2014Annual Report.pdf

THIS FILING IS
Item 1: I An lnitial (Original) OR D Resubmission No. _
Submission
AVU'05"r,frr?8ffi,,(Expires 0913012017)
Form 3-Q Approved
OMB No.1902-0205
(Expires 1113012016')
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FERC FINANCIAL REPORT
FERC 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 18
CFR Parts 260.1 and 260.300. Failure to report may result in criminal fines, civil
penalties, and olher 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 20141Q4
FERC FORM No.2/3Q (02-04)
QUARTERLY/ANNUAL REPORT OF MAJOR NATURAL GAS COMPANIES
IDENTIFICATION
01 Exact Legal Name of Respondent
Avista Corporation
Year/Period of Report
End of 2014/Q4
03 Previous Name and Date of Change (lf name changed during year)
04 Address of Principal Office at End of Year (Street, City, State, Zip Code)
141 1 East Mission Avenue, Spokane, WA 99207
05 Name of Contact Person
Christy BurmeisterSmith
06 Title of Contact Person
VP, Controller, Prin. Acctg Officer
07 Address of Contact Person (Street, City, State, Zip Code)
1411 East Mission Avenue, Spokane, WA 99207
08 Telephone of Contac{ Person, lncluding Area Code
509-495-4256
This Report ls:
(1) E]An Originat(2) [A Resubmission
10 Date of Report
(Mo, Da, Yr)
o4t15t20'15
ANNUAL CORPOMTE OFFICER CERTIFICATION
The undersigned officer certifies that:
I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct
statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all
material respects to the Uniform System of Accounts.
11 Name
Christy Burmeister-Smith .\
12 Title
VP, Controller, Prin. Acctg Officer
l3Signature ,4/ , 2 )_ -Christy Burmeister-Smith (' /r,*n/ ).,;n,--1- /
14 Date Signed
44u,.5t2015
Title 18, U.S.C. 1001, makeEit afrime for any person knowingly and wffi!'ly to make to any Agency or Department of the United States any
false, fictitious or fraudulent slatdments as to any matter within its jurisdiction.
FERC FORM NO.2/3Q (02-04)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn orisinat(2\ l_lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Repor
End of 2014/Q4
List of Schedules (Natural Gas Company)
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."
Line
No.
Tifle of Schedule
(a)
Reference
Page No.
(b)
Date Revised
(c)
Remarks
(d)
GENERAL CORPORATE INFORMATION AND FINANCIAL STATEMENTS
1 General lnformation 101
2 Control Over Respondent 102 N/A
3 Corporations Controlled by Respondent 103
4 Security Holders and Voting Powers 107
5 lmportant Changes During the Year 108
b Comparative Balance Sheet 110-113
7 Statement of lncome for the Year 1 14-1 16
8 Statement of Accumulated Comprehensive lncome and Hedging Aclivities 117
I Statement of Retained Eamings for the Year 118-119
10 Statements of Cash Flows 120-121
1'.!Notes to Financial Statements 122
BALANCE SHEET SUPP0RTING SCHEDULES (Assets and Other Debits)
12 Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization, and Depletion 200-201
13 Gas Plant in Service 204-209
14 Gas Propefi and Capacity Leased from Others 212 N/A
15 Gas Propefty and Capacity Leased to Others 2',13 N/A
16 Gas Plant Held for Future Use 2',t4
17 Construc{ion Work in Progress-Gas 216
18 Non-Traditional Rate Treatment Atlorded New Projects 217 N/A
19 General Description of Construction Overhead Procedure 218
20 Accumulated Provision for Depreciation of Gas Utility Plant 219
21 Gas Stored 220
22 lnvestments 222-223
23 lnvestments in Subsidiary Companies 224-225
24 Prepayments 230
25 Extraordinary Property Losses 230 N/A
26 Unrecovered Plant and Regulatory Study Costs 230 N/A
27 Other Regulatory Asseb 232
28 Miscellaneous Defened Debits 233
29 Accumulated Defened lncome Taxes 234-235
BALANCE SHEET SUPPORTING SCHEDULES (Liabilities and Other Credib)
30 Capital Stock 250-251
31 Capital Stock Subscribed, Capital Stock Liability for Conversion, Premium on Capital Stock, and
lnslallmenb Received on Capital Stock 252 N/A
32 Other Paid-in Capital 253
33 Dismunt on Capital Stock 254 N/A
34 Capital Stock Expense 254
35 Securities issued or Assumed and Securities Refunded or Retired During the Year 255
36 Long-Term Debt 256-257
37 Unamortized Debt Expense, Premium, and Discount on Long-Term Debl 258-259
FERC FORM NO. 2 (REV 12-07)Page 2
Name of Respondent
Avista Corporation
This Report ls:(1) ffiRn originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Repor
End of 2014/Q4
List of Schedules (Natural Gas Company) (continued)
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."
Line
No.
Title of Schedule
(a)
Reference
Page No.
