yr amort,ends 2077
Community Solar ITC-20yr amort,ends 2035
Nine Mile ITC-65yr amoM ends 2080.
Le)Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
Amortized over remaining book life of lard,estimated 36 years.
4Q Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
WA Orders Dockets UE-190912 and UG-I90920,Idaho Docket AVU-E-I8-12 and AVU-G-I8-08,OR Order No.19-424.
kg)Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
\%A Docket No UE-190912,UG-I90920 .
ID Docket No AVU-E-18-12,AVU-G-I8-08
OR RG 81,Docket No ADV 1063(Advice No.19-10-G)
Concept:DescriptionAndPurposeOfOtherRegulatoryLiabilities
OR Docket No UM 2124.Deferral of associated state tax savings.
kU Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
WA Docket No.UG-170486
tD Docket No.AVU-E-23-01
W Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
AvisWs contribution in the Energy Assistance Fund as per ID Settlement Stipulation Case#AVU-E-19-04
(k)Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
Deferral of COVID-19 costs as per Idaho PUC Order No.34718,OR PUC Order No.20401,Docket UM 2069 and WA UTC Order No.01.Dockets UE-200407 and UG-200408.
I Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
WA Order 01,Dockets No UE-200895 and UG-200896,ID Case Nos.AVU-E-20-12 and AVU-G-20-07 Order No.34906,and OR Docket No UM 2124 Order No 21-131.
Accounting method change for federal income tax from normalization flow4hrough for Industry Director Directive No.5 mixed service costs and meters.
Lm)Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
Insurance proceeds for failed transformer at Coyote Springs per WA Order UE-210893 Order 01.
Ln)Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
Stale inome tax NOL earryforward will reverse over the period in which we are able to utilize the loss to offset taxable income on the ID,W.and OR tax returns.
U Concept:DescdptionAndPurposeOfOtherRegulatoryLiabilities
To defer costs ofcompiianee with the Climate Commitment Act in accordance with WAC 480-100-203(3)and WAC 480-90-203(3).WA Docket No UG-220803.
FERC FORM No.2(REV 12-07)
Page 278

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)El A Resubmission
Gas Operating Revenues
Revenues for Trans#'ron Revenues for Transaction Revenues for GRI and Revenues for GRI and
Line Title of Account Costs and Take-or-Pay CostsandTake-or-Fay ACA Amount for Current ACAAmountfor
No. (a) Amount for Current Year Amount for Previous Year Year ProviousYear
(b) (c) (d) (e)
1 (480)Residential Sales
2 (481)Commercial and Industrial Sales
3 (482)Other Sales to Public Authorities
4 (483)Sales for Resale
5 (484)Interdepartmental Sales
6 (485)Intracompany Transfers
7 (487)Forfeited Discounts
8 (488)Miscellaneous Service Revenues
9 (489.1)Revenues from Transportation of
Gas of Others Through Gathering Facilities
(489.2)Revenues from Transportation of
10 Gas of Others Through Transmission
Facilities
(489.3)Revenues from Transportation of
11 Gas of Others Through Distribution
Facilities
12 (489.4)Revenues from Storing Gas of
Others
13 (490)Sales of Prod.Ext.from Natural Gas
14 (491)Revenues from Natural Gas Proc.by
Others
15 (492)Incidental Gasoline and Oil Sales
16 (493)Rent from Gas Property
17 (494)Interdepartmental Rents
18 (495)Other Gas Revenues
19 Subtotal: 0 0 0 0
20 (496)(Less)Provision for Rate Refunds
21 TOTAL 0 I 0 0 0
FERC FORM No.2(REV 12-07)
Page 300

Gas Operating Revenues
Line Other Revenues Amount for Other Revenues Amount for Total Operating Revenues Total Operating Revenues Dehatherrn of Natural Gas
No. Current Year Previous Year Amount for Current Year Amount for Previous Year Amount for Current Year
(� (9) (h) (1) (I)
1 317,424,010 325,631,612 317,424,010 325,631,612 21,780,756
2 175,876,636 181,362,883 175,876,636 181,362,883 16,300,128
3 0 0 0 0 0
4 61,533,529 68,247,032 61,533,529 68,247,032 27,783,355
5 463,532 441,326 463,532 441,326 39,062
6 0 0 0 0
7 0 0 0 0
8 64,224 67,247 64,224 67,247
9 0 0 0 0 0
10 0 0 0 0 0
11 11,679,885 8,171,615 11,679,885 8,171,615 19,253,318
12 0 0 0 0 0
13 0 0 0 0
14 0 0 0 0
15 0 0 0 0
16 11,050 12,000 11,050 12,000
17 0 0 0 0
18 38,145,909 35,532,787 38,145,909 35,532,787
19 605,198.775 619,466,502 605,198,775 619,466,502
20 0 0 0 0
21 605,198,775 619,466,502 605,198,775 619,466,502
FERC FORM No.2(REV 12-07)
Page 300

Gas Operating Revenues
Gekathemi of Natural Gas AMvtiAi6rP4e�ir$%W
Line No. (k)
1 22.566,453
2 16,379,078
3 0
4 27,083,664
5 41,323
6
7
8
9 0
10 0
11 17.475,829
12 0
13
14
15
16
17
18
19
20
21
FERC FORM No.2(REV 12-07)
Page 300

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Other Gas Revenues(Account 495)
Line No. Descdptiefa 6fTrtzttsaet�ap — Amoin (hi iltif�rs)
_(a). (b) -
1 Commissions on Sale or Distribution of Gas of Others
2 Compensation for Minor or Incidental Services Provided for Others
3 Profit or Loss on Sale of Material and Supplies not Ordinarily Purchased for Resale
4 Sales of Stream,Water,or Electricity,including Sales or Transfers to Other Departments
5 Miscellaneous Royalties
6 Revenues from Dehydration and Other Processing of Gas of others except as provided for in
the Instructions to Account 495
7 Revenues for Right and/or Benefits Received from Others which are Realized Through
Research,Development,and Demonstration Ventures J_
8 Gains on Settlements of Imbalance Receivables and Payables
9 Revenues from Penalties earned Pursuant to Tariff Provisions,including Penalties Associated
with Cash-out Settlements
10 Revenues from Shipper Supplied Gas
11 Other revenues(Specify):
12 Misc Bills Revenue 497,016
13 CCA Allowance Revenue 19,965,465
14 Deferred Exchange Revenue 5,625,000
15 Deferred Decoupling Revenue 11,997,237
40 TOTAL 38,084,718
FERC FORM No.2(12-96)
Page 308

