2020Annual Report Gas.pdf

THIS FILING IS
Item 1: E An lnitial(Original)
Submission
OR E Resubmission No. _
Form 2 Approved
OMB No.1902-0028
(Expires 1213112021)
Form 3-Q Approved
OMB No.1902-0205
(Expires 1113012022)
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FERC FINANGIAL REPORT
FERG FORM No.2: Annual Report of
Major Natural Gas Gompanies and
Supplemental Form 3-Q: Quarterly
Financial Report
These reports are mandatory under the Natural Gas Act, Sections 10(a), and 16 and 'l 8
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 consider these reports to be of a confidential nature.
Exact Legal Name of Respondent (Company)
Avista Corporation
Year/Period of Report
End of 20201Q4
FERC FORM No.2/3Q (02-04)
AVU-G
QUARTERLY/ANNUAL REPORT OF MAJOR NATURAL GAS COMPANIES
1411 East Mission Avenue, Spokane, WA 99207
04/15/2021Ryan Krasselt
VP, Controller, Prin Acctg OfficerRyan L. Krasselt
04/15/2021
1411 East Mission Avenue, Spokane, WA 99207
VP, Controller, Prin Acctg OfficerRyan L. Krasselt
This Report Is:
(1) An Original
(2) A Resubmission
Year/Period of Report
End ofAvista Corporation
X
2020/Q4
01 Exact Legal Name of Respondent
IDENTIFICATION
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)
05 Name of Contact Person 06 Title of Contact Person
07 Address of Contact Person (Street, City, State, Zip Code)
509-495-2273
08 Telephone of Contact Person, Including Area Code 10 Date of Report
(Mo, Da, Yr)
11 Name 12 Title
13 Signature 14 Date Signed
Title 18, U.S.C. 1001, makes it a crime for any person 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.
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.
Page 1FERC FORM NO. 2/3Q (02-04)
List of Schedules (Natural Gas Company)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Title of Schedule
(a)
Enter in column (d) the terms "none," "not applicable," or "NA" as appropriate, where no information or amounts have been reported for
certain pages. Omit pages where the responses are "none," "not applicable," or "NA."
Reference
Page No.
(b)
Date Revised
(c)
Remarks
(d)
GENERAL CORPORATE INFORMATION AND FINANCIAL STATEMENTS
101General Information 1
N/A102Control Over Respondent 2
103Corporations Controlled by Respondent 3
107Security Holders and Voting Powers 4
108Important Changes During the Year 5
110-113Comparative Balance Sheet 6
114-116Statement of Income for the Year 7
117Statement of Accumulated Comprehensive Income and Hedging Activities 8
118-119Statement of Retained Earnings for the Year 9
120-121Statements of Cash Flows 10
122Notes to Financial Statements 11
BALANCE SHEET SUPPORTING SCHEDULES (Assets and Other Debits)
200-201Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization, and Depletion 12
204-209Gas Plant in Service 13
N/A212Gas Property and Capacity Leased from Others 14
N/A213Gas Property and Capacity Leased to Others 15
214Gas Plant Held for Future Use 16
216Construction Work in Progress-Gas 17
N/A217Non-Traditional Rate Treatment Afforded New Projects 18
218General Description of Construction Overhead Procedure 19
219Accumulated Provision for Depreciation of Gas Utility Plant 20
220Gas Stored 21
222-223Investments 22
224-225Investments in Subsidiary Companies 23
230Prepayments 24
N/A230Extraordinary Property Losses 25
N/A230Unrecovered Plant and Regulatory Study Costs 26
232Other Regulatory Assets 27
233Miscellaneous Deferred Debits 28
234-235Accumulated Deferred Income Taxes 29
BALANCE SHEET SUPPORTING SCHEDULES (Liabilities and Other Credits)
250-251Capital Stock 30
N/A252
Capital Stock Subscribed, Capital Stock Liability for Conversion, Premium on Capital Stock, and
Installments Received on Capital Stock
31
253Other Paid-in Capital 32
N/A254Discount on Capital Stock 33
254Capital Stock Expense 34
255Securities issued or Assumed and Securities Refunded or Retired During the Year 35
256-257Long-Term Debt 36
258-259Unamortized Debt Expense, Premium, and Discount on Long-Term Debt 37
Page 2FERC FORM NO. 2 (REV 12-07)
List of Schedules (Natural Gas Company) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Title of Schedule
(a)
Enter in column (d) the terms "none," "not applicable," or "NA" as appropriate, where no information or amounts have been reported for
certain pages. Omit pages where the responses are "none," "not applicable," or "NA."
Reference
Page No.
(b)
Date Revised
(c)
Remarks
(d)
260Unamortized Loss and Gain on Reacquired Debt 38
261Reconciliation of Reported Net Income with Taxable Income for Federal Income Taxes 39
262-263Taxes Accrued, Prepaid, and Charged During Year 40
268Miscellaneous Current and Accrued Liabilities 41
269Other Deferred Credits 42
274-275Accumulated Deferred Income Taxes-Other Property 43
276-277Accumulated Deferred Income Taxes-Other 44
278Other Regulatory Liabilities 45
INCOME ACCOUNT SUPPORTING SCHEDULES
N/A299Monthly Quantity & Revenue Data by Rate Schedule 46
300-301Gas Operating Revenues 47
N/A302-303Revenues from Transportation of Gas of Others Through Gathering Facilities 48
N/A304-305Revenues from Transportation of Gas of Others Through Transmission Facilities 49
N/A306-307Revenues from Storage Gas of Others 50
308Other Gas Revenues 51
N/A313Discounted Rate Services and Negotiated Rate Services 52
317-325Gas Operation and Maintenance Expenses 53
N/A328Exchange and Imbalance Transactions 54
331Gas Used in Utility Operations 55
N/A332Transmission and Compression of Gas by Others 56
334Other Gas Supply Expenses 57
335Miscellaneous General Expenses-Gas 58
336-338Depreciation, Depletion, and Amortization of Gas Plant 59
340Particulars Concerning Certain Income Deduction and Interest Charges Accounts 60
COMMON SECTION
350-351Regulatory Commission Expenses 61
352Employee Pensions and Benefits (Account 926) 62
354-355Distribution of Salaries and Wages 63
357Charges for Outside Professional and Other Consultative Services 64
358Transactions with Associated (Affiliated) Companies 65
GAS PLANT STATISTICAL DATA
N/A508-509Compressor Stations 66
512-513Gas Storage Projects 67
N/A514Transmission Lines 68
N/A518Transmission System Peak Deliveries 69
519Auxiliary Peaking Facilities 70
520Gas Account-Natural Gas 71
N/A521Shipper Supplied Gas for the Current Quarter 72
N/A522System Map 73
N/A551Footnote Reference 74
552Footnote Text 75
Stockholder's Reports (check appropriate box) 76
Four copies will be submitted
No annual report to stockholders is prepared
X
Page 3FERC FORM NO. 2 (REV 12-07)
This Page Intentionally Left Blank
General Information
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Ryan Krasselt, Vice President and Controller, Principal Accounting Officer
1411 East Mission Avenue
Spokane, WA 99207
Electric service in the states of Washington, Idaho and Montana
Natural gas service in the states of Washington, Idaho and Oregon
Not Applicable
(1)
(2)
State of Washington, Incorporated March 15,1889
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.
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.
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.
4. State the classes of utility and other services furnished by respondent during the year in each State in which the respondent operated.
Yes... Enter the date when such independent accountant was initially engaged:
NoX
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?
Page 101FERC FORM NO. 2 (12-96)
Corporations Controlled by Respondent
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Name of Company Controlled
(a)
Type of Control
(b)
Kind of Business
(c)
1. Report below the names of all corporations, business trusts, and similar organizations, controlled directly or indirectly by respondent
at any time during the year. If control ceased prior to end of year, give particulars (details) in a footnote.
2. If control was by other means than a direct holding of voting rights, state in a footnote the manner in which control was held, naming
any intermediaries involved.
3. If control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
4. In column (b) designate type of control of the respondent as "D" for direct, an "I" for indirect, or a "J" for joint control.
---------------------------
DEFINITIONS
---------------------------
1. See the Uniform System of Accounts for a definition of control.
2. Direct control is that which is exercised without interposition of an intermediary.
3. Indirect control is that which is exercised by the interposition of an intermediary that exercises direct control.
4. Joint control is that in which neither interest can effectively control or direct action without the consent of the other, as where the
voting control is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutual
agreement or understanding between two or more parties who together have control within the meaning of the definition of control in the
Uniform System of Accounts, regardless of the relative voting rights of each party.
Percent Voting
Stock Owned
(d)
Footnote
Reference
(e)
Avista Capital Parent to the Company's subsidiaries Not used 100D 1
Avista Development Investment in Real Estate Not used 100I 2
Avista Edge, Inc.Investment in Technology providing
high spd intrnt
Not used 100I 3
Pentzer Corporation Parent of Bay Area Mfg and Penture
Venture Holdngs
Not used 100I 4
Pentzer Venture Holdings II Holding Company-Inactive Not used 100I 5
Bay Area Manufacturing Holding Company Not used 100I 6
Avista Capital II Affiliated business trust issued pref
trust Securi
Not used 100D 7
Avista Northwest Resources, LLC Owns an interest in a venture fund
investment
Not used 100I 8
Steam Plant Square, LLC Commerical office and Retail leasing Not used 100I 9
Courtyard Office Center, LLC Commerical office and Retail leasing Not used 100I 10
Steam Plant Brew Pub, LLC Restaurant Operations Not used 100I 11
Salix, Inc.Liquified Natural Gas Operations Not used 100I 12
Alaska Energy and Resources Company Parent company of Alaska operation Not used 100D 13
Alaska Electric Light and Power Company Utility operations in Juneau Not used 100I 14
AJT Mining Properties, Inc Inactive mining Company holding
Certain Properties
Not used 100I 15
Snettisham Electric Company Right to Purchase Snetti Not used 100I 16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
Page 103FERC FORM NO. 2 (12-96)
59595295
12/31/2020
5/11/2020
59595295
12/09/2020
Other
(e)
Security Holders and Voting Powers
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Name (Title) and Address of
Security Holder
(a)
Total Votes
(b)
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. Furnish 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, or rights were
Common Stock
(c)
Preferred Stock
(d)
1. Give date of the latest closing of the stock
book prior to end of year, and, in a footnote, state
the purpose of such closing:
2. State the total number of votes cast at the latest general
meeting prior to the end of year for election of directors of the
respondent and number of such votes cast by proxy.
3. Give the date and place of
such meeting:
Total:
By Proxy:
VOTING SECURITIES
4. Number of votes as of (date):
TOTAL votes of all voting securities 5 69,238,901 69,238,901
TOTAL number of security holders 6 6,845 6,845
TOTAL votes of security holders listed below 7 35,757,598 35,757,598
8
BlackRock Institutional Trust, 55 East 52nd Street, New York, NY 10055 9 11,384,967 11,384,967
The Vanguard Group, 100 Vanguard Blvd., Malvern, PA 19355 10 7,573,332 7,573,332
PSP Investments, 1250 Rene-Levesque West, Suite 1400, Montreal, QC,
H3B 5E9 Canada
11
5,126,530 5,126,530
Mitsubishi UFJ Trust and Banking, Tokyo Japan 12 2,527,493 2,527,493
State Street Global Advisors (US), Boston, MA 13 2,340,120 2,340,120
First Trust Advisors, Wheaton, IL 14 1,492,036 1,492,036
Hotchkis and Wiley Capital Management, Los Angeles, CA 15 1,385,659 1,385,659
Nuance Investments, LLC, Kansas City, MO 16 1,327,638 1,327,638
Mellon Investments, Boston, MA 17 1,300,417 1,300,417
Dimensional Fund Advisors, Austin, TX 18 1,299,406 1,299,406
19
20
Page 107FERC FORM NO. 2 (12-96)
Give details concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries.
Answer each inquiry. Enter "none" or "not applicable" where applicable. If the answer is given elsewhere in the report, refer to 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 amaterial 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 11, 12, 13 and 14 of the Notes to Financial Statements.
7. None
8. Average annual wage increases were 3.0% for non-exempt employees effective March 2, 2020. Average
annual wage increases were 3.1% for exempt employees effective March 2, 2020. Officers received average
increases of 5.5% effective February 22, 2020. Certain bargaining unit employees received increases of 3.0%
effective March 26, 2020.
9. Reference is made to Note 17 of the Notes to Financial Statements.
10. None
11. Reserved
12. See page 123 of this report.
13. Effective March 1, 2020, Karen S. Feltes, Senior Vice President and Chief Human Resources Officer,
retired.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Important Changes During the Quarter/Year
FERC FORM NO. 2 (12-96)108.1
Effective January 1, 2020, Marian Durkin moved from Chief Compliance Officer to Chief Legal Officer. She
retained her role as the Corporate Secretary. Effective August 1, 2020, Marian Durkin retired.
Effective January 1, 2020, Greg Hesler has been promoted from Senior Counsel II to Vice President, General
Counsel and Chief Compliance Officer. Effective May 11, 2020, Greg Hesler has been promoted from Chief
Compliance Officer to Chief Ethics/Compliance Officer.
Effective January 1, 2020, Latisha Hill has been promoted from Director of Business and Community
Development to Vice President of Community and Economic Vitality.
On March 10, 2021, the Company announced Sena Kwawu has been nominated to join the Avista Corp. board
of directors. Mr. Kwawu will stand for election by the shareholders and, if elected, will join the baord effective
May 11, 2021.
On March 10, 2021, the Company announced the upcoming retirement board of directors member, Marc
Racicot, who has reached the mandatory retirement age of 72 under the Company's bylaws.
14. Proprietary capital is not less than 30 percent.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Important Changes During the Quarter/Year
FERC FORM NO. 2 (12-96)108.2
Comparative Balance Sheet (Assets and Other Debits)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year End of
Quarter/Year Balance
(c)
Prior Year
End Balance
12/31
(d)
0UTILITY PLANT 0 1
6,385,433,383Utility Plant (101-106, 114) 6,713,727,078200-201 2
157,909,990Construction Work in Progress (107) 172,073,892200-201 3
6,543,343,373 TOTAL Utility Plant (Total of lines 2 and 3) 6,885,800,970200-201 4
2,121,893,905(Less) Accum. Provision for Depr., Amort., Depl. (108, 111, 115) 2,294,362,603 5
4,421,449,468Net Utility Plant (Total of line 4 less 5) 4,591,438,367 6
0Nuclear Fuel (120.1 thru 120.4, and 120.6)0 7
0(Less) Accum. Provision for Amort., of Nuclear Fuel Assemblies (120.5)0 8
0Nuclear Fuel (Total of line 7 less 8)0 9
4,421,449,468Net Utility Plant (Total of lines 6 and 9) 4,591,438,367 10
0Utility Plant Adjustments (116)0122 11
6,992,076Gas Stored-Base Gas (117.1) 6,992,076220 12
0System Balancing Gas (117.2)0220 13
0Gas Stored in Reservoirs and Pipelines-Noncurrent (117.3) 0220 14
0Gas Owed to System Gas (117.4)0220 15
0OTHER PROPERTY AND INVESTMENTS 0 16
4,340,611Nonutility Property (121) 5,311,287 17
176,234(Less) Accum. Provision for Depreciation and Amortization (122) 212,107 18
11,547,000Investments in Associated Companies (123) 11,547,000222-223 19
207,105,954Investments in Subsidiary Companies (123.1) 207,410,330224-225 20
0(For Cost of Account 123.1 See Footnote Page 224, line 40)0 21
0Noncurrent Portion of Allowances 0 22
77,972Other Investments (124) 77,890222-223 23
0Sinking Funds (125)0 24
0Depreciation Fund (126)0 25
0Amortization Fund - Federal (127)0 26
22,034,002Other Special Funds (128) 24,673,076 27
922,948Long-Term Portion of Derivative Assets (175) 596,015 28
0Long-Term Portion of Derivative Assets - Hedges (176) 0 29
245,852,253 TOTAL Other Property and Investments (Total of lines 17-20, 22-29) 249,403,491 30
0CURRENT AND ACCRUED ASSETS 0 31
3,067,240Cash (131) 7,363,358 32
4,434,090Special Deposits (132-134) 4,335,989 33
730,965Working Funds (135) 1,116,351 34
155,890Temporary Cash Investments (136) 152,774222-223 35
0Notes Receivable (141)0 36
153,814,551Customer Accounts Receivable (142) 161,513,344 37
15,726,829Other Accounts Receivable (143) 56,664,630 38
2,373,469(Less) Accum. Provision for Uncollectible Accounts - Credit (144) 11,336,140 39
0Notes Receivable from Associated Companies (145)0 40
222,671Accounts Receivable from Associated Companies (146) 719,507 41
4,148,891Fuel Stock (151) 4,088,628 42
0Fuel Stock Expenses Undistributed (152)0 43
Page 110FERC FORM NO. 2 (REV 06-04)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year End of
Quarter/Year Balance
(c)
Comparative Balance Sheet (Assets and Other Debits)(continued)
Prior Year
End Balance
12/31
(d)
0Residuals (Elec) and Extracted Products (Gas) (153) 0 44
46,558,819Plant Materials and Operating Supplies (154) 51,854,056 45
0Merchandise (155)0 46
0Other Materials and Supplies (156)0 47
0Nuclear Materials Held for Sale (157)0 48
0Allowances (158.1 and 158.2)0 49
0(Less) Noncurrent Portion of Allowances 0 50
0Stores Expense Undistributed (163)0 51
14,305,397Gas Stored Underground-Current (164.1) 9,535,324220 52
0Liquefied Natural Gas Stored and Held for Processing (164.2 thru 164.3)0220 53
24,682,259Prepayments (165) 26,280,659230 54
0Advances for Gas (166 thru 167)0 55
129,823Interest and Dividends Receivable (171) 24,973 56
3,609,148Rents Receivable (172) 2,934,797 57
0Accrued Utility Revenues (173)0 58
193,803Miscellaneous Current and Accrued Assets (174) 236,392 59
1,780,327Derivative Instrument Assets (175) 1,523,219 60
922,948(Less) Long-Term Portion of Derivative Instrument Assets (175) 596,014 61
0Derivative Instrument Assets - Hedges (176)0 62
0(Less) Long-Term Portion of Derivative Instrument Assests - Hedges (176)0 63
270,264,286 TOTAL Current and Accrued Assets (Total of lines 32 thru 63) 316,411,847 64
0DEFERRED DEBITS 0 65
13,795,818Unamortized Debt Expense (181) 15,341,338 66
0Extraordinary Property Losses (182.1)0230 67
0Unrecovered Plant and Regulatory Study Costs (182.2) 0230 68
643,207,368Other Regulatory Assets (182.3) 717,281,643232 69
0Preliminary Survey and Investigation Charges (Electric)(183) 0 70
0Preliminary Survey and Investigation Charges (Gas)(183.1 and 183.2)0 71
131,978Clearing Accounts (184) 152,201 72
0Temporary Facilities (185)0 73
18,484,386Miscellaneous Deferred Debits (186) 29,826,563233 74
0Deferred Losses from Disposition of Utility Plant (187) 0 75
0Research, Development, and Demonstration Expend. (188) 0 76
8,883,822Unamortized Loss on Reacquired Debt (189) 7,512,371 77
177,056,526Accumulated Deferred Income Taxes (190) 216,728,536234-235 78
( 3,189,401)Unrecovered Purchased Gas Costs (191) 1,433,580 79
858,370,497 TOTAL Deferred Debits (Total of lines 66 thru 79) 988,276,232 80
5,802,928,580 TOTAL Assets and Other Debits (Total of lines 10-15,30,64,and 80) 6,152,522,013 81
Page 111FERC FORM NO. 2 (REV 06-04)
Comparative Balance Sheet (Liabilities and Other Credits)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year
End of
Quarter/Year
Balance
Prior Year
End Balance
12/31
(d)
PROPRIETARY CAPITAL 00 1
Common Stock Issued (201) 1,176,498,977 1,249,688,206250-251 2
Preferred Stock Issued (204)00250-251 3
Capital Stock Subscribed (202, 205)00252 4
Stock Liability for Conversion (203, 206)00252 5
Premium on Capital Stock (207)00252 6
Other Paid-In Capital (208-211)( 10,696,711)( 10,696,711)253 7
Installments Received on Capital Stock (212)00252 8
(Less) Discount on Capital Stock (213)00254 9
(Less) Capital Stock Expense (214)( 44,938,398)( 47,076,877)254 10
Retained Earnings (215, 215.1, 216) 747,158,701 771,613,505118-119 11
Unappropriated Undistributed Subsidiary Earnings (216.1)( 13,386,701)( 13,577,380)118-119 12
(Less) Reacquired Capital Stock (217)00250-251 13
Accumulated Other Comprehensive Income (219)( 10,258,024)( 14,378,164)117 14
TOTAL Proprietary Capital (Total of lines 2 thru 14) 1,934,254,640 2,029,726,333 15
LONG TERM DEBT 00 16
Bonds (221) 1,904,200,000 2,017,200,000256-257 17
(Less) Reacquired Bonds (222) 83,700,000 83,700,000256-257 18
Advances from Associated Companies (223) 51,547,000 51,547,000256-257 19
Other Long-Term Debt (224)00256-257 20
Unamortized Premium on Long-Term Debt (225) 142,133 133,250258-259 21
(Less) Unamortized Discount on Long-Term Debt-Dr (226) 930,270 843,651258-259 22
(Less) Current Portion of Long-Term Debt 00 23
TOTAL Long-Term Debt (Total of lines 17 thru 23) 1,871,258,863 1,984,336,599 24
OTHER NONCURRENT LIABILITIES 00 25
Obligations Under Capital Leases-Noncurrent (227) 65,565,105 67,716,314 26
Accumulated Provision for Property Insurance (228.1)00 27
Accumulated Provision for Injuries and Damages (228.2) 245,000 395,000 28
Accumulated Provision for Pensions and Benefits (228.3) 212,005,607 211,880,117 29
Accumulated Miscellaneous Operating Provisions (228.4)00 30
Accumulated Provision for Rate Refunds (229) 11,767,158 3,820,594 31
Page 112FERC FORM NO. 2 (REV 06-04)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year
End of
Quarter/Year
Balance
Comparative Balance Sheet (Liabilities and Other Credits)(continued)
Prior Year
End Balance
12/31
(d)
Long-Term Portion of Derivative Instrument Liabilities 19,684,476 37,427,278 32
Long-Term Portion of Derivative Instrument Liabilities - Hedges 00 33
Asset Retirement Obligations (230) 20,338,053 17,194,050 34
TOTAL Other Noncurrent Liabilities (Total of lines 26 thru 34) 329,605,399 338,433,353 35
CURRENT AND ACCRUED LIABILITIES 00 36
Current Portion of Long-Term Debt 00 37
Notes Payable (231) 182,300,000 202,000,000 38
Accounts Payable (232) 107,406,813 104,217,591 39
Notes Payable to Associated Companies (233) 14,722,348 8,742,915 40
Accounts Payable to Associated Companies (234)00 41
Customer Deposits (235) 4,745,573 3,028,142 42
Taxes Accrued (236) 38,022,918 45,266,874262-263 43
Interest Accrued (237) 15,282,041 15,884,942 44
Dividends Declared (238)00 45
Matured Long-Term Debt (239)00 46
Matured Interest (240)00 47
Tax Collections Payable (241) 168,034 111,813 48
Miscellaneous Current and Accrued Liabilities (242) 50,808,479 60,781,094268 49
Obligations Under Capital Leases-Current (243) 4,127,561 4,249,213 50
Derivative Instrument Liabilities (244) 30,612,670 51,435,582 51
(Less) Long-Term Portion of Derivative Instrument Liabilities 19,684,476 37,427,277 52
Derivative Instrument Liabilities - Hedges (245)00 53
(Less) Long-Term Portion of Derivative Instrument Liabilities - Hedges 00 54
TOTAL Current and Accrued Liabilities (Total of lines 37 thru 54) 428,511,961 458,290,889 55
DEFERRED CREDITS 00 56
Customer Advances for Construction (252) 2,083,490 2,444,383 57
Accumulated Deferred Investment Tax Credits (255) 30,443,961 29,866,627 58
Deferred Gains from Disposition of Utility Plant (256)00 59
Other Deferred Credits (253) 29,659,558 31,450,029269 60
Other Regulatory Liabilities (254) 481,207,133 473,121,377278 61
Unamortized Gain on Reacquired Debt (257) 1,448,359 1,318,822260 62
Accumulated Deferred Income Taxes - Accelerated Amortization (281)00 63
Accumulated Deferred Income Taxes - Other Property (282) 514,870,007 603,415,433 64
Accumulated Deferred Income Taxes - Other (283) 179,585,209 200,118,168 65
TOTAL Deferred Credits (Total of lines 57 thru 65) 1,239,297,717 1,341,734,839 66
TOTAL Liabilities and Other Credits (Total of lines 15,24,35,55,and 66) 5,802,928,580 6,152,522,013 67
Page 113FERC FORM NO. 2 (REV 06-04)
Prior Three
Months Ended
Quarterly Only
No Fourth Quarter
(f)
Total
Current Year to
Date Balance
for Quarter/Year
(c)
Quarterly
1. Enter in column (d) the balance for the reporting quarter and in column (e) the balance for the same three month period for the prior year.
2. Report in column (f) the quarter to date amounts for electric utility function; in column (h) the quarter to date amounts for gas utility, and in (j) the quarter to date amounts for
other utility function for the current year quarter.
3. Report in column (g) the quarter to date amounts for electric utility function; in column (i) the quarter to date amounts for gas utility, and in (k) the quarter to date amounts for
other utility function for the prior year quarter.
4. If additional columns are needed place them in a footnote.
Annual or Quarterly, if applicable
5. Do not report fourth quarter data in columns (e) and (f)
6. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility columnin a similar manner to a utility department.
Spread the amount(s) over lines 2 thru 26 as appropriate. Include these amounts in columns (c) and (d) totals.
7. Report amounts in account 414, Other Utility Operating Income, in the same manner as accounts 412 and 413 above.
8. Report data for lines 8, 10 and 11 for Natural Gas companies using accounts 404.1, 404.2, 404.3, 407.1 and 407.2.
9. Use page 122 for important notes regarding the statement of income for any account thereof.
10. Give concise explanations concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's
customers or which may result in material refund to the utility with respect to power or gas purchases. State for each year effected the gross revenues or costs to which the
contingency relates and the tax effects together with an explanation of the major factors which affect the rights of the utility to retain such revenues or recover amounts paid
with respect to power or gas purchases.
11 Give concise explanations concerning significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding affecting
revenues received or costs incurred for power or gas purches, and a summary of the adjustments made to balance sheet, income, and expense accounts.
12. If any notes appearing in the report to stokholders are applicable to the Statement of Income, such notes may be included at page 122.
13. Enter on page 122 a concise explanation of only those changes in accounting mehods made during the year which had an effect on net income, including the basis of
allocations and apportionments from those used in the preceding year. Also, give the appropriate dollar effect of such changes.
14. Explain in a footnote if the previous year's/quarter's figures are different from that reported in prior reports.
15. If the columns are insufficient for reporting additional utility departments, supply the appropriate account titles report the information in a footnote to this schedule.
Statement of Income
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Title of Account
(a)
Reference
Page
Number
(b)
Total
Prior Year to Date
Balance
for Quarter/Year
(d)
Current Three
Months Ended
Quarterly Only
No Fourth Quarter
(e)
0 0 0 0UTILITY OPERATING INCOME 1
1,428,099,066 1,379,875,645 0 0Gas Operating Revenues (400) 300-301 2
0 0 0 0Operating Expenses 3
818,533,678 762,581,592 0 0 Operation Expenses (401) 317-325 4
70,160,821 74,568,922 0 0 Maintenance Expenses (402) 317-325 5
163,503,287 181,300,837 0 0 Depreciation Expense (403) 336-338 6
0 0 0 0 Depreciation Expense for Asset Retirement Costs (403.1) 336-338 7
40,625,925 44,668,607 0 0 Amortization and Depletion of Utility Plant (404-405) 336-338 8
99,047 99,047 0 0 Amortization of Utility Plant Acu. Adjustment (406) 336-338 9
0 0 0 0 Amort. of Prop. Losses, Unrecovered Plant and Reg. Study Costs (407.1) 10
0 0 0 0 Amortization of Conversion Expenses (407.2) 11
7,343,186 12,453,020 0 0 Regulatory Debits (407.3) 12
24,373,462 57,223,861 0 0 (Less) Regulatory Credits (407.4) 13
104,229,614 114,634,576 0 0 Taxes Other than Income Taxes (408.1) 262-263 14
1,016,853( 41,194,492) 0 0 Income Taxes-Federal (409.1) 262-263 15
( 512,990) 654,441 0 0 Income Taxes-Other (409.1) 262-263 16
16,095,155 134,834,319 0 0 Provision of Deferred Income Taxes (410.1) 234-235 17
3,735,815 82,145,804 0 0 (Less) Provision for Deferred Income Taxes-Credit (411.1) 234-235 18
718,518( 577,334) 0 0 Investment Tax Credit Adjustment-Net (411.4) 19
0 0 0 0 (Less) Gains from Disposition of Utility Plant (411.6) 20
0 0 0 0 Losses from Disposition of Utility Plant (411.7) 21
0 0 0 0 (Less) Gains from Disposition of Allowances (411.8) 22
0 0 0 0 Losses from Disposition of Allowances (411.9) 23
0 0 0 0 Accretion Expense (411.10) 24
1,193,703,817 1,144,653,870 0 0 TOTAL Utility Operating Expenses (Total of lines 4 thru 24) 25
234,395,249 235,221,775 0 0
Net Utility Operating Income (Total of lines 2 less 25) (Carry forward to page 116,
line 27)
26
Page 114FERC FORM NO. 2 (REV 06-04)
Statement of Income
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Gas Utility
Current
Year to Date
(in dollars)
(i)
Gas Utility
Previous
Year to Date
(in dollars)
(j)
Elec. Utility
Current
Year to Date
(in dollars)
(g)
Elec. Utility
Previous
Year to Date
(in dollars)
(h)
Other Utility
Current
Year to Date
(in dollars)
(k)
Other Utility
Previous
Year to Date
(in dollars)
(l)
0 0 0 0 0 1 0
0 437,144,281 444,615,322 983,483,744 942,731,364 2 0
0 0 0 0 0 3 0
0 283,284,697 303,138,157 515,395,521 479,296,895 4 0
0 16,135,031 15,618,412 54,542,409 58,433,891 5 0
0 39,241,553 36,824,230 126,679,057 142,059,284 6 0
0 0 0 0 0 7 0
0 11,806,796 10,079,068 30,546,857 32,861,811 8 0
0 0 0 99,047 99,047 9 0
0 0 0 0 0 10 0
0 0 0 0 0 11 0
0 4,291,441 1,453,061 5,890,125 8,161,579 12 0
0 9,347,623 3,442,644 20,930,818 47,876,238 13 0
0 28,331,560 24,983,566 79,246,048 86,303,016 14 0
0( 19,275,221) ( 6,428,201) 7,445,054( 21,919,271) 15 0
0 868,554 ( 8,110)( 504,880)( 214,113) 16 0
0 51,367,113 11,059,318 5,035,837 83,467,206 17 0
0 20,182,500 1,346,919 2,388,896 61,963,304 18 0
0( 14,643) 172,256 546,262( 562,691) 19 0
0 0 0 0 0 20 0
0 0 0 0 0 21 0
0 0 0 0 0 22 0
0 0 0 0 0 23 0
0 0 0 0 0 24 0
0 386,506,758 392,102,194 801,601,623 758,147,112 25 0
0 50,637,523 52,513,128 181,882,121 184,584,252 26 0
Page 115FERC FORM NO. 2 (REV 06-04)
Prior Three
Months Ended
Quarterly Only
No Fourth Quarter
(f)
Total
Current Year to
Date Balance
for Quarter/Year
(c)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Title of Account
(a)
Reference
Page
Number
(b)
Statement of Income(continued)
Total
Prior Year to Date
Balance
for Quarter/Year
(d)
Current Three
Months Ended
Quarterly Only
No Fourth Quarter
(e)
234,395,249 235,221,775 0 0 Net Utility Operating Income (Carried forward from page 114) 27
0 0 0 0OTHER INCOME AND DEDUCTIONS 28
0 0 0 0Other Income 29
0 0 0 0 Nonutility Operating Income 30
0 0 0 0 Revenues form Merchandising, Jobbing and Contract Work (415) 31
0 0 0 0 (Less) Costs and Expense of Merchandising, Job & Contract Work (416) 32
0 108,256 0 0 Revenues from Nonutility Operations (417) 33
14,612,589 5,439,625 0 0 (Less) Expenses of Nonutility Operations (417.1) 34
( 31,291)( 31,838) 0 0 Nonoperating Rental Income (418) 35
13,582,269 5,304,376 0 0 Equity in Earnings of Subsidiary Companies (418.1) 119 36
4,401,265 3,448,647 0 0 Interest and Dividend Income (419) 37
( 104,311) 338,811 0 0 Allowance for Other Funds Used During Construction (419.1) 38
0 0 0 0 Miscellaneous Nonoperating Income (421) 39
109,159 289,281 0 0 Gain on Disposition of Property (421.1) 40
3,344,502 4,017,908 0 0 TOTAL Other Income (Total of lines 31 thru 40) 41
0 0 0 0Other Income Deductions 42
0 0 0 0 Loss on Disposition of Property (421.2) 43
( 33,721)( 815,484) 0 0 Miscellaneous Amortization (425) 44
11,332,979 2,999,603 0 0 Donations (426.1) 340 45
2,640,044 3,072,596 0 0 Life Insurance (426.2) 46
21,180( 17,039) 0 0 Penalties (426.3) 47
1,718,553 1,773,265 0 0 Expenditures for Certain Civic, Political and Related Activities (426.4) 48
27,317,212 3,494,856 0 0 Other Deductions (426.5) 49
42,996,247 10,507,797 0 0 TOTAL Other Income Deductions (Total of lines 43 thru 49) 340 50
0 0 0 0Taxes Applic. to Other Income and Deductions 51
311,708 923,792 0 0 Taxes Other than Income Taxes (408.2) 262-263 52
( 8,257,303)( 60,470) 0 0 Income Taxes-Federal (409.2) 262-263 53
( 350,985) 800 0 0 Income Taxes-Other (409.2) 262-263 54
( 1,887,439) 218,831 0 0 Provision for Deferred Income Taxes (410.2) 234-235 55
196,940 3,167,528 0 0 (Less) Provision for Deferred Income Taxes-Credit (411.2) 234-235 56
0 0 0 0 Investment Tax Credit Adjustments-Net (411.5) 57
0 0 0 0 (Less) Investment Tax Credits (420) 58
( 10,380,959)( 2,084,575) 0 0 TOTAL Taxes on Other Income and Deductions (Total of lines 52-58) 59
( 29,270,786)( 4,405,314) 0 0 Net Other Income and Deductions (Total of lines 41, 50, 59) 60
0 0 0 0INTEREST CHARGES 61
86,591,406 88,943,778 0 0 Interest on Long-Term Debt (427) 62
321,206 937,453 0 0 Amortization of Debt Disc. and Expense (428) 258-259 63
2,266,507 2,222,423 0 0 Amortization of Loss on Reacquired Debt (428.1) 64
8,883 8,883 0 0 (Less) Amortization of Premium on Debt-Credit (429) 258-259 65
0 0 0 0 (Less) Amortization of Gain on Reacquired Debt-Credit (429.1) 66
489,554 186,289 0 0 Interest on Debt to Associated Companies (430) 340 67
8,205,984 6,170,081 0 0 Other Interest Expense (431) 340 68
4,169,531 2,152,002 0 0 (Less) Allowance for Borrowed Funds Used During Construction-Credit (432) 69
93,696,243 96,299,139 0 0 Net Interest Charges (Total of lines 62 thru 69) 70
111,428,220 134,517,322 0 0 Income Before Extraordinary Items (Total of lines 27,60 and 70) 71
0 0 0 0EXTRAORDINARY ITEMS 72
102,999,990 0 0 0 Extraordinary Income (434) 73
0 0 0 0 (Less) Extraordinary Deductions (435) 74
102,999,990 0 0 0 Net Extraordinary Items (Total of line 73 less line 74) 75
22,478,603 0 0 0 Income Taxes-Federal and Other (409.3) 262-263 76
80,521,387 0 0 0 Extraordinary Items after Taxes (Total of line 75 less line 76) 77
191,949,607 134,517,322 0 0 Net Income (Total of lines 71 and 77) 78
Page 116FERC FORM NO. 2 (REV 06-04)
This Page Intentionally Left Blank
Name of Respondent This Report Is:(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
1. Report in columns (b) (c) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate.
2. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges.
3. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote.
Item
(a)
Unrealized Gains
and Losses on
available-for-sale
securities
(b)
Minimum Pension
liabililty Adjustment
(net amount)
(c)
Foreign Currency
Hedges
(d)
Other
Adjustments
(e)
Statement of Accumulated Comprehensive Income and Hedging Activities
Balance of Account 219 at Beginning of Preceding
Year ( 7,866,070)
1
Preceding Quarter/Year to Date Reclassifications
from Account 219 to Net Income
2
Preceding Quarter/Year to Date Changes in Fair
Value ( 2,391,954)
3
Total (lines 2 and 3)( 2,391,954)4
Balance of Account 219 at End of Preceding
Quarter/Year ( 10,258,024)
5
Balance of Account 219 at Beginning of Current Year ( 10,258,024)6
Current Quarter/Year to Date Reclassifications from
Account 219 to Net Income
7
Current Quarter/Year to Date Changes in Fair Value ( 4,120,140)8
Total (lines 7 and 8)( 4,120,140)9
Balance of Account 219 at End of Current
Quarter/Year ( 14,378,164)
10
FERC FORM NO. 2 (NEW 06-02)Page 117
Name of Respondent This Report Is:(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Statement of Accumulated Comprehensive Income and Hedging Activities(continued)
Other Cash Flow Hedges
Interest Rate Swaps
(f)
Other Cash Flow Hedges
[Insert Footnote at Line 1
to specify category]
(g)
Totals for each
category of
items recorded in
Account 219
(h)
Net Income
(Carried Forward
from Page 116,
Line 78)
(i)
Total
Comprehensive
Income
(j)
( 7,866,070)1
2
( 2,391,954)3
196,979,195 194,587,241( 2,391,954)4
( 10,258,024)5
( 10,258,024)6
7
( 4,120,140)8
134,517,321 130,397,181( 4,120,140)9
( 14,378,164)10
FERC FORM NO. 2 (NEW 06-02)Page 117a

This Page Intentionally Left Blank
1. Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
2. Each credit and debit during the year should be identified as to the retained earnings account in which recorded (Accounts 433, 436-439 inclusive). Show the contra primary account
affected in column (b).
3. State the purpose and amount for each reservation or appropriation of retained earnings.
4. List first Account 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow by credit, then debit items, in that order.