(b)
Date Revised
(c)
Remarks
(d)
38 Unamortized Loss and Gain on Reacquhed Debt 260
39 Remnciliation of Repofied Net lncome with Taxable lncome for Federal lncome Taxes 261
40 Taxes Accrued, Prepaid, and Charged During Year 262-263
41 Miscellaneous Cunent and Accrued Liabilities 268
42 Other Delened Credits 269
43 Accumulated Defened lncome Taxes-Other Property 274-275
44 Accumulated Defened lncome Taxes-Other 276-277
45 Other Regulatory Liabilities 278
INCOME ACCOUNT SUPPORTING SCHEDULES
46 Monthly Quantity & Revenue Data by Rate Schedule 299 N/A
47 Gas Operating Revenues 300-30'r
48 Revenues from Transportation of Gas of Others Through Gathering Facilities 302-303 N/A
49 Revenues from Transportation of Gas of Ofien Through Transmission Facilities 304-305 N/A
50 Revenues from Storage Gas of Othen 306-307 N/A
51 Other Gas Revenues 308
52 Discounted Rate Services and Negotiated Rate Services 313 N/A
53 Gas Operation and Maintenance Expenses 317-325
54 Exchange and lmbalance Transactions 328 N/A
55 Gas Used in Utility Operations 331
56 Tnnsmission and Compression of Gas by Others 332 N/A
57 Other Gas Supply Expenses 334
58 Miscellaneous General Expenses4as 33s
59 Depreciation, Depletion, and Amortization of Gas Plant 336-338
60 Particulars Conceming Certain lncome Deduction and lnterest Charges Accounts 340
COMMON SECTION
61 Regulatory Commission Expenses 350-351
62 Employee Pensions and Benefib (Acmunt 926)352
63 Distribution of Salaries and Wages 354-355
64 Charges for Outside Professional and Other Consultative Services 357
65 Transactions with Associated (Affiliated) Companies 358
GAS PLANT STATISTICAL DATA
66 Compressor Stations 508-509 N/A
67 Gas Storage Projecb 512-513
68 Transmission Lines 514 N/A
69 Transmission System Peak Deliveries 518 N/A
70 Auxiliary Peaking Facilities 519
71 Gas AccounlNatural Gas 520
72 Shipper Supplied Gas for the Cunent Quarter 521 N/A
73 System Map 522 N/A
74 Footnote Reference 551
75 Footnote Texl 552
76 Stockholde/s Reports (check appropriate box)
tr
tr
Four copies will be submitted
No annual report to stockholders is prepared
FERC FORM NO. 2 (REV 12-071 Page 3
Name or Kesponoenl
Avista Corporation
This Reoort ls:(1) fiAn Originat(2) l_lA Resubmission
uate or xepon(Mo, Da, Yr)
04t1512015
Year/Period of Repor
End of 2014/Q4
General lnformation
1 . Provide name and title ol ofiicer having custody of the general corprate books of acmunt and address of office where the general corporate books are kept and address of ofiice
where any other corporate books of a@ount are kept, if different ftom that where the general corporate books are kepl
Christy Burmeister-Smith, Vice Presldent and Controller
1411 E Mission Avenue
Spokane, WA 99207
incorporated, state that fact and give the type of organization and the date organized.
State of Washington, lncorporated March 15, '1889
the auhority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.
Not Applicable
4. State the classes of utility and other services fum'shed by respondent during the year in each State in which the respondent operated.
Electric service in the states of Washington, ldaho and Montana
Natural gas service in the states of Washington, ldaho and Oregon
5. Have you engaged as the principal accounlant to audit your financial statements an accountant who is nol the principal accountant for your previous yea/s certified fnancial
statements?
(1) f] Yes... Enter the date when such independent accountant was initially engaged:
(2) E No
FERC FORM NO. 2 (12-96)Page 101
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn Originat(2) I-lA Resubmission
Date of Reporl(Mo, Da, Yr)
o4t15t2015
Year/Period of Reporl
End of 20141Q4
Corporations Controlled by Respondent
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. lf control ceased prior to end of year, give particulars (details) in a footnote.2. lf 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. lf control was held jointly with one or more other interests, state the fact in a footnote and name the other interests.
4. ln column (b) designate type of control of the respondent as "D" for direct, an "1" for indirect, or a "J" for joint control.
DEFINITIONS
1 . See the Uniform System of Accounts for a definition of control.
2. Direcl control is that which is exercised without interposition of an intermediary.
3. lndirect 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.
Line
No.
Name of Company Controlled
(a)
Type of Control
(b)
Kind of Business
(c)
Percent Voting
Stock Owned
(d)
Footnote
Reference
(e)
1 Avista Capital, lnc.D Parent company to the Company's
subsidiaries.
100 Alol used
2 Ecova, lnc Provides utility bill processing services 80 Nof used
3
4 Avista Development, lnc.Maintains investment portfol'.'r:#:100 Not used
5 Avista Energy, lnc.lnactlve 100 Nof used
6 Pentzer Corporation Parent of Bay Area Mfg and PenDer
Venture Hldngs
100 Not used
7 PenEer Venture Holdings ll, lnc.lnactive 100 Aiot usecl
8 Bay Area Manufacturing, lnc.Holding co. of AM&D dba MetalFX 100 tVol ased
I Advanced Manufacturing & Development Custom mfg of electronic enclosures 83 A/ot used
10 dba MetalFX Nof usecl
11 Spokane Energy, LLC )Owns an electric capacity contracl.100 Not used
12 Avista Capital ll )Afiiliated business trust issued prel
trust sec.
100 Not lsed
13 Avista Northwest Resources, LLC Orns an interest in a venture fund
investment
100 /Vol used
14 Steam Plant Square, LLC Commercial office and retail leasing 85 Nof used
15 Courtyard Office Center, LLC Commercial office and retail leasing 100 Noi used
16 Steam Plant Brew Pub, LLC Restaurant openations 85 Not used
17 Salix, lnc.Liquified natural gas operations 100 Nof usec/
18 Aldska Eriergy ald Resources Company )Parent mmpany of Alaska operations 100 Not used
19 Utility operations based in the City and
Borough
100 Nol used
20 of Juneau, AK
21 AJT Mining Properties, lnc,lnactive mining company holding
certain properties
100 Not Ltsed
22 in the City and Borough of Juneau, AK
23 Snettisham Electic Company I Holds certain righh to purchase the
Snettisham
100 l\/of t/sed
24 Hydroelectric pro)ect in the City and
Borough of
25 Juneau, AK
26
FERC FORM NO. 2 (12-96)Page 103
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2015
Year/Period of Report
2U4tA4
FOOTNOTE DATA
FSbedglg_?eg9;L03 Line No.:2 Column: a I
Ecova, lnc. was disposed of on June 30,2014. See Note 4 of the Notes to Financial Statements for further information.