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:20241 Q4
(2)❑A Resubmission
Gas Operation and Maintenance Expenses
Line Account Amount for Current Year Amount for Previous Year
No. (a) (b) (c)
1 1.PRODUCTION EXPENSES
2 A.Manufactured Gas Production
3 Manufactured Gas Production(Submit Supplemental Statement)
4 B.Natural Gas Production
5 131.Natural Gas Production and Gathering �I
6 Operation
7 750 Operation Supervision and Engineering 0
8 751 Production Maps and Records 0
9 752 Gas Well Expenses 0
10 753 Field Lines Expenses 0
11 754 Field Compressor Station Expenses 0
12 755 Field Compressor Station Fuel and Power 0
13 756 Field Measuring and Regulating Station Expenses 0
14 757 Purification Expenses 0
15 758 Gas Well Royalties 0
16 759 Other Expenses 0
17 760 Rents 0
18 TOTAL Operation(Total of lines 7 thru 17) 0
19 Maintenance
20 761 Maintenance Supervision and Engineering 0
21 762 Maintenance of Structures and Improvements 0
22 763 Maintenance of Producing Gas Wells 0
23 764 Maintenance of Field Lines 0
24 765 Maintenance of Field Compressor Station Equipment 0
25 766 Maintenance of Field Measuring and Regulating Station 0
Equipment
26 767 Maintenance of Purification Equipment 0
27 768 Maintenance of Drilling and Cleaning Equipment 0
28 769 Maintenance of Other Equipment 0
29 TOTAL Maintenance(Total of lines 20 thru 28) 0
30 TOTAL Natural Gas Production and Gathering(Total of lines 18 and 0
29)
31 B2.Products Extraction
32 Operation
33 770 Operation Supervision and Engineering 0
34 771 Operation Labor 0
35 772 Gas Shrinkage 0
FERC FORM No.2(12-96)
Page 317

Gas Operation and Maintenance Expenses
Line Account
(a) NMI,
36 773 Fuel 0
37 774 Power 0
38 775 Materials 0
39 776 Operation Supplies and Expenses 0
40 777 Gas Processed by Others 0
41 778 Royalties on Products Extracted 0
42 779 Marketing Expenses 0
43 780 Products Purchased for Resale 0
44 781 Variation in Products Inventory 0
45 (Less)782 Extracted Products Used by the Utility-Credit 0
46 783 Rents 0
47 TOTAL Operation(Total of lines 33 thru 46) 0
48 Maintenance
49 784 Maintenance Supervision and Engineering 0
50 785 Maintenance of Structures and Improvements 0
51 786 Maintenance of Extraction and Refining Equipment 0
52 787 Maintenance of Pipe Lines 0
53 788 Maintenance of Extracted Products Storage Equipment 0
54 789 Maintenance of Compressor Equipment 0
55 790 Maintenance of Gas Measuring and Regulating Equipment 0
56 791 Maintenance of Other Equipment 0
57 TOTAL Maintenance(Total of lines 49 thru 56) 0
58 TOTAL Products Extraction(Total of lines 47 and 57) p
59 C.Exploration and Development
60 Operation
61 795 Delay Rentals 0
62 796 Nonproductive Well Drilling 0
63 797 Abandoned Leases 0
64 798 Other Exploration 0
65 TOTAL Exploration and Development(Total of lines 61 thru 64) 0
66 D.Other Gas Supply Expenses
67 Operation
68 800 Natural Gas Well Head Purchases 0
69 800.1 Natural Gas Well Head Purchases,Intracompany Transfers 0
70 801 Natural Gas Field Line Purchases 0
71 802 Natural Gas Gasoline Plant Outlet Purchases 0
72 803 Natural Gas Transmission Line Purchases 0
73 804 Natural Gas City Gate Purchases 181,582,033 287,111,521
74 804.1 Liquefied Natural Gas Purchases 0
FERC FORM No.2(12-96)
Page 317

Gas Operation and Maintenance Expenses
Line Account Amount for Current Year WPtievfousYbw
No. (a) (b) — (c)
75 805 Other Gas Purchases 0
76 (Less)805.1 Purchases Gas Cost Adjustments (76,799,217) (5,546,259)
77 TOTAL Purchased Gas(Total of lines 68 thru 76) 258,381,250 292,657,780
78 806 Exchange Gas 0
79 Purchased Gas Expenses
80 807.1 Well Expense-Purchased Gas 0
81 807.2 Operation of Purchased Gas Measuring Stations 0
82 807.3 Maintenance of Purchased Gas Measuring Stations 0
83 807.4 Purchased Gas Calculations Expenses 0
84 807.5 Other Purchased Gas Expenses 0
85 TOTAL Purchased Gas Expenses(Total of lines 80 thru 84) 0
86 808A Gas Withdrawn from Storage-Debit 13,798,600 36,449,990
87 (Less)808.2 Gas Delivered to Storage-Credit 7,785.790 25,933,582
88 809.1 Withdrawals of Liquefied Natural Gas for Processing-Debit 0
89 (Less)809.2 Deliveries of Natural Gas for Processing-Credit 0
90 Gas used in Utility Operation-Credit
91 810 Gas Used for Compressor Station Fuel-Credit 0
92 811 Gas Used for Products Extraction-Credit 908,059 597,452
93 812 Gas Used for Other Utility Operations-Credit 0
94 TOTAL Gas Used in Utility Operations-Credit(Total of lines 91 thru 908,069 597,452
93)
95 813 Other Gas Supply Expenses 32,380,278 46,258,884
96 TOTAL Other Gas Supply Exp.(Total of lines 77,78,85,86 thru 295,866,279 348,835,620
89,94,95)
97 TOTAL Production Expenses(Total of lines 3,30,58,65,and 96) 295,866,279 348,835,620
98 2.NATURAL GAS STORAGE,TERMINALING AND
PROCESSING EXPENSES
99 A.Underground Storage Expenses
100 Operation
101 814 Operation Supervision and Engineering 0
102 815 Maps and Records 0
103 816 Wells Expenses 0
104 817 Lines Expense 0
105 818 Compressor Station Expenses 0
106 819 Compressor Station Fuel and Power 0
107 820 Measuring and Regulating Station Expenses 0
108 821 Purification Expenses 0
109 822 Exploration and Development 0
110 823 Gas Losses 0
111 824 Other Expenses 939,896 1,035,406
FERC FORM No.2(12-96)
Page 317