5. Show dividends for each class and series of capital stock.
Statement of Retained Earnings
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Item
(a)
Contra Primary
Account Affected
(b)
Current Quarter
Year to Date
Balance
(c)
Previous Quarter
Year to Date
Balance
(d)
UNAPPROPRIATED RETAINED EARNINGS
Balance-Beginning of Period 623,531,170 705,980,176 1
Changes (Identify by prescribed retained earnings accounts) 2
Adjustments to Retained Earnings (Account 439) 3
TOTAL Credits to Retained Earnings (Account 439) (footnote details) 4
TOTAL Debits to Retained Earnings (Account 439) (footnote details) 5
Balance Transferred from Income (Acct 433 less Acct 418.1) 178,367,338 129,212,945 6
Appropriations of Retained Earnings (Account 436)( 3,725,552) 4,274,422 7
TOTAL Appropriations of Retained Earnings (Account 436) (footnote details) 4,274,422 8
Dividends Declared-Preferred Stock (Account 437) 9
TOTAL Dividends Declared-Preferred Stock (Account 437) (footnote details) 10
Dividends Declared-Common Stock (Account 438) 11
TOTAL Dividends Declared-Common Stock (Account 438) (footnote details) 102,772,642 110,253,196 12
Transfers from Account 216.1, Unappropriated Undistributed Subsidiary Earnings 10,579,862 5,495,055 13
Balance-End of Period (Total of lines 1, 4, 5, 6, 8, 10, 12, and 13) 709,705,728 726,160,558 14
APPROPRIATED RETAINED EARNINGS (Account 215) 15
TOTAL Appropriated Retained Earnings (Account 215) (footnote details) 41,178,525 45,452,947 16
APPROPRIATED RETAINED EARNINGS-AMORTIZATION RESERVE, FEDERAL (Account 17
TOTAL Appropriated Retained Earnings-Amortization Reserve, Federal (Account ( 3,725,552) 18
TOTAL Appropriated Retained Earnings (Accounts 215, 215.1) (Total of lines 37,452,973 45,452,947 19
TOTAL Retained Earnings (Accounts 215, 215.1, 216) (Total of lines 14 and 1 747,158,701 771,613,505 20
UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account 216.1) 21
Report only on an Annual Basis no Quarterly
Balance-Beginning of Year (Debit or Credit)( 16,389,107)( 13,386,701) 22
Equity in Earnings for Year (Credit) (Account 418.1) 13,582,269 5,304,376 23
(Less) Dividends Received (Debit) 10,000,000 5,000,000 24
Other Changes (Explain)( 579,863)( 495,055) 25
Balance-End of Year ( 13,386,701)( 13,577,380) 26
Page 118-119FERC FORM NO. 2 (REV 06-04)
(1) Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) Include commercial paper; and (d) Identify
separately such items as investments, fixed assets, intangibles, etc.
(2) Information about noncash investing and financing activities must be provided in the Notes to the Financial statements. Also provide a reconciliation
between "Cash and Cash Equivalents at End of Period" with related amounts on the Balance Sheet.
(3) Operating Activities - Other: Include gains and losses pertaining to operating activities only. Gains and losses pertaining to investing and financing
activities should be reported in those activities. Show in the Notes to the Financials the amounts of interest paid (net of amount capitalized) and income
taxes paid.
(4) Investing Activities: Include at Other (line 25) net cash outflow to acquire other companies. Provide a reconciliation of assets acquired with liabilities
assumed in the Notes to the Financial Statements. Do not include on this statement the dollar amount of leases capitalized per the USofA General
Instruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
Statement of Cash Flows
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description (See Instructions for explanation of codes)
(a)
Current Year
to Date
Quarter/Year
Previous Year
to Date
Quarter/Year
1 Net Cash Flow from Operating Activities
2 191,949,607 134,517,322 Net Income (Line 78(c) on page 116)
3 Noncash Charges (Credits) to Income:
4 202,496,251 225,969,444Depreciation and Depletion
5 ( 41,704,853)( 6,772,236)Amortization of deferred power and gas costs, debt expense and exchange power
6 10,274,962 49,739,817 Deferred Income Taxes (Net)
7 718,518( 577,334) Investment Tax Credit Adjustments (Net)
8 ( 9,860,829)( 51,466,229) Net (Increase) Decrease in Receivables
9 ( 6,255,653)( 464,901) Net (Increase) Decrease in Inventory
10 Net (Increase) Decrease in Allowances Inventory
11 1,823,471 6,150,782 Net Increase (Decrease) in Payables and Accrued Expenses
12 ( 6,065,721)( 9,597,307) Net (Increase) Decrease in Other Regulatory Assets
13 ( 5,135,361)( 4,626,804) Net Increase (Decrease) in Other Regulatory Liabilities
14 6,434,430 6,711,875 (Less) Allowance for Other Funds Used During Construction
15 13,582,269 5,304,376 (Less) Undistributed Earnings from Subsidiary Companies
16 71,865,969( 13,266,559) Other (footnote details):
17 Net Cash Provided by (Used in) Operating Activities
18 390,089,662 317,589,743(Total of Lines 2 thru 16)
19
20 Cash Flows from Investment Activities:
21 Construction and Acquisition of Plant (including land):
22 ( 439,249,001)( 399,504,892)Gross Additions to Utility Plant (less nuclear fuel)
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 (footnote details):
28 ( 439,249,001)( 399,504,892) Cash Outflows for Plant (Total of lines 22 thru 27)
29
30 Acquisition of Other Noncurrent Assets (d)
31 882,641 570,225 Proceeds from Disposal of Noncurrent Assets (d)
32 Federal and state grant payments received
33 ( 3,693,898)( 6,476,269) Investments in and Advances to Assoc. and Subsidiary Companies
34 10,000,000 5,000,000 Contributions and Advances from Assoc. and Subsidiary Companies
35 Disposition of Investments in (and Advances to)
36 Associated and Subsidiary Companies
37 Cash paid for acquisition
38 Purchase of Investment Securities (a)
39 Proceeds from Sales of Investment Securities (a)
Page 120FERC FORM NO. 2 (REV 06-04)
Statement of Cash Flows (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description (See Instructions for explanation of codes)
(a)
Current Year
to Date
Quarter/Year
Previous Year
to Date
Quarter/Year
40 Loans Made or Purchased
41 Collections on Loans
42 Restricted cash
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 ( 1,750,738)( 1,362,792)Changes in other property and investments
48 Net Cash Provided by (Used in) Investing Activities
49 ( 433,810,996)( 401,773,728) (Total of lines 28 thru 47)
50
51 Cash Flows from Financing Activities:
52 Proceeds from Issuance of:
53 180,000,000 165,000,000Long-Term Debt (b)
54 Preferred Stock
55 64,572,145 72,200,592Common Stock
56 Other (footnote details):
57 19,700,000 Net Increase in Short-term Debt (c)
58 Other (footnote details):
59 244,572,145 256,900,592 Cash Provided by Outside Sources (Total of lines 53 thru 58)
60
61 Payments for Retirement of:
62 ( 90,000,000)( 52,000,000)Long-Term Debt (b)
63 Preferred Stock
64 Common Stock
65 ( 2,007,040)( 5,785,023)Other
66 ( 7,700,000) Net Decrease in Short-Term Debt (c)
67 Premium paid to repurchase long-term debt
68 Dividends on Preferred Stock
69 ( 102,772,642)( 110,253,196) Dividends on Common Stock
70 Net Cash Provided by (Used in) Financing Activities
71 42,092,463 88,862,373 (Total of lines 59 thru 69)
72
73 Net Increase (Decrease) in Cash and Cash Equivalents
74 ( 1,628,871) 4,678,388 (Total of line 18, 49 and 71)
75
76 5,586,966 3,954,095 Cash and Cash Equivalents at Beginning of Period
77
78 3,958,095 8,632,483 Cash and Cash Equivalents at End of Period
Page 120aFERC FORM NO. 2 (REV 06-04)
Schedule Page: 120 Line No.: 16 Column: b
Power and natural gas deferrals 1,092,888
Change in special deposits 1,579,362
Change in other current assets (861,790)
Non-cash stock compensation 5,846,058
Gain on sale of property and equipment (289,281)
Other 195,317
Allowance for Doubtful Accounts 4,149,939
Changes in Other Non-Current Assets
and Liabilities 8,520,219
Cash Paid for Settlement of Interest
Rate Swaps (33,499,271)
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1
This Page Intentionally Left Blank
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 therespondent’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. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Nature of Business
Avista Corp. (the Company) is primarily an electric and natural gas utility with certain other business ventures. Avista Corp. provides
electric distribution and transmission, and natural gas distribution services in parts of eastern Washington and northern Idaho. Avista
Corp. also provides natural gas distribution service in parts of northeastern and southwestern Oregon. Avista Corp. has electric
generating facilities in Washington, Idaho, Oregon and Montana. Avista Corp. also supplies electricity to a small number of
customers in Montana, most of whom are employees who operate the Company's Noxon Rapids generating facility.
Alaska Electric and Resources Company (AERC) is a wholly-owned subsidiary of Avista Corp. The primary subsidiary of AERC is
Alaska Electric Light and Power (AEL&P), which comprises Avista Corp.'s regulated utility operations in Alaska.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.1
Avista Capital, a wholly owned non-regulated subsidiary of Avista Corp., is the parent company of all of the 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 Regulatory Commission (FERC) as set forth in its applicable Uniform System
of Accounts and published accounting releases, which is a comprehensive basis of accounting other than accounting principles
generally accepted in the United States of America (U.S. GAAP). As required by the FERC, the Company accounts for its investment
in majority-owned subsidiaries on the equity method rather than consolidating the assets, liabilities, revenues, and expenses of these
subsidiaries, as required by U.S. GAAP. The accompanying financial statements include the Company’s proportionate share of utility
plant and related operations resulting from its interests in jointly owned plants. In addition, under the requirements of the FERC, there
are differences from U.S. GAAP in the presentation of (1) current portion of long-term debt (2) assets and liabilities for cost of
removal of 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” (not physically delivered), (9) non-service
portion of pension and other postretirement benefit costs and (10) leases.
Use of Estimates
The preparation of the 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 of contingent assets and liabilities at the date of the financial
statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include:
determining the market value of energy commodity derivative assets and liabilities,
pension and other postretirement benefit plan obligations,
contingent liabilities,
goodwill impairment testing for goodwill held at subsidiaries,
recoverability of regulatory 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 of Accounts
The accounting records of the 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, and Oregon. The Company is also subject to federal
regulation primarily by the FERC, as well as various other federal agencies with regulatory oversight of particular aspects of its
operations.
Depreciation
For utility operations, depreciation expense is estimated by a method of depreciation accounting utilizing composite rates for utility
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.2
plant. Such rates are designed to provide for retirements of properties at the expiration of their service lives. For utility operations, the
ratio of depreciation provisions to average depreciable property was as follows for the years ended December 31:
2020 2019
Avista Corp.
Ratio of depreciation to average depreciable property 3.43% 3.28%
The average service lives for the following broad categories of utility plant in service are (in years):
Avista Corp.
Electric thermal/other production 27
Hydroelectric production 81
Electric transmission 49
Electric distribution 39
Natural gas distribution property 44
Other shorter-lived general plant 8
Allowance for Funds Used During Construction (AFUDC)
AFUDC represents the cost of both 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 of the cost of utility plant. The debt component of AFUDC is
credited against total interest expense in the Statements of Income in the line item “capitalized interest.” The equity component of
AFUDC is included in the Statements of Income in the line item “other expense (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 after the 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 WUTC and IPUC have authorized Avista Corp. to calculate AFUDC using its allowed rate of return. 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 of Avista 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 for the years ended December 31:
2020 2019
Avista Corp.
Effective state AFUDC rate 7.25% 7.39%
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 of items for
tax and accounting purposes. A deferred 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 deferred income tax expense for the period is equal to the net
change in the deferred income tax asset and liability accounts from the beginning to the end of the period. 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
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.3
order specifies deferral of the effect of the change in tax rates over a longer period of time. The Company establishes a valuation
allowance when it is more likely than not that all, or a portion, of a deferred tax asset will not be realized. Deferred income tax
liabilities and regulatory assets are established for income tax benefits flowed through to customers.
The Company's largest deferred income tax item is the difference between the book and tax basis of utility 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 incur any penalties on income tax positions in 2020 or 2019. The Company would recognize interest accrued
related to income tax positions as interest expense and any penalties incurred as other operating expense.
Stock-Based Compensation
The Company currently issues three types of stock-based compensation awards - restricted shares, market-based awards and
performance-based awards. Historically, these stock compensation awards have not been material to the Company's overall financial
results. Compensation cost relating to share-based payment transactions is recognized in the Company’s financial statements based on
the fair value of the equity or liability 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 of the following amounts for the years ended December 31 (dollars in thousands):
2020 2019
Stock-based compensation expense $5,846 $11,353
Income tax benefits 1,228 2,384
Excess tax benefits (expenses) on settled share-based employee
payments (165)(612)
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 if the service condition is met. In addition to the service condition, for restricted shares granted in 2017, the Company must meet
a return on equity target in order for the Chief Executive Officer's restricted shares to vest. Restricted stock is valued at the close of
market of the Company’s common stock on the grant date.
Total Shareholder Return (TSR) awards are market-based awards and Cumulative Earnings Per Share (CEPS) awards are
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
end of the three-year period. The method of settlement is at the discretion of the Company and historically the Company has settled
these awards through issuance of Avista Corp. common stock and intends to continue this practice. Both types of awards entitle the
recipients to dividend equivalent rights, are subject to forfeiture under certain circumstances, and are subject to meeting specific
market or performance conditions. Based on the level of attainment of the market or performance conditions, the amount of cash paid
or common stock issued will range from 0 to 200 percent of the initial awards granted. Dividend equivalent rights are accumulated
and paid out only on shares that eventually vest and have met the market and performance conditions.
For both the TSR awards and the CEPS awards, the Company accounts for them as equity awards and compensation cost for these
awards is recognized over the requisite service period, provided that the requisite service period is rendered. For TSR awards, if the
market condition is not met at the end of the three-year service period, there will be no change in the cumulative amount of
compensation cost recognized, since the awards are still considered vested even though the market metric was not met. For CEPS
awards, at the end of the three-year service period, if the internal performance metric of cumulative earnings per share is not met, all
compensation cost for these awards is reversed as these awards are not considered vested.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.4
The fair value of each TSR award is estimated on the date of grant using a statistical model that incorporates the probability of
meeting the market targets based on historical returns relative to a peer group. The estimated fair value of the equity component of
CEPS awards was estimated on the date of grant as the share price of Avista Corp. common stock on the date of grant, less the net
present value of the estimated dividends over the three-year period.
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 December 31:
2020 2019
Restricted Shares
Shares granted during the year 45,540 50,061
Shares vested during the year 56,203 48,228
Unvested shares at end of year 71,706 93,351
Unrecognized compensation expense at end of year
(in thousands) $2,003 $2,054
TSR Awards
TSR shares granted during the year 47,848 99,214
TSR shares vested during the year (1)71,299 106,858
Unvested TSR shares at end of year 122,133 178,035
Unrecognized compensation expense (in thousands) $2,296 $3,377
CEPS Awards
CEPS shares granted during the year 47,848 49,609
CEPS shares vested during the year 35,622 53,454
CEPS shares earned based on market metrics 63,763 106,908
Unvested CEPS shares at end of year 83,464 88,990
Unrecognized compensation expense (in thousands) $1,090 $2,401
(1) The market metrics were not met during 2020 and 2019 and no TRS shares were earned during these periods.
Outstanding TSR and CEPS share awards include a dividend component that is paid in cash. This component of the share grants is
accounted for as a liability award. These liability awards are revalued on a quarterly basis taking into account the number of awards
outstanding, historical dividend rate, the change in the value of the Company’s common stock relative to an external benchmark (TSR
awards only) and the amount of CEPS earned to date compared to estimated CEPS over the performance period (CEPS awards only).
Over the life of these awards, the cumulative amount of compensation expense recognized will match the actual cash paid. As of
December 31, 2020 and 2019, the Company had recognized cumulative compensation expense and a liability of $0.8 million and $0.9
million, respectively, related to the dividend component on the outstanding and unvested share grants.
Cash and Cash Equivalents
For the purposes of the Statements of Cash Flows, the Company considers all temporary investments with a maturity of three months
or less when purchased to be cash equivalents.
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 for utility 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.
Utility Plant in Service
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.5
The cost of additions to utility plant in service, including AFUDC and replacements of units of property and improvements, is
capitalized. The cost of depreciable units of property retired plus the cost of removal less salvage is charged to accumulated
depreciation.
Asset Retirement Obligations (ARO)
The Company records the fair value of a liability for an ARO in the period in which it is incurred. When the liability is initially
recorded, the associated costs of the ARO are capitalized as part of the carrying amount of the 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 of the related asset. In
addition, if there are changes in the estimated timing or estimated costs of the AROs, 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 of the asset, the Company either settles the ARO for its recorded amount or recognizes a regulatory asset or liability for the
difference, which will be surcharged/refunded 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 7 for further discussion of the 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 Washington Utilities and Transportation Commission (WUTC) and the Idaho Public Utilities Commission (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 of mark-to-market gains and losses on energy commodity
transactions until the period of delivery. Realized benefits and costs result in adjustments to retail rates through Purchased Gas
Adjustments (PGA), the Energy Recovery Mechanism (ERM) in Washington, the Power Cost Adjustment (PCA) mechanism in
Idaho, and periodic general rates cases. The resulting regulatory assets associated with energy commodity derivative instruments have
been concluded to be 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 that are 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 of the contract that is determined to be
other-than-temporary.
For interest rate swap derivatives, Avista Corp. records all mark-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 are risk management tools similar to energy commodity derivatives. Upon settlement of interest rate swap derivatives, the
regulatory asset or liability is amortized as a component of interest expense over the term of the associated debt. The Company
records an offset of interest rate swap derivative assets and liabilities with regulatory assets and liabilities, based on the prior practice
of the commissions to provide recovery through the ratemaking process.
The Company has multiple master netting agreements with a variety of entities that allow for cross-commodity netting of derivative
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 of commodity derivatives and interest rate swap derivatives for the same counterparty. The
Company does not have any 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
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.6
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 swap derivatives and foreign currency exchange derivatives, are
reported at estimated fair value on the Balance Sheets. See Note 15 for the 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 recover the cost of providing the regulated services, and
in view of demand for the regulated services and the level of competition, it is reasonable to assume that rates can
be charged to and collected from customers at levels that will recover costs.
Regulatory accounting practices require that certain costs and/or obligations (such as incurred power and natural gas costs not
currently reflected in rates, but expected to be recovered or refunded in the future), are reflected as deferred charges or credits on the
Balance Sheets. These costs and/or obligations are not reflected in the Statements of Income until the period during which matching
revenues are recognized. The Company also has decoupling revenue deferrals. See Note 3 for discussion on decoupling revenue
deferrals.
If at some point in the future the Company determines that it no longer meets the criteria for continued application of regulatory
accounting practices for all or a portion of its regulated operations, the Company could be:
required to write off its 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 if the Company expected to recover these amounts from customers in the future.
Unamortized Debt Expense
Unamortized debt expense includes debt issuance costs that are amortized over the life of the related debt.
Unamortized Debt Repurchase Costs
For the Company’s Washington regulatory jurisdiction and for any debt repurchases beginning in 2007 in all jurisdictions, premiums
or discounts paid to repurchase debt are amortized over the remaining life of the original debt that was repurchased or, if new debt is
issued in connection with the repurchase, these amounts are amortized over the life of the 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 of outstanding debt when no new debt was issued in connection with the debt repurchase. The premiums and discounts are
recovered or returned to customers through retail rates as a component of interest expense.
Appropriated Retained Earnings
In accordance with the hydroelectric licensing requirements of section 10(d) of the Federal Power Act (FPA), the Company maintains
an appropriated retained earnings account for any earnings in excess of the specified rate of return on the Company's investment in the
licenses for its various hydroelectric projects. Per section 10(d) of the FPA, the Company must maintain these excess earnings in an
appropriated retained earnings account until the termination of the licensing agreements or apply them to reduce the net investment in
the licenses of the hydroelectric projects at the discretion of the FERC. The Company calculates the earnings in excess of the
specified rate of return on an annual basis, usually during the second quarter.
The appropriated retained earnings amounts included in retained earnings were as follows as of December 31 (dollars in thousands):
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.7
2020 2019
Appropriated retained earnings $45,453 $41,179
Contingencies
The Company has unresolved regulatory, legal and tax issues which have inherently uncertain outcomes. The Company accrues a loss
contingency if it is probable that a liability has been incurred and the amount of the 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 of December 31, 2020, the Company has not recorded any significant amounts related to unresolved
contingencies. See Note 17 for further discussion of the Company's commitments and contingencies.
COVID-19
In 2020, the WUTC, IPUC, and OPUC approved accounting orders that allow the Company to defer certain net COVID-19 related
costs and benefits. As such, as of December 31, 2020, the Company has deferred a net benefit to customers of $2.8 million for all
jurisdictions.
The respective regulatory authorities will determine the appropriateness and prudency of any deferred expenses when the Company
seeks recovery. See “Regulatory Deferred Charges and Credits”.
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 for the years ended December 31 (dollars in thousands):
2020 2019
Avista Capital $(2,491)$6,404
AERC 7,795 7,178
Total equity in earnings of subsidiary companies $5,304 $13,582
Subsequent Events
Management has evaluated the impact of events occurring after December 31, 2020 up to February 23, 2021, the date that Avista
Corp.’s U.S. GAAP financial statements were issued and has updated such evaluation for disclosure purposes through the date of this
filing. These financial statements include all necessary adjustments and disclosures resulting from these evaluations.
NOTE 2. NEW ACCOUNTING STANDARDS
Accounting Standards Update (ASU) No. 2016-02, "Leases (Topic 842)"
ASU No. 2018-01, "Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842"
ASU No. 2018-11, "Leases (Topic 842): Targeted Improvements"
On January 1, 2019, the Company adopted ASU No. 2016-02, which outlines a model for entities to use in accounting for leases and
supersedes previous lease accounting guidance, as well as several practical expedients in ASU Nos. 2018-01 and 2018-11.
The Company adopted ASU No. 2016-02 utilizing a modified retrospective adoption method with the "package of three" and
hindsight practical expedients offered by the standard. The "package of three" provides for an entity to not reassess at adoption
whether any expired or existing contracts are deemed, for accounting purposes, to be or contain leases, the classification of any
expired or existing leases, and any initial direct costs for any existing leases. As a result, the Company did not reassess existing or
expired contracts under the new lease guidance, and it did not reassess the classification of any existing leases. The Company used the
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.8
benefit of hindsight in determining both term and impairments associated with any existing leases. Use of this practical expedient has
resulted in lease terms that best represent management's expectations with respect to use of the underlying asset but did not result in
recognition of any impairment.
The Company elected to adopt ASU No. 2018-01, which allows an entity to exclude from application of Topic 842 all easements
executed prior to January 1, 2019. In addition, the Company elected to adopt the "comparatives under 840" practical expedient offered
in ASU No. 2018-11, which allows an entity to apply the new lease standard at the adoption date, recognizing any necessary
cumulative-effect adjustment to the opening balance of retained earnings in the period of adoption and presenting comparative periods
in the financial statements under Accounting Standards Codification (ASC) 840 (previous lease accounting guidance). Adoption of
the standard did not result in a cumulative effect adjustment within the Company's financial statements.
As allowed by ASU No. 2016-02, the Company elected not to apply the requirements of the standard to short-term leases, those leases
with an initial term of 12 months or less. These leases are not recorded on the balance sheet and are not material to the financial
statements.
Adoption of the standard impacted the Company's Balance Sheets through recognition of right-of-use (ROU) assets and lease
liabilities for the Company's operating leases. Accounting for finance leases (formerly capital leases) remained substantially
unchanged. See Note 4 for further information on the Company's leases.
ASU 2018-13 "Fair Value Measurement (Topic 820)"
In August 2018, the FASB issued ASU No. 2018-13, which amends the fair value measurement disclosure requirements of ASC 820.
The requirements of this ASU include additional disclosure regarding the range and weighted average used to develop significant
unobservable inputs for Level 3 fair value estimates and the elimination of certain other previously required disclosures, such as the
narrative description of the valuation process for Level 3 fair value measurements. This ASU became effective on January 1, 2020
and the requirements of this ASU did not have a material impact on the Company's fair value disclosures. See Note 15 for the
Company's fair value disclosures.
ASU No. 2018-14 "Compensation - Retirement Benefits - Defined Benefit Plans - General (Subtopic 715-20)"
In August 2018, the FASB issued ASU No. 2018-14, which amends ASC 715 to add, remove and/or clarify certain disclosure
requirements related to defined benefit pension and other postretirement plans. The additional disclosure requirements are primarily
narrative discussion of significant changes in the benefit obligations and plan assets. The removed disclosures are primarily
information about accumulated other comprehensive income expected to be recognized over the next year and the effects of changes
associated with assumed health care costs. This ASU became effective for periods ending after December 15, 2020 and the
requirements of this ASU did not have a material impact on the Company’s disclosures upon adoption.
NOTE 3. REVENUE
ASC 606 defines the core principle of the 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 of Avista 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 of
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.9
energy 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 of energy. The commodity is sold and/or delivered to and consumed
by the customer simultaneously, and the provisions of the relevant utility commission authorization determine the charges the
Company may bill the customer. Given that all revenue recognition criteria are met upon the delivery of energy 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 of service, and prices. Collectively, these rates, charges, terms and conditions are included in a “tariff,” which governs
all aspects of the provision of regulated 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.
Tariff sales involve the current provision of commodity service (electricity and/or natural gas) to customers for a price that generally
has a basic charge and a usage-based component. Tariff rates 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 of the relevant tariff determine the charges the Company may bill the customer, payment
due date, and other pertinent rights and obligations of both parties. Generally, tariff sales do not involve a written contract. Given that
all revenue recognition criteria are met upon the delivery of energy to customers, revenue is recognized immediately at that time.
Unbilled Revenue from Contracts with Customers
The determination of the volume of energy sales to individual customers is based on the reading of their meters, which occurs on a
systematic basis throughout the month (once per month for each individual customer). At the end of each calendar month, the amount
of energy delivered to customers since the date of the last meter reading is estimated and the corresponding unbilled revenue is
estimated and recorded. The Company's estimate of unbilled revenue is based on:
the number of customers,
current rates,
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 automatically corrected in the following month when the actual meter reading
and customer billing occurs.
Accounts receivable includes unbilled energy revenues of the following amounts as of December 31 (dollars in thousands):
2020 2019
Unbilled accounts receivable $68,545 $60,560
Non-Derivative Wholesale Contracts
The Company has certain wholesale contracts which are not accounted for as derivatives that are within the scope of ASC 606 and
considered revenue from contracts with customers. Revenue is recognized as energy is delivered to the customer or the service is
available for specified period of time, consistent with the discussion of tariff sales above.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.10
Alternative Revenue Programs (Decoupling)
ASC 606 specifies that alternative revenue programs are contracts between an entity and a regulator of utilities, not a contract between
an entity and a customer. GAAP requires that an entity present revenue arising from alternative revenue programs separately from
revenues arising from contracts with customers on the face of the Statements of Income. The Company's decoupling mechanisms
(also known as a FCA in 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 of revenue shortfall or excess due to fluctuations in
customer usage), subject to certain limitations, and a regulatory asset or liability is established which will be surcharged or rebated to
customers in future periods. GAAP requires that for any alternative revenue program, like decoupling, the revenue must be expected
to be collected from customers within 24 months of the deferral to qualify for recognition in the current period Statements of Income.
Any 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 which must be made by the Company on an ongoing basis due to it
being based on the volumes of electric 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 of the overall tariff paid 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 of the 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 scoped out of ASC 606. As such, these revenues are disclosed separately from revenue from
contracts with customers. Revenue is recognized for these items upon the settlement/expiration of the derivative contract. Derivative
revenue includes those transactions which are entered into and settled within the same month.
Other Utility Revenue
Other utility revenue includes rent, revenues from the lineman training school, sales of materials, late fees and other charges that do
not represent contracts with customers. Other utility revenue also includes the provision for earnings sharing and the deferral and
amortization of refunds to customers associated with the Tax Cuts and Jobs Act, enacted in December 2017. This revenue is scoped
out of ASC 606, 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 of the 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
Contracts with Multiple Performance Obligations
In addition to the tariff sales described above, which are stand-alone energy sales, the Company has bundled arrangements which
contain multiple performance obligations including some combination of energy, capacity, energy reserves and RECs. Under these
arrangements, the total contract price is allocated to the various performance obligations and revenue is recognized as the obligations
are satisfied. Depending on the source of the revenue, it could either be included in revenue from contracts with customers or
derivative revenue.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.11
Gross Versus Net Presentation
Utility-related taxes collected from customers (primarily state excise taxes and city utility taxes) are taxes that are imposed on Avista
Corp. as opposed to being imposed on its 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 other than income taxes).
Utility-related taxes that were included in revenue from contracts with customers were as follows for the years ended December 31
(dollars in thousands):
2020 2019
Utility-related taxes $59,319 $59,528
Significant Judgments and Unsatisfied Performance Obligations
The vast majority of the Company's revenues are derived from the rate-regulated sale of electricity and natural gas that have two
performance obligations that are satisfied throughout the period and as energy is delivered to customers. In addition, the customers do
not pay for energy in advance of receiving it. As such, the Company does not have any significant unsatisfied performance
obligations or deferred revenues as of period-end associated with these revenues. Also, the only significant judgments involving
revenue recognition are estimates surrounding unbilled revenue and receivables from contracts with customers (discussed in detail
above) and estimates surrounding the amount of decoupling revenues which will be collected from customers within 24 months.
The Company has certain capacity arrangements, where the Company has a contractual obligation to provide either electric or natural
gas capacity to its customers for a fixed fee. Most of these 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 does have one capacity agreement where the
customer makes payments throughout the year, and depending on the timing of the customer payments, it can result in an immaterial
amount of deferred revenue or a receivable from the customer. As of December 31, 2020, the Company estimates it had unsatisfied
capacity performance obligations of $23.8 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.
Disaggregation of Total Operating Revenue
The following table disaggregates total operating revenue by source for the years ended December 31 (dollars in thousands):
2020 2019
Avista Corp.
Revenue from contracts with customers $1,168,207 $1,160,853
Derivative revenues 203,099 246,355
Alternative revenue programs (3,814) 9,614
Deferrals and amortizations for rate refunds to customers 4,795 1,093
Other utility revenues 7,589 10,184
Total Avista Corp. 1,379,876 1,428,099
Utility Revenue from Contracts with Customers by Type and Service
The following table disaggregates revenue from contracts with customers associated with the Company's electric operations for the
years ended December 31 (dollars in thousands):
2020 2019
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.12
ELECTRIC OPERATIONS
Revenue from contracts with customers
Residential
$
377,78
5 $
369,10
2
Commercial and governmental 303,97
2
317,58
9
Industrial 113,56
3
114,53
0
Public street and highway lighting 7,304 7,448
Total retail revenue 802,62
4
808,66
9
Transmission 18,236 18,180
Other revenue from contracts
with customers 19,252 26,969
Total revenue from contracts
with customers $
840,11
2 $
853,81
8
The following table disaggregates revenue from contracts with customers associated with the Company's natural gas operations for
the years ended December 31 (dollars in thousands):
2020 2019
Avista Corp. Avista Corp.
NATURAL GAS OPERATIONS
Revenue from contracts with customers
Residential $213,612 $196,430
Commercial 94,937 92,168
Industrial and interruptible 7,128 5,263
Total retail revenue 315,677 293,861
Transportation 7,917 8,674
Other revenue from contracts with customers 4,501 4,500
Total revenue from contracts with customers $328,095 $307,035
NOTE 4. LEASES
ASC 842, which outlines a model for entities to use in accounting for leases and supersedes previous lease accounting guidance,
became effective on January 1, 2019. The core principle of the model is that an entity should recognize the ROU assets and liabilities
that arise from leases on the balance sheet and depreciate or amortize the asset and liability over the term of the lease, as well as
provide disclosure to enable users of the financial statements to assess the amount, timing, and uncertainty of cash flows arising from
leases. For regulatory reporting, the FERC provided prescribed accounts for the ROU assets and lease 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 GAAP reporting, which results in a FERC/GAAP difference.
Significant Judgments and Assumptions
The Company determines if an 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 arising from the lease. Operating lease ROU assets and lease liabilities are recognized at the
commencement date of the agreement based on the present value of lease payments over the lease term. As most of the Company's
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.13
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 of lease payments. The implicit rate is used when it is readily determinable. The
operating lease ROU assets also include any lease payments made and exclude lease incentives, if any, that accrue to the benefit of the
lessee.
Lease terms may include options to extend or terminate the lease when it is reasonably certain that the Company will exercise that
option. Lease expense for lease payments is recognized on a straight-line basis over the lease term. Any difference between lease
expense and cash paid for leased assets is recognized as a regulatory asset or regulatory liability.
Description of Leases
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 of this lease are subject to renegotiation,
depending on the outcome of ongoing litigation between Montana and NorthWestern Energy. In addition, the State of Montana and
Avista Corp. are engaged in litigation regarding lease terms, including how much money, if any, the State of Montana will return to
Avista Corp. The Company is currently paying all lease payments to the State of Montana into an escrow account until the litigation is
resolved. As such, amounts recorded for this lease are uncertain and amounts may change in the future depending on the outcome of
the ongoing litigation. Any reduction in future lease payments or the return of previously paid amounts to Avista Corp. will be
included in the future ratemaking process.
In addition to the lease with the State of Montana, the Company also 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 73 years. Most of the 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 of the Company's lease agreements include rental payments which are periodically adjusted over the term of the agreement
based on the consumer price index. The Company's lease agreements do not include any material residual value guarantees or material
restrictive covenants.
Avista Corp. does not record leases with a term of 12 months or less in the Balance Sheets. Total short-term lease costs for the year
ended December 31, 2020 are immaterial.
The components of lease expense were as follows for the year ended December 31 (dollars in thousands):
2020 2019
Operating lease cost:
Fixed lease cost $4,746 $4,425
Variable lease cost 1,099 988
Total operating lease cost $5,845 $5,413
Supplemental cash flow information related to leases was as follows for the year ended December 31 (dollars in thousands):
2020 2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash outflows:
Operating lease payments $4,612 $4,375
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.14
Supplemental balance sheet information related to leases was as follows for December 31 (dollars in thousands):
December 31, December 31,
2020 2019
Operating Leases
Operating lease ROU assets (Utility Plant) $71,891 $69,746
Obligations under capital lease - current $4,249 $4,128
Obligations under capital lease - noncurrent 67,716 65,565
Total operating lease liabilities $71,965 $69,693
Weighted Average Remaining Lease Term
Operating leases 25.20 years 26.60 years
Weighted Average Discount Rate
Operating leases 4.28% 3.82%
Maturities of lease liabilities (including principal and interest) were as follows as of December 31, 2020 (dollars in thousands):
Operating Leases
2021 $4,779
2022 4,799
2023 4,827
2024 4,852
2025 4,865
Thereafter 96,734
Total lease payments $120,856
Less: imputed interest (48,891)
Total $71,965
Maturities of lease liabilities (including principal and interest) were as follows as of December 31, 2019 (dollars in thousands):
Operating Leases
2020 $4,372
2021 4,375
2022 4,383
2023 4,399
2024 4,411
Thereafter 91,654
Total lease payments $113,594
Less: imputed interest (43,901)
Total $69,693
NOTE 5. 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 of the 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 in order to manage the various
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.15
risks relating to these commodity price exposures. Avista Corp. has an energy resources risk policy and control procedures to manage
these risks.
As part of Avista Corp.'s resource procurement and management operations in the electric business, the Company engages in an
ongoing process of resource 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 of electric capacity and energy, fuel for electric generation, and derivative contracts related to
capacity, energy and fuel. Such transactions are part of the process of matching resources with load obligations and hedging a portion
of the related financial risks. These transactions range from terms of intra-hour up to multiple years.
As part of its resource procurement and management of its natural gas business, Avista Corp. makes continuing projections of its
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. On the basis of these projections, Avista Corp. plans and executes a series of transactions to hedge a
portion of its 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 for a 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 helps mitigate 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. However, if market conditions
and prices indicate that Avista Corp. should buy or sell natural gas during other times in 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 of surplus natural gas supplies, purchases and sales of natural gas to optimize use of pipeline and storage
capacity, and participation in the transportation capacity release market.
The following table presents the underlying energy commodity derivative volumes as of December 31, 2020 that are expected to be
delivered in each respective year (in thousands of MWhs and mmBTUs):
Purchases Sales
Electric Derivatives Gas Derivatives Electric Derivatives Gas Derivatives
Year
Physical (1)
MWh
Financial (1)
MWh
Physical (1)
mmBTUs
Financial (1)
mmBTUs
Physical (1)
MWh
Financial (1)
MWh
Physical (1)
mmBTUs
Financial (1)
mmBTUs
2021 1 224 10,353 65,188 17 451 5,448 39,273
2022 — — 450 25,525 — — 1,360 12,030
2023 — — — 4,950 — — 1,360 900
2024 — — — — — — 1,370 —
2025 — — — — — — 1,115 —
As of December 31, 2020, there are no expected deliveries of energy commodity derivatives after 2025.
The following table presents the underlying energy commodity derivative volumes as of December 31, 2019 that were expected to be
delivered in each respective year (in thousands of MWhs and mmBTUs):
Purchases Sales
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.16
Electric Derivatives Gas Derivatives Electric Derivatives Gas Derivatives
Year
Physical (1)
MWh
Financial (1)
MWh
Physical (1)
mmBTUs
Financial (1)
mmBTUs
Physical (1)
MWh
Financial (1)
MWh
Physical (1)
mmBTUs
Financial (1)
mmBTUs
2020 2 442 9,813 78,803 133 1,724 2,984 37,848
2021 — — 153 25,523 — 246 1,040 13,108
2022 — — 225 4,725 — — — 675
As of December 31, 2019, there were no expected deliveries of energy commodity derivatives after 2022.
(1)Physical transactions represent commodity transactions in which Avista Corp. will take or make delivery of either electricity
or natural gas; financial transactions represent derivative instruments with delivery of cash in the amount of the benefit or
cost but with no physical delivery of the 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 or natural gas supply costs during
the period they are 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 collected through retail rates from customers.
Foreign Currency Exchange Derivatives
A significant portion of Avista Corp.'s natural gas supply (including fuel for power generation) is obtained from Canadian sources.
Most of those transactions are executed in U.S. dollars, which avoids foreign currency risk. A portion of Avista Corp.’s short-term
natural gas transactions and long-term Canadian transportation contracts are committed based on Canadian currency prices and settled
within 60 days with U.S. dollars. Avista Corp. hedges a portion of the 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 that Avista Corp. has outstanding as of December 31
(dollars in thousands):
2020 2019
Number of contracts 22 20
Notional amount (in United States dollars) $3,860 $5,932
Notional amount (in Canadian dollars)4,949 7,828
Interest Rate Swap Derivatives
Avista Corp. is affected by fluctuating interest rates related to a portion of its existing debt, and future borrowing requirements. Avista
Corp. hedges a portion of its interest rate risk with financial derivative instruments. These financial derivative instruments 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 that Avista Corp. has outstanding as of the balance sheet
date indicated below (dollars in thousands):
Balance Sheet Date Number of Contracts
Notional
Amount
Mandatory Cash
Settlement Date
December 31, 2020 4 45,000 2021
11 120,000 2022
1 10,000 2023
December 31, 2019 7 70,000 2020
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.17
3 35,000 2021
10 110,000 2022
See Note 13 for discussion of the bond purchase agreement and the related settlement of interest rate swaps in connection with the
pricing of the bonds in June 2020.