Thisffi
This
was on Julv 1,2014. See Footnote 3 of the Notes to Financial Statements for further information.
: 103 Line No.: 19
was on Julv 1.2014. See Footnote 3 of the Notes to Financial Statements for further information,
: 103 Line No.:21 Column: a
This cgmpany was acquired on July 1, 20 information.
-,
This company was acquired on July 1,2014. See Footnote 3 of the Notes to Financial Statements for further information.
FERC FORM NO.2 (12-96 552.1
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn Originat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
YearPenoo oI Kepor
End of 2014/Q4
Security lolders and Voting Powers
1 . Give the names and addresses of the 10 security holders of the respondent who, at the date of the latest closing of the stock book
or compilation of list of stockholders of the respondent, prior to the end of the year, had the highest voting powers in the respondent,
and state the number of votes that each could cast on that date if a meeting were held. lf 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. lf 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. lf 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. lf 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,
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:
12n4D014
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.
Total: 53897547
By Proxy: 53897447
Give the date and place of
such meeting:
May 8, 2014
Spokane, WA
Line
No.
Name (fitle) and Address of
Security Holder
(a)
VOTING SECURITIES
4. Number of votes as of (date): 1210412014
Total Votes
(b'l
Common Stock
(c)
Preferred Stock
(d)
Other
(e)
5 TOTAL votes of all voting securities 60,129,33r 60,129,33t
6 TOTAL number of security holders 9,597 9,597
7 TOTAL votes of security holders listed below 1,739,70t 1.739.705
I Stanford University, Stanford, CA 485,02t 485,029
s Computershare Trust Company NA as escrow agent for
't0 Alaska Energy and Resources Company, Canton, MA 451,54t 451,54€
11 George Barclay Corbus, Arvada, C0 308,74:308,744
12 William A. Corbus, Juneau, AK 171,66?171,667
13 Malcolm A. Menzies, Juneau, AK 101,93(101,936
14 E, Neil MacKinnon, Juneau, AK 63,170 63,17(
15 Gary Ely, Liberty Lake, WA 56,98r 56,984
16 Niels F, Larsen & Wilhelmine J. Larsen Jt Ten, Juneau, AK 35,369 35,36!
17 Jane N. MacKinnon, Juneau, AK 33,601 33,601
18 James S. Webb, Goldendale, WA 31,65t 31,6sr
19
20
FERC FORM NO. 2 (12-96)Page 107
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04!15t2015
Year/Period of Report
2014to,4
FOOTNOTE DATA
'Sghedule Pase: 107 Lj?e Nq:1 Column:1
To pay the December 15,2014 dividend.
_l
FERC FORM NO.2 (1 552,1
Name of Respondent
Avista Comoration
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2015
Year/Period of Report
2014tQ4
lmportant Chanqes Durinq the Quarter/Year
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. lf 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. lf 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. lmportantleaseholds(otherthanleaseholdsfornatural gaslands)thathavebeenacquiredorgiven,assignedorsurrendered: Giveeffective
dates, lengths of terms, names of parties, rents, and other conditions. State name of Commission authorizing lease and give reference to such
authorization.
5. lmportant 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 reguired.
7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
8. State the estirnated annual effect and nature of any important wage scale changes during the year.
9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings
culminated during the year.
10. Describe briefly any materially important transactions of the respondent not disclosed elsewhere in this report in which an officer, director,
security holder, voting trustee, associated company or known associate of any of these persons was a party or in which any such person had a
material interest.
1 1. 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, ln 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 exent to which the
respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companles through a cash management program(s).
Additionally, please describe plans, if any to regain at least a 30 percent proprietary ratio.
l. None
2. A merger transaction with Alaska Energy and Resources Company was completed on July l, 2014. This
merger was approved by each of our various Commissions on the following Orders: UTC U-132222Order l,
IPUC Order 32991, OPUC Order 14-ll2 and RCA Order U-13-197. Refer to Note 3 of the Notes to Financial
Statements for further details regarding this merger transaction.
3. Avista Corp. sold its interest in Ecova, Inc. (Ecova), effective June 30, 2014. Ecova was the primary
unregulated subsidiary of Avista Corp. and no Commission authorization was required. Refer to Note 4 of the
Notes to Financial Statements for further details regarding this sales transaction.
4. None
5. None
6. Avista Corp. has a committed line of credit with various financial institutions in the total amount of $400
million. In April 2074, the Company amended this committed line of credit agreement to extend the expiration
date to April 2019. The amendment also provides the Company the option to request an extension for an
additional one or two years beyond April 2019, provided there is no event of default prior to the requested
extension and the requested extension does not cause the rernaining term until the expiration date to exceed five
years. The amendment did not change the amount of the committed line of credit. 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
FERCiFORM NO.2 (1 1 08.1
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2015
Year/Period of Report
2014tQ4
lmDortant Chanoes Durino the Quarter/Year
under the committed line of credit.
Balances outstanding under the Company's revolving committed line of credit were as follows as of December
31,2014 and December 31, 2013 (dollars in thousands):
2014
Balance outstanding at end of period
Letters of credit outstanding at end of period
$105,000
$32,579
$171,000
$27,434
In December 2014, Avista Co.p. issued $60.0 million of first mortgage bonds to three institutional investors in a
private placement transaction. The first mortgage bonds bear an interest rate of 4.1I percent and mature in2044.
The total net proceeds from the sale of the new bonds were used to repay a portion of the borrowings
outstanding under the Company's $400.0 million committed line of credit and for general corporate purposes.