Gas Operation and Maintenance Expenses
Line Account Amount for Current Year ArnountforpreviousYear
No. (a) (b) (c)
112 825 Storage Well Royalties 0
113 826 Rents 0
114 TOTAL Operation(Total of lines of 101 thru 113) 939,896 1,035,406
115 Maintenance
116 830 Maintenance Supervision and Engineering 0
117 831 Maintenance of Structures and Improvements 0
118 832 Maintenance of Reservoirs and Wells 0
119 833 Maintenance of Lines 0
120 834 Maintenance of Compressor Station Equipment 0
121 835 Maintenance of Measuring and Regulating Station Equipment 0
122 836 Maintenance of Purification Equipment 0
123 837 Maintenance of Other Equipment 2,601,197 2,107,953
124 TOTAL Maintenance(Total of lines 116 thru 123) 2,601,197 2,107,953
125 TOTAL Underground Storage Expenses(Total of lines 114 and 124) 3,541.093 3,143,359
126 B.Other Storage Expenses
127 Operation
128 840 Operation Supervision and Engineering 0
129 841 Operation Labor and Expenses 0
130 842 Rents 0
131 842.1 Fuel 0
132 842.2 Power 0
133 842.3 Gas Losses 0
134 TOTAL Operation(Total of lines 128 thru 133) 0
135 Maintenance
136 843.1 Maintenance Supervision and Engineering 0
137 843.2 Maintenance of Structures 0
138 843.3 Maintenance of Gas Holders 0
139 843.4 Maintenance of Purification Equipment 0
140 843.5 Maintenance of Liquefaction Equipment 0
141 843.6 Maintenance of Vaporizing Equipment 0
142 843.7 Maintenance of Compressor Equipment 0
143 843.8 Maintenance of Measuring and Regulating Equipment 0
144 843.9 Maintenance of Other Equipment 0
145 TOTAL Maintenance(Total of lines 136 thru 144) 0
146 TOTAL Other Storage Expenses(Total of lines 134 and 145) 0
147 C.Liquefied Natural Gas Temrinaling and Processing Expenses
148 Operation 009006
149 844.1 Operation Supervision and Engineering 0
150 844.2 LNG Processing Terminal Labor and Expenses 0
FERC FORM No.2(12-96)
Page 317

Gas Operation and Maintenance Expenses
Une Account AMajoltfor current Year Amount for Pm iousYear
(b) (c)
151 844.3 Liquefaction Processing Labor and Expenses 0
152 844.4 Liquefaction Transportation Labor and Expenses 0
153 844.5 Measuring and Regulating Labor and Expenses 0
154 844.6 Compressor Station Labor and Expenses 0
155 844.7 Communication System Expenses 0
156 844.8 System Control and Load Dispatching 0
157 845.1 Fuel 0
158 845.2 Power 0
159 845.3 Rents 0
160 845.4 Demurrage Charges 0
161 (less)845.5 Wharfage Receipts-Credit 0
162 845.6 Processing Liquefied or Vaporized Gas by Others 0
163 846.1 Gas Losses 0
164 846.2 Other Expenses 0
165 TOTAL Operation(Total of lines 149 thru 164) 0
166 Maintenance
167 847.1 Maintenance Supervision and Engineering 0
168 847.2 Maintenance of Structures and Improvements 0
169 847.3 Maintenance of LNG Processing Terminal Equipment 0
170 847A Maintenance of LNG Transportation Equipment 0
171 847.5 Maintenance of Measuring and Regulating Equipment 0
172 847.6 Maintenance of Compressor Station Equipment 0
173 847.7 Maintenance of Communication Equipment 0
174 847.8 Maintenance of Other Equipment 0
175 TOTAL Maintenance(Total of lines 167 thru 174) 0
176 TOTAL Liquefied Nat Gas Terminaling and Proc Exp(Total of lines 0
165 and 175)
177 TOTAL Natural Gas Storage(Total of lines 125,146,and 176) 3,541,093 3,143,359
178 3.TRANSMISSION EXPENSES
179 Operation
180 850 Operation Supervision and Engineering 0
181 851 System Control and Load Dispatching 0
182 852 Communication System Expenses 0
183 853 Compressor Station Labor and Expenses 0
184 854 Gas for Compressor Station Fuel 0
185 855 Other Fuel and Power for Compressor Stations 0
186 856 Mains Expenses 0
187 857 Measuring and Regulating Station Expenses 0
r188 858 Transmission and Compression of Gas by Others 0
FERC FORM No.2(12-96)
Page 317

Gas Operation and Maintenance Expenses
189 859 Other Expenses 0
190 860 Rents 0
191 TOTAL Operation(Total of lines 180 thru 190) 0
192 Maintenance
193 861 Maintenance Supervision and Engineering 0
194 862 Maintenance of Structures and Improvements 0
195 863 Maintenance of Mains 0
196 864 Maintenance of Compressor Station Equipment 0
197 865 Maintenance of Measuring and Regulating Station Equipment 0
198 866 Maintenance of Communication Equipment 0
199 867 Maintenance of Other Equipment 0
200 TOTAL Maintenance(Total of lines 193 thru 199) 0
201 TOTAL Transmission Expenses(Total of lines 191 and 200) 0
202 4.DISTRIBUTION EXPENSES
203 Operation
204 870 Operation Supervision and Engineering 3,365,057 3,333,244
205 871 Distribution Load Dispatching 0
206 872 Compressor Station Labor and Expenses 0
207 873 Compressor Station Fuel and Power 0
208 874 Mains and Services Expenses 8,854,434 10,210,439
209 875 Measuring and Regulating Station Expenses-General 255,792 253,322
210 876 Measuring and Regulating Station Expenses-Industrial 6.752 20,590
211 877 Measuring and Regulating Station Expenses-City Gas Check 108,066 91,988
Station
212 878 Meter and House Regulator Expenses 809,601 739,668
213 879 Customer Installations Expenses 2,100,686 9,861,398
214 880 Other Expenses 3,600,705 5,244,257
215 881 Rents (1,613) (1,461)
216 TOTAL Operation(Total of lines 204 thru 215) 19,099,480 29,753,445
217 Maintenance
218 885 Maintenance Supervision and Engineering 199,790 96,313
219 886 Maintenance of Structures and Improvements 0
220 887 Maintenance of Mains 1,530,480 1,670,494
221 888 Maintenance of Compressor Station Equipment 0
222 889 Maintenance of Measuring and Regulating Station Equipment- 539,274 650,541
General
223 890 Maintenance of Meas.and Reg.Station Equipment-Industrial 52,648 60,613
224 891 Maintenance of Meas.and Reg.Station Equip-City Gate Check 206,410 145,290
Station
225 892 Maintenance of Services 1,444,783 1,897,884
FERC FORM No.2(12-96)
Page 317

Gas Operation and Maintenance Expenses
Line Account AavmklbrC09941ear �kttt®tmtforP�.vidu5.Yew
No .. (a) (b) W
226 893 Maintenance of Meters and House Regulators 2,295,216 2,469.855
227 894 Maintenance of Other Equipment 322,834 631,912
228 TOTAL Maintenance(Total of lines 218 thru 227) 6,591,435 7,622,902
229 TOTAL Distribution Expenses(Total of lines 216 and 228) 25,690,915 37,376,347
230 5.CUSTOMER ACCOUNTS EXPENSES
231 Operation
232 901 Supervision 131,218 124,466
233 902 Meter Reading Expenses 594,847 613,160
234 903 Customer Records and Collection Expenses 8,383,455 8,017,053
235 904 Uncollectible Accounts 1,482,544 1,747,971
236 905 Miscellaneous Customer Accounts Expenses 169,867 255,262
237 TOTAL Customer Accounts Expenses(Total of lines 232 thru 236) 10,761,931 10,757,912
238 6.CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
239 Operation
240 907 Supervision 0
241 908 Customer Assistance Expenses 28,394,959 22,364,969
242 909 Informational and Instructional Expenses 810,619 786,208
243 910 Miscellaneous Customer Service and Informational Expenses 57,425 210,546
244 TOTAL Customer Service and Information Expenses(Total of lines 29,263,003 23,361,723
240 thru 243)
245 7.SALES EXPENSES
246 Operation
247 911 Supervision 0
248 912 Demonstrating and Selling Expenses 260
249 913 Advertising Expenses 536 0
250 916 Miscellaneous Sales Expenses (5)
251 TOTAL Sales Expenses(Total of lines 247 thru 250) 536 255
252 8.ADMINISTRATIVE AND GENERAL EXPENSES
253 Operation
254 920 Administrative and General Salaries 12,524,097 13,189,888
255 921 Office Supplies and Expenses 1,553,940 1,667,382
256 (Less)922 Administrative Expenses Transferred-Credit 16,088 19,248
257 923 Outside Services Employed 6,397,565 6,089,644
258 924 Property Insurance 1,065,859 964,898
259 925 Injuries and Damages 3,696,174 2,758,757
260 926 Employee Pensions and Benefits 11,714,208 11,106,187
261 927 Franchise Requirements 0
262 928 Regulatory Commission Expenses 2,931,344 2,834,410
263 (Less)929 Duplicate Charges-Credit 0
FERC FORM No.2(12-96)
Page 317