The fair value of outstanding interest rate swap derivatives can vary significantly from period to period depending on the total
notional amount of swap 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 of settlement. Conversely, Avista Corp. receives cash to settle its interest rate swap derivatives
when prevailing market rates at the time of settlement exceed the fixed swap rates.
Summary of Outstanding Derivative Instruments
The amounts recorded on the Balance Sheets as of December 31, 2020 and December 31, 2019 reflect the offsetting of derivative
assets and liabilities where a legal right of offset exists.
The following table presents the fair values and locations of derivative instruments recorded on the Balance Sheets as of
December 31, 2020 (in thousands):
Fair Value
Derivative and Balance Sheet Location
Gross
Asset
Gross
Liability
Collateral
Netting
Net Asset
(Liability)
on Balance
Sheet
Foreign currency exchange derivatives
Derivative instrument assets current $30 $— $— $30
Interest rate swap derivatives
Derivative instrument liabilities current — (19,575) 8,050 (11,525)
Long-term portion of derivative liabilities 952 (32,190) — (31,238)
Energy commodity derivatives
Derivative instrument assets current 9,203 (8,306) — 897
Long-term portion of derivative assets 1,755 (1,159) — 596
Derivative instrument liabilities current 11,037 (14,007) 487 (2,483)
Long-term portion of derivative liabilities 1,725 (8,043) 129 (6,189)
Total derivative instruments recorded on the
balance sheet $24,702 $(83,280) $8,666 $(49,912)
The following table presents the fair values and locations of derivative instruments recorded on the Balance Sheets as of
December 31, 2019 (in thousands):
Fair Value
Derivative and Balance Sheet Location
Gross
Asset
Gross
Liability
Collateral
Netting
Net Asset
(Liability)
on Balance
Sheet
Foreign currency exchange derivatives
Derivative instrument assets current $97 $— $— $97
Interest rate swap derivatives
Derivative instrument assets current 589 — — 589
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.18
Derivative instrument liabilities current 238 (9,379) 1,316 (7,825)
Long-term portion of derivative liabilities 725 (24,677) 5,454 (18,498)
Energy commodity derivatives
Derivative instrument assets 416 (245) — 171
Long-term portion of derivative assets 6,369 (5,446) — 923
Derivative instrument liabilities current 34,760 (41,241) 3,378 (3,103)
Long-term portion of derivative liabilities 28 (1,215) — (1,187)
Total derivative instruments recorded on the
balance sheet $43,222 $(82,203) $10,148 $(28,833)
Exposure to Demands for Collateral
Avista Corp.'s derivative contracts often require collateral (in the form of cash or letters of credit) or other credit enhancements, or
reductions or terminations of a portion of the contract through cash settlement. In the event of a downgrade in Avista Corp.'s credit
ratings or changes in market prices, additional collateral may be required. In periods of price volatility, the level of exposure can
change significantly. As a result, sudden and significant demands may be made against Avista Corp.'s credit facilities and cash. Avista
Corp. actively monitors the exposure to possible collateral calls and takes steps to mitigate capital requirements.
The following table presents Avista Corp.'s collateral outstanding related to its derivative instruments as of December 31 (in
thousands):
2020 2019
Energy commodity derivatives
Cash collateral posted $4,953 $7,812
Letters of credit outstanding 23,500 17,400
Balance sheet offsetting (cash collateral against net derivative positions)616 3,378
Interest rate swap derivatives
Cash collateral posted (offset by net derivative positions)8,050 6,770
There were no letters of credit outstanding related to interest rate swap derivatives as of December 31, 2020 and December 31, 2019.
Certain of Avista Corp.’s derivative instruments contain provisions that require the Company to maintain an "investment grade" credit
rating from the major credit rating agencies. If Avista Corp.’s credit ratings were to fall below “investment grade,” it would be in
violation of these 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 fair value of all derivative instruments with credit-risk-related contingent features that are
in a liability position and the amount of additional collateral Avista Corp. could be required to post as of December 31 (in thousands):
2020 2019
Interest rate swap derivatives
Liabilities with credit-risk-related contingent features $50,813 $34,056
Additional collateral to post 42,763 26,912
NOTE 6. JOINTLY OWNED ELECTRIC FACILITIES
The Company has a 15 percent ownership interest in Units 3 & 4 of the Colstrip generating station, a coal-fired plant located in
southeastern Montana, and provides financing for its ownership interest in the project. Pursuant to the ownership and operating
agreements among the co-owners, the Company’s share of related fuel costs as well as operating expenses for plant in service are
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.19
included in the corresponding accounts in the Statements of Income. The Company’s share of utility plant in service for Colstrip and
accumulated depreciation (inclusive of the ARO assets and accumulated amortization) were as follows as of December 31 (dollars in
thousands):
2020 2019
Utility plant in service $391,922 $387,860
Accumulated depreciation (284,282) (268,637)
See Note 7 for further discussion of AROs.
While the obligations and liabilities with respect to Colstrip are to be shared among the co-owners on a pro-rata basis, many of the
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 7. 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 of the 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 EPA issued a final rule regarding CCRs. Colstrip, of which Avista Corp. is a 15 percent owner of Units 3 & 4, produces
this byproduct. The CCR rule has been the subject of ongoing litigation. In August 2018, the D.C. Circuit struck down provisions of
the 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.
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 of data used to
estimate costs, such as the quantity of coal 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 of any increased costs related to complying with the CCR rule through customer rates.
In addition to the above, under a 2018 Administrative Order on Consent and ongoing negotiations with the Montana Department of
Ecological Quality, the owners of Colstrip are required to provide financial assurance, primarily in the form of surety bonds, to secure
each owner's pro-rata share of various anticipated closure and remediation of the ash ponds and coal holding areas. The amount of
financial assurance required of each owner may, like the ARO, vary substantially due to the uncertainty and evolving nature of
anticipated 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 December 31
(dollars in thousands):
2020 2019
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.20
Asset retirement obligation at beginning of year $20,338 $18,266
Liabilities incurred (2,315) 2,699
Liabilities settled (1,645) (1,503)
Accretion expense 816 876
Asset retirement obligation at end of year $17,194 $20,338
NOTE 8. PENSION PLANS AND OTHER POSTRETIREMENT BENEFIT PLANS
The pension and other postretirement benefit plans described below only relate to Avista Corp. AEL&P (not discussed below)
participates in a defined contribution multiemployer plan for its union workers and a defined contribution money purchase pension
plan for its nonunion workers. None of the subsidiary retirement plans, individually or in the aggregate, are significant to Avista Corp.
Avista Corp.
The Company has a defined benefit pension plan covering the majority of all regular full-time employees at Avista Corp. that were
hired prior to January 1, 2014. 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 participate in a defined
contribution 401(k) plan in lieu of a defined benefit pension plan. Union employees hired on or after January 1, 2014 are still covered
under the defined benefit pension plan. The Company’s funding policy is to contribute at least the minimum amounts that are required
to be funded under the Employee Retirement Income Security Act, but not more than the maximum amounts that are currently
deductible for income tax purposes. The Company contributed $22.0 million in cash to the pension plan in 2020 and 2019. The
Company expects to contribute $42.0 million in cash to the pension plan in 2021.
The Company also has a SERP that provides additional pension benefits to certain executive officers and certain key employees of the
Company. The SERP is intended to provide benefits to individuals whose benefits under the defined benefit pension plan are reduced
due to the application of Section 415 of the Internal Revenue Code of 1986 and the deferral of salary under deferred compensation
plans. The liability and expense for this plan are included as pension benefits in the tables included in this Note.
The Company expects that benefit payments under the pension plan and the SERP will total (dollars in thousands):
2021 2022 2023 2024 2025
Total 2026-
2030
Expected benefit payments
$42,390 $42,673 $42,478 $43,149 $43,752 $
223,78
8
The expected long-term rate of return on plan assets is based on past performance and economic forecasts for the types of investments
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 of the expected term of pension benefits.
The Company provides certain health care and life insurance benefits for eligible retired employees that were hired prior to January 1,
2014. The Company accrues the estimated cost of postretirement benefit obligations during the years that employees provide services.
The liability and expense of this 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 of the HRA are included as other postretirement benefits.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.21
The Company provides death benefits to beneficiaries of executive officers who die during their term of office or after retirement.
Under the plan, an executive officer’s designated beneficiary will receive a payment equal to twice the executive officer’s annual base
salary at the time of death (or if death occurs after retirement, a payment equal to twice the executive officer’s total annual pension
benefit). The liability and expense for this plan are included as other postretirement benefits.
The Company expects that benefit payments under other postretirement benefit plans will total (dollars in thousands):
2021 2022 2023 2024 2025
Total
2026-
2030
Expected benefit payments $6,610 $6,800 $6,891 $7,021 $7,164 $37,156
The Company expects to contribute $6.8 million to other postretirement benefit plans in 2021, representing expected benefit payments
to be paid during the year excluding the Medicare Part D subsidy. The Company uses a December 31 measurement date for its
pension and other postretirement benefit plans.
The following table sets forth the pension and other postretirement benefit plan disclosures as of December 31, 2020 and 2019 and the
components of net periodic benefit costs for the years ended December 31, 2020 and 2019 (dollars in thousands):
Pension Benefits
Other Post-
retirement Benefits
2020 2019 2020 2019
Change in benefit obligation:
Benefit obligation as of beginning of year $742,382 $671,629 $159,296 $134,053
Service cost 22,392 19,755 3,902 3,006
Interest cost 27,853 28,417 6,042 5,598
Actuarial (gain)/loss 74,688 57,829 (2,589) 23,344
Benefits paid (40,400) (35,248) (5,418) (6,705)
Benefit obligation as of end of year $826,915 $742,382 $161,233 $159,296
Change in plan assets:
Fair value of plan assets as of beginning of year $642,063 $544,051 $44,853 $36,852
Actual return on plan assets 96,591 109,942 7,320 8,001
Employer contributions 22,000 22,000 — —
Benefits paid (38,630) (33,930) — —
Fair value of plan assets as of end of year $722,024 $642,063 $52,173 $44,853
Funded status $(104,891) $(100,319) $(109,060) $(114,443)
Amounts recognized in the Balance Sheets:
Current liabilities $(1,943) $(1,602) $(669) $(640)
Non-current liabilities (102,948) (98,717) (108,391) (113,803)
Net amount recognized $(104,891) $(100,319) $(109,060) $(114,443)
Accumulated pension benefit obligation $710,023 $644,004
Accumulated postretirement benefit obligation:
For retirees $75,876 $72,816
For fully eligible employees $32,097 $34,545
For other participants $53,260 $51,935
Included in accumulated other comprehensive loss (income) (net of tax):
Unrecognized prior service cost $1,902 $2,105 $(3,570) $(4,400)
Unrecognized net actuarial loss 119,318 114,368 53,737 63,101
Total 121,220 116,473 50,167 58,701
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.22
Less regulatory asset (108,301) (107,395) (48,708) (57,520)
Accumulated other comprehensive loss for unfunded
benefit
obligation for pensions and other postretirement benefit
plans $12,919 $9,078 $1,459 $1,181
Pension Benefits
Other Post-
retirement Benefits
2020 2019 2020 2019
Weighted-average assumptions as of December 31:
Discount rate for benefit obligation 3.25% 3.85% 3.27% 3.89%
Discount rate for annual expense 3.85% 4.31% 3.89% 4.32%
Expected long-term return on plan assets 5.50% 5.90% 5.30% 5.70%
Rate of compensation increase 4.74% 4.66%
Medical cost trend pre-age 65 – initial 6.25% 5.75%
Medical cost trend pre-age 65 – ultimate 5.00% 5.00%
Ultimate medical cost trend year pre-age 65 2026 2023
Medical cost trend post-age 65 – initial 6.25% 6.50%
Medical cost trend post-age 65 – ultimate 5.00% 5.00%
Ultimate medical cost trend year post-age 65 2026 2026
Pension Benefits
Other Post-retirement
Benefits
2020 2019 2020 2019
Components of net periodic benefit cost:
Service cost (a) $22,392 $19,755 $3,902 $3,006
Interest cost 27,853 28,417 6,042 5,598
Expected return on plan assets (34,886) (31,763) (2,377) (2,101)
Amortization of prior service cost 257 257 (958) (981)
Net loss recognition 6,717 10,216 4,871 4,013
Net periodic benefit cost $22,333 $26,882 $11,480 $9,535
(a)(a) Total service costs in the table above are 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 40
percent of all labor and benefits is capitalized to utility property and 60 percent is expensed to utility other operating
expenses.
Plan Assets
The Finance Committee of the Company’s Board of Directors approves investment policies, objectives and strategies that seek an
appropriate return for the pension plan and other postretirement benefit plans 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 compliance with investment policy objectives and strategies.
Pension plan assets are invested in mutual funds, trusts and partnerships that hold marketable debt and equity securities, real estate,
and absolute return. In seeking to obtain a return that aligns with the funded status of the pension plan, the investment consultant
recommends allocation percentages by asset classes. These recommendations are reviewed by the internal benefits committee, which
then recommends their adoption by the Finance Committee. The Finance Committee has established target investment allocation
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.23
percentages by asset classes and also investment ranges for each asset class. The target investment allocation percentages are typically
the midpoint of the established range. The target investment allocation percentages by asset classes are indicated in the table below:
2020 2019
Equity securities 35% 35%
Debt securities 49% 49%
Real estate 7% 7%
Absolute return 9% 9%
The target investment allocation percentages were revised in the first quarter of 2021 and the pension plan assets are being reinvested
to move toward the new target investment allocation percentages of 55 percent equity securities, 40 percent debt securities, 5 percent
real estate and 0 percent absolute return. The target asset allocation percentages were modified to better align the asset allocations
with the funded status of the pension plan.
The fair value of pension plan assets invested in debt and equity securities was based primarily on fair value (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-the-counter market are valued at the last reported bid price. Investment securities for which market prices are not
readily available or for which market prices do not represent the value at the time of pricing, the investment manager estimates fair
value based upon other inputs (including valuations of securities that are comparable in coupon, rating, maturity and industry).
Pension plan and other postretirement plan assets whose fair values are measured using net asset value (NAV) are excluded from the
fair value hierarchy and are included as reconciling items in the tables below.
The Company's investments in common/collective trusts have redemption limitations that permit quarterly redemptions following
notice requirements of 45 to 60 days. Most of the Company's investments in closely held investments and partnership interests have
redemption limitations that range from bi-monthly to semi-annually following redemption notice requirements of 60 to 90 days. One
investment in a partnership has a lock-up for redemption currently expiring in 2022 and is subject to extension.
The following table discloses by level within the fair value hierarchy (see Note 15 for a description of the fair value hierarchy) of the
pension plan’s assets measured and reported as of December 31, 2020 at fair value (dollars in thousands):
Level 1 Level 2 Level 3 Total
Cash equivalents $— $3,309 $— $3,309
Fixed income securities:
U.S. government issues — 10,990 — 10,990
Corporate issues — 279,857 — 279,857
International issues — 39,634 — 39,634
Municipal issues — 22,431 — 22,431
Mutual funds:
U.S. equity securities 146,375 — — 146,375
International equity securities 96,311 — — 96,311
Absolute return (1)11,640 — — 11,640
Plan assets measured at NAV (not subject to hierarchy
disclosure)
Common/collective trusts:
Real estate — — — 29,532
Partnership/closely held investments:
Absolute return (1)— — — 47,188
International equity securities — — — 26,760
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.24
Real estate — — — 7,997
Total $254,326 $356,221 $— $722,024
The following table discloses by level within the fair value hierarchy (see Note 15 for a description of the fair value hierarchy) of the
pension plan’s assets measured and reported as of December 31, 2019 at fair value (dollars in thousands):
Level 1 Level 2 Level 3 Total
Cash equivalents $— $2,852 $— $2,852
Fixed income securities:
U.S. government issues — 37,297 — 37,297
Corporate issues — 207,222 — 207,222
International issues — 35,836 — 35,836
Municipal issues — 23,539 — 23,539
Mutual funds:
U.S. equity securities 173,568 — — 173,568
International equity securities 46,416 — — 46,416
Absolute return (1)16,720 — — 16,720
Plan assets measured at NAV (not subject to hierarchy
disclosure)
Common/collective trusts:
Real estate — — — 31,473
Partnership/closely held investments:
Absolute return (1)— — — 59,260
Real estate — — — 7,880
Total $236,704 $306,746 $— $642,063
(1) This category invests in multiple strategies to diversify risk and reduce volatility. The strategies include: (a) event driven,
relative value, convertible, and fixed income arbitrage, (b) distressed investments, (c) long/short equity and fixed income,
and (d) market neutral strategies.
The fair value of other postretirement plan assets invested in debt and equity securities was based primarily on market prices. The fair
value of investment 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. Investment securities for which market prices are not
readily available are fair-valued by the investment manager based upon other inputs (including valuations of securities that are
comparable in coupon, rating, maturity and industry). The target asset allocation was 60 percent equity securities and 40 percent debt
securities in both 2020 and 2019.
The fair value of other postretirement plan assets was determined as of December 31, 2020 and 2019.
The following table discloses by level within the fair value hierarchy (see Note 15 for a description of the fair value hierarchy) of
other postretirement plan assets measured and reported as of December 31, 2020 at fair value (dollars in thousands):
Level 1 Level 2 Level 3 Total
Balanced index mutual fund (1) $52,173 $— $— $52,173
The following table discloses by level within the fair value hierarchy (see Note 15 for a description of the fair value hierarchy) of
other postretirement plan assets measured and reported as of December 31, 2019 at fair value (dollars in thousands):
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.25
Level 1 Level 2 Level 3 Total
Balanced index mutual fund (1) $44,853 $— $— $44,853
(1)The balanced index fund for 2020 and 2019 is a single mutual fund that includes a percentage of U.S. equity and fixed
income securities and International equity and fixed income securities.
401(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 of the 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 thousands):
2020 2019
Employer 401(k) matching contributions $11,742 $10,412
The Company has an Executive Deferral Plan. This plan allows executive officers and other key employees the opportunity to defer
until the earlier of their retirement, termination, disability or death, up to 75 percent of their base salary and/or up to 100 percent of
their incentive payments. Deferred compensation funds are held by the Company in a Rabbi Trust.
There were deferred compensation assets and corresponding deferred compensation liabilities on the Balance Sheets of the following
amounts as of December 31 (dollars in thousands):
2020 2019
Deferred compensation assets and liabilities $9,174 $8,948
NOTE 9. ACCOUNTING FOR INCOME TAXES
The realization of deferred income tax assets is dependent upon the ability to generate taxable income in future periods. The Company
evaluated available evidence supporting the realization of its deferred income tax assets and determined it is more likely than not that
deferred income tax assets will be realized.
As of December 31, 2020, the Company had $18.3 million of state tax credit carryforwards. Of the total amount, the Company
believes that it is more likely than not that it will only be able to utilize $8.6 million of the state tax credits. As such, the Company has
recorded a valuation allowance of $9.7 million against the state tax credit carryforwards and reflected the net amount of $8.6 million
as an asset as of December 31, 2020. State tax credits expire from 2021 to 2034.
Status of Internal Revenue Service (IRS) and State Examinations
The Company and its eligible subsidiaries file federal income tax returns. All tax years after 2016 are open for an IRS tax
examination.
The Company also files state income tax returns in certain jurisdictions, including Idaho, Oregon, and Montana. Subsidiaries are
charged or credited with the tax effects of their operations on a stand-alone basis.
The Idaho State Tax Commission is currently reviewing tax years 2014 through 2017. All tax years after 2016 are open for
examination in Montana and Oregon, and all tax years after 2017 are open for examination in Idaho.
The Company believes that any open tax years for federal or state income taxes will not result in adjustments that would be significant
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.26
to the financial statements.
NOTE 10. ENERGY PURCHASE CONTRACTS
Avista Corp. has contracts for the purchase of fuel for thermal generation, natural gas for resale and various agreements for the
purchase or exchange of electric energy with other entities. The remaining term of the contracts range from one month to twenty-five
years.
Total expenses for power purchased, natural gas purchased, fuel for generation and other fuel costs, which are included in utility
resource costs in the Statements of Income, were as follows for the years ended December 31 (dollars in thousands):
2020 2019
Utility power resources $324,297 $376,769
The following table details Avista Corp.’s future contractual commitments for power resources (including transmission contracts) and
natural gas resources (including transportation contracts) (dollars in thousands):
2021 2022 2023 2024 2025 Thereafter Total
Power resources
$
181,87
2 $
177,78
6 $
173,53
6 $
157,22
1 $
157,88
7 $849,444 $
1,697,74
6
Natural gas resources 67,717 52,158 42,499 35,598 32,473 241,145 471,590
Total
$
249,58
9 $
229,94
4 $
216,03
5 $
192,81
9 $
190,36
0 $
1,090,58
9 $
2,169,33
6
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. As a result, these costs are recovered
either through base retail rates or adjustments to retail rates as part of the power and natural gas cost deferral and recovery
mechanisms.
The above future contractual commitments for power resources include fixed contractual amounts related to the Company's contracts
with certain Public Utility Districts (PUD) to purchase portions of the output of certain generating facilities. Although Avista Corp.
has no investment in the PUD generating facilities, the fixed contracts obligate Avista Corp. to pay certain minimum amounts whether
or not the facilities are operating. The cost of power obtained under the contracts, including payments made when a facility 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 of existing debt service cost and its proportionate share of the variable operating expenses of these projects. The
minimum amounts payable under these contracts are based in part on the proportionate share of the debt service requirements of the
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, 2020 (principal and interest) was $63.7 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 of Income. The following table details future contractual commitments under these agreements (dollars in thousands):
2021 2022 2023 2024 2025 Thereafter Total
Contractual obligations
$
33,88
5 $
31,33
9 $
32,08
3 $
35,68
2 $
33,70
6 $
208,52
6 $
375,22
1
NOTE 11. NOTES PAYABLE
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.27
Avista Corp. has a committed line of credit with various financial institutions in the total amount of $400.0 million. During 2020, the
Company amended and extended, for one additional year, the revolving line of credit agreement for a revised expiration date of April
2022, with the option to extend for an additional one year period. The committed line of credit is secured by non-transferable first
mortgage bonds of the 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 under the committed line of credit.
The committed line of credit agreement contains customary covenants and default provisions. The credit agreement has a covenant
which does not permit the ratio of “ consolidated total debt” to “consolidated total capitalization” of Avista Corp. to be greater than 65
percent at any time. As of December 31, 2020, the Company was in compliance with this covenant.
Balances outstanding and interest rates of borrowings (excluding letters of credit) under the Company’s revolving committed lines of
credit were as follows as of December 31 (dollars in thousands):
2020 2019
Balance outstanding at end of period $102,000 $182,300
Letters of credit outstanding at end of period $27,618 $21,473
Average interest rate at end of period 1.22%2.64%
As of December 31, 2020 and 2019, the borrowings outstanding under Avista Corp.'s committed line of credit were classified as
short-term borrowings on the Balance Sheets.
NOTE 12. CREDIT AGREEMENT
In April 2020, the Company entered into a Credit Agreement with various financial institutions, in the amount of $100 million with an
expiration date of April 2021. Indebtedness under this agreement is unsecured.
The Credit Agreement contains customary covenants and default provisions, including a covenant not to permit the ratio of "
consolidated total debt" to "consolidated total capitalization" of Avista Corp. to be greater than 65 percent at any time.
The Company borrowed the entire $100 million available under this agreement.
NOTE 13. BONDS
The following details long-term debt outstanding as of December 31 (dollars in thousands):
Maturity
Year Description
Interest
Rate 2020 2019
Avista Corp. Secured Long-Term Debt
2020 First Mortgage Bonds 3.89%— 52,000
2022 First Mortgage Bonds 5.13%250,000 250,000
2023
Secured Medium-Term Notes
7.18%-7.54
%13,500 13,500
2028 Secured Medium-Term Notes 6.37%25,000 25,000
2032 Secured Pollution Control Bonds (1)(1)66,700 66,700
2034 Secured Pollution Control Bonds (1)(1)17,000 17,000
2035 First Mortgage Bonds 6.25%150,000 150,000
2037 First Mortgage Bonds 5.70%150,000 150,000
2040 First Mortgage Bonds 5.55%35,000 35,000
2041 First Mortgage Bonds 4.45%85,000 85,000
2044 First Mortgage Bonds 4.11%60,000 60,000
2045 First Mortgage Bonds 4.37%100,000 100,000
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.28
2047 First Mortgage Bonds 4.23%80,000 80,000
2047 First Mortgage Bonds 3.91%90,000 90,000
2048 First Mortgage Bonds 4.35%375,000 375,000
2049 First Mortgage Bonds 3.43%180,000 180,000
2050 First Mortgage Bonds (2)3.07%165,000 —
2051 First Mortgage Bonds 3.54%175,000 175,000
Total Avista Corp. secured long-term bonds 2,017,200 1,904,200
Secured Pollution Control Bonds held by Avista
Corporation (1)(83,700) (83,700)
Total long-term bonds $1,933,500 $1,820,500
(1) In December 2010, $66.7 million and $17.0 million of the City of Forsyth, Montana Pollution Control Revenue Refunding
Bonds (Avista Corporation Colstrip Project) due in 2032 and 2034, respectively, which had been held by Avista Corp. since
2008 and 2009, respectively, were refunded by new variable rate bond issues (Series 2010A and Series 2010B). The new
bonds were not offered to the public and were purchased by Avista Corp. due to market conditions. The Company expects
that at a later date, subject to market conditions, these bonds may be remarketed to unaffiliated investors. So long as Avista
Corp. is the holder of these bonds, the bonds will not be reflected as an asset or a liability on Avista Corp.'s Balance Sheets.
(2) In September 2020, the Company issued and sold $165.0 million of 3.07 percent first mortgage bonds due in 2050 pursuant
to a bond purchase agreement with institutional investors in the private placement market. The total net proceeds from the
sale of the bonds were used to repay maturing long-term debt of $52.0 million and repay a portion of the outstanding balance
under Avista Corp.'s $400.0 million committed line of credit. In connection with the pricing of the first mortgage bonds in
June 2020, the Company cash settled seven interest rate swap derivatives (notional aggregate amount of $70.0 million) and
paid a net amount of $33.5 million. See Note 5 for a discussion of interest rate swap derivatives.
The following table details future long-term debt maturities including advances from associated companies (see Note 14) (dollars in
thousands):
2021 2022 2023 2024 2025 Thereafter Total
Debt maturities
$— $
250,00
0 $
13,50
0 $— $— $
1,721,54
7 $
1,985,04
7
Substantially all of Avista Corp.'s owned properties are subject to the lien of its mortgage indenture. Under the Mortgage and Deed of
Trust (Mortgage) securing its first mortgage bonds (including secured medium-term notes), Avista Corp. may each issue additional
first mortgage bonds under its mortgage in an aggregate principal amount equal to the sum of:
66-2/3 percent of the cost or fair value (whichever is lower) of property additions which have not previously been
made the basis of any application under the Mortgage, or
an equal principal amount of retired first mortgage bonds which have not previously been made the basis of any
application under the Mortgage, or
deposit of cash.
Avista Corp. may not issue any additional first mortgage bonds (with certain exceptions in the case of bonds issued on the basis of
retired bonds) unless it has “net earnings” (as defined in the Mortgage) for any period of 12 consecutive calendar months out of the
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 of prior rank. As of December 31, 2020,
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.29
property additions and retired bonds would have allowed, and the net earnings test would not have prohibited, the issuance of $1.7
billion in an aggregate principal amount of additional first mortgage bonds at Avista Corp.
NOTE 14. ADVANCES FROM ASSOCIATED COMPANIES
In 1997, the Company issued Floating Rate Junior Subordinated Deferrable Interest Debentures, Series B, with a principal amount of
$51.5 million to Avista Capital II, an affiliated business trust formed by the Company. Avista Capital II issued $50.0 million of
Preferred Trust Securities with a floating distribution rate of LIBOR plus 0.875 percent, calculated and reset quarterly.
The distribution rates paid were as follows during the years ended December 31:
2020 2019
Low distribution rate 1.10% 2.79%
High distribution rate 2.79% 3.61%
Distribution rate at the end of the year 1.10% 2.79%
Concurrent with the issuance of the Preferred Trust Securities, Avista Capital II issued $1.5 million of Common Trust Securities to
the Company. These Preferred Trust Securities may be redeemed at the option of Avista Capital II at any time and mature on June 1,
2037. In December 2000, the Company purchased $10.0 million of these Preferred Trust Securities.
The Company owns 100 percent of Avista Capital II and has solely and unconditionally guaranteed the payment of distributions on,
and redemption price and liquidation amount for, the Preferred Trust Securities to the extent that Avista Capital II has funds available
for such payments from the respective debt securities. Upon maturity or prior redemption of such debt securities, the Preferred Trust
Securities will be mandatorily redeemed.
NOTE 15. FAIR VALUE
The carrying values of cash and cash equivalents, special deposits, accounts and notes receivable, accounts payable and notes payable
are reasonable estimates of their fair values. Bonds and advances from associated companies are reported at carrying value on the
Balance Sheets.
The fair value hierarchy prioritizes the inputs used to measure fair value. 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 fair values derived from
unobservable inputs (Level 3 measurements).
The three levels of the fair value hierarchy are defined as follows:
Level 1 – Quoted prices are available in active markets for identical assets or liabilities. Active markets are those in which
transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis.
Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, but which are either directly or
indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other
valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted
forward prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying
instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace
throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which
transactions are executed in the marketplace.
Level 3 – Pricing inputs include significant inputs that are generally unobservable from objective sources. These inputs may be
used with internally developed methodologies that result in management’s best estimate of fair value.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.30
Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value
measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment,
and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The
determination of the fair values incorporates various factors that not only include the credit standing of the 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 fair value of the Company’s financial instruments not reported at
estimated fair value on the Balance Sheets as of December 31 (dollars in thousands):
2020 2019
Carrying
Value
Estimated
Fair Value
Carrying
Value
Estimated
Fair Value
Bonds (Level 2) $963,500 $1,189,824 $963,500 $1,124,649
Bonds (Level 3)970,000 1,125,618 857,000 946,674
Advances from associated companies (Level 3)51,547 43,815 51,547 41,238
These estimates of fair value of bonds and advances from associated trusts were primarily based on available market information,
which generally consists of estimated market prices from third party brokers for debt with similar risk and terms. The price ranges
obtained from the third party brokers consisted of par values of 85.0 to 144.9, where a par value of 100.00 represents the carrying
value recorded on the Balance Sheets. Level 2 bonds represent 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 using comparable
bonds with similar risk and terms if there is no trading activity near a period end. Level 3 bonds consist of private placement bonds
and advances from affiliated companies, which typically have no secondary trading activity. Fair values in Level 3 are estimated
based on market prices from third party brokers using secondary market quotes for bonds with similar risk and terms to generate
quotes for Avista Corp. bonds.
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, 2020 at fair value on a recurring basis (dollars in thousands):
Level 1 Level 2 Level 3
Counterparty
and Cash
Collateral
Netting (1)Total
December 31, 2020
Assets:
Energy commodity derivatives $— $23,645 $— $(22,152) $1,493
Level 3 energy commodity derivatives:
Natural gas exchange agreements — — 75 (75) —
Foreign currency exchange derivatives — 30 — — 30
Interest rate swap derivatives — 952 — (952) —
Deferred compensation assets:
Mutual Funds:
Fixed income securities 2,471 — — — 2,471
Equity securities 6,228 — — — 6,228
Total $8,699 $24,627 $75 $(23,179) $10,222
Liabilities:
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.31
Energy commodity derivatives $— $23,030 $— $(22,768) $262
Level 3 energy commodity derivatives:
Natural gas exchange agreement — — 8,485 (75) 8,410
Interest rate swap derivatives — 51,765 — (9,002) 42,763
Total $— $74,795 $8,485 $(31,845) $51,435
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, 2019 at fair value on a recurring basis (dollars in thousands):
Level 1 Level 2 Level 3
Counterparty
and Cash
Collateral
Netting (1)Total
December 31, 2019
Assets:
Energy commodity derivatives $— $41,546 $— $(40,452) $1,094
Level 3 energy commodity derivatives:
Natural gas exchange agreement — — 27 (27) —
Foreign currency exchange derivatives — 97 — — 97
Interest rate swap derivatives — 1,552 — (963) 589
Deferred compensation assets:
Mutual Funds:
Fixed income securities 2,232 — — — 2,232
Equity securities 6,271 — — — 6,271
Total $8,503 $43,195 $27 $(41,442) $10,283
Liabilities:
Energy commodity derivatives $— $45,144 $— $(43,830) $1,314
Level 3 energy commodity derivatives:
Natural gas exchange agreement — — 3,003 (27) 2,976
Interest rate swap derivatives — 34,056 — (7,733) 26,323
Total $— $79,200 $3,003 $(51,590) $30,613
(1) 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
any payables and receivables for cash collateral held or placed with these same counterparties.
The difference between the amount of derivative assets and liabilities disclosed in respective levels in the table above and the amount
of derivative assets and liabilities disclosed on the Balance Sheets is due to netting arrangements with certain counterparties. See Note
4 for additional discussion of derivative netting.
To establish fair value for energy commodity derivatives, the Company uses quoted market prices and forward price curves to
estimate the fair value of energy commodity derivative instruments included in Level 2. In particular, electric derivative valuations are
performed using market quotes, adjusted for periods in between quotable periods. Natural gas derivative valuations are 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 of the 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 of
the swaps and discounts the cash flows back to present value using an appropriate discount rate. The discount rate is calculated by
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.32
third party brokers according to the terms of the swap derivatives and evaluated by the Company for reasonableness, with
consideration given to the potential non-performance risk by the Company. Future cash flows of the 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 for each
period.
To establish fair value for foreign currency derivatives, the Company uses forward market curves for Canadian dollars against the US
dollar and multiplies the difference between the locked-in price and the market price by the notional amount of the derivative.
Forward foreign currency market curves are provided by third party brokers. The Company's credit spread is factored into the
locked-in price of the foreign exchange contracts.
Deferred compensation assets and liabilities represent funds held by the Company in a Rabbi Trust for an executive deferral plan.
These funds consist of actively traded equity and bond funds with quoted prices in active markets. The balance disclosed in the table
above excludes cash and cash equivalents of $0.5 million as of December 31, 2020 and $0.4 million as of December 31, 2019.
Level 3 Fair Value
For the natural gas commodity exchange agreement, the Company uses the same Level 2 brokered quotes described above; however,
the Company also estimates the purchase and sales volumes (within contractual limits) as well as the timing of those transactions.
Changing the timing of volume estimates changes the timing of purchases and sales, impacting which brokered quote is used. Because
the brokered quotes can vary significantly from period to period, the unobservable estimates of the timing and volume of transactions
can have a significant impact on the calculated fair value. The Company currently estimates volumes and timing of transactions based
on a most likely scenario using historical data. Historically, the timing and volume of transactions have not been highly correlated
with market prices and market volatility.
The following table presents the quantitative information which was used to estimate the fair values of the Level 3 assets and
liabilities above as of December 31, 2020 (dollars in thousands):
Fair Value (Net) at
December 31,
2020
Valuation
Technique Unobservable Input Range
Natural gas exchange (8,410) Internally
derived
weighted
average
cost of gas
Forward purchase
prices
$1.71 - $2.54/mmBTU
$2.01 Weighted Average
Forward sales prices $1.76 - $4.16/mmBTU
$3.22 Weighted Average
Purchase volumes 130,000 - 310,000
mmBTUs
Sales volumes 75,000 - 310,000
mmBTUs
The valuation methods, significant inputs and resulting fair values described above were developed by the Company's management
and are reviewed on at least a quarterly basis to ensure they provide a reasonable estimate of fair value each reporting period.
The following table presents activity for energy commodity derivative assets (liabilities) measured at fair value using significant
unobservable inputs (Level 3) for the years ended December 31 (dollars in thousands):
Natural Gas
Exchange
Power
Exchange
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.33
Agreement Agreement Total
Year ended December 31, 2020:
Balance as of January 1, 2020 $(2,976) $— $(2,976)
Total losses (realized/unrealized):
Included in regulatory assets (1)(4,311) — (4,311)
Settlements (1,123) — (1,123)
Ending balance as of December 31, 2020 (2) $(8,410) $— $(8,410)
Year ended December 31, 2019:
Balance as of January 1, 2019 $(2,774) $(2,488) $(5,262)
Total losses (realized/unrealized):
Included in regulatory assets (1)8,175 435 8,610
Settlements (8,377) 2,053 (6,324)
Ending balance as of December 31, 2019 (2) $(2,976) $— $(2,976)
(1)All gains and losses are included in other regulatory assets and liabilities. There were no gains and losses included in either
net income or other comprehensive income during any of the periods presented in the table above.
(2)There were no purchases, issuances or transfers from other categories of any derivatives instruments during the periods
presented in the table above.
NOTE 16. COMMON STOCK
The payment of dividends 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 of section 10(d) of the FPA (see Note 1), and
certain requirements under the OPUC approval of the AERC acquisition in 2014. The OPUC's AERC acquisition
order requires Avista Corp. to maintain a capital structure of no less than 35 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 of the OPUC approval of the AERC acquisition are the most restrictive. Under the OPUC restriction, the amount
available for dividends at December 31, 2020 was $311.8 million.
The Company has 10 million authorized shares of preferred stock. The Company did not have any preferred stock outstanding as of
December 31, 2020 and 2019.
Equity Issuances
The Company issued equity in 2020 for total net proceeds of $72.2 million. Most of these issuances came through the Company's
sales agency agreements under which the sales agents may offer and sell new shares of common stock from time to time. The
Company has board and regulatory authority to issue a maximum of 3.2 million shares under these agreements, of which 1.3 million
remain unissued as of December 31, 2020. In 2020, 1.9 million shares were issued under these agreements resulting in total net
proceeds of $70.6 million.
NOTE 17. COMMITMENTS AND CONTINGENCIES
In the course of its business, the Company becomes involved in various claims, controversies, disputes and other contingent matters,
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.34
including the items described in this Note. Some of these claims, controversies, disputes and other contingent matters involve
litigation or other contested proceedings. For all such matters, the Company intends to vigorously protect and defend its interests and
pursue its rights. However, no assurance can be given as to the ultimate outcome of any particular matter because litigation and other
contested proceedings are inherently subject to numerous uncertainties. For matters that affect Avista Corp.’s operations, the
Company intends to seek, to the extent appropriate, recovery of incurred costs through the ratemaking process.
Collective Bargaining Agreements
The Company’s collective bargaining agreement with the IBEW represents approximately 40 percent of all of Avista Corp.’s
employees. Avista’s largest represented group, representing approximately 90 percent of Avista Corp.'s bargaining unit employees in
Washington and Idaho, are currently covered under a three-year agreement which expires in March 2021.
The Company is in the process of negotiating a new agreement with the IBEW. However, there is a risk that if the collective
bargaining agreement expired and a new agreement was not reached, employees subject to that agreement could strike. Given the
number of employees that are covered by the collective bargaining agreement, a strike could result in disruptions to our operations.
However, the Company believes that the possibility of this occurring is remote.