The debt issuance was approved by regulatory commissions as follows:WUTC (Docket No. U-l 11176 Order
02) IPUC (Case No. AVU-U-I1-01 Order No. 32338) and the OPUC (Docket UF 4269 Order No. I l-334).
7. None
8. Average annual wage increases were 2.3Yo for non-exempt employees effective February 24,2014. Average
annual wage increases were 3.0%ofor exempt employees effective February 24,2014. Officers received average
increases of 3.8% effective March 1,2014. Certain bargaining unit employees received increases of 3.25o/o
effective April 1, 2014.
9. Reference is made to Note 17 of the Notes to Financial Statements.
10. None
I 1 Reference is made to Note l9 of the Notes to Financial Statements.
12. On February 11,2014, Rick R. Holley provided notification to the Company that he will not stand for
reelection to Avista Corp.'s Board of Directors and he resigned effective February 15,2014. This is due to the
fact that the time requirements for his board service conflicts with his other professional commitments. He has
no disagreements with the Company.
On February 13,2014, Avista Corp.'s Board of Directors took action to reduce the number of board members
from 10 to 9, effective February 15,2014.
On July 8,2014, Avista Corp.'s Board of Directors decided to increase the number of board members from 9 to
10 and elected Janet D. Widmann to fill the vacancy and serve as a director on the board effective August 2,
20t4.
Effective January 2074, Jason R. Thackston was promoted to Senior Vice President. He has been Vice President
of Energy Resources since December 2012.
Effective February 2075, Kevin J Christie was promoted to Vice President of Customer Solutions. He had
previously held various other management and staff positions with the Company since 2005.
13. Proprietary capital is not less than 30 percent.
FERC FORM NO.2 (1 108.2
December 31, December 31,
Name of Respondent
Avista Corporation
Ihis Rer(1) 12!(2) r
rort ls;
An Original
A Resubmission
Date of Reporl(Mo, Da, Yr)
o4t1512015
Year/Period of Reporl
Endot p!@!
Comparative Balance Sheet (Assets and Other Debits)
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year End of
QuarterA/ear Balance
(c)
Prior Year
End Balance
12t31
(d)
1 UTIL]TY PLANT
2 Utility Plant (101-106, 114)200-201 4,513,148,224 4,280,005,6't1
3 Construction Work in Progress (107)200-201 223,330,993 157,258,690
4 TOTAL Utility Plant (Iotal of lines 2 and 3)200-201 4.736.479.217 4,437,264,301
5 (Less) Accum. Provision for Depr., Amort., Depl. (108, I 11, 115)1,573,767,832 1,491,212,830
6 Net Utility Plant (Total of line 4 less 5)3,162,711,385 2,946,05'.t,471
7 Nuclear Fuel (120.1 thru 120.4, and 120.6)0 0
I (Less) Accum. Provision for Amort., of Nuclear Fuel Assemblies (120.5)0 0
I Nuclear Fuel (Total of line 7 less 8)0 0
10 Net Utility Plant (Total of lines 6 and 9)3,162,71'1,385 2,946,051,471
11 Utility Plant Adjustments (1 16)122 0 0
12 Gas Stored-Base Gas (117.1)220 6,992,076 6,992,076
13 System Balancing Gas (117.2)220 0 0
14 Gas Stored in Reservoirs and Pipelines-Noncurrent (1'17.3)220 0 0
15 Gas Owed to System Gas (117.4)220 0 0
16 OTHER PROPERW AND INVESTMENTS
17 Nonutility Property (1 21 )5,288,635 5.438,891
18 (Less) Accum. Provision for Depreciation and Amortization (122)194,91 1 920,90s
19 lnvestments in Associated Companies (123)222-223 12,047,000 12,047,000
20 lnvestments in Subsidiary Companies (123.1)224-225 148,255,851 112,232,104
21 (For Cost ofAccount 123.1 See Footnote Page 224, line 40)
22 Noncurrent Portion of Allowances 0 0
23 Other lnvestments (1 24)222-223 11,525,386 13.980.638
24 Sinking Funds (125)0 0
25 Depreciation Fund (1 26)0 0
26 Amortization Fund - Federal (127)0 0
27 Other Special Funds (128)'11.488,865 10,897,909
28 Long-Term Portion of Derivative Assets (175)0 853,757
29 Long-Term Portion of Derivative Assets - Hedges (176)0 19,574,858
30 TOTAL Other Property and lnvestments (Total ot lines 17-20,22-29)188,410,825 174,104,252
31 CURRENT AND ACCRUED ASSETS
32 Cash (131)1,535,172 3,949,469
33 Special Deposits (1 32-1 34)6,832,649 19,283,082
34 Working Funds (',l35)971,206 864,092
35 Temporary Cash lnvestments (136)222-223 {.5,508,864 0
36 Notes Receivable (141)0 0
37 Customer Accounts Receivable (1 42)163,095,696 182,617,384
38 Other Accounts Receivable (143)5,091,552 8,417,179
39 (Less) Accum. Provision for Uncollectible Accounts - Credit (144)4,828,572 4,830,036
40 Notes Receivable from Associated Companies (145)0 5.720.836
4'.!Accounts Receivable from Associated Companies ('t46)401,126 286,696
42 Fuel Stock (151)4,116,727 3,170,050
43 Fuel Stock Expenses Undistributed (152)0 0