Gas Operation and Maintenance Expenses
Llne Account Amount for Current Year Amount for Previous Year
No. (a) (b) (c)
264 930.1 General Advertising Expenses (1) 15
265 930.2Miscellaneous General Expenses 2,285,963 2.496,206
266 931 Rents 206,219 215,230
267 TOTAL Operation(Total of lines 254 thru 266) 42,359,280 41,303,369
268 Maintenance
269 932 Maintenance of General Plant 5,423,087 5,542,623
270 TOTAL Administrative and General Expenses(Total of lines 267 and 269) 47,782,367 46,845,992
271 TOTAL Gas O&M Expenses(Total of lines 412,906,124 470,321,208
97,177,201,229,237,244,251,and 270)
FERC FORM No.2(12-96)
Page 317

Name of Respondent: This report is:
(1)0 An Original Date of Report: Year/Period of Report:
Corporation 04/18/2025 End of:2024/Q4
Avista Co
(2)❑A Resubmission
Gas Used in Utility Operations
Line J&Purpose for Which Gas Was Used Account Chargod Natural Gas Gas Used Dth Natural Gas Amount of Credit(in
dollars)
No. - (aj (b) (c) (d)
1 810 Gas Used for Compressor Station Fuel-Credit 2,323,025
2 811 Gas Used for Products Extraction-Credit -43,032,127 908,059
3 Gas Shrinkage and Other Usage in Respondent's Own
Processing-Credit
4 Gas Shrinkage,etc.for Respondent's Gas Processed by
Others-Credit
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25 Total 45,355,152 908,059
FERC FORM No.2(12-96)
Page 331

Name of Respondent: This report is:
(1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)ElA Resubmission 04/18/2025 End of:2024/Q4
FOOTNOTE DATA
Laj Concept:QuantityOfNaturalGasDeliveredByRespondentGasUsedForProductsExtraction
Represents the amount of processed gas run through the plant.
FERC FORM No.2(12-96)
Page 331

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)❑A Resubmission
Other Gas Supply Expenses(Account 813)
Amount(in dollars)
(b)
1 Gas Resource Management and Regulatory Affairs Labor 1,240,514
2 Gas Resource Management and Regulatory Affairs Overhead 310,359
3 Gas Resourcement Management Other Expenses(professional services,travel, 176,490
transportation,supplies,training)
4 Regulatory Affairs Other Expenses(Gas Technical Institute) 192,748
5 Climate Commitment Act Obligations 30,460,167
25 Total 32,380,278
FERC FORM No.2(12-96)
Page 334

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Miscellaneous General Expenses(Account 930.2)
Line No. Description Amount
(a) (b)
1 Industry association dues. 523,256
2 Experimental and general research expenses
2a a.Gas Research Institute(GRI)
2b b.Other
Publishing and distributing information and reports to stockholders,trustee,registrar,and
3 transfer agentfees and expenses,and other expenses ofservicing outstanding securities of 318,812
the respondent
4 Board of Director Activities 616,879
5 Community Relations 179,060
6 Education,Information&Training 247,782
7 Emergency Operating Procedure Events 28,503
8 Misc.Employee Expenses 22,337
9 Misc.Labor 182,118
10 Misc.Legal,Professional,and General Services 76,422
11 Misc.Transportation 75,169
12 Other Misc.Expenses<$5k 15,625
r25 TOTAL 2,285,963
FERC FORM No.2(12-96)
Page 335

Name of Respondent: This report is: Date of Report: Year/Period of Report:
(1)®An Original
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/04
Depreciation,Depletion and Amortization of Gas Plant(Accts 403,404.1,404.2,404.3,405)(Except Amortization of Acquisition Adjustments)
Amortization and' Amortization of
Depreciation Expense Amortization Expense for Depletion of Producing Underground Storage
Line Functional Classification Asset Retirement Costs Natural Gas Land and
No_ (a) (Account403) (Account403.1) Rights(Account Land and Land Rights
(b) (Account404.2)
(c) AMML404.11) (e)
d)
Section A.Summary of Depreciation,Depletion,and Amortization Charges
1 Intangible plant
2 Production plant,manufactured gas
3 Production and Gathering Plant
4 Products extraction plant
5 Underground Gas Storage Plant(footnote 927,140
details)
6 Other storage plant
7 Base load LNG terminaling and processing
plant
8 Transmission Plant
9 Distribution plant 36,607,923
10 General Plant(footnote details) 1,760,385
11 Common plant-gas 6,758,393
12 Total 46,053,841
FERC FORM No.2(12-96)
Page 336

Depreciation,Depletion and Amortization of Gas Plant(Accts 403,404.1,404.2,404.3,405)(Except Amortization of Acquisition Adjustments)
-— - —
Ltne A ��-- —- - ---- --th,-- - - —
tti+e✓ttizattott of QtileT WmttQd te►m Gas Plant
(Account404 3} Amo mi'o Qih�tTt %l;o* tt
No. 405) Total(b to 0}'
- --
Section A.Summary of Depreciation,Depletion,and Amortization Charges
1 472,563 472,563
2
3
4
5
927,140
6
7
8
9
36,607,923
10
1,760,385
11 15,059,615 21,818,008
12 15,532,178 61,586,019
FERC FORM No.2(12-96)
Page 336

i
Name of Respondent: This report is: Date of Report: Year/Period of Report:
(1)®An Original
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
Depreciation,Depletion and Amortization of Gas Plant(Accts 403,404.1,404.2,404.3,405)(Except Amortization of Acquisition Adjustments)
Line Functional Classification Plant Bases(in thousands) _ AppBod DeprocIfWon or
No. (a) (b) Amortization Rates(percent)
(c)
Section B.Factors Used in Estimating Depreciation Charges
1 Production and Gathering Plant
2 Offshore(footnote details)
3 Onshore(footnote details)
4 Underground Gas Storage Plant(footnote details)
5 Transmission Plant
6 Offshore(footnote details)
7 Onshore(footnote details)
8 General Plant(footnote details)
9
10
11
[14
15
FERC FORM No.2(12-96)
Page 338