2015 Washington General Rate Cases
In January 2016, the Company received an order (Order 05) that concluded its electric and natural gas general rate cases that were
originally filed with the WUTC in February 2015. New electric and natural gas rates were effective on January 11, 2016.
PC Petition for Judicial Review
In March 2016, PC filed in Thurston County Superior Court a Petition for Judicial Review of the WUTC's Order 05 and Order 06
described above. In April 2016, this matter was certified for review directly by the Court of Appeals, an intermediate appellate court
in the State of Washington.
In August 2018, the Court of Appeals issued a "Published Opinion" (Opinion) which concluded that the WUTC's use of an attrition
allowance to calculate Avista Corp.'s rate base violated Washington law. In the Opinion, the Court stated that because the projected
additions to rate base in the future were not "used and useful" for service at the time the request for the rate increase was made, they
may not lawfully be included in the Company's rate base to justify a rate increase. Accordingly, the Court concluded that the WUTC
erred in including an attrition allowance in the calculation of Avista Corp.’s electric and natural gas rate base. The Court noted,
however, that the law does not prohibit an attrition allowance in the calculation, for ratemaking purposes, of recoverable operating
and maintenance expense. Since the WUTC order provided one lump sum attrition allowance without distinguishing what portion was
for rate base and which was for operating and maintenance expenses or other considerations, the Court struck all portions of the
attrition allowance attributable to Avista Corp.'s rate base and reversed and remanded the case for the WUTC to recalculate Avista
Corp.’s rates without including an attrition allowance in the calculation of rate base.
In March 2020, the Company received an order from the WUTC that requires it to refund $8.5 million to electric and natural gas
customers. The Company will refund $4.9 million to electric customers and $3.6 million to natural gas customers, which is being
refunded over a twelve-month period that began on April 1, 2020. The Company previously recorded a customer refund liability of
$8.5 million in 2019.
Boyds Fire (State of Washington Department of Natural Resources v. Avista)
In August 2019, the Company was served with a complaint, captioned “State of Washington Department of Natural Resources v.
Avista Corporation,” seeking recovery 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 that the fire,
which became known as the “Boyds Fire,” was caused by a dead ponderosa pine tree falling into an overhead distribution line, and
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.35
that Avista Corp. was negligent in failing to identify and remove the tree before it came into contact with the line. Avista Corp.
disputes that the tree in question was the cause of the fire and that it was negligent in failing to identify and remove it. Additional
lawsuits have subsequently been filed by private landowners seeking property damages, and holders of insurance subrogation claims
seeking recovery of insurance proceeds paid.
The lawsuits were filed in the Superior Court of Ferry County, Washington. The Company intends to vigorously defend itself in the
litigation. However, the Company cannot predict the outcome of these matters.
Labor Day Windstorm
In September 2020, a severe windstorm occurred in eastern Washington and northern Idaho. The extreme weather event resulted in
customer outages and the cause of multiple wildfires in the region. With respect to wildfires, the Company’s investigation determined
that the primary cause of the fires was extreme high winds. To date, the Company has not found any evidence that the fires were
caused by any deficiencies in its equipment, maintenance activities or vegetation management practices.
The Company has become aware of instances where, during the course of the storm, otherwise healthy trees and limbs, located in
areas outside its maintenance right-of-way, broke under the extraordinary wind conditions and caused damage to its energy delivery
system at or near what is believed to be the potential area of origin of a wildfire. Those instances include what has been referred to as:
the Babb Road fire (near Malden and Pine City, Washington); the Christensen Road fire (near Airway Heights, Washington); and the
Mile Marker 49 fire (near Orofino, Idaho). These wildfires covered, in total, approximately 22,000 acres. The Company currently
estimates approximately 230 residential, commercial and other structures were impacted. Parallel investigations by applicable state
agencies, including the Washington Department of Natural Resources, are ongoing, and the Company is cooperating with those
efforts.
In addition to the instances identified above, the Company is aware of a 5-acre fire that occurred in Colfax, Washington, which
damaged several residential structures. The Company’s investigation determined that the Company’s facilities were not involved in
the ignition of this fire in any way.
The Company’s investigation has found no evidence of negligence with respect to any of the fires, and the Company intends to
vigorously defend any claims for damages that may be asserted against it with respect to the wildfires arising out of the extreme wind
event.
Other Contingencies
In the normal course of business, the Company has various other legal claims and contingent matters outstanding. The Company
believes that any ultimate liability arising from these actions will not have a material impact on its financial condition, results of
operations or cash flows. It is possible that a change could occur in the Company’s estimates of the probability or amount of a 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
for remediation of contaminated sites, including assessments of ranges and probabilities of recoveries from other responsible parties
who either have or have not agreed to a settlement as well as recoveries from insurance carriers. The Company’s policy is to accrue
and charge to current expense identified exposures related to environmental remediation sites based on estimates of investigation,
cleanup and monitoring costs to be incurred. For matters that affect Avista Corp.’s operations, the Company seeks, to the extent
appropriate, recovery of incurred costs through the ratemaking process.
The Company has potential liabilities under the Endangered Species Act for species of fish, plants and wildlife that have either
already been added to the endangered species list, listed as “threatened” or petitioned for listing. Thus far, measures adopted and
implemented have had minimal impact on the Company. However, the Company will continue to seek recovery, through the
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.36
ratemaking process, of all operating and capitalized costs related to these issues.
Under the federal licenses for its hydroelectric projects, the Company is obligated to protect its property rights, including water rights.
In addition, the Company holds additional non-hydro water rights. The State of Montana is examining the status of all water right
claims within state boundaries through a general adjudication. Claims within the Clark Fork River basin could adversely affect the
energy production of the Company’s Cabinet Gorge and Noxon Rapids hydroelectric facilities. The state of Idaho has initiated
adjudication in northern Idaho, which will ultimately include the lower Clark Fork River, the Spokane River and the Coeur d’Alene
basin. The Company is and will continue to be a participant in these and any other relevant adjudication processes. The complexity of
such adjudications makes each unlikely to be concluded in the foreseeable future. As such, it is not possible for the Company to
estimate the impact of any outcome at this time. The Company will continue to seek recovery, through the ratemaking process, of all
operating and capitalized costs related to this issue.
NOTE 18. REGULATORY MATTERS
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-term wholesale market prices and sales and purchase volumes,
the level, availability and optimization of hydroelectric generation,
the level and availability of thermal 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 with 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 and defer these
differences (over the $4.0 million deadband and sharing bands) for future surcharge or rebate to customers. For 2020, the Company
recognized a pre-tax benefit of $6.2 million under the ERM in Washington compared to a benefit of $4.4 million for 2019. Total net
deferred power costs under the ERM were a liability of $37.9 million as of December 31, 2020 and a liability of $37.0 million as of
December 31, 2019. These deferred power cost balances 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 customer rates to either return the balance to customers or recover the balance from customers. As the cumulative
rebate balance exceeded $30 million, the Company’s 2019 filing contained a proposed rate refund. The ERM proceeding was
considered with the Company’s 2019 general rate case proceeding and a refund was approved and is being returned to customers over
a two-year period that began on April 1, 2020. Avista Corp. makes an annual filing on, or before, April 1 of each year to provide the
opportunity for the WUTC staff and other interested parties to review the prudence of, and audit, the ERM deferred power cost
transactions for the prior calendar year.
Avista Corp. has a PCA mechanism in Idaho that allows it to modify electric rates on October 1 of each year with IPUC approval.
Under the PCA mechanism, Avista Corp. defers 90 percent of the difference between certain actual net power supply expenses and
the amount included in base retail rates for its Idaho customers. The October 1 rate adjustments recover or rebate power costs deferred
during the preceding July-June twelve-month period. Total net power supply costs deferred under the PCA mechanism were an asset
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.37
of $2.5 million as of December 31, 2020 and $0.3 million as of December 31, 2019. 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. Total net deferred natural gas costs were an asset of $1.4 million as of December 31, 2020 and
a liability of $3.2 million as of December 31, 2019. Asset balances represent amounts due from customers and liabilities represent
amounts due to customers.
Decoupling and Earnings Sharing Mechanisms
Decoupling (also known as an FCA in Idaho) is a mechanism designed to sever the link between a utility's revenues and consumers'
energy usage. In each of Avista Corp.'s jurisdictions, Avista Corp.'s electric and natural gas revenues are adjusted so as to be based on
the number of customers in certain customer rate classes and assumed "normal" kilowatt hour and therm 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 for a five-year period
beginning January 1, 2015. In 2019, the WUTC approved an extension of the mechanisms for an additional five-year term through
March 31, 2025, with one modification in that new customers added after any test period would not be decoupled until included in a
future test period.
Electric and natural gas decoupling surcharge rate adjustments to customers are limited to a 3 percent increase on an annual basis,
with any remaining surcharge balance carried forward for recovery in a future period. There is no limit on the level of rebate rate
adjustments.
The decoupling mechanisms each include an after-the-fact earnings test. At the end of each calendar year, separate electric and natural
gas earnings calculations are made for the calendar year just ended. These earnings tests reflect actual decoupled revenues,
normalized power supply costs and other normalizing adjustments. If the Company earns more than its authorized ROR in
Washington, 50 percent of excess earnings are rebated to customers through adjustments to decoupling surcharge or rebate balances.
See below for a summary of cumulative balances under the decoupling and earnings sharing mechanisms.
Idaho FCA and Earnings Sharing Mechanisms
In Idaho, the IPUC approved the implementation of FCAs for electric and natural gas (similar in operation and effect to the
Washington decoupling mechanisms) for an initial term of three years, beginning January 1, 2016. In 2019, the IPUC approved an
extension of the FCAs through March 31, 2025.
Oregon Decoupling Mechanism
In February 2016, the OPUC approved the implementation of a decoupling mechanism for natural gas, similar to the Washington and
Idaho mechanisms described above. The decoupling mechanism became effective on March 1, 2016. Changes related to deferral
interest rates were recommended by the parties in Avista Corp.'s 2019 general rate case and were implemented effective January 15,
2020. In Oregon, an earnings review is conducted on an annual basis. In the annual earnings review, if the Company earns more than
100 basis points above its allowed ROE, one-third of the earnings above the 100 basis points would be deferred and later returned to
customers. The earnings review is separate from the decoupling mechanism and was in place prior to decoupling. See below for a
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.38
summary of cumulative balances under the decoupling and earnings sharing mechanisms.
Cumulative Decoupling and Earnings Sharing Mechanism Balances
As of December 31, 2020 and December 31, 2019, the Company had the following cumulative balances outstanding related to
decoupling and earnings sharing mechanisms in its various jurisdictions (dollars in thousands):
December 31,December 31,
2020 2019
Washington
Decoupling surcharge $21,340 $22,440
Idaho
Decoupling surcharge $1,202 $2,549
Provision for earnings sharing rebate (686) (686)
Oregon
Decoupling rebate $(1,262) $(739)
There were no earnings sharing rebates associated with Washington and Oregon as of December 31, 2020 and December 31, 2019.
NOTE 19. TERMINATION OF PROPOSED ACQUISITION BY HYDRO ONE
In July 2017, Avista Corp. entered into a Merger Agreement that provided for Avista Corp. to become an indirect, wholly-owned
subsidiary of Hydro One, subject to the satisfaction or waiver of specified closing conditions, including approval by regulatory
agencies. Hydro One, based in Toronto, is Ontario’s largest electricity transmission and distribution provider.
Termination of the Merger Agreement
Due to the denial of the proposed merger by certain of the Company's regulatory commissions, in January 2019, Avista Corp., Hydro
One and certain subsidiaries thereof, entered into a Termination Agreement indicating their mutual agreement to terminate the Merger
Agreement, effective immediately. Pursuant to the terms of the Termination Agreement, Hydro One paid Avista Corp. a $103 million
termination fee in January 2019. The termination fee was used for reimbursing the Company's transaction costs incurred from 2017 to
2019. The balance of the termination fee remaining after payment of 2019 transaction costs and applicable income taxes was used for
general corporate purposes and reduced the Company's need for external financing. The 2019 costs were $19.7 million pre-tax and
included financial advisers' fees, legal fees, consulting fees and employee time.
NOTE 20. SALE OF METALfx
In April 2019, Bay Area Manufacturing, Inc., a non-regulated subsidiary of Avista Corp., entered into a definitive agreement to sell
its interest in METALfx to an independent third party. The transaction was a stock sale for a total cash purchase price of $17.5
million, plus cash on-hand, subject to customary closing adjustments. The transaction closed in April 2019, and as of that date the
Company has no further involvement with METALfx.
The purchase price of $17.5 million, as adjusted, was divided among the security holders of METALfx, including the minority
shareholder, pro-rata based on ownership (Avista Corp. owned 89.2 percent of the equity of METALfx). As required under the
purchase agreement, $1.2 million (7 percent of the purchase price) will be held in escrow for 24 months from the closing of the
transaction to satisfy certain indemnification obligations.
When all escrow amounts are released, the sales transaction is expected to provide cash proceeds to Avista Corp., net of payments to
the minority holder, contractually obligated compensation payments and other transaction expenses, of $16.5 million and result in a
net gain after-tax of $3.3 million. The Company expects to receive the full amount of its portion of the escrow accounts; therefore, the
full amounts are included in the gain calculation.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.39
NOTE 21. SUPPLEMENTAL CASH FLOW INFORMATION
Supplemental cash flow information consisted of the following items for the years ended December 31 (dollars in thousands):
2020 2019
Cash paid for interest $ 91,188 $ 92,681
Cash paid for income taxes 701 26,164
Cash received for income tax refunds (984) (589)
NOTE 22. SUBSEQUENT EVENTS
The Company has evaluated its subsequent events and noted no subsequent events have occurred.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Notes to Financial Statements
FERC FORM NO. 2/3-Q (REV 12-07)122.40
Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization and Depletion
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Item
(a)
Total Company
For the Current
Quarter/Year
UTILITY PLANT 1
In Service 2
Plant in Service (Classified) 6,627,834,919 3
Property Under Capital Leases 71,890,863 4
Plant Purchased or Sold 5
Completed Construction not Classified 6
Experimental Plant Unclassified 7
TOTAL Utility Plant (Total of lines 3 thru 7) 6,699,725,782 8
Leased to Others 9
Held for Future Use 13,727,648 10
Construction Work in Progress 172,073,892 11
Acquisition Adjustments 273,648 12
TOTAL Utility Plant (Total of lines 8 thru 12) 6,885,800,970 13
Accumulated Provisions for Depreciation, Amortization, & Depletion 2,294,362,603 14
Net Utility Plant (Total of lines 13 and 14) 4,591,438,367 15
DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION 16
In Service: 17
Depreciation 2,132,757,425 18
Amortization and Depletion of Producing Natural Gas Land and Land Rights 19
Amortization of Underground Storage Land and Land Rights 20
Amortization of Other Utility Plant 161,605,178 21
TOTAL In Service (Total of lines 18 thru 21) 2,294,362,603 22
Leased to Others 23
Depreciation 24
Amortization and Depletion 25
TOTAL Leased to Others (Total of lines 24 and 25) 26
Held for Future Use 27
Depreciation 28
Amortization 29
TOTAL Held for Future Use (Total of lines 28 and 29) 30
Abandonment of Leases (Natural Gas) 31
Amortization of Plant Acquisition Adjustment 32
TOTAL Accum. Provisions (Should agree with line 14 above)(Total of lines 22, 26, 30, 31, and 32) 2,294,362,603 33
Page 200FERC FORM NO. 2 (12-96)
Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization and Depletion (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Electric
(c)
Gas
(d)
Other (specify)
(e)
Common
(f)
1
2
691,730,453 1,410,775,568 4,525,328,898 3
71,890,863 4
5
6
7
763,621,316 1,410,775,568 4,525,328,898 8
9
714,936 190,585 12,822,127 10
17,575,548 3,747,095 150,751,249 11
273,648 12
781,911,800 1,414,713,248 4,689,175,922 13
236,921,589 421,698,079 1,635,742,935 14
544,990,211 993,015,169 3,053,432,987 15
16
17
104,602,692 421,097,745 1,607,056,988 18
19
20
132,318,897 600,334 28,685,947 21
236,921,589 421,698,079 1,635,742,935 22
23
24
25
26
27
28
29
30
31
32
236,921,589 421,698,079 1,635,742,935 33
Page 201FERC FORM NO. 2 (12-96)
Schedule Page: 200 Line No.: 4 Column: f
ROU Asset - $71,890,863
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1
This Page Intentionally Left Blank
Gas Plant in Service (Accounts 101, 102, 103, and 106)
1. Report below the original cost of gas plant in service according to the prescribed accounts.
2. In addition to Account 101, Gas Plant in Service (Classified), this page and the next include Account 102, Gas Plant Purchased or Sold, Account
103, Experimental Gas Plant Unclassified, and Account 106, Completed Construction Not Classified-Gas.
3. Include in column (c) and (d), as appropriate corrections of additions and retirements for the current or preceding year.
4. Enclose in parenthesis credit adjustments of plant accounts to indicate the negative effect of such accounts.
5. Classify Account 106 according to prescribed accounts, on an
estimated basis if necessary, and include the entries in column (c).Also to be included in column (c) are entries for reversals of tentative distributions of
prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary
accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to
the account for accumulated depreciation provision. Include also in column (d) reversals of tentative distributions of prior year's unclassified retirements.
Attach supplemental statement showing the account distributions of these tentative classifications in columns (c) and (d),
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Account
(a)
Balance at
Beginning of Year
(b)
Additions
(c)
Line
No.
INTANGIBLE PLANT 1
301 Organization 2
302 Franchises and Consents 3
303 Miscellaneous Intangible Plant 2,764,767 337,963 4
TOTAL Intangible Plant (Enter Total of lines 2 thru 4) 2,764,767 337,963 5
PRODUCTION PLANT 6
Natural Gas Production and Gathering Plant 7
325.1 Producing Lands 8
325.2 Producing Leaseholds 9
325.3 Gas Rights 10
325.4 Rights-of-Way 11
325.5 Other Land and Land Rights 12
326 Gas Well Structures 13
327 Field Compressor Station Structures 14
328 Field Measuring and Regulating Station Equipment 15
329 Other Structures 16
330 Producing Gas Wells-Well Construction 17
331 Producing Gas Wells-Well Equipment 18
332 Field Lines 19
333 Field Compressor Station Equipment 20
334 Field Measuring and Regulating Station Equipment 21
335 Drilling and Cleaning Equipment 22
336 Purification Equipment 23
337 Other Equipment 24
338 Unsuccessful Exploration and Development Costs 25
339 Asset Retirement Costs for Natural Gas Production and 26
TOTAL Production and Gathering Plant (Enter Total of lines 8 27
PRODUCTS EXTRACTION PLANT 28
340 Land and Land Rights 29
341 Structures and Improvements 30
342 Extraction and Refining Equipment 31
343 Pipe Lines 32
344 Extracted Products Storage Equipment 33
Page 204FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of
Account 101 and 106 will avoid serious omissions of respondent's reported amount for plant actually in service at end of year.
6. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account
classifications arising from distribution of amounts initially recorded in Account 102. In showing the clearance of Account 102, include in column (e) the
amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits
to primary account classifications.
7. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing
subaccount classification of such plant conforming to the requirements of these pages.
8. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchaser,
and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give date of such
filing.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at
End of Year
(g)
Line
No.
1
2
3
( 23,474) 2,585,617 493,639 4
( 23,474) 2,585,617 493,639 5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
Page 205FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Account
(a)
Balance at
Beginning of Year
(b)
Additions
(c)
Line
No.
345 Compressor Equipment 34
346 Gas Measuring and Regulating Equipment 35
347 Other Equipment 36
348 Asset Retirement Costs for Products Extraction Plant 37
TOTAL Products Extraction Plant (Enter Total of lines 29 thru 37) 38
TOTAL Natural Gas Production Plant (Enter Total of lines 27 and 39
Manufactured Gas Production Plant (Submit Supplementary 7,628 52,296 40
TOTAL Production Plant (Enter Total of lines 39 and 40) 7,628 52,296 41
NATURAL GAS STORAGE AND PROCESSING PLANT 42
Underground Storage Plant 43
350.1 Land 1,313,516 44
350.2 Rights-of-Way 66,742 45
351 Structures and Improvements 1,626,548 471,739 46
352 Wells 18,002,576 471,738 47
352.1 Storage Leaseholds and Rights 48
352.2 Reservoirs 1,667,492 49
352.3 Non-recoverable Natural Gas 5,810,311 50
353 Lines 2,230,522 51
354 Compressor Station Equipment 17,244,517 471,739 52
355 Other Equipment 769,085 471,739 53
356 Purification Equipment 560,248 54
357 Other Equipment 1,760,289 471,738 55
358 Asset Retirement Costs for Underground Storage Plant 56
TOTAL Underground Storage Plant (Enter Total of lines 44 thru 51,051,846 2,358,693 57
Other Storage Plant 58
360 Land and Land Rights 59
361 Structures and Improvements 60
362 Gas Holders 61
363 Purification Equipment 62
363.1 Liquefaction Equipment 63
363.2 Vaporizing Equipment 64
363.3 Compressor Equipment 65
363.4 Measuring and Regulating Equipment 66
363.5 Other Equipment 67
363.6 Asset Retirement Costs for Other Storage Plant 68
TOTAL Other Storage Plant (Enter Total of lines 58 thru 68) 69
Base Load Liquefied Natural Gas Terminaling and Processing Plant 70
364.1 Land and Land Rights 71
364.2 Structures and Improvements 72
364.3 LNG Processing Terminal Equipment 73
364.4 LNG Transportation Equipment 74
364.5 Measuring and Regulating Equipment 75
364.6 Compressor Station Equipment 76
364.7 Communications Equipment 77
364.8 Other Equipment 78
364.9 Asset Retirement Costs for Base Load Liquefied Natural Gas 79
TOTAL Base Load Liquefied Nat'l Gas, Terminaling and Processing 80
Page 206FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at
End of Year
(g)
Line
No.
34
35
36
37
38
39
59,924 40
59,924 41
42
43
1,313,516 44
66,742 45
2,098,287 46
18,474,314 47
48
1,667,492 49
5,810,311 50
2,230,522 51
17,716,256 52
1,240,824 53
560,248 54
2,232,027 55
56
53,410,539 57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
Page 207FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Account
(a)
Balance at
Beginning of Year
(b)
Additions
(c)
Line
No.
TOTAL Nat'l Gas Storage and Processing Plant (Total of lines 57, 51,051,846 2,358,693 81
TRANSMISSION PLAN 82
365.1 Land and Land Rights 83
365.2 Rights-of-Way 84
366 Structures and Improvements 85
367 Mains 86
368 Compressor Station Equipment 87
369 Measuring and Regulating Station Equipment 88
370 Communication Equipment 89
371 Other Equipment 90
372 Asset Retirement Costs for Transmission Plant 91
TOTAL Transmission Plant (Enter Totals of lines 83 thru 91) 92
DISTRIBUTION PLANT 93
374 Land and Land Rights 1,521,412 10,916 94
375 Structures and Improvements 1,974,279 184,084 95
376 Mains 633,397,298 39,472,241 96
377 Compressor Station Equipment 97
378 Measuring and Regulating Station Equipment-General 12,268,149 182,320 98
379 Measuring and Regulating Station Equipment-City Gate 9,235,056 178,533 99
380 Services 397,234,010 24,758,691100
381 Meters 145,607,514 18,157,020101
382 Meter Installations102
383 House Regulators103
384 House Regulator Installations104
385 Industrial Measuring and Regulating Station Equipment 6,154,052 242,810105
386 Other Property on Customers' Premises106
387 Other Equipment 539107
388 Asset Retirement Costs for Distribution Plant108
TOTAL Distribution Plant (Enter Total of lines 94 thru 108) 1,207,392,309 83,186,615109
GENERAL PLANT110
389 Land and Land Rights 3,921,827 100111
390 Structures and Improvements 29,741,833 207,888112
391 Office Furniture and Equipment 1,267,984 ( 533,647)113
392 Transportation Equipment 18,032,901 1,385,406114
393 Stores Equipment 112,801115
394 Tools, Shop, and Garage Equipment 8,775,280 680,984116
395 Laboratory Equipment 412,859 25,041117
396 Power Operated Equipment 4,199,994 115,836118
397 Communication Equipment 2,723,028 701,848119
398 Miscellaneous Equipment 2,367120
Subtotal (Enter Total of lines 111 thru 120) 69,190,874 2,583,456121
399 Other Tangible Property122
399.1 Asset Retirement Costs for General Plant123
TOTAL General Plant (Enter Total of lines 121, 122 and 123) 69,190,874 2,583,456124
TOTAL (Accounts 101 and 106) 1,330,407,424 88,519,023125
Gas Plant Purchased (See Instruction 8)126
(Less) Gas Plant Sold (See Instruction 8)127
Experimental Gas Plant Unclassified128
TOTAL Gas Plant In Service (Enter Total of lines 125 thru 128) 1,330,407,424 88,519,023129
Page 208FERC FORM NO. 2 (12-96)
Gas Plant in Service (Accounts 101, 102, 103, and 106) (continued)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance at
End of Year
(g)
Line
No.
53,410,539 81
82
83
84
85
86
87
88
89
90
91
92
93
1,532,328 94
2,151,098 7,265 95
671,777,189 1,092,350 96
97
12,448,254 2,215 98
9,365,034 48,555 99
421,652,768 339,933100
159,124,709 4,639,825101
102
103
104
6,391,429 5,433105
106
539107
108
1,284,443,348 6,135,576109
110
3,921,927111
29,895,088 54,633112
( 269,564) 464,773113
19,237,738 180,569114
85,263 27,538115
9,292,808 163,456116
396,983 40,917117
51,954 4,367,784118
( 744,612) 2,611,409 68,855119
2,367120
( 962,222) 70,276,140 535,968121
122
123
( 962,222) 70,276,140 535,968124
( 985,696) 1,410,775,568 7,165,183125
126
127
128
( 985,696) 1,410,775,568 7,165,183129
Page 209FERC FORM NO. 2 (12-96)
Gas Plant Held for Future Use (Account 105)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Description and Location
of Property
(a)
1. Report separately each property held for future use at end of the year having an original cost of $1,000,000 or more. Group other
items of property held for future use.
2. For property having an original cost of $1,000,000 or more previously used in utility operations, now held for future use, give in
column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original
cost was transferred to Account 105.
Date Originally Included
in this Account
(b)
Date Expected to be Used
in Utility Service
(c)
Balance at
End of Year
(d)
Gas Distribution Mains and Services 190,58512/31/202603/01/2007 1
located in Coeur d'Alene, Idaho 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
190,585Total 45
Page 214FERC FORM NO. 2 (12-96)
Construction Work in Progress-Gas (Account 107)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Description of Project
(a)
Construction Work in
Progress-Gas
(Account 107)
(b)
1. Report below descriptions and balances at end of year of projects in process of construction (Account 107).
2. Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development,
and Demonstration (see Account 107 of the Uniform System of Accounts).
3. Minor projects (less than $1,000,000) may be grouped.
Estimated Additional
Cost of Project
(c)
Minor Projects under $1,000,000: 1
764,049 863,400Regulator Reliable - Blanket 2
150,844 737,333Transportation Equip 3
236,686 476,540Gas Revenue Blanket 4
1,854,046 384,850Gas Replace-St&Hwy 5
21,274 314,166Gas Distribution Non-Revenue Blanket 6
183,633Structures & Improv 7
178,912APx Accrual adjustment to service/jurisd 8
50,320 138,970Cathodic Protection-Minor Blanket 9
149,292 107,161Gas Telemetry 10
69,855 57,172Facilities and Storage Locations Security 11
54,403Gas Airway Heights HP Reinforcement 12
53,114Gas Meter and Metering Equipment Purchases 13
2,204 48,844Aldyl -A Pipe Replacement 14
3,062,220 37,687Cheney HP Reinforcement 15
114,984 34,411Gas Reinforce-Minor Blanket 16
2,768,679 32,007NSC Greene St HP Gas Main 17
27,050Gas Op Qual - Tooling, Vehicles and Material 18
14,500 10,873Gas ERT Minor Blanket 19
46,506 3,570Tools Lab & Shop Equipment 20
2,182Immaterial Difference (GD.WA) 21
24,273 743Replace Deteriorating Gas System 22
2,491,01674Rathdrum Prairie HP Gas Reinforcement 23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
3,747,095 11,820,748Total 45
Page 216FERC FORM NO. 2 (12-96)
1.For each construction overhead explain: (a) the nature and extent of work, etc., the overhead charges are intended to cover, (b) the general
procedure for determining the amount capitalized, (c) the method of distribution to construction jobs, (d) whether different rates are applied to
different types of construction, (e) basis of differentiation in rates for different types of construction, and (f) whether the overhead is directly or
indirectly assigned.
2.Show below the computation of allowance for funds used during construction rates, in accordance with the provisions of Gas Plant
Instructions 3 (17) of the Uniform System of Accounts.
3.Where a net-of-tax rate for borrowed funds is used, show the appropriate tax effect adjustment to the computations below in a manner that
clearly indicates the amount of reduction in the gross rate for tax effects.
Construction costs with a direct relationship to new construction and capital replacement activities that cannot be clearly
identified with specific projects are charged to overhead pools. The established pools are:
Construction Overhead North Gas
Construction Overhead South Gas
Pool costs are allocated monthly to gas construction projects on a percent rate applied to direct project costs, excluding
AFUDC. Each pool's rate is calculated separately and applied only to the related gas construction projects for allocation.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
General Description of Construction Overhead Procedure
FERC FORM NO. 2 (REV 12-07)218.1
General Description of Construction Overhead Procedure (continued)
COMPUTATION OF ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION RATES
1. For line (5), column (d) below, enter the rate granted in the last rate proceeding. If not available, use the average rate earned during the preceding 3 years.
2. Identify, in a footnote, the specific entity used as the source for the capital structure figures.
3. Indicate, in a footnote, if the reported rate of return is one that has been approved in a rate case, black-box settlement rate, or an actual three-year average rate.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Title
(a)
Cost Rate
Percentage
(d)
Amount
(b)
Capitalization
Ration (percent)
(c)
1. Components of Formula (Derived from actual book balances and actual cost rates):
(1) Average Short-Term Debt 168,971,000S
(2) Short-Term Interest 1.51s
(3) Long-Term Debt 1,860,500,000 5.17D d
(4) Preferred Stock P p
(5) Common Equity 1,962,928,952 9.50C c
(6) Total Capitalization
(7) Average Construction Work In Progress Balance 179,952,000W
0.30
1.572. Gross Rate for Borrowed Funds s(S/W) + d[(D/(D+P+C)) (1-(S/W))]
3. Rate for Other Funds [1-(S/W)] [p(P/(D+P+C)) + c(C/(D+P+C))]
4. Weighted Average Rate Actually Used for the Year:
a. Rate for Borrowed Funds -
b. Rate for Other Funds -
Page 218aFERC FORM NO. 2 (REV 12-07)
Schedule Page: 218 Line No.: 1 Column: b
We elected to use the 2019 ST debt amount for calculating AFUDC for Months March-Dec 2020 as allowed in Docket No.
AC20-127-000.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1

This Page Intentionally Left Blank
Accumulated Provision for Depreciation of Gas Utility Plant (Account 108)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Item
(a)
Total
(c+d+e)
(b)
1. Explain in a footnote any important adjustments during year.
2. Explain in a footnote any difference between the amount for book cost of plant retired, line 10, column (c), and that reported for gas
plant in service, page 204-209, column (d), excluding retirements of nondepreciable property.
3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when
such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded
and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book
cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional
classifications.
4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
5. At lines 7 and 14, add rows as necessary to report all data. Additional rows should be numbered in sequence, e.g., 7.01, 7.02, etc.
Gas Plant in
Service
(c)
Gas Plant Held
for Future Use
(d)
Gas Plant Leased
to Others
(e)
Section A. BALANCES AND CHANGES DURING YEAR
1 394,754,186 394,754,186 Balance Beginning of Year
2 Depreciation Provisions for Year, Charged to
3 31,515,804 31,515,804(403) Depreciation Expense
4 (403.1) Depreciation Expense for Asset Retirement Costs
5 (413) Expense of Gas Plant Leased to Others
6 1,286,368 1,286,368 Transportation Expenses - Clearing
7 Other Clearing Accounts
8 Other Clearing (Specify) (footnote details):
9
10 32,802,172 32,802,172TOTAL Deprec. Prov. for Year (Total of lines 3 thru 8)
11 Net Charges for Plant Retired:
12 ( 6,671,545) ( 6,671,545) Book Cost of Plant Retired
13 ( 295,031) ( 295,031) Cost of Removal
14 Salvage (Credit)
15 ( 6,966,576) ( 6,966,576)TOTAL Net Chrgs for Plant Ret. (Total of lines 12 thru 14)
16 507,963 507,963 Other Debit or Credit Items (Describe) (footnote details):
17
18 Book Cost of Asset Retirement Costs
19 421,097,745 421,097,745Balance End of Year (Total of lines 1,10,15,16 and 18)
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
24 19,191,817 19,191,817 Underground Gas Storage
25 Other Storage Plant
26 Base Load LNG Terminaling and Processing Plant
27 Transmission
28 377,906,110 377,906,110 Distribution
29 23,999,818 23,999,818 General
30 421,097,745 421,097,745TOTAL (Total of lines 21 thru 29)
Page 219FERC FORM NO. 2 (12-96)
Schedule Page: 219 Line No.: 16 Column: c
Includes:
Change in Removal Work in Progress ($2,009,232)
Transfer of vehicle from Gas to Electric ($116,870)
AMI/MDM Balance $2,648.262
Other Misc Credits ($14,197)
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1

This Page Intentionally Left Blank
Gas Stored (Accounts 117.1, 117.2, 117.3, 117.4, 164.1, 164.2, and 164.3)
1. If during the year adjustments were made to the stored gas inventory reported in columns (d), (f), (g), and (h) (such as to correct cumulative inaccuracies of
gas measurements), explain in a footnote the reason for the adjustments, the Dth and dollar amount of adjustment, and account charged or credited.
2. Report in column (e) all encroachments during the year upon the volumes designated as base gas, column (b), and system balancing gas, column (c), and
gas property recordable in the plant accounts.
3. State in a footnote the basis of segregation of inventory between current and noncurrent portions. Also, state in a footnote the method used to report
storage (i.e., fixed asset method or inventory method).
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description
(a)
(Account
117.1)
(b)
(Account
117.2)
(c)
Noncurrent
(Account
117.3)
(d)
(Account
117.4)
(e)
Current
(Account
164.1)
(f)
LNG
(Account
164.2)
(g)
LNG
(Account
164.3)
(h)
Total
(i)
Balance at Beginning of 21,297,473 14,305,397 6,992,076 1
Gas Delivered to Storage 13,143,711 13,143,711 2
Gas Withdrawn from 17,913,784 17,913,784 3
Other Debits and Credits 4
Balance at End of Year 16,527,400 9,535,324 6,992,076 5
Dth 7,121,035 5,867,975 1,253,060 6
Amount Per Dth 2.3209 1.6250 5.5800 7
Page 220FERC FORM NO. 2 (REV 04-04)
Book Cost at Beginning of Year
(If book cost is different from
cost to respondent, give cost to
respondent in a footnote and
explain difference)
(c)
Investments (Account 123, 124, and 136)
1. Report below investments in Accounts 123, Investments in Associated Companies, 124, Other Investments, and 136, Temporary Cash Investments.
2. Provide a subheading for each account and list thereunder the information called for:
(a) Investment in Securities-List and describe each security owned, giving name of issuer, date acquired and date of maturity. For bonds, also give principal amount, date of issue,
maturity, and interest rate. For capital stock (including capital stock of respondent reacquired under a definite plan for resale pursuant to authorization by the Board of Directors, and
included in Account 124, Other Investments) state number of shares, class, and series of stock. Minor investments may be grouped by classes. Investments included in Account 136,
Temporary Cash Investments, also may be grouped by classes.
(b) Investment Advances-Report separately for each person or company the amounts of loans or investment advances that are properly includable in Account 123. Include advances
subject to current repayment in Account 145 and 146. With respect to each advance, show whether the advance is a note or open account.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description of Investment
(a)
Purchases or
Additions
During the Year
(d)
*
(b)
11,547,000Investment in Avista Capital II (123010) 1
59,355Other Investment - WZN Loans Sandpoint (124350) 2
28,776,235Other Investment - Coli Cash Value (124600) 3
( 28,776,235)Other Investment - Coli Borrowings (124610) 4
18,617Other Investment - WZN Loans Oregon (124680) 5
155,891Temp Cash Investments (136000) 6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 222FERC FORM NO. 2 (12-96)
Investments (Account 123, 124, and 136) (continued)
List each note, giving date of issuance, maturity date, and specifying whether note is a renewal. Designate any advances due from officers, directors, stockholders, or employees.
3. Designate with an asterisk in column (b) any securities, notes or accounts that were pledged, and in a footnote state the name of pledges and purpose of the pledge.
4. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and cite Commission, date of authorization, and case or docket
number.
5. Report in column (h) interest and dividend revenues from investments including such revenues from securities disposed of during the year.
6. In column (i) report for each investment disposed of during the year the gain or loss represented by the difference between cost of the investment (or the other amount at which carried
in the books of account if different from cost) and the selling price thereof, not including any dividend or interest adjustment includible in column (h).
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Gain or Loss from
Investment
Disposed of
(i)
Revenues for
Year
(h)
Sales or Other
Dispositions
During Year
(e)
Principal Amount or
No. of Shares at
End of Year
(f)
Book Cost at End of Year
(If book cost is different from cost
to respondent, give cost to
respondent in a footnote and
explain difference)
(g)
11,547,000 1
59,355 2
( 2,793,579) 31,569,814 3
2,793,579 ( 31,569,814) 4
82 18,535 5
3,117 152,774 6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 223FERC FORM NO. 2 (12-96)
Date of
Maturity
(c)
Investments in Subsidiary Companies (Account 123.1)
1. Report below investments in Account 123.1, Investments in Subsidiary Companies.
2. Provide a subheading for each company and list thereunder the information called for below. Sub-total by company and give a total in columns (e), (f), (g) and (h).
(a) Investment in Securities-List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate.
(b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect
to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal.
3. Report separately the equity in undistributed subsidiary earnings since acquisition. The total in column (e) should equal the amount entered for Account 418.1.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description of Investment
(a)
Amount of
Investment at
Beginning of Year
(d)
Date
Acquired
(b)
256,138,97101/01/1997Investment in Avista Capital 1
( 152,844,453)Avista Capital - Equity in Earnings 2
89,816,38007/01/2014Investment in AERC 3
13,995,056AERC- Equity in Earnings 4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
207,105,954TOTAL Cost of Account 123.1 $ 40 TOTAL
Page 224FERC FORM NO. 2 (12-96)
Investments in Subsidiary Companies (Account 123.1) (continued)
4. Designate in a footnote, any securities, notes, or accounts that were pledged, and state the name of pledgee and purpose of the pledge.
5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or
docket number.
6. Report in column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year.
7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which
carried in the books of account if different from cost), and the selling price thereof, not including interest adjustments includible in column (f).