FERC FORM NO. 2 (REV 06-04)Page 110
Name of Respondent
Avista Corporation
lnrs HeDon ls:(1) fien originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End ol 20141Q4
Comparative Balance Sheet (Assets and Other Debitsxcontinued)
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year End of
Quarter/Year Balance
(c)
Prior Year
End Balance
12t31
(d)
44 Residuals (Elec) and Extracted Products (Gas) (153)0 0
45 Plant Materials and Operating Supplies (154)29,419,472 26,655,710
46 Merchandise (155)0 0
47 Other Materials and Supplies (156)0 0
48 Nuclear Materials Held for Sale (157)0 0
49 Allowances (158.1 and 158.2)0 0
50 (Less) Noncurrent Portion of Allowances 0 0
5'1 Stores Expense Undistributed (1 63)0 0
52 Gas Stored Underground-Current (1 64. 1 )220 28,731,498 I 3,028.710
53 Liquefled Natural Gas Stored and Held for Processing (164.2 thru 164.3)220 0 0
54 Prepayments (165)230 13,368,084 7,938,050
55 Advances for Gas (166 thru 167)0 0
56 lnterest and Dividends Receivable (171)31,080 30,982
57 Rents Receivable (172)1,740,695 1,360,262
58 Accrued Utility Revenues (173)0 0
59 Miscellaneous Cunent and Accrued Assets (174)614,449 752,953
60 Derivative lnstrument Assets (1 75)1,524,582 3,875,269
61 (Less) Long-Term Portion of Derivative lnstrument Assets (175)0 853,757
62 Derivative lnstrument Assets - Hedges (176)460,316 33,544,588
63 (Less) Long-Term Portion of Derivative lnstrument Assests - Hedges (176)0 19,574,858
64 TOTAL Cunent and Accrued Assets (Total of lines 32 thru 63)268,614,596 286,236,661
65 DEFERRED DEBITS
bo Unamortized Debt Expense ('t81)12.476,292 12,505,134
67 Extraordinary Property Losses ('l 82.'l )230 0 0
68 Unrecovered Plant and Regulatory Study Costs (182.2)230 0 0
69 Other Regulatory Assets (182.3)232 576,247,558 381,581,939
70 Preliminary Survey and lnvestigation Charges (Electric)(183)165,866 875,1 53
71 Preliminary Survey and lnvestigation Charges (Gas)(183.1 and 183.2)0 0
72 Clearing Accounts (1 84)28,145 0
73 Temporary Facilities (1 85)0 0
74 Miscellaneous Deferred Debits (1 86)233 11,803,983 13,312,292
75 Deferred Losses from Disposition of Utility Plant (187)0 o
76 Research, Development, and Demonstration Expend. (188)0 0
77 Unamortized Loss on Reacquired Debt (189)17,356.781 1 9,41 7,1 03
78 Accumulated Deferred lncome Taxes (190)234-235 123,261,474 70,239,422
79 Unrecovered Purchased Gas Costs (191)( 3,921,214\( 12,074,780)
80 TOTAL Deferred Debits (Total of lines 66 thru 79)737.418,885 485,856,263
81 TOTAL Assets and Other Debits (Total of lines 10-15,30,64,and 80)4.364,147,768 3,899,240,723
FERC FORM NO. 2 (REV 06-04)Page 111
Name of Respondent
Avista Corporation
This Rer(1) l2!_(2) r
rort ls:
An Original
A Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2015
Year/Period of Reporl
End of 2014/Q4
Comparative Balance Sheet (Liabilities and Other Credits)
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year
End of
Quarterl/ear
Balance
Prior Year
End Balance
12t31
(d)
1 PROPRIETARY CAPITAL
2 Common Stock lssued (201)250-251 984,400,740 869,342,827
3 Preferred Stock lssued (204)250-251 0 0
4 Capital Stock Subscribed (202, 205')252 0 0
5 Stock Liability for Conversion (203, 206)252 0 0
6 Premium on Capital Stock (207)252 0 0
7 Other Paid-ln Capital (208-21 1)253 ( 9,520,161)8,089,025
8 lnstallments Received on Capital Stock (212)252 0 0
I (Less) Discount on Capital Stock (213)254 0 0
10 (Less) Capital Stock Expense (214)254 ( 25,079,123)( 19,561,527)
11 Retained Earnings (215, 215.'1, 2'16)118-119 507,257,161 4't3,009,873
12 Unappropriated Undiskibuted Subsidiary Earnings (216.1 )1't8-1 19 ( 15,658,s53)( 5,918,024)
13 (Less) Reacquired Capital Stock (2'17)250-251 0 0
14 Accumulated Other Comprehensive lncome (219)117 ( 7,887,881)( 5,819,930)
15 TOTAL Proprietary Capital (Total of lines 2 thru 14)1,483,670,429 1,298,265,298
16 LONG TERM DEBT
17 Bonds (221)256-257 1,436,700,000 '1,376,700,000
18 (Less) Reacquired Bonds (222)256-257 83,700,000 83,700,000
19 Advances from Associated Companies (223)256-257 51,547,000 51,547,000
20 Other Long-Term Debt (224)256-257 0 0
2'.l Unamortized Premium on Long-Term Debt (225)258-259 186,550 195,433
22 (Less) Unamortized Discount on Long-Term DebtDr (226)258-259 1,308,604 1,482,644
23 (Less) Current Portion of Long-Term Debt 0 0
24 TOTAL Long-Term Debt (Total of lines 17 thru 23)1,403,424,946 1,343,259,789
25 OTHER NONCURRENT LIABILITIES
26 Obligations Under Capital Leases-Noncu rrenl (227)0 4,193,852
27 Accumulated Provision for Property lnsurance (228.1)0 0
28 Accumulated Provision for lnjuries and Damages (228.2)240,000 240,000