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/1
(2) A Resubmission
8/2025 End of:2024/04
❑
Particulars Concerning Certain Income Deductions and Interest Charges Accounts
Line No: Item Amount
1 Account 425-Miscellaneous Amortization
2 Items under$250,000 5,617
3 TOTAL Account 425-Miscellaneous Amortization 5,617
4 Account 426.1-Donations
5 Avista Stadium Sponsorship 400,000
6 Items under$250,000 2,407,938
7 TOTAL Account426.1-Donations 2,807,938
8 Account426.2-Life Insurance
9 Officers Life 156.937
10 SERP 1,721.326
11 Officers Life Cash Value and Interest-Net 441,060
12 Items under$250,000 171,870
13 TOTAL Account 426.2-Life Insurance 2,491,193
14 Account 426.3-Penalties
15 Items under$250,000 41,895
16 TOTAL Account 426.3-Penalties 41,895
17 Account426.4 Expenditures for Certain Civic,Political,and Related Activities
18 Items under$250,000 1,728,138
19 Total Account426.4-Expenditues for Certain Civic,Political,and Related Activities 1,728,138
20 Account 426.5-Other Deductions
21 Executive Deferred Compensation 1,865,739
22 Items under$250,000 615,113
23 TOTAL Account 426.5-Other Deductions 2,480,852
24 Account 430-Interest on Debt to Associated Companies
25 Avista Capital II(variable rate ranged from 5.46 to 6.51 percent) 2,575,297
26 TOTAL Account 430-Interest on Debt to Associated Companies 2,575,297
27 Account 431-Other Interest Expense
28 Interest on Electric Deferrals 1,651,115
29 Interest on Gas Deferrals 3,556,378
30 Interest on ST Borrowings 18,075,246
31 Interest on South Lake CDA (327,528)
32 Interest on Transmission Deposits 612,079
33 Items under$250,000 41,602
34 TOTAL Account 431-Other Interest Expense 23,608,892
FERC FORM No.2(12-96)
Page 340

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)El A Resubmission
Regulatory Commission Expenses(Account 928)
Description(Furnish name of roguiatory Assessed by Regulatory RefetsOd in Account
Line commission or body the docket or care Commission Expenses of Utility Tot it Expenses to Date 182.3 3t Beginning of No. number and a description of the case) (c) (d) Year
(a) (b) (e)
Federal Energy Regulatory Commission-
Charges include annual fee and license
1 fees for the Spokane River Project,the 3,796,836 198,558 3,995,394
Cabinet Gorge Project and the Noxon
Rapids Project
2 Not directly assigned Electric 773,990 773,990
3 Not directly assigned Natural Gas 320,686 320.686
4 Washington Utilities and Transportation 0
Commission
5 Electric-Includes annual fee and various 2,462,995 674,807 3,137,802 1,264,383
other electric dockets
6 Gas-Includes annual fee and various other 1,035,092 165,232 1,200,324 571.217
natural gas dockets
7 Idaho Public Utilities Commission 0
8 Electric-Includes annual fee and various 621,446 208,785 830,231
other electric dockets
9 Gas-Includes annual fee and various other 229,886 39,137 269,023
natural gas dockets
10 Public Utility Commission of Oregon 0
11 Includes annual fees and various other 907,658 233,653 1,141,311 79,816
natural gas dockets
25 TOTAL 9,053,913 2,614,848 11,668,761 1,915,416
FERC FORM No.2(12-96)
Page 350

Regulatory Commission Expenses(Account 928)
Expenses
Incurred Amortized
During Year Expenses Incurred Expenses incurred During Year
arge
Line Expenses Incurred During Year Charged Currently To Department Chd During Year Charged During Year Deferred Contra
No. (f) Currently To Amount to Account 182.3
Currently To Account
Account No. (h) ��) �)
(g)
1 Electric 928 3,995,394
2 Electric 928 773,990
3 Gas 928 320,686
4
5 Electric 928 3,137,802 1.421,566 407
6 Gas 928 1,200,324 754,157 407
7
8 Electric 928 830,231
9 Gas 928 269,023
10
11 Gas 928 1,141,311 36,731 407
25 11,668,761 2,212,454
FERC FORM No.2(12-96)
Page 350

Regulatory Commission Expenses(Account 928)
A noriliedBuritmf I&ArAmount Deferred-in Account 182.3 End of Year
L.ineft. (k) (9
1 0
2 0
3 0
4 0
5 2,685,949
6 1,325,374
7 0
8 0
9 0
10 0
11 86.100 30,447
P5 86,100 4,041,770
FERC FORM No.2(12-96)
Page 350

This report is:
Name of Respondent: (1){/]An Original Date of Report: Year/Period of Report:
Avista Corporation (2) AResubmission
04/18/2025 End of:2024/Q4
❑
Employee Pensions and Benefits(Account 926)
Line No. Expense Amount(fn dollars)
(a) (b)
1 Pensions-defined benefit plans 7,156,922
2 Pensions-other 0
3 Post-retirement benefits otherthan pensions(PBOP) 4,358,908
4 Post-employment benefit plans 0
5 Health Insurance and Benefits 38,921,607
6 401(K)Savings Plan 16,064.906
7 Employee Education 1,414,492
8 Other 637,073
9 Allocated to Electric and other expense accounts (56,839,700)
r4O Total
11,714,208
FERC FORM No.2(NEW 12-07)
Page 352

Name of Respondent: This report is:
(1){a An Original Date of Report: Year/Period of Report:
04/18/2025 End of:2024/Q4
Avista Corporation
(2)❑A Resubmission
Distribution of Salaries and Wages
Line Classification Dl=tPuyroll Payroll Billed by `^
No. (i) Distribution Af iliatod Companies el
(b) (e) (el)
1 Electric
2 Operation AM
3 Production 15,700,218 15,700,218
4 Transmission 5,892,185 5,892,185
5 Distribution 12,378,149 12,378,149
6 Customer Accounts 7,095,274 7,095,274
7 Customer Service and Informational 349,066 349,066
8 Sales 0 0
9 Administrative and General 31,629,021 7,827,270 39,456,291
10 TOTAL Operation(Total of lines 3 thru 9) 73,043,913 l 7,827,270 80,871,183
11 Maintenance
12 Production 4,398,381 4,398,381
13 Transmission 895,333 895,333
14 Distribution 4,431,644 4,431,644
15 Administrative and General 0 0
16 1 TOTAL Maintenance(Total of lines 12 thru 9,725,358 9,725,358
17 Total Operation and Maintenance
18 Production(Total of lines 3 and 12) ` 20,098,599 20,098,599
19 Transmission(Total of lines 4 and 13) I 6,787,518 6,787,518
20 Distribution(Total of lines 5 and 14) 111 16,809,793 16,809,793
21 Customer Accounts(line 6) 7,095,274 7,095,274
22 Customer Service and Informational(line 349,066 349,066
7)
23 Sales(line 8) 0 0
24 Administrative and General(Total of lines 31,629,021 7,827,270 39,456,291
9 and 15)
25 TOTAL Operation and Maintenance(Total 82,769,271 7,827,270 90,596,541
of lines 18 thru 24)
26 Gas
27 Operation
28 Production-Manufactured Gas
29 Production-Natural Gas(Including
Exploration and Development)
30 Other Gas Supply 1,240,514 1,240,514
31 Storage,LNG Terrninaling and Processing
32 Transmission 0
33 Distribution 7,466,749 7,466,749
FERC FORM No.2(REVISED)
Page 354