8. Report on Line 40, column (a) the total cost of Account 123.1.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Gain or Loss from
Investment
Disposed of
(h)
Equity in Subsidiary
Earnings for Year
(e)
Revenues for Year
(f)
Amount of Investment
at End of Year
(g)
256,138,971 1
( 155,335,304)( 2,490,851) 2
89,816,380 3
16,790,283 5,000,000 7,795,227 4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
207,410,330 5,000,000 5,304,37640
Page 225FERC FORM NO. 2 (12-96)
Prepayments (Acct 165), Extraordinary Property Losses (Acct 182.1), Unrecovered Plant and Regulatory Study Costs (Acct 182.2)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Nature of Payment
(a)
Balance at End
of Year
(in dollars)
(b)
1. Report below the particulars (details) on each prepayment.
PREPAYMENTS (ACCOUNT 165)
Prepaid Insurance 2,785,960 1
Prepaid Rents 4,491 2
Prepaid Taxes 4,047,487 3
Prepaid Interest 4
Miscellaneous Prepayments 19,442,721 5
TOTAL 26,280,659 6
Page 230aFERC FORM NO. 2 (12-96)
This Page Intentionally Left Blank
Other Regulatory Assets (Account 182.3)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Description and Purpose of
Other Regulatory Assets
(a)
Balance at
Beginning
Current
Quarter/Year
(b)
1. Report below the details called for concerning other regulatory assets which are created through the ratemaking actions of regulatory agencies (and not includable
in other accounts).
2. For regulatory assets being amortized, show period of amortization in column (a).
3. Minor items (5% of the Balance at End of Year for Account 182.3 or amounts less than $250,000, whichever is less) may be grouped by classes.
4. Report separately any "Deferred Regulatory Commission Expenses" that are also reported on pages 350-351, Regulatory Commission Expenses.
5. Provide in a footnote, for each line item, the regulatory citation where authorization for the regulatory asset has been granted (e.g. Commission Order, state
commission order, court decision).
Balance at End of
Current
Quarter/Year
(g)
Debits
(c)
Written off During
Quarter/Year
Account
Charged
(d)
Written off
During Period
Amount Recovered
(e)
Written off
During Period
Amount Deemed
Unrecoverable
(f)
3,068,230407WA Excess nat Gas Line Extension Allowance 8,597,671 1,321,185 10,344,716 1
12,639,368228Reg Asset Post Ret Liab 202,321,377 4,159,538 210,801,207 2
1,351,599283Regulatory Asset FAS109 Utility Plant 93,708,282 11,703,947 83,355,934 3
1,971,362283Regulatory Asset FAS109 DSIT Non Plant 2,344,905 1,293,066 3,023,201 4
133,911407Regulatory Asset - Spokane River Relicense 133,911 5
1,266,390407Regulatory Asset-Lake CDA Settlement-Varies 40,042,767 41,309,157 6
18,525,668456, 495Reg Assets-Decouplings Surcharge-2 years 10,093,117 9,292,164 19,326,621 7
1,820,200407Reg Asset - Colstrip 7,891,134 4,765,647 4,945,687 8
7,374,854244, 175Commodity MTM ST & LT Regulatory Asset 7,794,852 8,596,118 6,573,588 9
Regulatory Asset FAS143 Asset Retirement
Obligation 1,916,300 116,094 1,800,206
10
206,551242Regulatory Asset Workers Comp 1,017,959 98,214 1,126,296 11
38,064,531VariousInterest Rate Swap Asset 214,851,166 84,321,626 168,594,071 12
33,756,305VariousDSM Asset 3,813,813 25,399,919 12,170,199 13
70,968283, 410Deferred ITC 3,910,987 3,981,955 14
68,655407, 419Regulatory Asset MDM System 26,378,924 13,052,758 13,394,821 15
1,846,303407Regulatory Asset BPA Residential Exchange 1,484,961 2,004,379 1,326,885 16
1,326,173407, 419Regulatory Asset FISERV- 3 years 2,720,100 452,238 3,594,035 17
27,652,017Various
Regulatory Asset-AFUDC (PIS,WIP) & Equity
DFIT 52,370,433 35,928,791 44,093,659
18
2,805,313557, 419Regulatory Asset ID PCA Deferral - 1 year 2,547,168 5,095,887 256,594 19
4,177,507108Existing Meters/ERTS Retirement Def 25,913,958 17,039,161 13,052,304 20
Regulatory Asset-Colstrip Community Fund 1,500,000 1,500,000 21
8,520,795VariousRegulatory Asset- COVID -19 2,859,947 11,380,742 22
58,098407Regulatory Asset- Energy Imbalance Market 194,925 253,023 23
86,636407, 419Regulatory Asset- Oregon CAT Tax 829,587 916,223 24
13,133407, 419Deferred Regulatory Fees 59,519 72,652 25
Regulatory Asset- Wildfire Resiliency 1,006,452 1,006,452 26
1,101,894407Deferral for CS2 & Colstrip (O&M, Excess Depr) 1,108,935 2,210,829 27
Other Regulatory Assets 2,404 83 2,321 28
29
30
31
32
33
34
35
36
37
38
39
0 167,906,461 643,207,368 241,980,736 717,281,643Total 40
Page 232FERC FORM NO. 2/3Q (REV 12-07)
Schedule Page: 232 Line No.: 1 Column: a
Residential Schedule 101 customers who receive a natural gas line extension as part of conversion to natural gas from
another fuel source. Amortization for a period of 3 years on the excess allowance exceeding the cost of the line
extension.
Schedule Page: 232 Line No.: 2 Column: a
Recognition of the overfunded and underfunded status of a defined benefit post retirement plan based on ASC 715 for
financial reporting.
Schedule Page: 232 Line No.: 3 Column: a
Amortized over remaining book lifeof pre 1986 vintage assets. Amortization amount varies yearly.
Schedule Page: 232 Line No.: 5 Column: a
Amortization for TDG Idaho ended on December 2019. Spokane River relicensing amortization costs ended on
11/30/2020.
Schedule Page: 232 Line No.: 6 Column: a
WA Docket UE-080416 & ID Order AVU-E-08-01. Amortization thru 2059.
Schedule Page: 232 Line No.: 7 Column: a
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.
Schedule Page: 232 Line No.: 8 Column: a
For Washington Electric, we are currently deferring ARO expenses. Amortization period to be detrmined. For Idaho
Electric, amortization is for 34 years as per Order 34276, AVU-E-18-03.
Schedule Page: 232 Line No.: 9 Column: a
Washington Docket# UE-002066 and Idaho Order# 28648
Schedule Page: 232 Line No.: 10 Column: a
Reclass of Regulatory Assets related to Colstrip to state jurisdictions.
Schedule Page: 232 Line No.: 11 Column: a
Quarterly adjustments to workers comp reserve for current unpaid claims.
Schedule Page: 232 Line No.: 12 Column: a
Settled swaps are amortized over the life of the associated debt.
Schedule Page: 232 Line No.: 13 Column: a
Amortization period varies depending on timing of transactions.
Schedule Page: 232 Line No.: 14 Column: a
Amortization period varies depending on underlying transactions.
Schedule Page: 232 Line No.: 15 Column: a
Washington Docket #s UE-180418, UG-180419
Schedule Page: 232 Line No.: 16 Column: a
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 Washington and Idaho.
Amortization is based on customer usage.
Schedule Page: 232 Line No.: 17 Column: a
Idaho Order# 33494, Docket Nos. AVU-E-16-01 and Stipulation and Settlement Docket# AVU-E-19-04.
Schedule Page: 232 Line No.: 18 Column: a
Deferring the difference between FERC formula and State approved AFUDC rates primarily from 2010-2017.
Schedule Page: 232 Line No.: 20 Column: a
Washington Docket #s UE-180418 and UG-180419. Amortization perios to be determined.
Schedule Page: 232 Line No.: 21 Column: a
WA Order 09 in Dockets UE-190334, UE-190222. Deferral of customer portion for future rate recovery. The funds are set
aside to helping the Colstrip community transition away from economic activity related to coal-fired generation.
Schedule Page: 232 Line No.: 22 Column: a
Deferral of COVID-19 costs as per Idaho PUC Order No. 34718, Oregon PUC Order No. 20-401, Docket UM 2069, and
Washington UTC Order No.01, Dockets UE-200407 and UG-200408.
Schedule Page: 232 Line No.: 23 Column: a
Idaho PUC Order No. 34606. Deferral of costs related to Avista's entry in the Energy Imbalance Market in March 2022.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1
Schedule Page: 232 Line No.: 24 Column: a
Oregon PUC Order No. 20-398, Docket UM-2042.
Schedule Page: 232 Line No.: 25 Column: a
Oregon Order# 20-354. Deferral of cost of variance in annual regulatory fee rate and the amount collected in rates.
Schedule Page: 232 Line No.: 26 Column: a
Idaho PUC Order 34883
Schedule Page: 232 Line No.: 27 Column: a
WA order 09, Docket #s UE-190334, UG-190335, UE-190222
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.2
Miscellaneous Deferred Debits (Account 186)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Description of Miscellaneous
Deferred Debits
(a)
Balance at
Beginning
of Year
(b)
1. Report below the details called for concerning miscellaneous deferred debits.
2. For any deferred debit being amortized, show period of amortization in column (a).
3. Minor items (less than $250,000) may be grouped by classes.
Balance at
End of Year
(f)
Debits
(c)
Credits
Account
Charged
(d)
Credits
Amount
(e)
1
1,110,999 1,110,999Colstrip Common Facility 2
2,355,642 2,355,642Colstrip Common Facility 3
851,006 3,964,981 4,815,987 VARPlant Alloc of Clearing Journal 4
517,205 20,224 496,981Gas Supply Transactions 5
145,434 394,831 540,265 557WA REC Deferral 6
15,376,953 6,825,184 8,551,769Reg Asset - Decoupling Deferred 7
5,305,694 5,305,694Reg Asset - COVID 19 Deferral 8
5,188 119,125 124,313 VARNez Perce Settlement 9
142,508 32,241 110,267Clarkston Hts Solar Project#60 10
( 226,818)( 226,818)Timber Harvest Revenue 11
108,776 76,675 32,101Rattlesnake II Wind Proj #62 12
656,667 83,787 572,880Misc. Deferred Debits <$100,000 13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
Miscellaneous Work in Progress 39
29,826,563 1,001,628 12,343,805 18,484,386Total 40
Page 233FERC FORM NO. 2 (12-96)
1. Report the information called for below concerning the respondent's accounting for deferred income taxes.
2. At Other (Specify), include deferrals relating to other income and deductions.
3. Provide in a footnote a summary of the type and amount of deferred income taxes reported in the beginning-of-year and end-of-year balances for deferred income
taxes that the respondent estimates could be included in the development of jurisdictional recourse rates.
Accumulated Deferred Income Taxes (Account 190)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Account Subdivisions
(a)
Changes During
Year
Amounts Credited
to Account 411.1
(d)
Balance at
Beginning
of Year
(b)
Changes During
Year
Amounts Debited
to Account 410.1
(c)
Account 190 1
22,884,253( 242,524) 20,510,338Electric 2
20,025 747,938 3,791,114Gas 3
49,743,422 42,686,343 152,755,074Other (Define) (footnote details) 4
72,647,700 43,191,757 177,056,526Total (Total of lines 2 thru 4) 5
Other (Specify) (footnote details) 6
72,647,700 43,191,757 177,056,526TOTAL Account 190 (Total of lines 5 thru 6) 7
Classification of TOTAL 8
72,647,700 43,191,757 177,056,526Federal Income Tax 9
State Income Tax 10
Local Income Tax 11
Page 234FERC FORM NO. 2 (REV 12-07)
Accumulated Deferred Income Taxes (Account 190) (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Adjustments
Debits
Account No.
(g)
Changes During
Year
Amounts Debited
to Account 410.2
(e)
Changes During
Year
Amounts Credited
to Account 411.2
(f)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
(i)
Adjustments
Credits
Amount
(j)
Balance at
End of Year
(k)
1
102,475,097 58,344,414 458,265( 35,303) 2
21,374,121 18,265,719 20,944( 24,257) 3
92,879,318 68,793,365 1,788,878( 71,652) 4
216,728,536 76,610,133 68,793,365 2,268,087( 131,212) 5
6
216,728,536 76,610,133 68,793,365 2,268,087( 131,212) 7
8
216,728,536 76,610,133 68,793,365 2,268,087( 131,212) 9
10
11
Page 235FERC FORM NO. 2 (REV 12-07)
Schedule Page: 234 Line No.: 4 Column: a
Beg. Balance End. Balance
Plant Excess Deferred Gross Up      91,824,390    88,267,393   
Plant Excess allocated to Electric and Gas    (80,198,316)
Pension, Medical, and SERP      37,657,367    33,779,058 
State Income Tax Carryforwards    6,529,835    18,682,559 
Federal Income Tax Carryforwards   242,707    11,857,126 
Derivative Instruments    7,138,000    10,930,946 
Compensation and Payroll    7,080,529      7,695,408 
Other Common Deferred Tax Assets    2,282,246      1,865,144 
 152,755,074   92,879,318 
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1

This Page Intentionally Left Blank
Capital Stock (Accounts 201 and 204)
1. Report below the details called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and
preferred stock.
2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
3. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Class and Series of Stock and
Name of Stock Exchange
(a)
Call Price at
End of Year
(d)
Number of Shares
Authorized by Charter
(b)
Par or Stated Value
per Share
(c)
Acct. 201 - Common Stock Issued: 1
200,000,000 2
Restriced shares 3
TOTAL Common 200,000,000 4
5
6
Account 204 - Preferred Stock Issued 10,000,000 7
8
Total Preferred 10,000,000 9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 250FERC FORM NO. 2 (12-96)
Capital Stock (Accounts 201 and 204)
4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
5. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year.
6. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and
purpose of pledge.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Outstanding per Bal. Sheet
(total amt outstanding
without reduction for amts
held by respondent)
Shares
(e)
Held by
Respondent
As Reacquired
Stock (Acct 217)
Cost
(h)
Outstanding per Bal.
Sheet
Amount
(f)
Held by
Respondent
As Reacquired
Stock (Acct 217)
Shares
(g)
Held by
Respondent
In Sinking and
Other Funds
Amount
(j)
Held by
Respondent
In Sinking and
Other Funds
Shares
(i)
3,667,762.00 71,706.00 1,249,688,206 69,238,901 1
2
3
3,667,762.00 71,706.00 1,249,688,206 69,238,901 4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 251FERC FORM NO. 2 (12-96)
Other Paid-In Capital (Accounts 208-211)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Item
(a)
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts.
Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the
balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change.
(a) Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
(b) Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave
rise to amounts reported under this caption including identification with the class and series of stock to which related.
(c) Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits,
and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which
related.
(d) Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with
brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Amount
(b)
( 10,696,711)Equity transactions of subsidiaries 1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
( 10,696,711)Total 40
Page 253FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
DISCOUNT ON CAPITAL STOCK (ACCOUNT 213)
1. Report the balance at end of year of discount on capital stock for each class and series of capital stock. Use as many rows as necessary to report all data.
2. If any change occurred during the year in the balance with respect to any class or series of stock, attach a statement giving details of the change. State the reason for any charge-off
during the year and specify the account charged.
Line
No.
Class and Series of Stock
(a)
Balance at
End of Year
(b)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
TOTAL
Class and Series of Stock
(a)
Balance at
End of Year
(b)
CAPITAL STOCK EXPENSE (ACCOUNT 214)
Line
No.
1. Report the balance at end of year of capital stock expenses for each class and series of capital stock. Use as many rows as necessary to report all data. Number the rows in
sequence starting from the last row number used for Discount on Capital Stock above.
2. If any change occurred during the year in the balance with respect to any class or series of stock, attach a statement giving details of the change. State the reason for any charge-off
of capital stock expense and specify the account charged.
( 47,076,877)Common Stock - no par 16
17
18
19
20
21
22
23
24
25
26
27
28
( 47,076,877)TOTAL
Page 254FERC FORM NO. 2 (12-96)

This Page Intentionally Left Blank
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 of the 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 of the refunding or
refinancing transactions with respect to securities previously refunded or retired.
3. Include in the identification of each class and series of security, as appropriate, the interest or dividend rate, nominal date of issuance,
maturity date, aggregate principal amount, par value or stated value, and number of shares. Give also the issuance of redemption price and
name of the 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 of the Uniform
System of Accounts, cite the Commission authorization for the different accounting and state the accounting method.5. For securities assumed, give the name of the company for which the liability on the securities was assumed as well as details of the
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 of these amounts with amounts relating to refunded securities clearly
earmarked.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
Securities Issued or Assumed and Securities Refunded or Retired During the Year
FERC FORM NO. 2 (12-96)255.1
In September 2020, the Company issued and sold $165.0 million of 3.07 percent first mortgage bonds due in 2050 pursuant to a bond purchase agreement with institutional investors in the private placement market. The total net
proceeds from the sale of the bonds were used to repay maturing long-term debt of $52.0 million, repay a portion of the outstanding balance under Avista Corp.'s $400.0 million committed line of credit and for other general corporate purposes. In connection with the issuance and sale of the first mortgage bonds, the Company cash settled seven interest rate swap derivatives (notional aggregate amount of $70.0 million) and paid a net amount of $33.5 million. See note 7 for a discussion of interest rate swap derivatives.
The new issuance is based on the following state commission orders:
1.Order of the Washington Utilities and Transportation Commission in Docket No.171210 entered January 11, 2018 and Order of the Washington Utilities andTransportation Commission in Docket No. 190554 entered September 12, 2019
2.Order of the Idaho Public Utilities Commission, Order No. 33978 entered January 30,2018 and Order of the Idaho Public Utilities Commission, Order No. 34386 entered
July 31, 2019
3.Order of the Public Utility Commission of Oregon, Order No. 19-249, entered July 30,
2019;
Order of the Public Service Commission of the State of Montana, Default Order No.
4535
We issued equity in 2020 for total net proceeds of $72.4 million. Most of these issuances came through our four
separate sales agency agreements under which the sales agents may offer and sell new shares of our common stock
from time to time. These agreements provide for the offering of a maximum of 3.2 million shares, of which
approximately 1.3 million remain unissued as of December 31, 2020. In 2020, 1.9 million shares were issued under
these agreements resulting in total net proceeds of $71.5 million. Subject to the satisfaction of customary conditions
(including any required regulatory approvals), we have the right to increase the maximum number of shares that
may be offered under these agreements. These agreements expire on May 13, 2024.
Date of
Maturity
(c)
Long-Term Debt (Accounts 221, 222, 223, and 224)
1. Report by Balance Sheet Account the details concerning long-term debt included in Account 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and
224, Other Long-Term Debt.
2. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds.
3. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of
associated companies from which advances were received.
4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Class and Series of Obligation and
Name of Stock Exchange
(a)
Outstanding
(Total amount
outstanding without
reduction for amts
held by respondent)
(d)
Nominal Date
of Issue
(b)
FMBS - SERIES A - 7.53% DUE 05/05/2023 5,500,00005/05/202305/06/1993 1
FMBS - SERIES A - 7.54% DUE 05/05/2023 1,000,00005/05/202305/07/1993 2
FMBS - SERIES A - 7.18% DUE 08/11/2023 7,000,00008/11/202308/12/1993 3
ADVANCE ASSOCIATED-AVISTA CAPITAL II (ToPRS) 51,547,00006/01/203706/03/1997 4
FMBS - 6.37% SERIES C 25,000,00006/19/202806/19/1998 5
FMBS - 6.25% SERIES 150,000,00012/01/203511/17/2005 6
FMBS - 5.70% SERIES 150,000,00007/01/203712/15/2006 7
FMBS - 5.125% SERIES 250,000,00004/01/202209/22/2009 8
COLSTRIP 2010A PCRBs DUE 2032 66,700,00010/01/203212/15/2010 9
COLSTRIP 2010B PCRBs DUE 2034 17,000,00003/01/203412/15/2010 10
FMBS - 5.55% SERIES 35,000,00012/20/204012/20/2010 11
FMBS - 4.45% SERIES 85,000,00012/14/204112/14/2011 12
FMBS - 4.23% SERIES 80,000,00011/29/204711/30/2012 13
FMBS - 4.11% SERIES 60,000,00012/01/204412/18/2014 14
FMBS - 4.37% SERIES 100,000,00012/01/204512/16/2015 15
FMBS - 3.54% SERIES 175,000,00012/01/205112/15/2016 16
FMBS - 3.91% SERIES 90,000,00012/01/204712/14/2017 17
FMBS - 4.35% SERIES 375,000,00006/01/204805/22/2018 18
FMBS - 3.43% SERIES 180,000,00012/01/204911/26/2019 19
FMBS - 3.07% SERIES 165,000,00009/30/205009/30/2020 20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
2,068,747,00040 TOTAL
Page 256FERC FORM NO. 2 (12-96)
Held by
Respondent
Reacquired Bonds
(Acct 222)
(g)
Long-Term Debt (Accounts 221, 222, 223, and 224)
5. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)
principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates.
6. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name
of the pledgee and purpose of the pledge.
7. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote.
8. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (f). Explain in a footnote any
difference between the total of column (f) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies.
9. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Interest for
Year
Rate
(in %)
(e)
Redemption Price
per $100 at
End of Year
(i)
Interest for
Year
Amount
(f)
Held by
Respondent
Sinking and
Other Funds
(h)
414,150 7.530 1
75,400 7.540 2
502,600 7.180 3
712,864 1.380 4
1,592,500 6.370 5
9,375,000 6.250 6
8,550,000 5.700 7
12,812,500 5.125 8
475,775 0.710 9
121,425 0.710 10
1,942,500 5.550 11
3,782,500 4.450 12
3,384,000 4.230 13
2,466,000 4.110 14
4,370,000 4.370 15
6,195,000 3.540 16
3,519,000 3.910 17
16,312,500 4.350 18
6,174,000 3.430 19
5,065,500 3.070 20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
87,843,21440
Page 257FERC FORM NO. 2 (12-96)
Unamortized Debt Expense, Premium and Discount on Long-Term Debt (Accounts 181, 225, 226)
1. Report under separate subheadings for Unamortized Debt Expense, Unamortized Premium on Long-Term Debt and Unamortized Discount on Long-Term Debt, details of expense,
premium or discount applicable to each class and series of long-term debt.
2. Show premium amounts by enclosing the figures in parentheses.
3. In column (b) show the principal amount of bonds or other long-term debt originally issued.
4. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Designation of
Long-Term Debt
(a)
Amortization
Period
Date From
(d)
Principal Amount
of Debt Issued
(b)
Total Expense
Premium or
Discount
(c)
Amortization
Period
Date To
(e)
05/05/202305/06/1993 42,712 5,500,000FMBS - SERIES A - 7.53% DUE 05/05/2023 1
05/05/202305/07/1993 7,766 1,000,000FMBS - SERIES A - 7.54% DUE 5/05/2023 2
08/11/202308/12/1993 54,364 7,000,000FMBS - SERIES A - 7.18% DUE 8/11/2023 3
06/01/203706/03/1197 1,296,086 51,547,000ADVANCE ASSOCIATED-AVISTA CAPITAL II (ToPRS) 4
06/19/202806/19/1998 158,304 25,000,000FMBS - 6.37% SERIES C 5
12/01/201911/18/2004 1,432,081 90,000,000FMBS - 5.45% SERIES 6
12/01/203511/17/2005 2,180,435 150,000,000FMBS - 6.25% SERIES 7
07/01/203712/15/2006 4,924,304 150,000,000FMBS - 5.70% SERIES 8
04/01/202209/22/2009 2,859,788 250,000,000FMBS - 5.125% SERIES 9
12/20/202012/20/2010 385,129 52,000,000FMBS - 3.89% SERIES 10
12/20/204012/20/2010 258,834 35,000,000FMBS - 5.55% SERIES 11
04/18/202212/14/2011 5,070,271Short-Term Credit Facility 12
12/14/204112/14/2011 692,833 85,000,0004.45% SERIES DUE 12-14-2041 13
11/29/204711/30/2012 730,833 80,000,0004.23% SERIES DUE 11-29-2047 14
12/01/204412/18/2014 428,205 60,000,0004.11% Seires Due 12-1-2044 15
12/01/204512/16/2015 590,761 100,000,0004.37% Series Due 12-1-2045 16
12/01/205112/15/2016 1,042,569 175,000,0003.54% Series Due 12-1-2051 17
12/01/204712/14/2017 552,539 90,000,0003.91% Series Due 12-1-2047 18
06/01/204806/01/2018 4,625,198 375,000,0004.35% Series due 6-1-2048 19
12/01/204912/01/2019 1,113,113 180,000,0003.43% Series Due 12-1-2049 20
12/01/203509/30/2005 71,646Rathrum 2005 21
08/01/203508/01/2005 858Debt Strategies 22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 258FERC FORM NO. 2 (12-96)
Unamortized Debt Expense, Premium and Discount on Long-Term Debt (Accounts 181, 225, 226)
5. Furnish in a footnote details regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote the
date of the Commission's authorization of treatment other than as specified by the Uniform System of Accounts.
6. Identify separately undisposed amounts applicable to issues which were redeemed in prior years.
7. Explain any debits and credits other than amortization debited to Account 428, Amortization of Debt Discount and Expense, or credited to Account 429, Amortization of Premium on
Debt-Credit.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Balance at
Beginning
of Year
(f)
Debits During
Year
(g)
Credits During
Year
(h)
Balance at
End of Year
(i)
4,863 4,863 1
884 884 2
6,645 6,645 3
245,258 245,258 4
44,853 44,853 5
6
1,161,102 1,161,102 7
2,831,471 2,831,471 8
530,972 530,972 9
38,620 38,620 10
181,189 181,189 11
579,108 579,108 12
508,286 508,286 13
583,071 583,071 14
357,055 357,055 15
512,239 512,239 16
953,402 953,402 17
515,830 515,830 18
4,382,258 4,382,258 19
1,110,034 1,110,034 20
37,898 37,898 21
447 447 22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 259FERC FORM NO. 2 (12-96)
Unamortized Loss and Gain on Reacquired Debt (Accounts 189, 257)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Designation of
Long-Term Debt
(a)
Date
Reacquired
(b)
1. Report under separate subheadings for Unamortized Loss and Unamortized Gain on Reacquired Debt, details of gain and loss,
including maturity date, on reacquisition applicable to each class and series of long-term debt. If gain or loss resulted from a refunding
transaction, include also the maturity date of the new issue.
2. In column (c) show the principal amount of bonds or other long-term debt reacquired.
3. In column (d) show the net gain or net loss realized on each debt reacquisition as computed in accordance with General Instruction
17 of the Uniform Systems of Accounts.
4. Show loss amounts by enclosing the figures in parentheses.
5. Explain in a footnote any debits and credits other than amortization debited to Account 428.1, Amortization of Loss on Reacquired
Debt, or credited to Account 429.1, Amortization of Gain on Reacquired Debt-Credit.
Balance at
End of Year
(f)
Principal
of Debt
Reacquired
(c)
Net Gain or
Loss
(d)
Balance at
Beginning
of Year
(e)
( 138,869)( 183,104)( 4,695,395)05/10/1993Misc Debt Repurchases I 1
801,190 849,993 1,769,125 10,000,00012/18/2000
ADVANCE ASSOCIATED-AVISTA CAPITAL II
(ToPRS)
2
360,301 412,393 2,228,153 10,000,00012/31/2002Misc 2002 Repurchase 3
64,860 71,860 315,274 25,330,00012/31/2003Misc 2003 Repurchase 4
( 462,009)( 497,013)( 1,700,371) 26,000,00012/31/2005Misc 2005 Repurchase 5
8,226 10,922 43,13212/31/2008Misc 2008 Repurchase Costs 6
( 305,699)( 534,974)( 2,875,817) 60,000,00004/01/2009AVA Capital Trust III (2022) 7
( 1,842,069)( 1,997,737)( 3,709,174) 66,700,00012/14/2010COLSTRIP 2010A PCRBs DUE 2032 8
( 1,089,500)( 1,171,994)( 1,916,297) 17,000,00012/14/2010COLSTRIP 2010B PCRBs DUE 2034 9
( 3,509,214)( 3,684,675)( 5,263,822) 30,000,00012/20/2010FMBS - 7.25% SERIES (2040) 10
( 627,366)( 6,273,664) 45,000,00012/20/2010FMBS - 6.125% SERIES (2020) 11
( 80,766)( 83,766)( 105,020) 4,100,00006/28/2012KETTLE FALLS P C REV BONDS DUE 14 (2047) 12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 260FERC FORM NO. 2 (12-96)
Reconciliation of Reported Net Income with Taxable Income for Feder Income Taxes
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Details
(a)
1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal Income Tax accruals
and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule
M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the
nature of each reconciling amount.
2. If the utility is a member of a group that files consolidated Federal tax return, reconcile reported net income with taxable net income
as if a separate return were to be filed, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State
names of group members, tax assigned to each group member, and basis of allocation, assignments, or sharing of the consolidated tax
among the group members.
Amount
(b)
134,517,321Net Income for the Year (Page 116) 1
Reconciling Items for the Year 2
3
Taxable Income Not Reported on Books 4
8,180,842 5
6
7
8,180,842TOTAL 8
Deductions Recorded on Books Not Deducted for Return 9
301,465,914 10
7,957,636Federal Income Tax Expense 11
( 534,566)State Income Tax Expense Adj 12
308,888,984TOTAL 13
Income Recorded on Books Not Included in Return 14
( 39,821,309) 15
16
17
( 39,821,309)TOTAL 18
Deductions on Return Not Charged Against Book Income 19
( 413,202,637) 20
21
22
( 5,304,376)Equity in Sub Earnings 23
626,652Corporate Overhead Unallocated Subs 24
25
( 417,880,361)TOTAL 26
( 6,114,523)Federal Tax Net Income 27
Show Computation of Tax: 28
29
( 1,284,050)Federal Tax at 21% 30
31
( 39,280,403)Prior Year True Ups 32
( 690,508)Customer refunds related to prior years at 35 percent 33
34
( 41,254,961)Total Federal Current Tax Expense 35
Page 261FERC FORM NO. 2 (12-96)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
1. Give details of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other
sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual or estimated amounts of such taxes are known, show the amounts in a
footnote and designate whether estimated or actual amounts.
2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes). Enter the amounts in both columns (d) and (e). The
balancing of this
page is not affected by the inclusion of these taxes.
3. Include in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b) amounts credited to the
portion of prepaid taxes charged to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Kind of Tax
(See Instruction 5)
(a)
Balance at
Beg. of Year
Prepaid Taxes
(c)
Balance at
Beg. of Year
Taxes Accrued
(b)
FEDERAL: 1
247,648Income Tax 2014 2
Income Tax 2015 3
( 520,411)Income Tax 2016 4
( 104,399)Income Tax 2017 5
( 1,252,305)Income Tax 2018 6
( 6,543,388)Income Tax 2019 7
Income Tax 2020 8
( 8,172,855) Total Federal 9
10
STATE OF WASHINGTON 11
Payroll Taxes 2020 12
5,584Property Tax 2018 13
18,740,467Property Tax 2019 14
Property Tax 2020 15
892,951Excise Tax 2016 16
2,915,002Excise Tax 2019 17
Excise Tax 2020 18
490Natural Gas Use Tax 19
3,130,051Municipal Occupation Tax 20
( 31,729)Community Solar 21
2,669Sales & Use Tax 2018 22
286,528Sales & Use Tax 2019 23
Sales & Use Tax 2020 24
25,942,013 Total Washington 25
26
STATE OF IDAHO: 27
( 319,616)Income Tax 2019 28
Payroll Taxes 2020 29
3,817,356Property Tax 2019 30
Property Tax 2020 31
Hydro Relicensing 2020 32
9,341Sales & Use Tax 2019 33
Sales & Use Tax 2020 34
Irrigation Credits 2020 35
26,277KWH Tax 2019 36
KWH Tax 2020 37
21Franchise Tax 2018 38
1,103,281Franchise Tax 2019 39
Page 262aFERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (a).
6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a footnote. Designate debit adjustments by parentheses.
7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing
authority.
8. Show in columns (i) thru (p) how the taxes accounts were distributed. Show both the utility department and number of account charged. For taxes charged to utility plant, show the
number of the appropriate balance sheet plant account or subaccount.
9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
10. Items under $250,000 may be grouped.
11. Report in column (q) the applicable effective state income tax rate.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Balance at
End of Year
Prepaid Taxes
(Included in Acct 165)
(h)
Balance at
End of Year
Taxes Accrued
(Account 236)
(g)
Taxes Charged
During Year
(d)
Taxes Paid
During Year
(e)
Adjustments
(f)
1
( 4,864,887)( 315,720)( 5,428,255) 2
( 4,076,471)( 202,821)( 4,279,292) 3
1 520,410 4
333,945( 104,399) 333,945 5
( 18,377,863)( 1)( 17,125,557) 6
( 22,000,000)( 15,456,612) 7
( 65,559)( 65,559) 8
( 49,050,835)( 622,940)( 41,500,920) 9
10
11
( 235,053) 235,053 12
( 5,585) 13
17,835,066( 905,401) 14
18,089,813 493 18,090,306 15
892,951 16
2,981,767 66,765 17
2,930,000 24,129,961 27,059,961 18
480 1,859 1,849 19
3,065,253 23,992,990 23,928,191 20
688( 333,921)( 301,505) 21
( 2,669) 22
( 1)( 126,166) 160,363 23
115,214 128,835 1,061,712 1,048,091 24
24,859,345 70,065,343 68,982,672 25
26
27
( 329,840)( 10,224) 28
( 16,105) 16,105 29
3,817,414 58 30
3,933,011 3,954,640 7,887,651 31
27,134 27,134 32
2,040 11,381 33
27,502( 2,040) 187,358 216,900 34
35
24,981( 1,296) 36
28,115 341,275 369,390 37
( 21) 38
14 21 1,103,288 39
Page 263aFERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
1. Give details of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other
sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual or estimated amounts of such taxes are known, show the amounts in a
footnote and designate whether estimated or actual amounts.
2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes). Enter the amounts in both columns (d) and (e). The
balancing of this
page is not affected by the inclusion of these taxes.
3. Include in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b) amounts credited to the
portion of prepaid taxes charged to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts.
4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Other Income and
Deductions
(Account 408.2,
409.2)
(l)
Other Utility Dept.
(Account 408.1,
409.1)
(k)
Electric
(Account 408.1,
409.1)
(i)
Gas
(Account 408.1,
409.1)
(j)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
1
( 66,752)( 154,443) 2
84,055 194,476 3
303,406 701,981 4
5
689( 12,282) 6
1,811,389( 19,594,973)( 22,547,949) 7
( 1,871,859)( 1,646)( 101,054) 8
( 60,470)( 19,275,221)( 21,919,271) 9
10
11
25,172 771,430 2,772,402 12
( 60)( 5,525) 13
51,755( 281,121)( 676,035) 14
88,009 3,619,482 14,382,815 15
16
1( 78) 66,842 17
123,847 5,922,924 21,013,190 18
1,849 19
5,434,681 18,449,768 20
21
22
23
24
288,724 15,467,318 56,005,306 25
26
27
( 1,533)( 8,691) 28
2,357 110,980 495,425 29
7 50 30
23,573 1,707,061 6,128,579 31
27,134 32
33
34
3,558 35
( 1,296) 36
369,390 37
38
653 3,224 39
Page 262bFERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
5. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (a).
6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a footnote. Designate debit adjustments by parentheses.
7. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing
authority.
8. Show in columns (i) thru (p) how the taxes accounts were distributed. Show both the utility department and number of account charged. For taxes charged to utility plant, show the
number of the appropriate balance sheet plant account or subaccount.
9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
10. Items under $250,000 may be grouped.
11. Report in column (q) the applicable effective state income tax rate.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Other
(p)
Adjustment to Ret.
Earnings
(Account 439)
(o)
Extraordinary Items
(Account 409.3)
(m)
Other Utility Opn.
Income
(Account 408.1,
409.1)
(n)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
State/Local
Income Tax
Rate
(q)
1
( 842,015) 2
( 504,397) 3
37,911 4
5
6
( 846,457) 7
1,909,000 8
( 245,958) 9
10
11
( 3,569,004) 12
13
14
15
16
17
18
19
43,742 20
( 301,505) 21
22
1,048,091 23
24
( 2,778,676) 25
26
27
28
( 608,762) 29
1 30
28,438 31
32
33
216,900 34
( 3,558) 35
36
37
38
( 3,877) 39
Page 263bFERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Kind of Tax
(See Instruction 5)
(a)
Balance at
Beg. of Year
Prepaid Taxes
(c)
Balance at
Beg. of Year
Taxes Accrued
(b)
Franchise Tax 2020 1
( 319,616) 4,956,276 Total Idaho 2
3
STATE OF MONTANA 4
( 124,334)Income Tax 2019 5
Income Tax 2020 6
Payroll Taxes 2020 7
5,767,811Property Tax 2019 8
Property Tax 2020 9
Colstrip Generation Tax 10
226,610KWH Tax 2019 11
KWH Tax 2020 12
15Consumer Council Fee 13
51Public Commission Fee 14
( 124,334) 5,994,487 Total Montana 15
16
STATE OF OREGON 17
Income Tax 2019 18
Income Tax 2020 19
Corp Activities Tax-CAT 2020 20
Payroll Taxes 2020 21
( 3,759,647)Property Tax 2019 22
Property Tax 2020 23
43,414Franchise Tax 2018 24
1,046,390Franchise Tax 2019 25
Franchise Tax 2020 26
( 3,759,647) 1,089,804 Total Oregon 27
28
STATE OF CALIFORNIA 29
Income Tax 2020 30
Total California 31
32
MISCELLANEOUS STATES: 33
( 1,590)Income Tax (Current) 34
Payroll Taxes 2020 35
( 1,590) Total Misc States 36
37
MISCELLANEOUS OTHER 38
33,158Misc/Distribution 39
Page 262a.1FERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Balance at
End of Year
Prepaid Taxes
(Included in Acct 165)
(h)
Balance at
End of Year
Taxes Accrued
(Account 236)
(g)
Taxes Charged
During Year
(d)
Taxes Paid
During Year
(e)
Adjustments
(f)
1,090,306 3,535,443 4,625,749 1
( 329,840) 5,062,843 13,019,019 13,115,362 2
3
4
( 359,950)( 235,616) 5
( 52) 50( 2) 6
( 4,910) 4,910 7
( 1) 5,753,442( 14,367) 8
5,898,062 5,924,294 11,822,356 9
1,837 1,837 10
226,610 11
201,716 760,983 962,699 12
58 66 109 13
42 227 218 14
( 52) 6,094,968( 1) 12,312,469 12,537,234 15
16
17
18
100,000 100,000 19
200,004 600,000 800,004 20
( 9,574) 9,574 21
3,759,648 22
( 4,047,487) 8,094,817 4,047,330 23
43,414 24
1,046,389 25
1,038,154 2,758,478 3,796,632 26
( 4,047,487) 1,228,584 12,652,672 12,503,614 27
28
29
800 800 30
800 800 31
32
33
( 100)( 1,211) 279 34
( 402) 402 35
( 100)( 402)( 809) 279 36
37
38
326( 32,834) 39
Page 263a.1FERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Other Income and
Deductions
(Account 408.2,
409.2)
(l)
Other Utility Dept.