29 Accumulated Provision for Pensions and Benefits (228.3)1 89,489,1 00 122,512,892
30 Accumulated Miscellaneous Operating Provisions (228.4)0 0
31 Accumulated Provision for Rate Refunds (229)5,855,845 2,489,686
FERC FORM NO. 2 (REV 06-04)1'.!2Page
Name of Respondent
Avista Corporation
This Rer(1) tr(2) -
rort ls:
An Original
A Resubmission
Date of Report(Mo, Da, Yr)
04t15/2015
YearHenoo oI Kepon
End of @fQ4
Comparative Balance Sheet (Liabilities and Other Credits)(continued)
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year
End of
QuarterfYear
Balance
Prior Year
End Balance
12t31
(d)
32 Long-Term Portion of Derivative lnstrument Liabilities 22,093,1 66 18,355,040
33 Long-Term Portion of Derivative lnstrument Liabilities - Hedges 40,857,456 0
34 Asset Retirement Obligations (230)3,028,391 2,847,207
35 TOTAL Other Noncurrent Liabilities (Total of lines 26 thru 34)261,563,958 150,638,677
36 CURRENT AND ACCRUED LIABILITIES
37 Current Portion of Long-Term Debt 0 0
38 Notes Payable (231)105,000,000 't71 ,000,000
39 Accounts Payable (232)111,077,010 107,675,81 9
40 Notes Payable to Associated Companies (233)9,934,843 0
41 Accounts Payable to Associated Companies (234)7't4,039 810,91 1
42 Customer Deposits (235)4,977,?59 3,393,269
43 Taxes Accrued (236)262-263 ( 10,72s,297)22j03,801
44 lnterest Accrued (237)'13,595,667 13,444,066
45 Dividends Declared (238)0 0
46 Matured Long-Term Debt (239)0 0
47 Matured lnterest (240)0 0
48 Tax Collections Payable (241)50,226 115,213
49 Miscellaneous Current and Accrued Liabilities (242)268 57,483,998 55.243.462
50 Obligations Under Capital Leases-Current (243)4,1 93,852 297,339
51 Derivative lnstrument Liabilities (244)40,138,',t2',1 29,230,059
52 (Less) Long-Term Portion of Derivative lnstrument Liabilities 22,093,1 66 18,355,041
53 Derivative lnstrument Liabilities - Hedges (245)48,202,046 0
54 (Less) Long-Term Portion of Derivative lnstrument Liabilities - Hedges 40,857,456 0
55 TOTAL Current and Accrued Liabilities (Total of lines 37 thru 54)321,69',t,142 384,958,898
56 DEFERRED CRED]TS
57 Customer Advances for Construction (252)1,864,508 1,459,',t17
58 Accumulated Deferred lnvestment Tax Credits (255)12,157,507 12,387,031
59 Deferred Gains from Disposition of Utility Plant (256)0 0
60 Other Deferred Credits (253)259 21,269,740 25,359,333
61 Other Regulatory Liabilities (254)278 48,834,355 7',t,742.330
62 Unamortized Gain on Reacquired Debt (257)260 2,096,044 2,225,581
63 Accumulated Deferred lncome Taxes - Accelerated Amortization (281)0 0
64 Accumulated Deferred lncome Taxes - Other Property (282)582,721,352 447j00,235
65 Accumulated Deferred lncome Taxes - Other (283)224,853,787 161.844.434
66 TOTAL Defened Credits (Total of lines 57 thru 65)893,797,293 722,118,061
67 TOTAL Liabilities and Other Credits (Total of lines 15,24,35,55,and 66)4,364,147,768 3,899,240,723
FERC FORM NO. 2 (REV 06-04)Page 113
Name of Respondent
Avista Corporation
This ReDort ls:(1) ffiRn Originat(2t l-lA Resubmission
Date of Report(Mo, Da, Yr)
0411512015
Yea/Henoo oI Kepon
End ot 20141Q4
Statement of lncome
Quarterly
1. Enter in column (d) the balance tor the reporting quarter and in column (e) the balance for the same three month period for the prior year.
other utility function for the cunent year quarter.
other utility function for the prior year quarter.
4. lf 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 (D
6. Report amounts for accounts 412 and 413, Revenues and Expenses ftom 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. lnclude these amounts in columns (c) and (d) totals.
7. Report amounts in account 414, Other Utility Operating lncome, in the same manner as ac@unts 412 and 413 above.
B. Report data for lines 8, 10 and 1 1 for Natural Gas companies using accounts 404.1 , 404.2, 4O4.3, 407 .1 and 407 .2.
9. Use page 1 22 for important notes regarding the statement of income for any account thereof.
10. Give concise explanations mncerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utility's
lustomers 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
respecl to power or gas purchases.
1 1 Give concise explanations concerning signifcant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding afesting 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. lf any notes appearing in the report to stokholders are applicable to the Statement of lncome, such notes may be included at page 1 22.
1 3. 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 effecl of such changes.
14. Explain in a footnote if the previous yea/s/quarte/s figures are different from that reported in prior reports.
Title of Account
Line (a)
No.