Distribution of Salaries and Wages
ML
Direct Payroll Payroll Billed by Allocation of Payroll
CtJssification Distribution Affiliated Compadles Charged for Clearing Total
a) (b) (c) Accounts (e)
(d)
*34CustomerAcco..t.unts 3,044,179 3,044,179
35 Customer Service and Informational 176,702 176,702
36 Sales
37 Administrative and General 12,015.074 1,711,691 13,726,765
38 TOTAL Operation(Total of lines 28 thru 37) 23,943,218 1,711,691 25,654,909
39 Maintenance
40 Production-Manufactured Gas
41 Production-Natural Gas(Including
Exploration and Development)
42 Other Gas Supply 0
43 Storage,LNG Tenninaling and Processing
44 Transmission 2,386,026 2,386,026
45 Distribution 3,217,694 3,217,694
46 Administrative and General 0
47 TOTAL Maintenance(Total of lines 40 thru 5,603,720 5,603,720
46)
49 Total Operation and Maintenance
50 Production-Manufactured Gas(Total of
lines 28 and 40)
51 Production-Natural Gas(Including Expl.
and Dev.)(II.29 and 41)
52 Other Gas Supply(Total of lines 30 and 1,240,514 1,240,514
42)
53 Storage,LNG Tenminaling and Processing
(Total of 11.31 and 43)
54 Transmission(Total of lines 32 and 44) 2,386,026 2,386.026
55 Distribution(Total of lines 33 and 45) 10,684,443 10,684,443
56 Customer Accounts(Total ofline 34) 3,044,179 3,044,179
57 Customer Service and Informational(Total of line 35) 176,702 176,702
58 Sales(Total of line 36)
59 Administrative and General(Total of lines 12,015,074 1,711,691 13,726,765
37 and 46)
60 Total Operation and Maintenance(Total of 29,546,938 1,711,691 31,258,629
lines 50 thru 59)
61 Other Utility Departments
62 Operation and Maintenance 0
63 TOTALALL Utility Dept.(Total of lines 25, 112,316,209 9,538,961 121.855,170
60,and 62)
64 Utility Plant
65 Construction(By Utility Departments)
66 Electric Plant 59,034,485 7,104,286 66,138.771
67 Gas Plant 16,885,126 2,031,978 18,917,104
FERC FORM No.2(REVISED)
Page 354

Distribution of Salaries and Wages
Dircct Payroll Payroll Baled by Allocation of Payroll
c Charged
Distribution Affiliated Companies A for Clearing Total
Accounts (e)
(d)
68 Other 0
69 TOTAL Construction(Total of lines 66 thru 75,919,611 0 9,136,264 85,055,875
68)
70 Plant Removal(By Utility Departments)
71 Electric Plant 2,463,236 131,593 2,594,829
72 Gas Plant 895,249 47,826 943,075
73 Other 0
74 TOTAL Plant Removal(Total of lines 71 3,358,485 0 179,419 3,537,904
thru 73)
75.1 Stores Expense(163) 3,068,445 (3,068,445) 0
75.2 Preliminary Survey and Investigation(183) 0 0
75.3 Small Tool Expense(184) 5,550,716 (5,550,716) 0
75.4 Miscellaneous Deferred Debits(186) 3,422,254 3,422,254
75.5 Non-operating Expenses(417) 437,167 437,167
75.6 Retirement Bonus/SERP/HRA(228) 10,199 10,199
75.7 Other Income Deductions(426) 1,128,800 1,128,800
75.8 Employee Incentive Plan(232380) 7,746,717 (7,746,717) 0
75.9 DSM Tariff Rider(242600) 2,488,766 (2,488,766) 0
75.10 Incentive/Stock Compensation(238000) 0 0
75.11 Payroll Equalization Liability(242700) 33,241,787 33,241,787
75.12 Miscellaneous Deferred Credits(253) 7,219 7,219
76 TOTALOtherAccounts 57,102.070 0 (18,854,644) 38,247,426
77 TOTAL SALARIES AND WAGES 248,696,375 0 0 248,696,375
FERC FORM No.2(REVISED)
Page 354

This.report is:®
Name of Respondent: (1) An Original Date of Report: Year/Period of Report
Avista Corporation (2)El A Resubmission 0411 8/2 02 5 End of.2024/Q4
Charges for Outside Professional and Other Consultative Services
Line No. Description Amount(In dollars)
a (b)
1 VOLT MANAGEMENT CORP 19,413,441
2 MICHELS PIPELINE INC 14,842,259
3 NPL CONSTRUCTION CO 13,579,033
4 ASPLUNDH TREE EXPERT LLC 13,373,980
5 INTERNATIONAL LINE BUILDERS INC 12,585,611
6 SLAYDEN CONSTRUCTORS INC 12,384,268
7 BOUTEN CONSTRUCTION COMPANY 8,630,469
8 WILSON CONSTRUCTION COMPANY 8.483,485
9 WRIGHT TREE SERVICE INC 5,681,686
10 ONE CALL LOCATORS LTD 5,586,329
11 PERFECTION TRAFFIC CONTROL LLC 4,370,736
12 BLACK&VEATCH CORPORATION 3,724,330
13 IBM CORPORATION 3,562,473
14 SCHNABEL ENGINEERING LLC 3,238,160
15 NAGARRO INC 2,937,278
16 HENKELS&MCCOY WEST 2,813,258
17 GARCO CONSTRUCTION INC 2,738,255
18 POTELCOINC 2,720,599
19 TRAFFIC CONTROL SERVICES LLC 2,713,866
20 HYDROMAX USA LLC 2,710,480
21 SPOKANE TRAFFIC CONTROL INC 2,519,762
22 CASCADE CABLE CONSTRUCTORS INC 2,415,147
23 WALKER INDUSTRIES LLC 2,316,378
24 HEATH CONSULTANTS INCORPORATED 2,275,954
25 PANOAI INC 2,190,000
26 COMMERCIAL GRADING INC 2,154,610
27 DELOITTE 1,977,000
28 KNIGHT CONSTRUCTION&SUPPLY INC 1,884,982
29 UTILITY SOLUTIONS PARTNERS LLC 1.799,409
30 NOBLE EXCAVATING INC 1,778,755
31 INTELLITECT 1,760,570
32 PALOUSE POWER LLC 1,681,329
33 BCI CONSTRUCTION USA INC 1,669,498
34 TRAFFICORP 1,667,596
35 GAS TRANSMISSION NORTHWEST LLC 1,493,129
36 GE ENERGY MANAGEMENT SERVICES LLC 1,466,649
FERC FORM No.2(REVISED)
Page 357