(Account 408.1,
409.1)
(k)
Electric
(Account 408.1,
409.1)
(i)
Gas
(Account 408.1,
409.1)
(j)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
( 1) 1,129,224 3,505,313 1
25,936 2,946,385 10,522,686 2
3
4
( 235,616) 5
( 2) 6
132,045 7
( 14,367) 8
11,822,356 9
( 230) 10
11
962,699 12
109 13
218 14
12,667,212 15
16
17
26 18
70,000 30,000 19
800,004 20
2,749 280,263 9,053 21
2,112,879 1,646,769 22
2,282,154 1,765,176 23
24
25
3,791,045 26
2,749 800,004 8,536,367 3,450,998 27
28
29
800 30
800 31
32
33
57 196 34
35
57 196 36
37
38
16 39
Page 262b.1FERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Other
(p)
Adjustment to Ret.
Earnings
(Account 439)
(o)
Extraordinary Items
(Account 409.3)
(m)
Other Utility Opn.
Income
(Account 408.1,
409.1)
(n)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
State/Local
Income Tax
Rate
(q)
( 8,787) 1
( 379,645) 2
3
4
5
6
( 132,045) 7
8
9
2,067 10
11
12
13
14
( 129,978) 15
16
17
( 26) 18
19
20
( 292,065) 21
22
23
24
25
5,587 26
( 286,504) 27
28
29
30
31
32
33
26 34
35
26 36
37
38
( 32,850) 39
Page 263b.1FERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Kind of Tax
(See Instruction 5)
(a)
Balance at
Beg. of Year
Prepaid Taxes
(c)
Balance at
Beg. of Year
Taxes Accrued
(b)
Payroll Taxes 2020 1
Timber Excise Tax 2
WA Renewable Energy 3
7,180Thermal Fuel Tax 4
40,338 Total County 5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
( 12,378,042) 38,022,918TOTAL
Page 262a.2FERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Balance at
End of Year
Prepaid Taxes
(Included in Acct 165)
(h)
Balance at
End of Year
Taxes Accrued
(Account 236)
(g)
Taxes Charged
During Year
(d)
Taxes Paid
During Year
(e)
Adjustments
(f)
8,019,298 6,664,088 14,683,386 1
2
( 1,933,932)( 1,933,932) 3
1,912 34,724 29,456 4
8,021,536 4,764,880 12,746,076 5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
( 53,428,314) 45,266,874( 1) 112,191,434 78,385,117TOTAL
Page 263a.2FERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Other Income and
Deductions
(Account 408.2,
409.2)
(l)
Other Utility Dept.
(Account 408.1,
409.1)
(k)
Electric
(Account 408.1,
409.1)
(i)
Gas
(Account 408.1,
409.1)
(j)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
606,367 1
2
3
4
606,383 5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
864,122 800,004 7,674,906 60,727,127TOTAL
Page 262b.2FERC FORM NO. 2 (REV 12-07)
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Other
(p)
Adjustment to Ret.
Earnings
(Account 439)
(o)
Extraordinary Items
(Account 409.3)
(m)
Other Utility Opn.
Income
(Account 408.1,
409.1)
(n)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
State/Local
Income Tax
Rate
(q)
14,077,019 1
2
( 1,933,932) 3
29,456 4
12,139,693 5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
8,318,958TOTAL
Page 263b.2FERC FORM NO. 2 (REV 12-07)
This Page Intentionally Left Blank
Miscellaneous Current and Accrued Liabilities (Account 242)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Item
(a)
1. Describe and report the amount of other current and accrued liabilities at the end of year.
2. Minor items (less than $250,000) may be grouped under appropriate title.
Balance at
End of Year
(b)
1,093,948MARGIN CALL DEPOSIT 1
2,630,952FOREST USE PERMITS 2
1,008,114SUA JPMORGAN CHASE 3
137,615SOFTWARE LICENCES - ST 4
4,742ST LEASE ACCRUAL 5
550,000FERC ADMIN FEE 6
114,657FERC ELEC ADMIN CHG 7
5,098,000MT LEASE PAYMENTS 8
402,526MT INVASIVE SPECIES FEE 9
14,387MISC NON-MON PWR EXCHANGE 10
8,766,351CUSTOMER ACCOUNTS 11
26,028,992PAID TIME OFF 12
39,847OL DONATION POOL 13
81,807PREPAYMENTS 14
1,017,959WORKERS COMP LIABILITY 15
1,803,429EXPENSE ACCRUAL - SC 16
11,987,144CURRENT PORTION - BENEFIT LIAB 17
624CLEARING ACCOUNTS 18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
60,781,094Total 45
Page 268FERC FORM NO. 2 (12-96)
Other Deferred Credits (Account 253)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.Description of Other
Deferred Credits
(a)
Balance at
Beginning
of Year
(b)
1. Report below the details called for concerning other deferred credits.
2. For any deferred credit being amortized, show the period of amortization.
3. Minor items (less than $250,000) may be grouped by classes.
Balance at
End of Year
(f)
Debit
Contra
Account
(c)
Debit
Amount
(d)
Credits
(e)
1,125,000 1,125,000Deferred Gas Exchange - 1 year 1
254,006514, 545 43,072 297,078Kettle Falls Diesel Leak 2
918,828 465,598172 646,335 193,105Bills Pole Rentals 3
2,115,126 1,888,925128 9,173,880 8,947,679Defer Comp Active Execs 4
140,000 140,000Executive Incent Plan 5
18,629,136 19,767,661908 105,445 1,243,970Unbilled Revenue 6
15,861,541 18,632,775Various 11,383,248 14,154,482WA Energy Recovery Mechanism 7
9,917,842 11,589,552456, 495 1,855,168 3,526,878Decoupling Deferred Credits 8
6,660,724 6,660,724Reg Liability-COVID-19 Deferral 9
341,916 56,125186, 550 317,157 31,366Misc Deferred Credits 10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
29,659,558 31,450,029 52,654,642 54,445,113Total 45
Page 269FERC FORM NO. 2 (12-96)
Schedule Page: 269 Line No.: 1 Column: a
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 April, 2025.
Schedule Page: 269 Line No.: 2 Column: a
Kettle Falls Generation Station underground fuel leak. Continuing remidation liability is recorded.
Schedule Page: 269 Line No.: 7 Column: a
The Washington Energy Recovery Merchanism (ERM) allows Avista to periodically increase or decrease electric rates.
This accounting method tracks differences between actual power supply costs, net of wholesale sales and sales of fuel,
and the amount included in base rates.
Schedule Page: 269 Line No.: 9 Column: a
Deferral of COVID-19 costs as per Idaho PUC Order No. 34718, Oregon PUC Order No. 20-401, Docket UM 2069, and
Washington UTC Order No. 01, Dockets UE-200407 and UG-200408.
Schedule Page: 269 Line No.: 8 Column: a
Washington Decoupling for electric and natural gas for a 5 year period beginning January 1, 2015. Idaho approved for an
initial term of 3 years beginning January 1, 2016, but extended thru March 31, 2025. Oregon approved similar to
Washington and Idaho beginning March 1, 2016.
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.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1
Accumulated Deferred Income Taxes-Other Property (Account 282)
1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to property not subject to accelerated amortization.
2. At Other (Specify), include deferrals relating to other income and deductions.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Account Subdivisions
(a)
Amounts
Credited to
Account 411.1
(d)
Balance at
Beginning
of Year
(b)
Amounts
Debited to
Account 410.1
(c)
Account 282 1
44,688,310Electric 339,209,550 2
32,594,670Gas 86,849,511 3
( 1,572,234)Other (Define) (footnote details) 88,810,946 4
75,710,746Total (Enter Total of lines 2 thru 4) 514,870,007 5
Other (Specify) (footnote details) 6
75,710,746TOTAL Account 282 (Enter Total of lines 5 thr 514,870,007 7
Classification of TOTAL 8
75,710,746Federal Income Tax 514,870,007 9
State Income Tax 10
Local Income Tax 11
Page 274FERC FORM NO. 2 (REV 12-07)
Accumulated Deferred Income Taxes-Other Property (Account 282) (continued)
3. Provide in a footnote a summary of the type and amount of deferred income taxes reported in the beginning-of-year and end-of-year balances for deferred income taxes that the
respondent estimates could be included in the development of jurisdictional recourse rates.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Adjustments
Debits
Acct. No.
(g)
Changes during
Year
Amounts Debited
to Account 410.2
(e)
Changes during
Year
Amounts Credited
to Account 411.2
(f)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
(i)
Adjustments
Credits
Amount
(j)
Balance at
End of Year
(k)
1
398,244,120 14,346,260 2
143,910,347 24,466,166 3
61,260,966 25,977,746 4
603,415,433 25,977,746 38,812,426 5
6
603,415,433 25,977,746 38,812,426 7
8
603,415,433 25,977,746 38,812,426 9
10
11
Page 275FERC FORM NO. 2 (REV 12-07)
Accumulated Deferred Income Taxes-Other (Account 283)
1. Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283.
2. At Other (Specify), include deferrals relating to other income and deductions.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Account Subdivisions
(a)
Changes During Year
Amounts
Credited to
Account 411.1
(d)
Balance at
Beginning
of Year
(b)
Changes During Year
Amounts
Debited to
Account 410.1
(c)
Account 283 1
745,973 1,968,358Electric 13,393,102 2
362,272 1,762,139Gas 2,385,096 3
5,921,872Other (Define) (footnote details) 163,807,011 4
1,108,245 9,652,369Total (Total of lines 2 thru 4) 179,585,209 5
Other (Specify) (footnote details) 6
1,108,245 9,652,369TOTAL Account 283 (Total of lines 5 thru 179,585,209 7
Classification of TOTAL 8
1,108,245 9,652,369Federal Income Tax 179,585,209 9
State Income Tax 10
Local Income Tax 11
Page 276FERC FORM NO. 2/3Q (REV 12-07)
Accumulated Deferred Income Taxes-Other (Account 283) (continued)
3. Provide in a footnote a summary of the type and amount of deferred income taxes reported in the beginning-of-year and end-of-year balances for deferred income taxes that the
respondent estimates could be included in the development of jurisdictional recourse rates.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Adjustments
Debits
Acct. No.
(g)
Changes during
Year
Amounts Debited
to Account 410.2
(e)
Changes during
Year
Amounts Credited
to Account 411.2
(f)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
(i)
Adjustments
Credits
Amount
(j)
Balance at
End of Year
(k)
1
12,928,052 1,063,055 899,441 275,061 2
3,042,547 714,455( 27,961) 3
184,147,569 14,315,742 102,944 4
200,118,168 1,777,510 14,315,742 899,441 350,044 5
6
200,118,168 1,777,510 14,315,742 899,441 350,044 7
8
200,118,168 1,777,510 14,315,742 899,441 350,044 9
10
11
Page 277FERC FORM NO. 2/3Q (REV 12-07)
Other Regulatory Liabilities (Account 254)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.Description and Purpose of
Other Regulatory Liabilities
(a)
Balance at
Beginning of
Current
Quarter/Year
(b)
1. Report below the details called for concerning other regulatory liabilities which are created through the ratemaking actions of regulatory agencies (and not
includable in other amounts).
2. For regulatory liabilities being amortized, show period of amortization in column (a).
3. Minor items (5% of the Balance at End of Year for Account 254 or amounts less than $250,000, whichever is less) may be grouped by classes.
4. Provide in a footnote, for each line item, the regulatory citation where the respondent was directed to refund the regulatory liability (e.g. Commission Order, state
commission order, court decision).
Balance at
End of Current
Quarter/Year
(g)
Written off during
Quarter/Period
Account
Credited
(c)
Written off
During Period
Amount
Refunded
(d)
Credits
(f)
Written off
During Period
Amount Deemed
Non-Refundable
(e)
1,072,903Idaho Invest,ment Tax Credit 190 4,756,652 8,874,779 5,191,030 1
1,099,869Oregon BETC Credit 190, 283 11,558 1,111,427 2
2,042,533Interest Rate Swaps 427, 175 15,045,752 17,088,285 3
22,008Nez Perce 557 506,300 528,308 4
Idaho Earnings Test 686,970 686,970 5
1,081,410Decoupling Rebate 495, 182 3,315,785 2,335,746 101,371 6
53,679,690WA ERM 182, 557 54,363,026 26,486,130 25,802,794 7
141,936Deferred Federal ITC- Varies 190 7,821,976 7,963,912 8
15,431,659Plant Excess Deferred 190, 282 382,938,797 398,370,456 9
11,015,304Non Plant Excess Deferred 108, 411 74,329 11,089,633 10
Reg Liability MDM System 307,687 897,416 589,729 11
AFUDC Equity Tax Deferral 342,811 2,606,448 2,263,637 12
13,254Exist Meters/ERTS Excess Depr Deferred 407 940,093 1,879,242 952,403 13
12,389,437DSM Tariff Rider Various 12,635,179 540,275 294,533 14
12,954,756Low Income Energy Assistance 242, 908 14,336,849 3,783,957 2,401,864 15
397,359Deferred CS2 & Colstrip O&M 407 397,359 16
6,385,196
Reg Liabilty- Tax Reform Amortization- 1
year 407, 431 3,030,529 994,068 4,348,735
17
Reg Liability- Energy Efficiency
Assistance 1,532,183 1,532,183
18
1,071,334Reg Liability- Colstrip Community Fund 407, 431 4,428,445 3,357,111 19
Reg Liability- COVID-19 Deferral 4,288,655 4,288,655 20
30,122Other Regulatory Liabilities-Varies Various 7,997,303 8,459,685 492,504 21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
118,828,770 0 473,121,377 481,207,133Total 45 110,743,014
Page 278FERC FORM NO. 2/3Q (REV 12-07)
Schedule Page: 278 Line No.: 1 Column: a
Not amortized
Schedule Page: 278 Line No.: 2 Column: a
Not amortized
Schedule Page: 278 Line No.: 3 Column: a
Mark-to-Market gains and losses for interest rate swap derivatives. Upon settlement, amortization of Regulatory Assets
and Liabilities as a component of interest expense over the term of the associated debt.
Schedule Page: 278 Line No.: 6 Column: a
Decoupling rebates are recognized during the period they occur, subject to certain limitations. Rebates are returned to
customers within 24 months of the deferral.
Schedule Page: 278 Line No.: 7 Column: a
The Washington Energy Recovery Mechanism allows Avista to periodically increase or decrease electric rates. This
accounting method tracks differences between actual power supply costs, net of wholesale sales and sales of fuel, and
the amount included in base rates. Avista files yearly on or before April 1 for prudence review by the commission.
Schedule Page: 278 Line No.: 8 Column: a
Noxon ITC - 65 year amortization, ends 2077
Community Solar ITC - 20 year amortization, ends 2035
Nine Mile ITC - 65 year amortization, ends 2080
Schedule Page: 278 Line No.: 9 Column: a
Amortized over remaining book life of plant, estimated 36 years.
Schedule Page: 278 Line No.: 10 Column: a
Washington Gas and Oregon Gas costs are amortized over 1 year. Idaho Electric was offset against Colstrip excess
depreciation impacts from Docket# AVU-E-18-03 Order No. 34276.
Schedule Page: 278 Line No.: 12 Column: a
Amortization period not yet determined in all jurisdictions. Idaho Electric Settlement AVU-E-19-04 ordered a transfer to
account 254320 for Idaho portion.
Schedule Page: 278 Line No.: 13 Column: a
Washington Docket #s UE-180418 and UG-180419
Schedule Page: 278 Line No.: 14 Column: a
Washington Order Docket #s UE-190912 and UG-190920, Idaho Docket AVU-E-18-12 and AVU-G-18-08, Oregon Order
No. 19-424
Schedule Page: 278 Line No.: 15 Column: a
Washington Docket# UE-190912, UG-190920
Idaho Docket# AVU-E-18-12, AVU-G-18-08
Oregon RG 81, Docket No. ADV 1063 (Advice No. 19-10-G)
Schedule Page: 278 Line No.: 17 Column: a
Washington Docket #s UE-170485, UG-170486
Oregon Advice# ADV 923/19-01-G (Schedule 474)
Idaho Case# GNR-U-18-01
Schedule Page: 278 Line No.: 18 Column: a
Avista's contribution in the Energy Assistance Fund as per Idaho Settlement Stipulation Case# AVU-E-19-04 (Page 10,
#16 a.ii).
Schedule Page: 278 Line No.: 19 Column: a
Washington Order 09 in Dockets UE-190334, UE-190222. Deferral of funds from shareholders and customers, set aside
to helping the Colstrip community transition away from economic activity related to coal-fired generation.
Schedule Page: 278 Line No.: 20 Column: a
Deferral of COVID-19 costs as per Idaho PUC Order No. 34718, Oregon PUC Order No. 20-401, Docket UM 2069, and
Washington UTC Order No. 01, Dockets UE-200407 and UG-200408.
Schedule Page: 278 Line No.: 21 Column: a
FAS 109 ITC - 18 year amortization, ends 2020.
State income tax net operating loss carryforward of $7.5M recorded during the year and will reverse over the period in
which we are able to utilize the loss to offset taxable income on the Idaho, Montana, and Oregon tax returns.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1
Deferral of depreciation expense of $0.5M per Idaho Order No. 34276, Case Nos. AVU-E-18-03 and AVU-G-18-02.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.2

This Page Intentionally Left Blank
Gas Operating Revenues
1. Report below natural gas operating revenues for each prescribed account total. The amounts must be consistent with the detailed data on succeeding pages.
2. Revenues in columns (b) and (c) include transition costs from upstream pipelines.
3. Other Revenues in columns (f) and (g) include reservation charges received by the pipeline plus usage charges, less revenues reflected in columns (b) through (e). Include in
columns (f) and (g) revenues for Accounts 480-495.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Title of Account
(a)
Revenues for
GRI and ACA
Amount for
Current Year
(d)
Revenues for
Transition
Costs and
Take-or-Pay
Amount for
Current Year
(b)
Revenues for
Transition
Costs and
Take-or-Pay
Amount for
Previous Year
(c)
Revenues for
GRI and ACA
Amount for
Previous Year
(e)
480 Residential Sales 1
481 Commercial and Industrial Sales 2
482 Other Sales to Public Authorities 3
483 Sales for Resale 4
484 Interdepartmental Sales 5
485 Intracompany Transfers 6
487 Forfeited Discounts 7
488 Miscellaneous Service Revenues 8
489.1 Revenues from Transportation of Gas of Others
Through Gathering Facilities
9
489.2 Revenues from Transportation of Gas of Others
Through Transmission Facilities
10
489.3 Revenues from Transportation of Gas of Others
Through Distribution Facilities
11
489.4 Revenues from Storing Gas of Others 12
490 Sales of Prod. Ext. from Natural Gas 13
491 Revenues from Natural Gas Proc. by Others 14
492 Incidental Gasoline and Oil Sales 15
493 Rent from Gas Property 16
494 Interdepartmental Rents 17
495 Other Gas Revenues 18
Subtotal: 19
496 (Less) Provision for Rate Refunds 20
TOTAL: 21
Page 300FERC FORM NO. 2 (REV 12-07)
Gas Operating Revenues
4. If increases or decreases from previous year are not derived from previously reported figures, explain any inconsistencies in a footnote.
5. On Page 108, include information on major changes during the year, new service, and important rate increases or decreases.
6. Report the revenue from transportation services that are bundled with storage services as transportation service revenue.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Dekatherm of
Natural Gas
Amount for
Current Year
(j)
Total
Operating
Revenues
Amount for
Current Year
(h)
Total
Operating
Revenues
Amount for
Previous Year
(i)
Dekatherm of
Natural Gas
Amount for
Previous Year
(k)
Other
Revenues
Amount for
Previous Year
(g)
Other
Revenues
Amount for
Current Year
(f)
23,123,796 21,998,766480 Residential Sales 213,611,519 196,429,738 213,611,519 196,429,738 1
15,592,762 14,793,672481 Commercial and Industrial Sales 102,065,963 97,431,048 102,065,963 97,431,048 2
482 Other Sales to Public Authorities 3
59,875,983 54,966,875483 Sales for Resale 105,073,763 136,305,522 105,073,763 136,305,522 4
42,081 36,886484 Interdepartmental Sales 252,564 253,068 252,564 253,068 5
485 Intracompany Transfers 6
487 Forfeited Discounts 7
488 Miscellaneous Service Revenues 43,452 106,672 43,452 106,672 8
489.1 Revenues from Transportation of Gas of Others
Through Gathering Facilities
9
489.2 Revenues from Transportation of Gas of Others
Through Transmission Facilities
10
19,542,094 18,573,063
489.3 Revenues from Transportation of Gas of Others
Through Distribution Facilities 7,916,862 8,673,782 7,916,862 8,673,782
11
489.4 Revenues from Storing Gas of Others 12
490 Sales of Prod. Ext. from Natural Gas 13
491 Revenues from Natural Gas Proc. by Others 14
492 Incidental Gasoline and Oil Sales 15
493 Rent from Gas Property 465 2,751 465 2,751 16
494 Interdepartmental Rents 17
495 Other Gas Revenues 4,986,835 7,228,294 4,986,835 7,228,294 18
118,176,716 110,369,262Subtotal: 433,951,423 446,430,875 433,951,423 446,430,875 19
496 (Less) Provision for Rate Refunds( 3,192,858) 1,815,553( 3,192,858) 1,815,553 20
118,176,716 110,369,262TOTAL: 437,144,281 444,615,322 437,144,281 444,615,322 21
Page 301FERC FORM NO. 2 (REV 12-07)
Other Gas Revenues (Account 495)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Description of Transaction
(a)
Report below transactions of $250,000 or more included in Account 495, Other Gas Revenues. Group all transactions below $250,000
in one amount and provide the number of items.
Amount
(in dollars)
(b)
Commissions on Sale or Distribution of Gas of Others 1
Compensation for Minor or Incidental Services Provided for Others 2
Profit or Loss on Sale of Material and Supplies not Ordinarily Purchased for Resale 3
Sales of Stream, Water, or Electricity, including Sales or Transfers to Other Departments 4
Miscellaneous Royalties 5
Revenues from Dehydration and Other Processing of Gas of Others except as provided for in the Instructions to Account 495 6
Revenues for Right and/or Benefits Received from Others which are Realized Through Research, Development, and Demonstration Ventures 7
Gains on Settlements of Imbalance Receivables and Payables 8
Revenues from Penalties earned Pursuant to Tariff Provisions, including Penalties Associated with Cash-out Settlements 9
Revenues from Shipper Supplied Gas 10
Other revenues (Specify): 11
Misc. Bills ( 60,096) 12
Deferred Exchange Revenue 4,500,000 13
Decoupling Deferred Revenue 546,931 14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
4,986,835Total
Page 308FERC FORM NO. 2 (12-96)
Gas Operation and Maintenance Expenses
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
1. PRODUCTION EXPENSES 00 1
A. Manufactured Gas Production 00 2
Manufactured Gas Production (Submit Supplemental Statement) 00 3
B. Natural Gas Production 00 4
B1. Natural Gas Production and Gathering 00 5
Operation 00 6
750 Operation Supervision and Engineering 00 7
751 Production Maps and Records 00 8
752 Gas Well Expenses 00 9
753 Field Lines Expenses 00 10
754 Field Compressor Station Expenses 00 11
755 Field Compressor Station Fuel and Power 00 12
756 Field Measuring and Regulating Station Expenses 00 13
757 Purification Expenses 00 14
758 Gas Well Royalties 00 15
759 Other Expenses 00 16
760 Rents 00 17
TOTAL Operation (Total of lines 7 thru 17)00 18
Maintenance 00 19
761 Maintenance Supervision and Engineering 00 20
762 Maintenance of Structures and Improvements 00 21
763 Maintenance of Producing Gas Wells 00 22
764 Maintenance of Field Lines 00 23
765 Maintenance of Field Compressor Station Equipment 00 24
766 Maintenance of Field Measuring and Regulating Station Equipment 00 25
767 Maintenance of Purification Equipment 00 26
768 Maintenance of Drilling and Cleaning Equipment 00 27
769 Maintenance of Other Equipment 00 28
TOTAL Maintenance (Total of lines 20 thru 28)00 29
TOTAL Natural Gas Production and Gathering (Total of lines 18 and 29)00 30
Page 317FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
B2. Products Extraction 00 31
Operation 00 32
770 Operation Supervision and Engineering 00 33
771 Operation Labor 00 34
772 Gas Shrinkage 00 35
773 Fuel 00 36
774 Power 00 37
775 Materials 00 38
776 Operation Supplies and Expenses 00 39
777 Gas Processed by Others 00 40
778 Royalties on Products Extracted 00 41
779 Marketing Expenses 00 42
780 Products Purchased for Resale 00 43
781 Variation in Products Inventory 00 44
(Less) 782 Extracted Products Used by the Utility-Credit 00 45
783 Rents 00 46
TOTAL Operation (Total of lines 33 thru 46)00 47
Maintenance 00 48
784 Maintenance Supervision and Engineering 00 49
785 Maintenance of Structures and Improvements 00 50
786 Maintenance of Extraction and Refining Equipment 00 51
787 Maintenance of Pipe Lines 00 52
788 Maintenance of Extracted Products Storage Equipment 00 53
789 Maintenance of Compressor Equipment 00 54
790 Maintenance of Gas Measuring and Regulating Equipment 00 55
791 Maintenance of Other Equipment 00 56
TOTAL Maintenance (Total of lines 49 thru 56)00 57
TOTAL Products Extraction (Total of lines 47 and 57)00 58
Page 318FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
C. Exploration and Development 00 59
Operation 00 60
795 Delay Rentals 00 61
796 Nonproductive Well Drilling 00 62
797 Abandoned Leases 00 63
798 Other Exploration 00 64
TOTAL Exploration and Development (Total of lines 61 thru 64)00 65
D. Other Gas Supply Expenses 00 66
Operation 00 67
800 Natural Gas Well Head Purchases 00 68
800.1 Natural Gas Well Head Purchases, Intracompany Transfers 00 69
801 Natural Gas Field Line Purchases 00 70
802 Natural Gas Gasoline Plant Outlet Purchases 00 71
803 Natural Gas Transmission Line Purchases 00 72
804 Natural Gas City Gate Purchases 266,160,172 202,359,237 73
804.1 Liquefied Natural Gas Purchases 00 74
805 Other Gas Purchases 00 75
(Less) 805.1 Purchases Gas Cost Adjustments 37,730,182 4,674,021 76
TOTAL Purchased Gas (Total of lines 68 thru 76) 228,429,990 197,685,216 77
806 Exchange Gas 00 78
Purchased Gas Expenses 00 79
807.1 Well Expense-Purchased Gas 00 80
807.2 Operation of Purchased Gas Measuring Stations 00 81
807.3 Maintenance of Purchased Gas Measuring Stations 00 82
807.4 Purchased Gas Calculations Expenses 00 83
807.5 Other Purchased Gas Expenses 00 84
TOTAL Purchased Gas Expenses (Total of lines 80 thru 84)00 85
Page 319FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
808.1 Gas Withdrawn from Storage-Debit 32,607,408 17,913,784 86
(Less) 808.2 Gas Delivered to Storage-Credit 35,303,621 13,143,711 87
809.1 Withdrawals of Liquefied Natural Gas for Processing-Debit 00 88
(Less) 809.2 Deliveries of Natural Gas for Processing-Credit 00 89
Gas used in Utility Operation-Credit 00 90
810 Gas Used for Compressor Station Fuel-Credit 00 91
811 Gas Used for Products Extraction-Credit 699,291 297,348 92
812 Gas Used for Other Utility Operations-Credit 00 93
TOTAL Gas Used in Utility Operations-Credit (Total of lines 91 thru 93) 699,291 297,348 94
813 Other Gas Supply Expenses 1,553,513 1,604,679 95
TOTAL Other Gas Supply Exp. (Total of lines 77,78,85,86 thru 89,94,95) 226,587,999 203,762,620 96
TOTAL Production Expenses (Total of lines 3, 30, 58, 65, and 96) 226,587,999 203,762,620 97
2. NATURAL GAS STORAGE, TERMINALING AND PROCESSING EXPENSES 00 98
A. Underground Storage Expenses 00 99
Operation 00100
814 Operation Supervision and Engineering 15,735 7,196101
815 Maps and Records 00102
816 Wells Expenses 00103
817 Lines Expense 00104
818 Compressor Station Expenses 00105
819 Compressor Station Fuel and Power 00106
820 Measuring and Regulating Station Expenses 00107
821 Purification Expenses 00108
822 Exploration and Development 00109
823 Gas Losses 00110
824 Other Expenses 772,251 805,804111
825 Storage Well Royalties 00112
826 Rents 00113
TOTAL Operation (Total of lines of 101 thru 113) 787,986 813,000114
Page 320FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
Maintenance 00115
830 Maintenance Supervision and Engineering 00116
831 Maintenance of Structures and Improvements 00117
832 Maintenance of Reservoirs and Wells 00118
833 Maintenance of Lines 00119
834 Maintenance of Compressor Station Equipment 00120
835 Maintenance of Measuring and Regulating Station Equipment 00121
836 Maintenance of Purification Equipment 00122
837 Maintenance of Other Equipment 2,239,715 2,186,040123
TOTAL Maintenance (Total of lines 116 thru 123) 2,239,715 2,186,040124
TOTAL Underground Storage Expenses (Total of lines 114 and 124) 3,027,701 2,999,040125
B. Other Storage Expenses 00126
Operation 00127
840 Operation Supervision and Engineering 00128
841 Operation Labor and Expenses 00129
842 Rents 00130
842.1 Fuel 00131
842.2 Power 00132
842.3 Gas Losses 00133
TOTAL Operation (Total of lines 128 thru 133)00134
Maintenance 00135
843.1 Maintenance Supervision and Engineering 00136
843.2 Maintenance of Structures 00137
843.3 Maintenance of Gas Holders 00138
843.4 Maintenance of Purification Equipment 00139
843.5 Maintenance of Liquefaction Equipment 00140
843.6 Maintenance of Vaporizing Equipment 00141
843.7 Maintenance of Compressor Equipment 00142
843.8 Maintenance of Measuring and Regulating Equipment 00143
843.9 Maintenance of Other Equipment 00144
TOTAL Maintenance (Total of lines 136 thru 144)00145
TOTAL Other Storage Expenses (Total of lines 134 and 145)00146
Page 321FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
C. Liquefied Natural Gas Terminaling and Processing Expenses 00147
Operation 00148
844.1 Operation Supervision and Engineering 00149
844.2 LNG Processing Terminal Labor and Expenses 00150
844.3 Liquefaction Processing Labor and Expenses 00151
844.4 Liquefaction Transportation Labor and Expenses 00152
844.5 Measuring and Regulating Labor and Expenses 00153
844.6 Compressor Station Labor and Expenses 00154
844.7 Communication System Expenses 00155
844.8 System Control and Load Dispatching 00156
845.1 Fuel 00157
845.2 Power 00158
845.3 Rents 00159
845.4 Demurrage Charges 00160
(less) 845.5 Wharfage Receipts-Credit 00161
845.6 Processing Liquefied or Vaporized Gas by Others 00162
846.1 Gas Losses 00163
846.2 Other Expenses 00164
TOTAL Operation (Total of lines 149 thru 164)00165
Maintenance 00166
847.1 Maintenance Supervision and Engineering 00167
847.2 Maintenance of Structures and Improvements 00168
847.3 Maintenance of LNG Processing Terminal Equipment 00169
847.4 Maintenance of LNG Transportation Equipment 00170
847.5 Maintenance of Measuring and Regulating Equipment 00171
847.6 Maintenance of Compressor Station Equipment 00172
847.7 Maintenance of Communication Equipment 00173
847.8 Maintenance of Other Equipment 00174
TOTAL Maintenance (Total of lines 167 thru 174)00175
TOTAL Liquefied Nat Gas Terminaling and Proc Exp (Total of lines 165 and 175)00176
TOTAL Natural Gas Storage (Total of lines 125, 146, and 176) 3,027,701 2,999,040177
Page 322FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
3. TRANSMISSION EXPENSES 00178
Operation 00179
850 Operation Supervision and Engineering 00180
851 System Control and Load Dispatching 00181
852 Communication System Expenses 00182
853 Compressor Station Labor and Expenses 00183
854 Gas for Compressor Station Fuel 00184
855 Other Fuel and Power for Compressor Stations 00185
856 Mains Expenses 00186
857 Measuring and Regulating Station Expenses 00187
858 Transmission and Compression of Gas by Others 00188
859 Other Expenses 00189
860 Rents 00190
TOTAL Operation (Total of lines 180 thru 190)00191
Maintenance 00192
861 Maintenance Supervision and Engineering 00193
862 Maintenance of Structures and Improvements 00194
863 Maintenance of Mains 00195
864 Maintenance of Compressor Station Equipment 00196
865 Maintenance of Measuring and Regulating Station Equipment 00197
866 Maintenance of Communication Equipment 00198
867 Maintenance of Other Equipment 00199
TOTAL Maintenance (Total of lines 193 thru 199)00200
TOTAL Transmission Expenses (Total of lines 191 and 200)00201
4. DISTRIBUTION EXPENSES 00202
Operation 00203
870 Operation Supervision and Engineering 2,571,709 2,566,384204
871 Distribution Load Dispatching 00205
872 Compressor Station Labor and Expenses 00206
873 Compressor Station Fuel and Power 00207
Page 323FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
874 Mains and Services Expenses 6,006,761 6,767,956208
875 Measuring and Regulating Station Expenses-General 202,120 213,070209
876 Measuring and Regulating Station Expenses-Industrial 9,837 6,318210
877 Measuring and Regulating Station Expenses-City Gas Check Station 79,264 69,259211
878 Meter and House Regulator Expenses 850,056 905,675212
879 Customer Installations Expenses 3,312,750 2,471,877213
880 Other Expenses 3,505,475 2,478,227214
881 Rents 52,175 48,470215
TOTAL Operation (Total of lines 204 thru 215) 16,590,147 15,527,236216
Maintenance 00217
885 Maintenance Supervision and Engineering 220,749 102,114218
886 Maintenance of Structures and Improvements 00219
887 Maintenance of Mains 2,283,909 2,472,876220
888 Maintenance of Compressor Station Equipment 00221
889 Maintenance of Measuring and Regulating Station Equipment-General 606,305 739,213222
890 Maintenance of Meas. and Reg. Station Equipment-Industrial 57,433 55,558223
891 Maintenance of Meas. and Reg. Station Equip-City Gate Check Station 129,459 233,429224
892 Maintenance of Services 2,113,144 1,874,030225
893 Maintenance of Meters and House Regulators 2,623,297 2,966,028226
894 Maintenance of Other Equipment 414,110 448,151227
TOTAL Maintenance (Total of lines 218 thru 227) 8,448,406 8,891,399228
TOTAL Distribution Expenses (Total of lines 216 and 228) 25,038,553 24,418,635229
5. CUSTOMER ACCOUNTS EXPENSES 00230
Operation 00231
901 Supervision 137,648 136,117232
902 Meter Reading Expenses 1,771,096 935,192233
903 Customer Records and Collection Expenses 8,318,773 6,893,675234
Page 324FERC FORM NO. 2 (12-96)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Account
(a)
Amount for
Current Year
(b)
Gas Operation and Maintenance Expenses(continued)
Amount for
Previous Year
(c)
904 Uncollectible Accounts 191,192 3,283,520235
905 Miscellaneous Customer Accounts Expenses 174,009 134,096236
TOTAL Customer Accounts Expenses (Total of lines 232 thru 236) 10,592,718 11,382,600237
6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES 00238
Operation 00239
907 Supervision 00240
908 Customer Assistance Expenses 13,934,510 13,354,719241
909 Informational and Instructional Expenses 1,239,099 975,808242
910 Miscellaneous Customer Service and Informational Expenses 241,254 295,212243
TOTAL Customer Service and Information Expenses (Total of lines 240 thru 243) 15,414,863 14,625,739244
7. SALES EXPENSES 00245
Operation 00246
911 Supervision 00247
912 Demonstrating and Selling Expenses 259 260248
913 Advertising Expenses 0 550249
916 Miscellaneous Sales Expenses 00250
TOTAL Sales Expenses (Total of lines 247 thru 250) 259 810251
8. ADMINISTRATIVE AND GENERAL EXPENSES 00252
Operation 00253
920 Administrative and General Salaries 10,145,930 11,834,574254
921 Office Supplies and Expenses 1,870,409 1,807,439255
(Less) 922 Administrative Expenses Transferred-Credit 17,719 20,135256
923 Outside Services Employed 3,805,281 4,513,246257
924 Property Insurance 489,741 572,070258
925 Injuries and Damages 1,613,044 1,575,608259
926 Employee Pensions and Benefits 11,308,297 12,341,599260
927 Franchise Requirements 00261
928 Regulatory Commission Expenses 1,959,465 1,933,458262
(Less) 929 Duplicate Charges-Credit 00263
930.1General Advertising Expenses 00264
930.2Miscellaneous General Expenses 1,857,212 2,455,256265
931 Rents 132,525 159,577266
TOTAL Operation (Total of lines 254 thru 266) 33,164,185 37,172,692267
Maintenance 00268
932 Maintenance of General Plant 4,930,291 5,057,592269
TOTAL Administrative and General Expenses (Total of lines 267 and 269) 38,094,476 42,230,284270
TOTAL Gas O&M Expenses (Total of lines 97,177,201,229,237,244,251, and 270) 318,756,569 299,419,728271
Page 325FERC FORM NO. 2 (12-96)
Gas Used in Utility Operations
1. Report below details of credits during the year to Accounts 810, 811, and 812.
2. If any natural gas was used by the respondent for which a charge was not made to the appropriate operating expense or other account, list separately in column (c) the Dth of gas
used, omitting entries in column (d).
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Purpose for Which Gas
Was Used
(a)
Natural Gas
Amount of
Credit
(in dollars)
(d)
Account
Charged
(b)
Natural Gas
Gas Used
Dth
(c)
Natural Gas
Amount of
Credit
(in dollars)
(d)
Natural Gas
Amount of
Credit
(in dollars)
(d)
2,482,889810 Gas Used for Compressor Station Fuel - Credit 1
297,348 40,105,509811 Gas Used for Products Extraction - Credit 2
Gas Shrinkage and Other Usage in Respondent's
Own Processing
3
Gas Shrinkage, etc. for Respondent's Gas
Processed by Others
4
812 Gas Used for Other Utility Operations - Credit
(Report separately for each principal use. Group
minor uses.)