Reference
Page
Number
(b)
Total
Cunent Year lo
Date Balance
for QuarterfYear
(c)
Total
Prior Year to Date
Balance
br ouarter/Year
(d)
Cunent Three
Months Ended
Quarterly Only
No Fourth Ouarter
(e)
Prior Three
i/onths Ended
Quarterly Only
No Fourlh Ouarter
(0
,|JTIL]TY OPERAIING INCOTE
2 3as Operating Revenues (400)30G301 1,s72,976,141 1.574,987,368 0
3 )perating Expenses
4 Operation Expenses (401 )317-325 1,0?A,794,12,1,054,58,447 n
5 Maintenance Expenses (402)317-325 65,573,48'60,947,443 0
6 Depreciation Expense (403)33&338 112562,2U 105,822,752 0
7 Depreciation Expense for Asset Retirement Costs (403.1 )336338 0 0
I Anrortization and Depletion of Utility Plant (404405)33G338 16,874,24',13,800,8s3 0
I Amortization of Utility Plant Acu. Ad.iustrnent (406)33&338 99,04i 99,047 0
10 Amort. ofProp. Losses, Unrecovered Plantand Reg. Study Costs (407.1)0 0
11 Amortization of Conversion Expenses (407.2)0 0
12 Regulatory Debits (407.3)1,871,411 12,986,972 0
13 (Less) Regulatory Credits (407.4)10,536,841 1 3,582,146 0
14 Taxes Other than lncome Taxes (408.1)262-263 93,076,91t 88,262,771 0
15 lncome Taxes-Federal (409. 1 )262-263 ( 55,133,870 39.972.039 0
16 lncome Taxes-Other (409. 1 )262-263 (1,858,807 2,066,338 0
't7 Provision of Delerred lncome Taxes (410.1)23+235 135,547,90(3't,154,269 0
18 (Less) Provision for Deferred lncome Taxes-C'edit (41 1.1 )2*235 4,060,58i 4,770,686 0
19 lnvestment Tax Credit Adjustment Net (41 1,4)( n9,s24 (238,869)0
20 (Less) Gains ftom Disposition of Utility Plant (41 1.6)0 0
21 Losses from Disposition ol Utility Plant (41 1.7)0 0
22 (Less) Gains from Disposition ofAllowances (41 1.8)0 0
23 Losses from Disposition ofAllowances (41 1.9)0
24 Accretion Expense (41 '1.1 0)0 0
25 TOTAL Utjlity Operating Expenses (Total of lines 4 thru 24)1,388,579,71:1,391,029,230 0
26 Net Utility Operating lncome fiotal of lines 2 less 25) (Carry fonrard to page I 16,
tne 271 184,396,42(1 83,958,1 38 0 0
FERC FORM NO. 2 (REV 06-04)Page 114
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn original(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2015
Year/Period of Report
End of 20l4lQzl
Statement of lncome
Ltne
No.
Elec. Utility
Current
Year to Date
(in dollars)
(s)
Elec. Utility
Previous
Year to Date
(in dollars)
(h)
Gas Utility
Current
Year to Date
(in dollars)
(i)
Gas Utility
Previous
Year to Date
(in dollars)
0)
Other Utility
Current
Year to Date
(in dollars)
(k)
Other Utility
Previous
Year to Date
(in dollars)
(t)
2 1,015,103,873 1,049,456,902 557.872.268 525,530,466 0 0
4 584,239,61 I 635,61 5,026 450,s54,506 418,893,421 0 0
5 51,160,378 48,867,669 '14.413,'103 12,079,774 0 0
b 89.097.411 84,631,445 23,464/89 21,191,307 0 0
7 0 0 0 0 0 0
8 13,008,487 10,778,960 3.865,760 3,021,893 0 0
I 99,047 99,047 0 0 0 0
10 0 0 0 0 0 0
11 0 0 0 0 0 0
12 1,s35,950 12,125,143 33s,464 861,829 0 0
13 10,108,656 13,080,536 428,185 501,610 0 0
14 69,580,534 66,342,004 23.496,384 21,920.767 0 0
15 27,894,913)31,663,448 ( 27,238,9s7)8,308,591 0 0
16 I 716,9721 1,388,109 ( 1,141,83s)678,229 0 0
17 94,097,395 25,700,222 41.450,511 5.454,047 0 0
18 4,203362 4,871,648 142,779\I 00,962)0 0
19 ( 19s,528)( 199,113)33,996)39,756)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 0 0 0 0
25 859,699,389 899,059,776 528,880,323 491,969,454 0 0
26 155,404,484 1 50,397,1 26 28,991,945 33,561,012 0 0
FERC FORM NO. 2 (REV 05-04)Page 115
Name of Respondent
Avista Corporation
This Reoort ls:(1) $Rn originat(2\ TIA Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End ot 20141Q4
Statement of lncome(continued)
Line
No.
Tile ofAccount Referenc€
Page
Number
(a)
o)
Total Total
Current Year to Prior Yearto Date
Date Balance Balance
,orQuarterlYea forouarler/Year
(c) (d)
Cunent Three
Months Ended
Quarterly Only
No Fourlh Quarter
(e)
Prior Three
ilonths Ended
Quarterly Only
No Fourth Quarter
(0
27 Net Utility Operating lncorne (Canied forward lrom page 1 14)184,396,429 183,958,138 n
28 )THER INCO]IIE A]{D DEDT,CTIONS
29 )fier lncorne
30 l,lonutility Operating lncome
31 Revenues lorm Merchandising, Jobbing and Contract Work (415)0 0
32 (Less) C.osts and Expense of Merchandising, Job & Contract Work (416)0 0
33 Revenues ftom Nonutility Operations (417)( 17,531 ( 13,1721 0
34 (Less) Expenses ol Nonutility Operations (417.1)9,837,241 10,644,789 0
35 Nonoperating Rental lncome (418)( 1,100 3,699)0
36 Equity in Eamings of Subsidiary Companies (418.1)119 82,361,71i 4,593,239 0
37 lnterest and Dvidend lnmrne (419)1,845,36 2,432,397 U
38 Allowance for Other Funds Used During Construction (419.1)8,678,38 6,065,628 U
39 Miscellaneous Nonoperating lncome (421 )0 0
40 Gain on Disposition of Proprty (421.1)2W,47 n 0
41 TOTAL Ottrer lncome (total of lines 31 thut0)83,320,041 2,4n,@4 0
42 )her lncorne Doductions
43 Loss on Disposition of Property (421.2)38,651 U 0
44 Miscellareous funortzation (425)0 0