Charges for Outside Professional and Other Consultative Services
Line No. Description Amount(in dollars)
(a) (b)
37 GE RENEWABLES US LLC 1,466,125
38 PER SE GROUP INC 1,404,782
39 SUNRISE ENGINEERING LLC 1,383,162
40 ASSOCIATED ARBORISTS 1,335,906
41 CENTERLINE DRILLING INC 1,300,885
42 NORTHWEST PIPELINE CORPORATION 1,289,078
43 EOCENE ENVIRONMENTAL GROUP OF THE WEST INC 1,255,855
44 AAA SWEEPING LLC 1,221,452
45 HILL INTERNATIONAL INC 1,207.701
46 CURRY INC 1,201,230
47 COLVICO INC 1,195,057
48 ARBORMETRICS SOLUTIONS LLC 1,172,778
49 POWER ENGINEERS INC 1,109,452
50 HDR ENGINEERING INC 1,085,025
51 RESSA&SON CONSTRUCTION LLC 1,060,744
52 NEURAFLASH LLC 1,053,706
53 NV5 GEOSPATIAL INC 1,020,576
54 LEDFORD CONSTRUCTION COMPANY 1,011,457
55 COEUR D ALENE TRIBE 958,695
56 CRUX SUBSURFACE INC 916,955
57 INTERSTATE CONCRETE&ASPHALT 914,681
58 MICHELS UTILITY SERVICES INC 888,217
59 FUJITSU NORTH AMERICA INC 878,221
60 STANTEC CONSULTING SERVICES INC 851,903
61 INTEC SERVICES INC 847,303
62 POWER CITY ELECTRIC INC 837,341
63 POE ASPHALT PAVING INC 833,991
64 CDW DIRECT 820,325
65 SNAP 794,669
66 RYAN LLC 792,759
67 DAY WIRELESS SYSTEMS 788,182
68 COMMONWEALTH ASSOCIATES INC 750,589
69 TITAN ELECTRIC INC 734,137
70 UTILITY CONSTRUCTION INSPECTION LLC 733,625
71 STEELHEAD MECHANICAL LLC 724,564
72 RANDALL DANSKIN ATTORNEYS 703,136
73 HANNA&ASSOCIATES INC 697,505
74 KASCO OF IDAHO LLC 660,691
75 AVANTE PARTNERS 646,235
FERC FORM No.2(REVISED)
Page 357

Charges for Outside Professional and Other Consultative Services
176 or EVANS AND ASSOCIATES INC 633,981
77 ACTALENT SERVICES LLC 629,640
78 PAINE HAMBLEN LLP 612,969
79 EBS INC 608,028
80 NORTH AMERICAN SUBSTATION SERVICES LLC 574,818
81 CARPI USA INC 571,610
82 KW ENERGY LLC 541,756
83 BAKER BOTTS LLP 534,071
84 DXC TECHNOLOGY SERVICES LLC 533,292
85 ABSCO SOLUTIONS 513,740
86 BOYER LAND DEVELOPMENT INC 481,680
87 BARNHART CRANE AND RIGGING CO 474,993
88 ROBINSON BROTHERS CONSTRUCTION INC 440,266
89 WESTERN POWER POOL 438.952
90 NEW EDGE INC 437,970
91 GE STEAM POWER INC 437,572
92 HICKEY BROTHERS RESEARCH LLC 437,508
93 PRO BUILDING SYSTEMS INC 434,529
94 UI SOLUTIONS GROUP 433,870
95 CN UTILITY CONSULTING INC 428,297
96 CIRRUS DESIGN INDUSTRIES INC 415,164
97 HELVETICKA INC 402,319
98 JENSENS TREE SERVICE INC 392,995
99 DHISOFT SOLUTIONS 391,829
100 COLEMAN ENVIRONMENTAL ENGINEERING INC 389,000
101 TAILORED SOLUTIONS LLC 368,599
102 NUVODIALLC 364,315
103 VERDIS 352,964
104 SLALOM INC 350,300
105 CANNON HILL INDUSTRIES INC 345,085
106 DW EXCAVATING INC 339,778
107 STOEL RIVES LLP 338,373
108 BOILER TUBE COMPANY OF AMERICA 338,001
109 SKYVIEW CONSTRUCTION COMPANY 337,150
110 IDAHO DEPT OF FISH&GAME 336,888
111 VERDANTAS 333,622
112 LANDAU ASSOCIATES 328,580
rl3 ACKERMAN HEATING AND AIR CONDITIONING 317,329
FERC FORM No.2(REVISED)
Page 357

Charges for Outside Professional and Other Consultative Services
Line No. Description Amount(in dollars)
(a) (b)
114 NEELBLUE TECHNOLOGIES CONSULTING INC 316,767
115 FOUR PEAKS ENVIRONMENTAL SCIENCE 315,352
116 MAVELAMERICAS INC 311,743
117 H2E INC 309,280
118 D W POLEHOLE 307,567
119 LIGHTHOUSE DOCUMENT TECHNOLOGIES INC 307,471
120 ONE SIXTEEN&WEST 300,136
121 PROLEC GE WAUKESHA INC 297,919
122 MESA PRODUCTS INC 297,175
123 AVCO CONSULTING INC 296.548
124 ARC OF SPOKANE 290,022
125 SPOKANE PRO CARE INC 277.637
126 RTI INTERNATIONAL 275,078
127 CERIUM NETWORKS 270,593
128 TROUTLODGE INC 262,090
129 GEOENGINEERS INC 260,794
130 BRENT WOODWARD INC 258,861
131 INGENIUM GROUP LLC 258,536
132 COMPUNET INC 256,649
133 WORLD WIDE TECHNOLOGY LLC 253,783
134 COFFMAN ENGINEERS 252,633
135 OPEN ENERGY SOLUTIONS INC 251,788
136 FIRE DAWG GREEN INC 251,136
137 OTHER<$250,000 27,995,764
138 TOTAL 266,806,614
FERC FORM No.2(REVISED)
Page 357

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of.2024/Q4
Transactions with Associated(Affiliated)Companies
Account(s)
Line Description of the Good or Service Name of Associated/Affiliated Company Charged or Amount Charged or Credited
No. (a) (b) Credited (d)
(c)
1 Goods or Services Provided by Affiliated
Company
19 TOTAL
20 Goods or Services Provided for Affiliated
Company - •- r
21 Corporate Support *Development 146000 35.563
22 Corporate Support Avista Capital 146000 76.304
23 Corporate Support AELP 146000 41,534
24 Corporate Support AJT Mining 146000 1,205
25 Corporate Support Avista Edge 146000 2,352
40 TOTAL 156,958
FERC FORM No.2(NEW 12-07)
Page 358