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
297,348 42,588,39825 Total
Page 331FERC FORM NO. 2 (12-96)
Schedule Page: 331 Line No.: 2 Column: c
Represents the amount of processed gas run through the plant
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1
Other Gas Supply Expenses (Account 813)
1. Report other gas supply expenses by descriptive titles that clearly indicate the nature of such expenses. Show maintenance expenses, revaluation of monthly encroachments
recorded in Account 117.4, and losses on settlements of imbalances and gas losses not associated with storage separately. Indicate the functional classification and purpose of property
to which any expenses relate. List separately items of $250,000 or more.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description
(a)
Amount
(in dollars)
(b)
Gas Resource Management 1
1,085,733Labor 2
209,795Labor Loading 3
113,694Other Expenses (Professional Services, Travel, Transportation, Office Supplies, Training) 4
5
Regulatory Affairs 6
18,648Labor 7
3,353Labor Loading 8
173,456Other Expenses (Travel, Transportation, Gas Technology Institute Payments) 9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
1,604,67925 Total
Page 334FERC FORM NO. 2 (12-96)
Miscellaneous General Expenses (Account 930.2)
1. Provide the information requested below on miscellaneous general expenses.
2. For Other Expenses, show the (a) purpose, (b) recipient and (c) amount of such items. List separately amounts of $250,000 or more however, amounts less than $250,000 may be
grouped if the number of items of so grouped is shown.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description
(a)
Amount
(in dollars)
(b)
Industry association dues. 199,563 1
Experimental and general research expenses. 2
a. Gas Research Institute (GRI)
b. Other
Publishing and distributing information and reports to stockholders, trustee, registrar, and transfer 3
agent fees and expenses, and other expenses of servicing outstanding securities of the respondent 340,320
Board of Director Activities 634,812 4
Education, Information & Training 39,585 5
Emergency Operating Procedure Events 878,144 6
Community Relations 179,197 7
Misc. Employee Expenses 16,707 8
Misc. Labor 3,741 9
Misc. Legal, Professional, and General Services 68,099 10
Misc. Transportation 84,892 11
Other Misc. Expenses <$5k 10,195 12
13
14
15
16
17
18
19
20
21
22
23
24
2,455,25525 Total
Page 335FERC FORM NO. 2 (12-96)
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 404.1, 404.2, 404.3, 405) (Except Amortization of
Acquisition Adjustments)
1. Report in Section A the amounts of depreciation expense, depletion and amortization for the accounts indicated and classified according to the plant functional groups shown.
2. Report in Section B, column (b) all depreciable or amortizable plant balances to which rates are applied and show a composite total. (If more desirable, report by plant account,
subaccount or functional classifications other than those pre-printed in column (a). Indicate in a footnote the manner in which column (b) balances are
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Functional Classification
(a)
Amortization of
Underground Storage
Land and Land
Rights
(Account 404.2)
(e)
Amortization
Expense for
Asset
Retirement
Costs
(Account
403.1) (c)
Amortization and
Depletion of
Producing Natural
Gas Land and Land
Rights
(Account 404.1)
(d)
Section A. Summary of Depreciation, Depletion, and Amortization Charges
Depreciation
Expense
(Account 403)
(b)
1 Intangible plant
2 Production plant, manufactured gas
3 Production and gathering plant, natural gas
4 Products extraction plant
748,685 5 Underground gas storage plant
6 Other storage plant
7 Base load LNG terminaling and processing plant
8 Transmission plant
29,006,170 9 Distribution plant
1,760,949 10 General plant
7,725,749 11 Common plant-gas
39,241,553 12 TOTAL
Page 336FERC FORM NO. 2 (12-96)
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 404.1, 404.2, 404.3, 405) (Except Amortization of
Acquisition Adjustments) (continued)
obtained. If average balances are used, state the method of averaging used. For column (c) report available information for each plant functional classification listed in column (a). If
composite depreciation accounting is used, report available information called for in columns (b) and (c) on this basis. Where the unit-of-production method is used to determine
depreciation charges, show in a footnote any revisions made to estimated gas reserves.
3. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state in a footnote the amounts and nature of the
provisions and the plant items to which related.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Total
(b to g)
(h)
Amortization of
Other Limited-term
Gas Plant
(Account 404.3)
(f)
Amortization of
Other Gas Plant
(Account 405)
(g)
Functional Classification
(a)
Section A. Summary of Depreciation, Depletion, and Amortization Charges
123,966 123,966 1 Intangible plant
2 Production plant, manufactured gas
3 Production and gathering plant, natural gas
4 Products extraction plant
748,685 5 Underground gas storage plant
6 Other storage plant
7 Base load LNG terminaling and processing plant
8 Transmission plant
29,006,170 9 Distribution plant
1,760,949 10 General plant
19,408,579 11,682,830 11 Common plant-gas
51,048,349 11,806,796 12 TOTAL
Page 337FERC FORM NO. 2 (12-96)
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 404.1, 404.2, 404.3, 405) (Except Amortization of
Acquisition Adjustments) (continued)
4. Add rows as necessary to completely report all data. Number the additional rows in sequence as 2.01, 2.02, 3.01, 3.02, etc.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Applied Depreciation
or Amortization Rates
(percent)
(c)
Plant Bases
(in thousands)
(b)
Functional Classification
(a)
Section B. Factors Used in Estimating Depreciation Charges
Production and Gathering Plant 1
Offshore (footnote details) 2
Onshore (footnote details) 3
Underground Gas Storage Plant (footnote details) 4
Transmission Plant 5
Offshore (footnote details) 6
Onshore (footnote details) 7
General Plant (footnote details) 8
9
10
11
12
13
14
15
Page 338FERC FORM NO. 2 (12-96)
Particulars Concerning Certain Income Deductions and Interest Charges Accounts
Report the information specified below, in the order given, for the respective income deduction and interest charges accounts.
(a) Miscellaneous Amortization (Account 425)-Describe the nature of items included in this account, the contra account charged, the total of amortization charges for the year, and the
period of amortization.
(b) Miscellaneous Income Deductions-Report the nature, payee, and amount of other income deductions for the year as required by Accounts 426.1, Donations; 426.2, Life Insurance;
426.3, Penalties; 426.4, Expenditures for Certain Civic, Political and Related Activities; and 426.5, Other Deductions, of the Uniform System of Accounts. Amounts of less than $250,000
may be grouped by classes within the above accounts.
(c) Interest on Debt to Associated Companies (Account 430)-For each associated company that incurred interest on debt during the year, indicate the amount and interest rate
respectively for (a) advances on notes, (b) advances on open account, (c) notes payable, (d) accounts payable, and (e) other debt, and total interest. Explain the nature of other debt on
which interest was incurred during the year.
(d) Other Interest Expense (Account 431) - Report details including the amount and interest rate for other interest charges incurred during the year.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Item
(a)
Amount
(b)
Acct. 425.00 - MISCELLANEOUS AMORTIZATIONS 1
Items Under $250,000 ( 815,484) 2
Total - 425.00 ( 815,484) 3
Acct. 426.10 - DONATIONS 4
Items Under $250,000 2,999,603 5
Total 426.10 2,999,603 6
Acct. 426.20 - LIFE INSURANCE 7
Officers Life 156,937 8
SERP 2,470,559 9
Items Under $250,000 445,100 10
Total 426.20 3,072,596 11
Acct. 426.30 - PENALTIES 12
Items Under $250,000 ( 17,039) 13
Total 426.30 ( 17,039) 14
Acct. 426.40 - EXPENDITURES FOR CERTAIN CIVIC, POLITICAL, AND RELATED ACTIVITIES 15
Items Under $250,000 1,773,265 16
Total 426.40 1,773,265 17
Acct. 426.50 - OTHER DEDUCTIONS 18
Executive Deferred Compensation 992,325 19
Items Under $250,000 5,449,131 20
Total 426.50 6,441,456 21
Acct. 430.00 - INTEREST ON DEBT TO ASSOC. COMPANIES 22
Avista Capital II (long-term debt) (variable rate ranged from 1.29 to 1.81 perc) 712,864 23
Acct. 430.00 - INTEREST ON DEBT TO ASSOC. COMPANIES 186,289 24
Total 430.00 899,153 25
Acct. 431.00 - OTHER INTEREST EXPENSE 26
Interest on electric deferrals 1,923,857 27
Interest on natural gas deferrals 692,325 28
Interest on committed line of credit 4,163,663 29
Other ( 609,764) 30
Total 431.00 6,170,081 31
32
33
34
35
Page 340FERC FORM NO. 2 (12-96)
Regulatory Commission Expenses (Account 928)
1. Report below details of regulatory commission expenses incurred during the current year (or in previous years, if being amortized) relating to formal cases before a regulatory body, or
cases in which such a body was a party.
2. In column (b) and (c), indicate whether the expenses were assessed by a regulatory body or were otherwise incurred by the utility.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description
(Furnish name of regulatory commission
or body, the docket number, and a
description of the case.)
(a)
Total
Expenses
to Date
(d)
Assessed by
Regulatory
Commission
(b)
Expenses
of
Utility
(c)
Deferred in
Account 182.3
at Beginning
of Year
(e)
Federal Energy Regulatory Commission 1
Charges include annual fee and license fee 2
for the Spokane River Project, the Cabinet 3
2,663,404 34,224 2,629,180Gorge Project and Noxon Rapids Project 4
5
Washington Utilities and Transportation Commission 6
1,787,265 687,609 1,099,656Includes annual fee and various other electric dockets 7
8
448,741 153,301 295,440Includes annual fee and various other natural gas
dockets
9
10
Idaho Public Utilities Commission 11
844,840 160,523 684,318Includes annual fee and various other electric dockets 12
13
209,818 46,147 163,671Includes annual fee and various other natural gas
dockets
14
15
Public Utility Commission of Oregon 16
962,908 351,510 611,398Includes annual fee and various other dockets 17
18
725,551 725,551Not directly assigned electric 19
311,991 311,991Not directly assigned natural gas 20
21
22
23
24
7,954,518 2,470,856 5,483,663Total25
Page 350FERC FORM NO. 2 (12-96)
Regulatory Commission Expenses (Account 928)
3. Show in column (k) any expenses incurred in prior years that are being amortized. List in column (a) the period of amortization.
4. Identify separately all annual charge adjustments (ACA).
5. List in column (f), (g), and (h) expenses incurred during year which were charges currently to income, plant, or other accounts.
6. Minor items (less than $250,000) may be grouped.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Amortized
During Year
Contra
Account
(j)
Expenses
Incurred
During Year
Charged
Currently To
Amount
(h)
Expenses
Incurred
During Year
Deferred to
Account
182.3
(i)
Deferred in
Account 182.3
End of Year
(l)
Expenses
Incurred
During Year
Charged
Currently To
Department
(f)
Expenses
Incurred
During Year
Charged
Currently To
Account No.
(g)
Amortized
During Year
Amount
(k)
1
2
3
2,663,404928Electric 4
5
6
1,787,265928Electric 7
8
448,741928Gas 9
10
11
844,840928Electric 12
13
209,818928Gas 14
15
16
59,519 13,133407.4 72,367 962,908928Gas 17
18
725,551928Electric 19
311,991928Gas 20
21
22
23
24
59,519 13,133 72,367 7,954,51825
Page 351FERC FORM NO. 2 (12-96)
Employee Pensions and Benefits (Account 926)
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Line
No.
Expense
(a)
1. Report below the items contained in Account 926, Employee Pensions and Benefits.
Amount
(b)
19,959,280Pensions – defined benefit plans 1
Pensions – other 2
10,990,971Post-retirement benefits other than pensions (PBOP) 3
Post- employment benefit plans 4
680,219Other (Specify) 5
29,051,500Health insurance and Benefits 6
11,742,316401(K) Savings Plan 7
948,254Employee Education 8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
73,372,540Total
Page 352FERC FORM NO. 2 (NEW 12-07)
This Page Intentionally Left Blank
Distribution of Salaries and Wages
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals and
Other Accounts, and enter such amounts in the appropriate lines and columns provided. Salaries and wages billed to the Respondent by an affiliated company must be assigned to the
particular operating function(s) relating to the expenses.
In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used. When reporting
detail of other accounts, enter as many rows as necessary numbered sequentially starting with 75.01, 75.02, etc.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Classification
(a)
Total
(e)
Direct Payroll
Distribution
(b)
Allocation of
Payroll Charged
for Clearing
Accounts
(d)
Payroll Billed
by Affiliated
Companies
(c)
Electric 1
Operation 2
13,667,061 13,667,061 Production 3
4,359,748 4,359,748 Transmission 4
9,555,026 9,555,026 Distribution 5
6,615,674 6,615,674 Customer Accounts 6
473,347 473,347 Customer Service and Informational 7
Sales 8
27,189,564 27,189,564 Administrative and General 9
61,860,420 61,860,420 TOTAL Operation (Total of lines 3 thru 9) 10
Maintenance 11
4,612,103 4,612,103 Production 12
907,722 907,722 Transmission 13
5,236,480 5,236,480 Distribution 14
9,141,941 9,141,941 Administrative and General 15
10,756,305 9,141,941 19,898,246 TOTAL Maintenance (Total of lines 12 thru 15) 16
Total Operation and Maintenance 17
18,279,164 18,279,164 Production (Total of lines 3 and 12) 18
5,267,470 5,267,470 Transmission (Total of lines 4 and 13) 19
14,791,506 14,791,506 Distribution (Total of lines 5 and 14) 20
6,615,674 6,615,674 Customer Accounts (line 6) 21
473,347 473,347 Customer Service and Informational (line 7) 22
Sales (line 8) 23
27,189,564 9,141,941 36,331,505 Administrative and General (Total of lines 9 and 15) 24
72,616,725 9,141,941 81,758,666 TOTAL Operation and Maintenance (Total of lines 18 thru 24) 25
Gas 26
Operation 27
Production - Manufactured Gas 28
Production - Natural Gas(Including Exploration and Development) 29
1,104,381 1,104,381 Other Gas Supply 30
6,045 6,045 Storage, LNG Terminaling and Processing 31
Transmission 32
5,936,287 5,936,287 Distribution 33
2,930,182 2,930,182 Customer Accounts 34
294,694 294,694 Customer Service and Informational 35
Sales 36
11,457,871 3,204,941 14,662,812 Administrative and General 37
21,729,460 3,204,941 24,934,401 TOTAL Operation (Total of lines 28 thru 37) 38
Maintenance 39
Production - Manufactured Gas 40
Production - Natural Gas(Including Exploration and Development) 41
Other Gas Supply 42
Storage, LNG Terminaling and Processing 43
1,955,158 1,955,158 Transmission 44
3,487,785 3,487,785 Distribution 45
Page 354FERC FORM NO. 2 (REVISED)
Distribution of Salaries and Wages (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Classification
(a)
Total
(e)
Direct Payroll
Distribution
(b)
Allocation of
Payroll Charged
for Clearing
Accounts
(d)
Payroll Billed
by Affiliated
Companies
(c)
Administrative and General 46
5,442,943 5,442,943 TOTAL Maintenance (Total of lines 40 thru 46) 47
Gas (Continued) 48
Total Operation and Maintenance 49
Production - Manufactured Gas (Total of lines 28 and 40) 50
Production - Natural Gas (Including Expl. and Dev.)(ll. 29 and 41) 51
1,104,381 1,104,381 Other Gas Supply (Total of lines 30 and 42) 52
6,045 6,045 Storage, LNG Terminaling and Processing (Total of ll. 31 and 43) 53
1,955,158 1,955,158 Transmission (Total of lines 32 and 44) 54
9,424,072 9,424,072 Distribution (Total of lines 33 and 45) 55
2,930,182 2,930,182 Customer Accounts (Total of line 34) 56
294,694 294,694 Customer Service and Informational (Total of line 35) 57
Sales (Total of line 36) 58
11,457,871 3,204,941 14,662,812 Administrative and General (Total of lines 37 and 46) 59
27,172,403 3,204,941 30,377,344Total Operation and Maintenance (Total of lines 50 thru 59) 60
Other Utility Departments 61
Operation and Maintenance 62
99,789,128 12,346,882 112,136,010 TOTAL ALL Utility Dept. (Total of lines 25, 60, and 62) 63
Utility Plant 64
Construction (By Utility Departments) 65
44,889,619 6,589,540 51,479,159 Electric Plant 66
11,755,963 2,383,819 14,139,782 Gas Plant 67
Other 68
56,645,582 8,973,359 65,618,941 TOTAL Construction (Total of lines 66 thru 68) 69
Plant Removal (By Utility Departments) 70
1,830,775 166,241 1,997,016 Electric Plant 71
610,391 55,425 665,816 Gas Plant 72
Other 73
2,441,166 221,666 2,662,832 TOTAL Plant Removal (Total of lines 71 thru 73) 74
44,042,013 ( 21,541,907) 22,500,106Other Accounts (Specify) (footnote details) 75
44,042,013 ( 21,541,907) 22,500,106TOTAL Other Accounts 76
202,917,889 202,917,889TOTAL SALARIES AND WAGES 77
Page 355FERC FORM NO. 2 (REVISED)
Charges for Outside Professional and Other Consultative Services
1. Report the information specified below for all charges made during the year included in any account (including plant accounts) for outside consultative and other professional services.
These services include rate, management, construction, engineering, research, financial, valuation, legal, accounting, purchasing, advertising,labor relations, and public relations, rendered
for the respondent under written or oral arrangement, for which aggregate payments were made during the year to any corporation partnership, organization of any kind, or individual (other
than for services as an employee or for payments made for medical and related services) amounting to more than $250,000, including payments for legislative services, except those
which should be reported in Account 426.4 Expenditures for Certain Civic, Political and Related Activities.
(a) Name of person or organization rendering services.
(b) Total charges for the year.
2. Sum under a description “Other”, all of the aforementioned services amounting to $250,000 or less.
3. Total under a description “Total”, the total of all of the aforementioned services.
4. Charges for outside professional and other consultative services provided by associated (affiliated) companies should be excluded from this schedule and be reported on Page 358,
according to the instructions for that schedule.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description
(a)
Amount
(in dollars)
(b)
25,552,618NPL CONSTRUCTION CO 1
14,280,899VOLT MANAGEMENT CORP 2
13,697,180INTERNATIONAL LINE BUILDERS INC 3
11,900,139INFRASOURCE SERVICES LLC 4
10,046,779WILSON CONSTRUCTION COMPANY 5
9,701,389WELLINGTON ENERGY INC 6
8,945,630ASPLUNDH TREE EXPERT LLC 7
7,126,801SLAYDEN CONSTRUCTORS INC 8
6,128,125MICHELS POWER 9
4,849,220POTELCO INC 10
3,627,190BOUTEN CONSTRUCTION COMPANY 11
3,561,027ONE CALL LOCATORS LTD 12
3,031,888IBM CORPORATION 13
2,698,704SIEMENS ENERGY INC 14
2,641,753STURGEON ELECTRIC INC 15
2,347,507MCMILLEN JACOBS ASSOCIATES 16
2,290,243PERFECTION TRAFFIC CONTROL LLC 17
2,271,560NAGARRO INC 18
2,130,985HEATH CONSULTANTS INCORPORATED 19
2,090,379CASCADE CABLE CONSTRUCTORS INC 20
1,897,850INTELLITECT 21
1,834,656WSP USA INC 22
1,824,648TRAFFICORP 23
1,793,061COMMERCIAL GRADING INC 24
1,729,110ITRON INC 25
1,709,000DELOITTE 26
1,704,296UTILITY SOLUTIONS PARTNERS LLC 27
1,689,111STANTEC CONSULTING SERVICES INC 28
1,609,819FUJITSU AMERICAN INC 29
1,580,170PER SE GROUP INC 30
1,391,366NBC TRAFFIC CONTROL 31
1,366,636SUNRISE ENGINEERING INC 32
1,346,063AAA SWEEPING LLC 33
1,345,671BRENT WOODWARD INC 34
1,326,118MCKINSTRY ESSENTION LLC 35
Page 357FERC FORM NO. 2 (REVISED)
Charges for Outside Professional and Other Consultative Services (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description
(a)
Amount
(in dollars)
(b)
1,239,874CERIUM NETWORKS 1
1,222,479RESSA & SON CONSTRUCTION LLC 2
1,219,324COMMONWEALTH ASSOCIATES INC 3
1,214,182NUVODIA STAFFING LLC 4
1,191,558CURRY INC 5
1,160,050PROFESSIONAL PIPE SERVICES 6
1,147,030UTILICAST LLC 7
1,114,541HDR ENGINEERING INC 8
1,095,068COGNIZANT WORLDWIDE LIMITED 9
1,091,818PRYSMIAN CABLES AND SYSTEMS USA LLC 10
1,066,746CN UTILITY CONSULTING INC 11
1,000,447HELVETICKA INC 12
987,966GREENBERRY INDUSTRIAL LLC 13
985,722POWER ENGINEERS INC 14
777,250SCHWEITZER ENGINEERING LAB INC 15
760,138PRICEWATERHOUSE COOPERS LLP 16
755,896POWER SYSTEMS CONSULTANTS INC 17
739,061POE ASPHALT PAVING INC 18
731,655GARCO CONSTRUCTION INC 19
691,892BLACK & VEATCH CORPORATION 20
676,167DXC TECHNOLOGY SERVICES LLC 21
662,942ALDEN RESEARCH LABORATORY INC 22
640,110NOBLE EXCAVATING INC 23
620,897TRAFFIC CONTROL SERVICES LLC 24
619,037COEUR D ALENE TRIBE 25
594,720D W POLEHOLE 26
577,265CIRRUS DESIGN INDUSTRIES INC 27
544,674SPOKANE TRAFFIC CONTROL INC 28
535,182POWER CITY ELECTRIC INC 29
531,330HANNA & ASSOCIATES INC 30
528,360ASSOCIATED CONSTRUCTION INC 31
526,253TEK SYSTEMS INC 32
522,885NUVODIA LLC 33
519,711ELM FIELDSIGHT LLC 34
518,399ALDRIDGE ELECTRIC INC 35
Page 357.1FERC FORM NO. 2 (REVISED)
Charges for Outside Professional and Other Consultative Services (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description
(a)
Amount
(in dollars)
(b)
506,964UTILITY CONSTRUCTION INSPECTION LLC 1
491,063CRUX SUBSURFACE INC 2
476,645WALKER CONSTRUCTION INC 3
472,154OXFORD GLOBAL RESOURCES LLC 4
456,956TECHNIBUS INC 5
455,787JENSENS TREE SERVICE INC 6
436,427INTEC SERVICES INC 7
434,952PRICEWATERHOUSE COOPERS ADVISORY SERVICES LLC 8
431,475ABREMOD LLC 9
420,514FIRST AMERICAN TITLE 10
413,892UTILITY GUYS INC 11
404,856PRO BUILDING SYSTEMS INC 12
386,811GINNO CONSTRUCTION CO 13
382,150H2E INC 14
371,933BOYER LAND DEVELOPMENT INC 15
370,118HICKEY BROTHERS RESEARCH LLC 16
364,776GEODIGITAL INTERNATIONAL CORP 17
349,009THYSSENKRUPP ELEVATOR CORPORATION 18
343,181ALITEK SOLUTIONS LP 19
340,438IDAHO DEPT OF FISH & GAME 20
327,812TRC SOLUTIONS INC 21
323,312SOUTHERN CROSS CORP 22
321,396NOVTECH 23
318,788DELOITTE TAX LLP 24
308,292ELECTRICAL CONSULTANTS INC 25
299,915AVCO CONSULTING INC 26
287,510PIONEER WATERPROOFING COMPANY INC 27
287,000ERNST & YOUNG US LLP 28
286,408PERFORMANCE INDUSTRIAL COMPANY LLC 29
285,816LANDAU ASSOCIATES 30
285,492HATTENBURG EXCAVATING 31
276,648KNIGHT CONSTRUCTION & SUPPLY INC 32
273,306NORTHWEST POWER POOL 33
269,317COFFMAN ENGINEERS 34
258,089RANDALL DANSKIN ATTORNEYS 35
Page 357.2FERC FORM NO. 2 (REVISED)
Charges for Outside Professional and Other Consultative Services (continued)
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description
(a)
Amount
(in dollars)
(b)
254,191TAILORED SOLUTIONS LLC 1
250,600SINISI SOLUTIONS LLC 2
205,102,213 SUBTOTAL 3
36,282,759OTHER 4
241,384,972 TOTAL 5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
Page 357.3FERC FORM NO. 2 (REVISED)
Transactions with Associated (Affiliated) Companies
1. Report below the information called for concerning all goods or services received from or provided to associated (affiliated) companies amounting to more than $250,000.
2. Sum under a description “Other”, all of the aforementioned goods and services amounting to $250,000 or less.
3. Total under a description “Total”, the total of all of the aforementioned goods and services.
4. Where amounts billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote the basis of the allocation.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Description of the Good or Service
(a)
Amount
Charged or
Credited
(d)
Name of Associated/Affiliated Company
(b)
Account(s)
Charged or
Credited
(c)
Goods or Services Provided by Affiliated Company 1
931000 155,496Steam Plant SquareOther 2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
Goods or Services Provided for Affiliated Company 20
146000 243,657SalixCorporate Support 21
146000 157,414Avista DevelopmentOther 22
146000 75,581Avista CapitalOther 23
146000 23,967AELPOther 24
146000 2,753AJT MiningOther 25
146000 155,000Steam Plant SquareOther 26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
Page 358FERC FORM NO. 2 (NEW 12-07)
Gas Storage Projects
1. Report injections and withdrawals of gas for all storage projects used by respondent.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Item
(a)
Total
Amount
(Dth)
(d)
Gas
Belonging to
Respondent
(Dth)
(b)
Gas
Belonging to
Others
(Dth)
(c)
STORAGE OPERATIONS (in Dth)
Gas Delivered to Storage 1
147,388 147,388January 2
88,036 88,036February 3
5,000 5,000March 4
1,368,531 1,368,531April 5
2,944,101 2,944,101May 6
3,093,070 3,093,070June 7
182,447 182,447July 8
15,348 15,348August 9
38,956 38,956September 10
158,433 158,433October 11
138,135 138,135November 12
44,808 44,808December 13
8,224,253 8,224,253TOTAL (Total of lines 2 thru 13) 14
Gas Withdrawn from Storage 15
2,347,660 2,347,660January 16
2,432,555 2,432,555February 17
1,062,969 1,062,969March 18
375,853 375,853April 19
1,439 1,439May 20
2,110 2,110June 21
10,754 10,754July 22
11,313 11,313August 23
51,548 51,548September 24
638,943 638,943October 25
1,105,649 1,105,649November 26
1,336,110 1,336,110December 27
9,376,903 9,376,903TOTAL (Total of lines 16 thru 27) 28
Page 512_FERC FORM NO. 2 (12-96)
Gas Storage Projects
1. On line 4, enter the total storage capacity certificated by FERC.
2. Report total amount in Dth or other unit, as applicable on lines 2, 3, 4, 7. If quantity is converted from Mcf to Dth, provide conversion factor in a footnote.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X
04/15/2021 2020/Q4
Item
(a)
Total Amount
(b)
STORAGE OPERATIONS
8,528,000Top or Working Gas End of Year 1
7,730,668Cushion Gas (Including Native Gas) 2
16,258,668Total Gas in Reservoir (Total of line 1 and 2) 3
16,258,668Certificated Storage Capacity 4
50Number of Injection - Withdrawal Wells 5
32Number of Observation Wells 6
120,598Maximum Days' Withdrawal from Storage 7
02/04/2020Date of Maximum Days' Withdrawal 8
LNG Terminal Companies (in Dth) 9
Number of Tanks 10
Capacity of Tanks 11
LNG Volume 12
Received at "Ship Rail" 13
Transferred to Tanks 14
Withdrawn from Tanks 15
"Boil Off" Vaporization Loss 16
Page 513_FERC FORM NO. 2 (12-96)
Schedule Page: 513 Line No.: 7 Column: b
Mcf converted to Dth using a factor of 1.0400
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1
Auxiliary Peaking Facilities
1. Report below auxiliary facilities of the respondent for meeting seasonal peak demands on the respondent's system, such as underground storage projects, liquefied petroleum gas
installations, gas liquefaction plants, oil gas sets, etc.
2. For column (c), for underground storage projects, report the delivery capacity on February 1 of the heating season overlapping the year-end for which this report is submitted.
For other facilities, report the rated maximum daily delivery capacities.
3. For column (d), include or exclude (as appropriate) the cost of any plant used jointly with another facility on the basis of predominant use, unless the auxiliary peaking facility is a
separate plant as contemplated by general instruction 12 of the Uniform System of Accounts.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Location of
Facility
(a)
Was Facility
Operated on Day
of Highest
Transmission Peak
Delivery?
Maximum Daily
Delivery Capacity
of Facility
Dth
(c)
Cost of
Facility
(in dollars)
(d)
Type of
Facility
(b)
46,368,949 346,667Underground Natural GasChehalis, Washington 1 Yes
Storage Field 2
Washington & Idaho Supply 3
6,813,975 52,000Underground Natural GasChehalis, Washington 4 Yes
Storage Field 5
Oregon Supply 6
2,623Underground Natural GasChehalis, Washington 7 Yes
Storage Field 8
Oregon Supply 9
Underground Natural GasRock Springs, Wyoming 10 Yes
Storage Field 11
Washington & Idaho Supply 12
Underground Natural GasRock Springs, Wyoming 13 Yes
Storage Field 14
Oregon Supply 15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
Page 519FERC FORM NO. 2 (12-96)
Schedule Page: 519 Line No.: 7 Column: a
Avista is a participant in the facilities, not an owner and is charged a fee for demand deliverability and capacity.
Schedule Page: 519 Line No.: 10 Column: a
Avista does not have firm rights but have interruptible access to it.
Schedule Page: 519 Line No.: 13 Column: a
Avista does not have firm rights but have interruptible access to it.
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2)A Resubmission
Date of Report
(Mo, Da, Yr)
04/15/2021
Year/Period of Report
2020/Q4
FOOTNOTE DATA
FERC FORM NO. 2 (12-96)Page 552.1
Gas Account - Natural Gas
1. The purpose of this schedule is to account for the quantity of natural gas received and delivered by the respondent.
2. Natural gas means either natural gas unmixed or any mixture of natural and manufactured gas.
3. Enter in column (c) the year to date Dth as reported in the schedules indicated for the items of receipts and deliveries.
4. Enter in column (d) the respective quarter’s Dth as reported in the schedules indicated for the items of receipts and deliveries.
5. Indicate in a footnote the quantities of bundled sales and transportation gas and specify the line on which such quantities are listed.
6. If the respondent operates two or more systems which are not interconnected, submit separate pages for this purpose.
7. Indicate by footnote the quantities of gas not subject to Commission regulation which did not incur FERC regulatory costs by showing (1) the local distribution volumes another jurisdictional pipeline delivered to
the local distribution company portion of the reporting pipeline (2) the quantities that the reporting pipeline transported or sold through its local distribution facilities or intrastate facilities and which the reporting
pipeline received through gathering facilities or intrastate facilities, but not through any of the interstate portion of the reporting pipeline, and (3) the gathering line quantities that were not destined for interstate
market or that were not transported through any interstate portion of the reporting pipeline.
8. Indicate in a footnote the specific gas purchase expense account(s) and related to which the aggregate volumes reported on line No. 3 relate.
9. Indicate in a footnote (1) the system supply quantities of gas that are stored by the reporting pipeline, during the reporting year and also reported as sales,transportation and compression volumes by the reporting
pipeline during the same reporting year, (2) the system supply quantities of gas that are stored by the reporting pipeline during the reporting year which the reporting pipeline intends to sell or transport in a future
reporting year, and (3) contract storage quantities.
10. Also indicate the volumes of pipeline production field sales that are included in both the company's total sales figure and the company's total transportation figure. Add additional information as necessary to the
footnotes.
Line
No.
Name of Respondent This Report Is:
(1) An Original
(2) A Resubmission
Date of Report(Mo, Da, Yr)Year/Period of Report
End ofAvista Corporation X 04/15/2021 2020/Q4
Item
(a)
Current Three Months
Ended Amount of Dth
Quarterly Only
(d)
Ref. Page No. of
(FERC Form Nos.
2/2-A)
(b)
Total Amount
of Dth
Year to Date
(c)
01 Name of System:
GAS RECEIVED 2
23,987,084 92,472,757Gas Purchases (Accounts 800-805) 3
303Gas of Others Received for Gathering (Account 489.1) 4
305Gas of Others Received for Transmission (Account 489.2) 5
5,182,568301 18,573,063Gas of Others Received for Distribution (Account 489.3) 6
307Gas of Others Received for Contract Storage (Account 489.4) 7
Gas of Others Received for Production/Extraction/Processing (Account 490 and 491) 8
328Exchanged Gas Received from Others (Account 806) 9
4,282328 42,537Gas Received as Imbalances (Account 806) 10
332Receipts of Respondent's Gas Transported by Others (Account 858) 11
2,750,963 1,226,823Other Gas Withdrawn from Storage (Explain) 12
Gas Received from Shippers as Compressor Station Fuel 13
Gas Received from Shippers as Lost and Unaccounted for 14
Other Receipts (Specify) (footnote details) 15
31,924,897 112,315,180Total Receipts (Total of lines 3 thru 15) 16
GAS DELIVERED 17
26,022,150 91,796,199Gas Sales (Accounts 480-484) 18
303Deliveries of Gas Gathered for Others (Account 489.1) 19
305Deliveries of Gas Transported for Others (Account 489.2) 20
4,962,923301 18,036,092Deliveries of Gas Distributed for Others (Account 489.3) 21
307Deliveries of Contract Storage Gas (Account 489.4) 22
Gas of Others Delivered for Production/Extraction/Processing (Account 490 and 491) 23
328Exchange Gas Delivered to Others (Account 806) 24
328Gas Delivered as Imbalances (Account 806) 25
332Deliveries of Gas to Others for Transportation (Account 858) 26
Other Gas Delivered to Storage (Explain) 27
939,824509 2,482,889Gas Used for Compressor Station Fuel 28
Other Deliveries and Gas Used for Other Operations 29
31,924,897 112,315,180Total Deliveries (Total of lines 18 thru 29) 30
GAS LOSSES AND GAS UNACCOUNTED FOR 31
Gas Losses and Gas Unaccounted For 32
TOTALS 33
31,924,897 112,315,180Total Deliveries, Gas Losses & Unaccounted For (Total of lines 30 and 32) 34
Page 520FERC FORM NO. 2 (REV 01-11)

Avista Corp.

2020

IDAHO

State Natural Gas Annual Report

(IC 61-405)

This Page Intentionally Left Blank
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line Refer to
No.Form 2
Page
(b)
1 UTILITY OPERATING INCOME
2 Operating Revenues (400)300-301
3 Operating Expenses
4 Operation Expenses (401)317-325
5 Maintenance Expenses (402)317-325
6 Depreciation Expense (403)336-338
7 Depreciation Expense for Asset Retirement Costs (403.1)336-338
8 Amortization & Depletion of Utility Plant (404-405)336-338
9 Amortization of Utility Plant Acquisition Adjustment (406)336-338
10 Amort. of Property Losses, Unrecov Plant and Regulatory Study Costs (407)
11 Amortization of Conversion Expenses (407)
12 Regulatory Debits (407.3)
13 (Less) Regulatory Credits (407.4)
14 Taxes Other Than Income Taxes (408.1)262-263
15 Income Taxes - Federal (409.1)262-263
16 - Other (409.1)262-263
17 Provision for Deferred Income Taxes (410.1)234-235
18 (Less) Provision for Deferred Income Taxes-Cr. (411.1)234-235
19 Investment Tax Credit Adjustment - Net (411.4)
20 (Less) Gains from Disposition of Utility Plant (411.6)
21 Losses from Disposition Of Utility Plant (411.7)
22 (Less) Gains from Disposition of Allowances (411.8)
23 Losses from Disposition of Allowances (411.9)
24 Accretion Expense (411.10)
25 TOTAL Utility Operating Expenses (Total of line 4 through 24)
26 Net Utility Operating Income (Total line 2 less 25)75,423,724
-
-
335,243,213
-
6,046,073
-
(170,725)
-
-
2,803,455
(8,396,725)
18,930,820
4,413,421
2020 / Q4
For each account below, report the amount attributable to the state of Idaho based on Idaho jurisdictional Results of Operations.
04/15/2021
Provide any necessary important notes regarding this statement of utility operating income in a footnote in the available space at the bottom of this
(a)(c)(d)
Current Year Prior Year
TOTAL SYSTEM - IDAHO
Account
STATEMENT OF UTILITY OPERATING INCOME - IDAHO
327,882,920
73,591,907
-
(168,096)
-
-
-
(12,771,604)
21,042,881
1,579,230
-
6,241,945
11,408,775
67,304
-
-
3,230,497
-
50,071,177
-
-
9,690,048
(333,312)
-
410,666,937
229,746,234
22,442,747
-
-
401,474,827
222,680,326
22,558,272
52,013,390
-
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.114-115
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
3.
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
77,526,728
14,282,301
2,428,152
-
(4,152)
-
-
-
-
-
-
-
-
-
-
805,479
(443,802)
3,416,549
(823,687) (362,781)
88,318,789
55,714,297
2,876,871
7,947,311
393,735
(222,432)
3,034,377
91,809,029
59,380,194
3,469,855
7,644,228
2,048,489
-
1,765,552
-
-
-
61,141,423
3,617,921
-
(166,573)
-
-
14,279,898
2,498,422
(1,038)
74,038,891
-
7,924,496
(333,312)
-
-
-
-
-
257,716,485 253,844,029
2,409,720
(8,174,293)
15,896,443
4,776,202
-
59,312,009
3,743,523
(167,058)
313,156,038
166,966,029
19,681,401
44,066,079
9,360,286
67,304
2,425,018
(12,327,802)
17,626,332
2,402,917
2020 / Q4
STATEMENT OF UTILITY OPERATING INCOME - IDAHO
page or in a separate schedule.
04/15/2021
GAS UTILITY
Current Year Prior Year
Explain in a footnote if the previous year's figures are different from those reported in prior reports.
(f)(e)
Prior YearCurrent Year
318,857,908
170,366,040
18,972,892
42,426,949
ELECTRIC UTILITY
(g)(h)
OTHER UTILITY
Current Year Prior Year
(i)(j)
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.114-115
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
1 Utility Plant
2 In Service
3 Plant in Service (Classified)
4 Property Under Capital Leases
5 Plant Purchased or Sold
6 Completed Construction not Classified
7 Experimental Plant Unclassified
8 Total (Total lines 3 through 7)
9 Leased to Others
10 Held for Future Use
11 Construction Work in Progress
12 Acquisition Adjustments
13 Total Utility Plant (Total lines 8 through 12)
14 Accumulated Provision for Depreciation, Amortization, and Depletion
15 Net Utility Plant (Line 13 less line 14)
16 Detail of Accumulated Provision for Depreciation, Amortization, and Depletion
17 In Service
18 Depreciation
19 Amortization and Depletion of Producing Natural Gas Lands / Land Rights
20 Amortization of Underground Storage Lands / Land Rights
21 Amortization of Other Utility Plant
22 Total (Total lines 18 through 21)
23 Leased to Others
24 Depreciation
25 Amortization and Depletion
26 Total Leased to Others
27 Held for Future Use
28 Depreciation
29 Amortization
30 Total Held for Future Use
31 Abandonment of Leases (Natural Gas)
32 Amortization of Plant Acquisition Adjustment
33 Total Accumulated Provision (Total lines 22, 26, 30, 31, 32)
2020 / Q4
04/15/2021
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION - IDAHO
Report in column (c) the amount for electric function, in column (d) the amount for gas function, in columns (e), (f), and (g) report other (specify),
accumulated provisions for depreciation, amortization, and depletion attributable to that plant in service.
Report below the original cost of utility plant in service necessary to furnish utility service to customers in the state of Idaho, and the
Total Company
2,013,413,723 1,530,217,343
(a)(b)(c)
Account End of Current Year Electric
24,173,936 -
-
-
-
-
2,037,587,659 1,530,217,343
55,129,303 49,431,352
1,614,766 1,424,181
2,094,331,728 1,581,072,876
- -
1,345,586,408 998,512,772
748,745,320 582,560,104
-
706,169,782 574,330,139
42,575,538 8,229,965
-
748,745,320 582,560,104
-
-
- -
-
-
-
- -
748,745,320 582,560,104
-
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.200-201
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
3.