Name of Respondent: This report is: Date of Report: Year/Period of Report:
(1)®An Original
Avista Corporation (2)❑A Resubmission 04/18/2025 End of:2024/Q4
Gas Storage Projects
Gas Belonging to ReOpoiident
Item Gas Belonging to Others(DW) i
ai A
(Oth) (c)
STORAGE OPERATIONS(in Dth)
1 Gas Delivered to Storage
2 January 243,753 243,753
3 February 15,887 15,887
4 March 1,012,380 1,012,380
5 April 1,226,356 1.226,356
6 May 2,293,091 2,293,091
7 June 821,956 821,956
8 July 702,714 702,714
9 August 354,191 354,191
10 September 281,809 281,809
11 October 232,603 232,603
12 November 154,617 154,617
13 December 133,935 133,935
14 TOTAL(Total of lines 2 thru 13) 7,473,292 0 7,473,292
15 Gas Withdrawn from Storage
16 January 2,533,429 2,533,429
17 February 1,217,800 1,217,800
18 March 822,118 822,118
19 April 525,121 525,121
20 May 6,098 6,098
21 June 70,625 70,625
22 July 479,761 479,761
23 August 52,735 52,735
24 September 40,471 40,471
25 October 308,385 308,385
26 November 341,785 341,785
27 December 669,515 669,515
28 TOTAL(Total of lines 16 thru 27) 7,067,843 0 7,067,843
FERC FORM No.2(12-96)
Page 512

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/04
(2)❑A Resubmission
Gas Storage Projects
Line No. Item Total Amount
(a) (b)
STORAGE OPERATIONS
1 Top or Working Gas End of Year 8.528,000
2 Cushion Gas(Including Native Gas) 7,730,668
3 Total Gas in Reservoir(Total of line 1 and 2) 16,258,668
4 Certificated Storage Capacity
5 Number of Injection-Withdrawal Wells 42
6 Number of Observation Wells 34
7 Maximum Days'Withdrawal from Storage 237,070
8 Date of Maximum Days'Withdrawal 01/12/2024
9 LNG Terminal Companies(in Dth)
10 NumberofTanks
11 Capacity of Tanks
12 LNG Volume
13 Received at"Ship Rail"
14 Transferred to Tanks
15 Withdrawn from Tanks
16 "Boil Off'Vaporization Loss
FERC FORM No.2(12-96)
Page 513

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation 04/18/2025 End of:2024/Q4
(2)El A Resubmission
Auxiliary Peaking Facilities
-- - - - Was Facility
Dolly Delivery Cost of Facility(in Operatrd on
Line Location of Facility Type of Facitify Day of Highest
No. (a) (b) of Facility Dth dollars) Transmission
(c) (d) Peak Delivery?
(e)
1 Chehalis,Washington Underground Natural Gas Storage Field: 346,667 54,733,772 true
WA&ID Supply
2 Chehalis,Washington Underground Natural Gas Storage Field; 52,000 7,937,429 true
OR Supply
3 Chehalis,Washington Underground Natural Gas Storage Field; 2,654 true
OR Supply
u
4 Rock Springs,Wyoming Underground Natural Gas Storage Field; false
WA&ID Supply
w
5 Rock Springs,Wyoming Underground Natural Gas Storage Field; false
OR Supply
FERC FORM No.2(12-96)
Page 519

This report is:
Name of Respondent: (1)0 An Original Date of Report Year/Pedod of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
FOOTNOTE DATA
La)Concept:AuxiliaryPeakingFacilitesTypeOfFacility
Avista is a participant In the facilities,not an owner and is charged a fee for demand deliverability and capacity.
Lb.)Concept:AuxiliaryPeakingFacilitiesTypeOfFacility
Avista does not have fine rights but has interruptible access to it.
fc.)Concept:AuxiliaryPeakingFacilitiesTypeOfFacility
vista does not have firm rights but has interruptible access to it.
FERC FORM No.2(12-96)
Page 519

This report is:
Name of Respondent: (1)®An Original Date of Report: Year/Period of Report:
Avista Corporation (2)El A Resubmission 04/18/2025 End of:2024/Q4
Gas Account-Natural Gas
Ref.Page No.of Current Three Months Ended
Line Item (FERC Form Nos. Told Amount of Dth Year to Date Amount of Dth Quarterly
(a) 2/2-A) (c) Only
(b) (d)
1 Name of System Avista Storage
2 GAS RECEIVED
3 Gas Purchases(Accounts 800-805) 67,214,023 19,517,824
Gas of Others Received for Gathering(Account
4 489.1) 7303
5 Gas of Others Received for Transmission 305
(Account 489.2)
6 Gas of Others Received for Distribution(Account 301 19,253,318 4,825,135
489.3)
7 Gas of Others Received for Contract Storage 307
(Account 489.4)
Gas of Others Received for
8 Production/Extraction/Processing(Account490
and 491)
9 Exchanged Gas Received from Others(Account 328
806)
10 Gas Received as Imbalances(Account 806) 328 (27,150) (100,501)
11 Receipts of Respondents Gas Transported by 332
Others(Account 858)
12 Other Gas Withdrawn from Storage(Explain) (390,293) 798,530
13 Gas Received from Shippers as Compressor
Station Fuel
14 Gas Received from Shippers as Lost and
Unaccounted for
15 Other Receipts(Specify)(footnote details)
16 Total Receipts(Total of lines 3 thru 15) 86,049,898 25,040,988
17 GAS DELIVERED
18 Gas Sales(Accounts 480-484) 65,903,300 19.995,016
19 Deliveries of Gas Gathered for Others(Account 303
489.1)
20 Deliveries of Gas Transported for Others(Account 305
489.2)
21 Deliveries of Gas Distributed for Others(Account 301 17,823,573 4,509,202
489.3)
22 Deliveries of Contract Storage Gas(Account 307
489.4)
Gas of Others Delivered for
23 Production/Extraction/Processing(Account490
and 491)
24 Exchange Gas Delivered to Others(Account 806) 328
25 Gas Delivered as Imbalances(Account 806) 328
26 Deliveries of Gas to Others for Transportation 332
(Account858)
27 Other Gas Delivered to Storage(Explain)
FERC FORM No.2(REV 01-11)
Page 520

Gas Account-Natural Gas
Ref.Page No.of Current Three Months Ended
Line Item (FERC Form Nos. Total Amount of Dth Year to Date Amount of Dth Quarterly
No. (a) 212-A) (c) Only
(b) (d)
28 Gas Used for Compressor Station Fuel 509 2,323.025 536,770
Other Deliveries and Gas Used for Other
29 Operations
30 Total Deliveries(Total of lines 18 thru 29) 86,049,898 25,040,988
31 GAS LOSSES AND GAS UNACCOUNTED FOR
32 Gas Losses and Gas Unaccounted For
33 TOTALS
34 Total Deliveries,Gas Losses&Unaccounted For 86,049,898 25,040,988
(Total of lines 30 and 32)
FERC FORM No.2(REV 01-11)
Page 520