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
2020 / Q4
04/15/2021
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION - IDAHO
plant not directly assigned is allocated to the state of Idaho as appropriate and included in column (c) and (d).
In order to accurately reflect utility plant in service necessary to furnish utility service to customers in the state of Idaho, electric and gas
and in column (h) common function.
Other (Specify)Common
(d)(e)(f)(g)(h)
Gas Other (Specify)Other (Specify)
294,219,534 188,976,846
- 24,173,936
213,150,782 294,219,534 - - -
683,990 5,013,961
190,585
295,094,109 - - - 218,164,743
66,501,468
195,410,361 - - - 151,663,275
99,683,748 - - -
32,301,956 99,537,687
146,061 34,199,512
66,501,468 99,683,748 - - -
- - - - -
- - - - -
99,683,748 - - - 66,501,468
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.200-201
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
3.
4.
5.
6.
Line
No.
1 INTANGIBLE PLANT
2 301 Organization
3 302 Franchises and Consents
4 303 Miscellaneous Intangible Plant
5 TOTAL Intangible Plant (Total of lines 2, 3, and 4)
6 PRODUCTION PLANT
7 Natural Gas Production and Gatherin Plant
8 325.1 Producing Lands
9 325.2 Producing Leaseholds
10 325.3 Gas Rights
11 325.4 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 Equipment
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
24 337 Other Equipment
25 338 Unsuccessful Exploration and Development Costs
26 339 Asset Retirement Costs for Natural Gas Production and Gathering Plant
27 TOTAL Natural Gas Production and Gathering Plant (Total of lines 8 through 26)
28 Products Extraction Plant
29 340 Land and Land Rights
30 341 Structures and Improvements
31 342 Extraction and Refining Equipment
32 343 Pipe Lines
33 344 Extracted Products Storage Equipment - -
- -
- -
- -
- -
- -
retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements,
on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of
Balance
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
880,066 19,115
880,066 19,115
- -
- -
(a)(b)(c)
Account Beginning of Year Additions
Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such amounts.
Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included
in column (c) are entries for reversals of tentative distributions of prior year in column (b). Likewise, if the respondent has a significant amount of plant
Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year.
For revisions to the amount of initial asset retirement costs capitalized, include by primary plant account increases in column (c), additions, and
reductions in column (e), adjustments.
Report below the original cost of gas plant in service necessary to furnish natural gas utility service to customers in the state of Idaho.
In addition to Account 101, Gas Plant in Service (Classified), this page and the next include Account 102, Gas Plant Purchased or Sold; Account
103, Experimental Gas Plant Unclassified; and Account 106, Completed Construction Not Classified-Gas.
2020 / Q4
04/15/2021
GAS PLANT IN SERVICE - IDAHO (Account 101, 102, 103 and 106)
Include gas plant not directly assigned as allocated to the state of Idaho.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.204-205
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
7.
8.
9.
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
844,166
844,166
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
(27,095)
(27,095)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Balance
(g)
- -
-
-
-
Adjustments
(e)
-
27,920
27,920
date of transaction. If proposed journal entries have been filed as required by the Uniform System of Accounts, give also the date of such filing.
Retirements
(d)
-
-
-
Transfers
(f)
End of Year
these tentative classifications in columns (c) and (d), including the reversals of the prior year's tentative account distributions of these amounts. Careful
Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account
classifications arising from distribution of amounts initially recorded in Account 102; include in column (e) the amounts with respect to accumulated
provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary
account classifications.
For Account 399, state the nature and use of plant included in this account, and, if substantial in amount, submit a supplementary statement showing
subaccount classification of such plant conforming to the requirement of these pages.
For each account comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and
2020 / Q4
04/15/2021
GAS PLANT IN SERVICE - IDAHO (Account 101, 102, 103 and 106)
observance of these instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent's plant
actually in service at end of year.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.204-205
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Line
No.
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 through 37)
39 TOTAL Natural Gas Production Plant (Total lines 27 and 38)
40 Manufactured Gas Production Plant (Submit Supplementary Schedule)
41 TOTAL Production Plant (Total lines 39 and 40)
42 NATURAL GAS STORAGE AND PROCESSING PLANT
43 Underground Storage Plant
44 350.1 Land
45 350.2 Rights-of-Way
46 351 Structures and Improvements
47 352 Wells
48 352.1 Storage Leaseholds and Rights
49 352.2 Reservoirs
50 352.3 Non-recoverable Natural Gas
51 353 Lines
52 354 Compressor Station Equipment
53 355 Other Equipment
54 356 Purification Equipment
55 357 Other Equipment
56 358 Asset Retirement Costs for Underground Storage Plant
57 TOTAL Underground Storage Plant
58 Other Storage Plant
59 360 Land and Land Rights
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
66 363.4 Measuring and Regulating 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 through 68)
70 Base Load Liquefied Natural Gas Terminaling 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
80
TOTAL Base Load Liquefied Natural Gas Terminaling and Processing Plant (Total lines 71
through 79)- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
13,823,501 -
- -
539,389 -
170,739 -
221,924 -
4,416,030 -
645,122 -
- -
- -
- -
6,961,339 -
496,103 -
20,694 -
352,161 -
- -
- -
- -
- -
- -
- -
- -
(a)(b)(c)
Account Beginning of Year Additions
- -
Balance
2020 / Q4
04/15/2021
GAS PLANT IN SERVICE - IDAHO (Account 101, 102, 103 and 106) (Continued)
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.206-207
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Line
No.
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
- -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - 605,614 14,429,115
- - - -
- 130,700 670,089
- (709) 170,030
- 132,016 353,940
- 114,608 4,530,638
- (2,678) 642,444
- - -
- - -
- - -
- 104,043 7,065,382
- 130,874 626,977
- (86) 20,608
- (3,154) 349,007
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
End of Year
(d)(e)(f)(g)
Retirements Adjustments Transfers
- -
Balance
2020 / Q4
04/15/2021
GAS PLANT IN SERVICE - IDAHO (Account 101, 102, 103 and 106) (Continued)
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.206-207
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Line
No.
81 TOTAL Natural Gas Storage and Processing Plant (Total of lines 57, 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
90 371 Other Equipment
91 372 Asset Retirement Costs for Transmission Plant
92 TOTAL Transmission Plant (Total lines 83 through 91)
93 DISTRIBUTION PLANT
94 374 Land and Land Rights
95 375 Structures and Improvements
96 376 Mains
97 377 Compressor Station Equipment
98 378 Measuring and Regulating Station Equipment-General
99 379 Measuring and Regulating Station Equipment-City Gate
100 380 Services
101 381 Meters
102 382 Meter Installations
103 383 House Regulators
104 384 House Regulator Installations
105 385 Industrial Measuring and Regulating Station Equipment
106 386 Other Propert on Customers' Premises
107 387 Other Equipment
108 388 Asset Retirement Costs for Distribution Plant
109 TOTAL Distribution Plant (Total lines 94 through 108)
110 GENERAL PLANT
111 389 Land and Land Rights
112 390 Structures and Improvements
113 391 Office Furniture and Equipment
114 392 Transportation Equipment
115 393 Stores Equipment
116 394 Tools, Shop, and Garage Equipment
117 395 Laboratory Equipment
118 396 Power Operated Equipment
119 397 Communication Equipment
120 398 Miscellaneous Equipment
121 Subtotal (Total of Lines 111 through 120)
122 399 Other Tangible Property
123 399.1 Asset Retirement Costs for General Plant
124 TOTAL General Plant (Total of lines 121, 122 and 123)
125 TOTAL (Accounts 101 and 106)
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 lines 125 through 128)278,899,922 15,504,474
-
-
-
278,899,922 15,504,474
6,127,572 548,528
-
-
6,127,572 548,528
- -
383,854 112,566
1,072,583 -
65,250 -
1,409,874 66,326
- -
3,149,323 350,184
46,688 19,452
- -
- -
258,068,783 14,936,831
- -
- -
- -
946,404 31,996
- -
- -
- -
30,529,495 845,320
88,085,453 5,748,864
4,463,164 8,042
2,522,953 (44,466)
- -
130,767,519 8,287,512
591,658 59,563
162,137 -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
13,823,501 -
2020 / Q4
04/15/2021
GAS PLANT IN SERVICE - IDAHO (Account 101, 102, 103 and 106) (Continued)
(a)(b)(c)
Balance
Account Beginning of Year Additions
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.208-209
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Line
No.
81
82
83
84
85
86
87
88
89
90
91
92
93
94
95
96
97
98
99
100
101
102
103
104
105
106
107
108
109
110
111
112
113
114
115
116
117
118
119
120
121
122
123
124
125
126
127
128
129867,327 - 682,465 294,219,534
-
-
-
867,327 - 682,465 294,219,534
59,049 - 79,266 6,696,317
-
-
59,049 - 79,266 6,696,317
- - - -
642 (45,624) 450,154
- 49,312 1,121,895
- (1,180) 64,070
34,403 6,976 1,448,773
- - -
24,004 76,371 3,551,874
(6,589) 59,551
- - - -
- - - -
780,358 - 24,680 272,249,936
- -
- - - -
- - - -
- (825) 977,575
- - -
- - -
- - -
399,121 - 30,975,694
65,611 - 93,768,706
7,765 - 4,463,441
- 333 2,478,820
- - -
300,596 25,173 138,779,608
7,265 (1) 643,955
- - - 162,137
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - - -
- - 605,614 14,429,115
2020 / Q4
04/15/2021
GAS PLANT IN SERVICE - IDAHO (Account 101, 102, 103 and 106) (Continued)
(d)(e)(f)
Balance
Retirements Adjustments Transfers End of Year
(g)
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.208-209

This Page Intentionally Left Blank
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
3.
Line (Account Total
No.117.1)
(b)(i)
1 1,794,969 5,732,035
2 - 3,906,519
3 - 5,007,616
4 - -
5 1,794,969 4,630,938
6 321,679 2,062,770
7 5.58 2.25
(1) Fuel is accounted for within injections and withdrawal accounts.
(2) All gas reported is current working gas. Avista uses the inventory method to report all working gas stored.
3,937,066
3,906,519
5,007,616
-
2,835,969
1,741,091
1.63
(f)(h)
- -
(a)
117.4)
(e)
- -
Description (Account
117.2)
164.2)164.1)
Amount per Dth
Dth
Balance at end of year
Other debits and credits
Gas withdrawn from storage
-
Gas delivered to storage
Balance at beginning of year
(c)(d)(g)
(Account
Noncurrent
(Account
117.3)
LNG(Account
164.3)
(Account
LNG
(Account
Current
State in a footnote, in the available space at the bottom of this page or in a separate schedule, the basis of segregation of inventory between current
and noncurrent portions. Also, state in a footnote the method used to report storage (i.e., fixed asset method or inventory method).
If during the year adjustments were made to the stored gas inventory reported in columns (d), (f), (g), and (h) (such as to correct cumulative
inaccuracies of gas measurements), explain in a footnote (in the available space at the bottom of this page or in a separate schedule) the reason for
the adjustments, the Dth and dollar amount of adjustment, and account charged or credited.
2020 / Q4
04/15/2021
GAS STORED - IDAHO (Accounts 117.1, 117.2, 117.3, 164.1, 164.2, and 164.3)
Report in column (e) all encroachments during the year upon the volumes designated as base gas, column (b), and system balancing gas, column (c),
and gas property recordable in the plant accounts.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.220
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
3.
Line
No.
1 480 Residential Sales
2 481 Commercial and Industrial Sales
3 482 Other Sales to Public Authorities
4 483 Sales for Resale (1)
5 484 Interdepartmental Sales
6 485 Intracompany Transfers
7 487 Forfeited Discounts
8 488 Miscellaneous Service Revenues
9
10
11
12 489.4 Revenues from Storing Gas of Others
13 490 Sales of Products Extracted from Natural Gas
14 491 Revenues from Natural Gas Processed by Others
15 492 Incidental Gasoline and Oil Sales
16 493 Rent from Gas Property
17 494 Interdepartmental Rents
18 495 Other Gas Revenues (1)
19 Subtotal
20 496 (Less) Provision for Rate Refunds
21 TOTAL
-
-
-
-
- -
- - - -
- -
- - - -
- - - -
-
- -
- -
- -
- -
-
-
-
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
489.1 Revenues from Transportation of Gas for Others
through Gathering Facilities
489.2 Revenues from Transportation of Gas for Others
through Transmission Facilities
489.3 Revenues from Transportation of Gas for Others
through Distribution Facilities
Current Year
-
(c)
Revenues for
Transition Costs
and Take-or-Pay
(b)
Previous Year
-
- -
- -
- -
- -
- -
- -
Revenues for
GRI and ACA
Account
(a)
Current Year Previous Year
- -
- -
- -
- -
- -
- -
- -
- -
(d)(e)
Report below natural gas operating revenues attributable to the state of Idaho for each prescribed account total in accordance with jurisdictional
Results of Operations.
Revenues in columns (b) and (c) include transition costs from upstream pipelines.
- -
2020 / Q4
04/15/2021
GAS OPERATING REVENUES - IDAHO
Other Revenues in columns (f) and (g) include reservation charges received by the pipeline plus usage charges, less revenues reflected in columns
(b) through (e). Include in columns (f) and (g) revenues for Accounts 480-495.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.300-301
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
4.
5.
6.
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
(1) Sales for Resale and Deferred Exchange dollars are allocated based on the Washington / Idaho monthly commodity allocations used in
Results of Operations.
91,831,716 88,318,789 91,831,716
91,809,029 88,318,789
Natural Gas
Current Year
(j)
Previous Year
(k)
- - -
-
-
91,809,029
Operating
Revenues
Previous Year
(i)
-
(22,687) - (22,687)
1,139,088 2,355,687 1,139,088 2,355,687
- -
- - -
88,318,789
88,318,789
Revenues
Current Year
(f)
Previous Year
(g)
-
585,309 587,215 585,309 587,215 7,143,693 6,162,727
- - - -
- - -
-
- - - -
- - -
- - -
3,912 7,690 3,912 7,690
5,082
- - -
27,763 28,869 27,763 28,869 4,467
21,436,034 26,355,725 21,436,034 26,355,725 16,440,077 16,410,210
19,061,256 19,504,175 19,061,256 3,316,929 3,515,311
- - - -
5,685,251
19,504,175
If increases or decreases from previous year are not derived from previously reported figures, explain any inconsistencies in a footnote in the
available space at the bottom of this page or attached in a separate schedule.
See pages 108 in the FERC Form 2, Important Changes During the Quarter/Year, for information on major changes during the year, new service,
Other Total Dekatherm of
45,622,508 43,435,274
Current Year
(h)
45,622,508 43,435,274 5,573,141
2020 / Q4
04/15/2021
GAS OPERATING REVENUES - IDAHO
and important rate increases or decreases.
Report the revenue from transportation services that are bundled with storage services as transportation service revenue.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.300-301
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
1 1. PRODUCTION EXPENSES
2 A. Manufactured Gas Production
3 Manufactured Gas Production (Submit Supplemental Statement)
4 B. Natural Gas Production
5 B1. Natural Gas Production and Gathering
6 Operation
7 750 Operation Supervision and Engineering
8 751 Production Maps and Records
9 752 Gas Well Expenses
10 753 Field Lines Expenses
11 754 Field Compressor Station Expenses
12 755 Field Compressor Station Fuel and Power
13 756 Field Measuring and Regulating Station Expenses
14 757 Purification Expenses
15 758 Gas Well Royalties
16 759 Other Expenses
17 760 Rents
18 TOTAL Operation (Total of lines 7 through 17)
19 Maintenance
20 761 Maintenance Supervision and Engineering
21 762 Maintenance of Structures and Improvements
22 763 Maintenance of Producing Gas Wells
23 764 Maintenance of Field Lines
24 765 Maintenance of Field Compressor Station Equipment
25 766 Maintenance of Field Measuring and Regulating Station Equipment
26 767 Maintenance of Purification Equipment
27 768 Maintenance of Drilling and Cleaning Equipment
28 769 Maintenance of Other Equipment
29 TOTAL Maintenance (Total of lines 20 through 28)
30 TOTAL Natural Gas Production and Gathering (Total of lines 18 and 29)- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
2020 / Q4
04/15/2021
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
(a)(b)(c)
Account Current Year Previous Year
Amount for Amount for
For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
Idaho.
If the amount for previous year is not derived from previously reported figures, explain in a footnote.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.317
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
31 B2. Products Extraction
32 Operation
33 770 Operation Supervision and Engineering
34 771 Operation Labor
35 772 Gas Shrinkage
36 773 Fuel
37 774 Power
38 775 Materials
39 776 Operation Supplies and Expenses
40 777 Gas Processed by Others
41 778 Royalties on Products Extracted
42 779 Marketing Expenses
43 780 Products Purchased for Resale
44 781 Variation in Products Inventory
45 782 (Less) Extracted Products Used by the Utility-Credit
46 783 Rents
47 TOTAL Operation (Total of line 33 through 46)
48 Maintenance
49 784 Maintenance Supervision and Engineering
50 785 Maintenance of Structures and Improvements
51 786 Maintenance of Extraction and Refining Equipment
52 787 Maintenance of Pipe Lines
53 788 Maintenance of Extracted Products Storage Equipment
54 789 Maintenance of Compressor Equipment
55 790 Maintenance of Gas Measuring and Regulating Equipment
56 791 Maintenance of Other Equipment
57 TOTAL Maintenance (Total of lines 49 through 56)
58 TOTAL Products Extraction (Total of lines 47 and 57)
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
Amount for Amount for
Account Current Year Previous Year
(a)(b)(c)
2020 / Q4
04/15/2021
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
Idaho.
If the amount for previous year is not derived from previously reported figures, explain in a footnote.
- -
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.318
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
59 C. Exploration and Development
60 Operation
61 795 Delay Rentals
62 796 Nonproductive Well Drilling
63 797 Abandoned Leases
64 798 Other Exploration
65 TOTAL Exploration and Development (Total of lines 61 through 64)
66 D. Other Gas Suppl Expenses
67 Operation
68 800 Natural Gas Well Head Purchases
69 800.1 Natural Gas Well Head Purchases, Intracompany Transfers
70 801 Natural Gas Field Line Purchases
71 802 Natural Gas Gasoline Plant Outlet Purchases
72 803 Natural Gas Transmission Line Purchases
73 804 Natural Gas City Gate Purchases
74 804.1 Liquefied Natural Gas Purchases
75 805 Other Gas Purchases
76 805.1 (Less) Purchased Gas Cost Adjustments
77 TOTAL Other Gas Supply Expenses (Total of lines 68 through 76)
78 806 Exchange Gas
79 Purchased Gas Expenses
80 807.1 Well Expense-Purchased Gas
81 807.2 Operation of Purchased Gas Measuring Stations
82 807.3 Maintenance of Purchased Gas Measuring Stations
83 807.4 Purchased Gas Calculations Expenses
84 807.5 Other Purchased Gas Expenses
85 TOTAL Purchased Gas Expenses (Total of lines 80 through 84)
-
- -
-
-
-
- -
-
-
-
40,365,902 46,740,473
-
40,365,902 46,740,473
-
-
-
-
-
- -
- -
- -
- -
Amount for Amount for
Account Current Year Previous Year
(a)(b)(c)
2020 / Q4
04/15/2021
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
Idaho.
If the amount for previous year is not derived from previously reported figures, explain in a footnote.
- -
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.319
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
86 808.1 Gas Withdrawn from Storage-Debit
87 808.2 (Less) Gas Delivered to Storage-Credit
88 809.1 Withdrawals of Liquefied Natural Gas for Processing-Debit
89 809.2 (Less) Deliveries of Natural Gas for Processing-Credit
90 Gas Used in Utility Operation-Credit
91 810 Gas Used for Compressor Station Fuel-Credit
92 811 Gas Used for Products Extraction-Credit
93 812 Gas Used for Other Utility Operations-Credit
94 TOTAL Gas Used in Utility Operations-Credit (Total of lines 91 through 93)
95 813 Other Gas Supply Expenses
96 TOTAL Other Gas Supply Expenses (Total of lines 77, 78, 85, 86 through 89, 94, 95)
97 TOTAL Production Expenses (Total of lines 3, 30, 58, 65, and 96)
98 2. NATURAL GAS STORAGE, TERMINALING AND PROCESSING EXPENSES
99 A. Underground Storage Expenses
100 Operation
101 814 Operation Supervision and Engineering
102 815 Maps and Records
103 816 Wells Expenses
104 817 Lines Expense
105 818 Compressor Station Expenses
106 819 Compressor Station Fuel and Power
107 820 Measuring and Regulating Station Expenses
108 821 Purification Expenses
109 822 Exploration and Development
110 823 Gas Losses
111 824 Other Expenses
112 825 Storage Well Royalties
113 826 Rents
114 TOTAL Operation (Total of lines 101 through 113)229,321 225,035
227,077 218,529
-
-
-
-
-
-
-
-
-
-
-
2,244 6,506
41,597,359 46,179,952
41,597,359 46,179,952
- -
(66,924) (157,729)
342,721 441,472
- -
(66,924) (157,729)
- -
Amount for Amount for
Account Current Year Previous Year
(a)(b)(c)
2020 / Q4
04/15/2021
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
Idaho.
If the amount for previous year is not derived from previously reported figures, explain in a footnote.
- (844,264)
- -
955,660 -
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.320
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
115 Maintenance
116 830 Maintenance Supervision and Engineering
117 831 Maintenance of Structures and Improvements
118 832 Maintenance of Reservoirs and Wells
119 833 Maintenance of Lines
120 834 Maintenance of Compressor Station Equipment
121 835 Maintenance of Measuring and Regulating Station Equipment
122 836 Maintenance of Purification Equipment
123 837 Maintenance of Other Equipment
124 TOTAL Maintenance (Total of lines 116 through 123)
125 TOTAL Underground Storage Expenses (Total of lines 114 and 124)
126 B. Other Storage Expenses
127 Operation
128 840 Operation Supervision and Engineering
129 841 Operation Labor and Expenses
130 842 Rents
131 842.1 Fuel
132 842.2 Power
133 842.3 Gas Losses
134 TOTAL Operation (Total of lines 128 through 133)
135 Maintenance
136 843.1 Maintenance Supervision and Engineering
137 843.2 Maintenance of Structures
138 843.3 Maintenance of Gas Holders
139 843.4 Maintenance of Purification Equipment
140 843.5 Maintenance of Liquefaction Equipment
141 843.6 Maintenance of Vaporizing Equipment
142 843.7 Maintenance of Compressor Equipment
143 843.8 Maintenance of Measuring and Regulating Equipment
144 843.9 Maintenance of Other Equipment
145 TOTAL Maintenance (Total of lines 136 through 144)
146 TOTAL Other Storage Expenses (Total of lines 134 and 145)- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
845,351 858,821
- -
616,030 633,786
616,030 633,786
- -
- -
- -
- -
Amount for Amount for
Account Current Year Previous Year
(a)(b)(c)
2020 / Q4
04/15/2021
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
Idaho.
If the amount for previous year is not derived from previously reported figures, explain in a footnote.
- -
- -
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.321
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
147 C. Liquefied Natural Gas Terminaling and Processing Expenses
148 Operation
149 844.1 Operation Supervision and Engineering
150 844.2 LNG Processing Terminal Labor and Expenses
151 844.3 Liquefaction Processing Labor and Expenses
152 844.4 Liquefaction Transportation Labor and Expenses
153 844.5 Measuring and Regulating Labor and Expenses
154 844.6 Compressor Station Labor and Expenses
155 844.7 Communication System Expenses
156 844.8 System Control and Load Dispatching
157 845.1 Fuel
158 845.2 Power
159 845.3 Rents
160 845.4 Demurrage Charges
161 845.5 (Less) Wharfage Receipts-Credit
162 845.6 Processing Liquefied or Vaporized Gas by Others
163 846.1 Gas Losses
164 846.2 Other Expenses
165 TOTAL Operation (Total of lines 149 through 164)
166 Maintenance
167 847.1 Maintenance Supervision and Engineering
168 847.2 Maintenance of Structures and Improvements
169 847.3 Maintenance of LNG Processing Terminal Equipment
170 847.4 Maintenance of LNG Transportation Equipment
171 847.5 Maintenance of Measuring and Regulating Equipment
172 847.6 Maintenance of Compressor Station Equipment
173 847.7 Maintenance of Communication Equipment
174 847.8 Maintenance of Other Equipment
175 TOTAL Maintenance (Total of lines 167 through 174)
176 TOTAL Liquefied Nat Gas Terminaling and Proc Exp (Total of lines 165 and 175)
177 TOTAL Natural Gas Storage (Total of lines 125, 146, and 176)
- -
- -
845,351 858,821
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
Amount for Amount for
Account Current Year Previous Year
(a)(b)(c)
2020 / Q4
04/15/2021
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
Idaho.
If the amount for previous year is not derived from previously reported figures, explain in a footnote.
- -
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.322
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
178 3. TRANSMISSION EXPENSES
179 Operation
180 850 Operation Supervision and Engineering
181 851 System Control and Load Dispatching
182 852 Communication System Expenses
183 853 Compressor Station Labor and Expenses
184 854 Gas for Compressor Station Fuel
185 855 Other Fuel and Power for Compressor Stations
186 856 Mains Expenses
187 857 Measuring and Regulating Station Expenses
188 858 Transmission and Compression of Gas by Others
189 859 Other Expenses
190 860 Rents
191 TOTAL Operation (Total of lines 180 through 190)
192 Maintenance
193 861 Maintenance Supervision and Engineering
194 862 Maintenance of Structures and Improvements
195 863 Maintenance of Mains
196 864 Maintenance of Compressor Station Equipment
197 865 Maintenance of Measuring and Regulating Station Equipment
198 866 Maintenance of Communication Equipment
199 867 Maintenance of Other Equipment
200 TOTAL Maintenance (Total of lines 193 through 199)
201 TOTAL Transmission (Total of lines 191 and 200)
202 4. DISTRIBUTION EXPENSES
203 Operation
204 870 Operation Supervision and Engineering
205 871 Distribution Load Dispatching
206 872 Compressor Station Labor and Expenses
207 873 Compressor Station Fuel and Power
- -
- -
398,176 594,221
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
- -
Amount for Amount for
Account Current Year Previous Year
(a)(b)(c)
2020 / Q4
04/15/2021
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
Idaho.
If the amount for previous year is not derived from previously reported figures, explain in a footnote.
- -
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.323
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
208 874 Mains and Services Expenses
209 875 Measuring and Regulating Station Expenses-General
210 876 Measuring and Regulating Station Expenses-Industrial
211 877 Measuring and Regulating Station Expenses-City Gas Check Station
212 878 Meter and House Regulator Expenses
213 879 Customer Installations Expenses
214 880 Other Expenses
215 881 Rents
216 TOTAL Operation (Total of lines 204 through 215)
217 Maintenance
218 885 Maintenance Supervision and Engineering
219 886 Maintenance of Structures and Improvements
220 887 Maintenance of Mains
221 888 Maintenance of Compressor Station Equipment
222 889 Maintenance of Measuring and Regulating Station Equipment-General
223 890 Maintenance of Measuring and Regulating Station Equipment-Industrial
224 891 Maintenance of Meas. and Reg. Station Equipment-City Gate Check Station
225 892 Maintenance of Services
226 893 Maintenance of Meters and House Regulators
227 894 Maintenance of Other Equipment
228 TOTAL Maintenance (Total of lines 218 through 227)
229 TOTAL Distribution Expenses Total of lines 216 and 228
230 5. CUSTOMER ACCOUNTS EXPENSES
231 Operation
232 901 Supervision
233 902 Meter Reading Expenses
234 903 Customer Records and Collection Expenses
145,329 201,241
1,645,655 2,242,512
33,341 39,653
64,926 73,670
1,373,145 1,887,368
4,287,868 5,461,149
151,417 30,505
273,635 435,760
472,791 868,293
-
79,559 102,639
11,784 7,137
42,853 117,220
-
276,180 252,144
8,887 10,486
2,914,723 3,573,781
227,227 205,791
496,727 662,804
344,628 589,973
27,849 36,039
Amount for Amount for
Account Current Year Previous Year
(a)(b)(c)
1,383,510 1,419,682
2020 / Q4
04/15/2021
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
Idaho.
If the amount for previous year is not derived from previously reported figures, explain in a footnote.
25,219 53,873
2,500 912
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.324
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
235 904 Uncollectible Accounts
236 905 Miscellaneous Customer Accounts Expenses
237 TOTAL Customer Accounts Expenses (Total of lines 232 through 236)
238 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
239 Operation
240 907 Supervision
241 908 Customer Assistance Expenses
242 909 Informational and Instructional Expenses
243 910 Miscellaneous Customer Service and Informational Expenses
244 TOTAL Customer Service and Informational Expenses (Total of lines 240 through 243)
245 7. SALES EXPENSES
246 Operation
247 911 Supervision
248 912 Demonstrating and Selling Expenses
249 913 Advertising Expenses
250 916 Miscellaneous Sales Expenses
251 TOTAL Sales Expenses (Total of lines 247 through 250)
252 8. ADMINISTRATIVE AND GENERAL EXPENSES
253 Operation
254 920 dministrative and General Salaries
255 921 Office Supplies and Expenses
256 922 (Less) Administrative Expenses Transferred-Credit
257 923 Outside Services Employed
258 924 Property Insurance
259 925 Injuries and Damages
260 926 Employee Pensions and Benefits
261 927 Franchise Requirements
262 928 Regulatory Commission Expenses
263 929 (Less) Duplicate Charges-Credit
264 930.1 General Advertising Expenses
265 930.2 Miscellaneous General Expenses
266 931 Rents
267 TOTAL Operation (Total of lines 254 through 266)
268 Maintenance
269 932 Maintenance of General Plant
270 TOTAL Administrative and General Expenses (Total of lines 267 and 269)
271 TOTAL Gas O&M Expenses (Total of lines 97, 177, 201, 229, 237, 244, 251, 270)
887,696 948,701
7,650,218 5,861,241
58,591,168 62,850,049
30,219 24,504
6,762,522 4,912,540
- -
- -
457,159 364,296
2,196,335 156,547
- -
268,651 333,207
859,714 720,863
107,216 93,582
289,724 224,791
2,222,675 2,631,692
336,283 367,914
(5,454) (4,856)
- -
- -
- -
- -
- -
193,517 308,452
71,533 60,377
1,747,164 1,912,200
-
1,482,114 1,543,371
2,463,208 2,576,686
Amount for Amount for
Account Current Year Previous Year
(a)(b)(c)
2020 / Q4
04/15/2021
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
Idaho.
If the amount for previous year is not derived from previously reported figures, explain in a footnote.
606,391 45,909
32,492 47,371
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.325
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
NOTE:
In accordance with the definitions established in the Uniform System of Accounts for production, transmission, and distribution plant, the Company's
gas mains are appropriately classified as distribution property for accounting purposes (see definitions 29 (B) and (C)).
2020 / Q4
04/15/2021
GAS TRANSMISSION MAINS - IDAHO
(b)
space at the bottom of this page or attached in a separate schedule) state the name of owner or co-owner, nature of respondent's title, and
percent ownership if jointly owned.
(a)
in Inches
Report below the requested details of transmission mains in system operated by respondent at end of year in the state of Idaho.
Report separately any lines held under a title other than full ownership. Designate such lines with an asterisk and in a footnote (in the available
Kind of
Material
Diameter of
Pipe
Total Length in Use
Beginning of Year
Total Length
in Use
End of Year
-
-
-
-
-
in Feet
(f)
-
in Feet
(c)
Laid During Year
in Feet
(d)
Taken Up
or Abandoned
During Year
in Feet
(e)
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.514
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
Line
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
2020 / Q4
04/15/2021
GAS DISTRIBUTION MAINS - IDAHO
Report below the requested details of distribution mains in system operated by respondent at end of year in the state of Idaho.
Report separately any lines held under a title other than full ownership. Designate such lines with an asterisk and in a footnote (in the available
space at the bottom of this page or attached in a separate schedule) state the name of owner or co-owner, nature of respondent's title, and
percent ownership if jointly owned.
Taken Up Total Length
Material Pipe Beginning of Year in Feet During Year End of Year
Kind of Diameter of Total Length in Use Laid During Year or Abandoned in Use
(a)(b)(c)(d)(e)(f)
in Inches in Feet in Feet in Feet
Steel Wrapped 2" to 4"617,427 612 1,309 616,730
Steel Wrapped Less than 2"1,751,218 1,898 3,509 1,749,607
Steel Wrapped 8" to 12"12,244 12,244
Steel Wrapped 4" to 8"446,181 33 102 446,112
- -
Steel Wrapped Over 12"- -
Plastic Less than 2"6,029,718 207,410 71,301 6,165,827
- -
Plastic 4" to 8"643,294 6,909 372 649,831
Plastic 2" to 4"1,543,122 11,180 6,850 1,547,452
Plastic Over 12"- -
Plastic 8" to 12"- -
-
- -
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.514A
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
Line Type of Diameter of
No. Material Pipe
in Inches
(a)(b)
1 Steel Wrapped 1" or Less
2 Steel Wrapped 1" to 2"
3 Steel Wrapped 2" to 4"
4 Steel Wrapped 4" to 8"
5 Steel Wrapped Over 8"
6 Steel Wrapped Unknown
7
8 Plastic 1" or Less
9 Plastic 1" to 2"
10 Plastic 2" to 4"
11 Plastic 4" to 8"
12 Plastic Over 8"
13 Plastic Unknown
14
15 Other Unknown
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
(1) Information not available.
2020 / Q4
04/15/2021
SERVICE PIPES - GAS - IDAHO
Report below the requested details of line service pipe in possession of the respondent at the end of the year in the state of Idaho.
Service Pipes During Year During Year Service Pipes Length
Number of Added Retired Number of Average
(c)(c)(d)(e)(f)
Beginning of Year End of Year in Feet
179 179 (1)
11,394 3 26 11,371 (1)
1 1 (1)
9 2 7 (1)
209 1 208 (1)
- - (1)
69,664 1,972 229 71,407 (1)
12 12 (1)
299 8 2 305 (1)
- - (1)
3 1 4 (1)
446 4 442 (1)
1 1 - (1)
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.514B
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
Line Size Type Make
No.
(a)(b)(c)
1
2 No Data available
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40 Total
(e)
Added During
Year
(f)
-
Retired During
Year
(g)
In Plant
End of Year
(h)
Capacity
2020 / Q4
04/15/2021
REGULATORS - GAS - IDAHO
Report below the requested details of gas regulators in possession of the respondent at the end of the year in the state of Idaho.
In Service
-
-
-
(d)
Beginning of Year
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
- - -
-
-
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.514C
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
Line Size Type Make
No.
(a)(b)(c)
1 All All All
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
(1) The Company's systems do not supply meter information tracking by type of meter.
2020 / Q4
04/15/2021
CUSTOMER METERS - GAS - IDAHO
Report below the requested details of gas customer meters in possession of the respondent at the end of the year in the state of Idaho.
Capacity In Service Added During Retired During In Plant
Beginning of Year Year Year End of Year
(d)(e)(f)(g)(h)
All 83,282 82,107
-
576 1,751
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.514D
Name of Respondent This Report is:Date of Report Year / Period of Report
Avista Corporation X An Original mm/dd/yyyy End of
A Resubmission
Instructions
1.
2.
3.
4.
5.
6.
7.
8.
9.
Line Refer to
No.Form 2
Page
(b)
1 Name of System
2 GAS RECEIVED
3 Gas Purchases (Accounts 800-805)
4 Gas of Others Received for Gathering (Account 489.1)303
5 Gas of Others Received for Transmission (Account 489.2)305
6 Gas of Others Received for Distribution (Account 489.3)301
7 Gas of Others Received for Contract Storage (Account 489.4)307
8 Exchanged Gas Received from Others (Account 806)328
9 Gas Received as Imbalances (Account 806)328
10 Receipts of Respondent's Gas Transported by Others (Account 858)332
11 Other Gas Withdrawn from Storage (Explain)
12 Gas Received from Shippers as Compressor Station Fuel
13 Gas Received from Shippers as Lost and Unaccounted For
14 Other Receipts (Specify) (footnote details)
15 Total Receipts (Total of lines 3 through 14)
16 GAS DELIVERED
17 Gas Sales (Accounts 480-484)
18 Deliveries of Gas Gathered for Others (Account 489.1)303
19 Deliveries of Gas Transported for Others (489.2)305
20 Deliveries of Gas Distributed for Others (Account 489.3)301
21 Deliveries of Contract Storage Gas (Account 489.4)307
22 Exchange Gas Delivered to Others (Account 806)328
23 Gas Delivered as Imbalances (Account 858)328
24 Deliveries of Gas to Others for Transportation (Account 858)332
25 Other Gas Delivered to Storage (Explain) (1)
26 Gas Used for Compressor Station Fuel 509
27 Other Deliveries (Specify) (footnote details)
28 Total Deliveries (Total of lines 17 through 27)
29 GAS UNACCOUNTED FOR
30 Production System Losses
31 Gathering System Losses
32 Transmission System Losses
33 Distribution System Losses
34 Storage System Losses
35 Other Losses (Specify) (footnote details)
36 Total Gas Unaccounted For (Total of lines 30 through 35)
37 Total Deliveries and Gas Unaccounted For (Total of lines 28 and 36)
(1) Represents net gas withdrawals and injections.
2020 / Q4
04/15/2021
GAS ACCOUNT - NATURAL GAS - IDAHO
Indicate by footnote the quantities of gas not subject to FERC regulation which did not incur FERC regulatory costs by showing (1) the local distribution
volumes another jurisdictional pipeline delivered to the local distribution company portion of the reporting pipeline, (2) the quantities that the reporting
figure. Add additional information as necessary to the footnotes.
pipeline transported or sold through its local distribution facilities or intrastate facilities and which the reporting pipeline received through gathering
facilities or intrastate facilities, but not through any of the interstate portion of the pipeline, and (3) the gathering line quantities that were not destined for
Indicate in a footnote (in the available space at the bottom of this page or in a separate schedule) the quantities of bundled sales and transportation gas
and specify the line on which such quantities are listed.
If the respondent operates two or more systems which are not interconnected, submit separate pages for this purpose.
The purpose of this schedule is to account for the quantity of natural gas received and delivered by the respondent for service in the state of Idaho.
Natural gas means either natural gas unmixed or any mixture of natural and manufactured gas.
Enter in column (c) the year-to-date Dth as reported in the schedules indicated for the items of receipts and deliveries.
20,331,339
(a)(c)(d)
Account Year to Date Current 3 Months Ended
7,143,693
374,129
(4,658)
19,980,806
27,844,503
-
Amount of Dth Amount of Dth
Also indicate the volumes of pipeline production field sales that are included in both the company's total sales figure and the company's total transportation
720,004
7,143,693
27,844,503
Quarterly Only
storage quantities.
interstate market or that were not transported through any interstate portion of the reporting pipeline.
Indicate in a footnote the specific gas purchase expense account(s) and related to which the aggregate volumes report on line 3 relate.
transportation and compression volumes by the reporting pipeline during the same reporting year, (2) the system supply quantities of gas that are stored
Indicate in a footnote (1) the system supply quantities of gas that are stored by the reporting pipeline during the reporting year and also reported as sales,
by the reporting pipeline during the reporting year which the reporting pipeline intends to sell or transport in a future reporting year, and (3) contract
-
-
-
-
-
-
27,844,503
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.ID.520