45 Donations (426.1)340 3,879,39 3,320,437 0
46 Life lnsurance (426.2)2,060,571 2,599,896 0
47 Penalties (426.3)( 24,718 1@,224 0
48 Expenditures ftr Certain Civic, Political and Related Activities (426.4)1,679,32 1,605,677 0
49 Other Deductions (426.5)3,29s,16t 4,3ffi,477 0
50 TOTAL Other lncome Deductions (Total of lines 43 thru 49)340 10,928,401 12,001,711 0
51 taxes Applic. to Other lncorne aod Huctions
52 Taxes Other than lncome Taxes (408.2)262-263 150,61,172,447 0
53 lncome Taxes-Federal (409.2)262-263 ( 314,356 ( 481,927)0
54 lncome Taxes-Other (409.2)262-263 2,579,611 ( 1,004,519)0
55 Povision for Defened lncome Taxes (410.2)2W23s ( 1,467,880 ( 1,731,439)0
56 (Less) Pmvision for Delered lncome Taxes-Credit (41 1.2)2U-235 6,039,381 5,632,031 0
57 lnvesfnent Tax Credit Adiustmenls-Net (41 1.5)U 0
58 (Less) lnvestment Tax Credits (420)U 0
59 TOTAL Taxes on Other lncome and Deductions (Total of lines 52-58)( s,091,393 ( 8,677,469)0
60 llet Olher lncome and Deductions fiotal of lines 41, 50, 59)77,483,03 ( 894,638)0
61 NTEREST CHARGES
62 lnterest on Long-Term Debt (427)67,341,171 68,485,495 0
63 Arnortization of Debt Disc. and Expense (428)25&259 424,83t 448,328 0
64 Amortization of Loss on Reacquired Debt (428.1)3,219,361 3,373,538 0
55 (Less) Amortization of Premium 0n Debt-Credit (429)25&259 8,881 8,883 0
66 (Less) Anndzation of Gain on Reacquired Debt-Credit (429.1)0 0
67 lnteresl on Debl to Associaled Companies (430)340 735,49 750,512 0
68 Other lnlerest Expense (431)340 2,037,95'2,613,463 0
69 (Less) Allowance for Borrowed Funds Used During Construction-Credit (432)3,91 1,171 3,67s,786 0
70 llet lnterest Charges [total of lines 62 thru 69)69.838,77 71,986,667 0
71 lncorne Before Extraordinary llems (Total of lines 27,60 and 70)192,040,68r 1 t 1,076,833 U
72 :XTRAORDINARY ]TEMS
73 Exhaordinary lncome (434)0 0
74 (Less) Exkaordinary Deductions (435)0
75 Net Exhaordinary ltems (Total ofline 73 less line 74)0 0
76 lncome Taxes-Federal and Other (409.3)262-263 0 0
77 Exkaordinary ltems after Taxes [Iotal of line 75 less line 76)0 0
78 Net lncome (Total of lines 71 and 77)192,040,68r 1 1 1,076,833 0
FERC FORM NO. 2 (REV 06-04)Page 116
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) E:lAn Orisinar(2) f-lA Resubmission
Date of Report(Mo, Da, Yr)
M.t15t2015
Year/Period of Report
End of 20141Q4
Statement of Accumulated Comorehensive lncome and Hedoino Activities
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 (D 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.
-tne
No.Item
(a)
Unrealized Gains
and Losses on
available-for-sale
securities
(b)
Minimum Pension
liabilitty Adjustment
(net amount)
(c)
Foreign Cunency
Hedges
(d)
Other
Adjustmenh
(e)
1 Balance of Account 2'19 at Beginning of Preceding
Year 167,261 ( 6,867,421)
2 Preceding Quarter/Year to Date Reclassifications
from Account 219 to Net lncome ( 12,411).
3 Preceding Quarterffear to Date Changes in Fair
Value ( 1,740,705)2,633,346
4 Total (lines 2 and 3)( 1,753,116)2,633,346
5 Balance of Account 219 at End of Preceding
Quarterffear ( 1,s85,855)( 4,234,075)
6 Balance of Account 21 9 at Beginning of Cunent Year ( 1,s85,855)( 4,234,075)
7 Cunent Quarterffear to Date Reclassifications lrom
Acount 219 to Net lncome 450,497
I Cunent Quarterffear to Date Changes in Fair Value 1,125,358 ( 3,653,806)
9 Total (lines 7 and 8)1,585,855 ( 3,6s3,806)
10 Balance of Account 219 at End of Cunent
Quarterffear ( 7,887,881)
FERC FORM NO. 2 (NEW 06-02)Page 117
Name of Respondent
Avista Corporation
This Report ls:(1) [An Original(2) -A Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End of 20141Q4
Statement of Accumulated Comorehensive lncome and Hedoino Activities(continued)
-ine
No.
Other Cash Flow Hedges
lnterest Rate Swaps
(0
Olher Cash Flow Hedges
(lnsert Category)
(s)
Totals ior each
calegory of
items recorded in
Account 219
(h)
Net lncome
(Canied Fouard
from Page 116,
Line 78)
(i)
Total
Comprehensive
lnmme
(i)
1 ( 6,700,160)
( 12,411)
892,641
880,230 111,076,833 111,957,063
( 5,819,930)( s,819,e30)
460,497
( 2,528,448)
( 2,067,9s1)192,040,688 189.972.737
1 ( 7,887,881)
FERC FORM NO. 2 (NEW 06-02)Page
Name of Respondent
Avista Corporation
This Reo(1) lI_J(2) Tl
ort ls:
An Original
A Resubmission
Date of Report(Mo, Da, Yr)
04115t2015
Year/Period of Report
End of 2014/Q4
Statement of Retained Earnings
1. Report all changes in appropriated retained eamings, unappropriated retained eamings, and unappropriated undistibuted subsidiary eamings for the year.
2. Each credit and debit during the year should be identified as to tre retained eamings acmunt in which recorded (Accounb 433, 436439 indusive). Show he confa primary account
affected in column (b).
3. State the purpose and amount for eaci reservation or appropriation of retained eamings.
4. List fint Account 439, Adjusfnenb to Retained Eamings, refec{ing adjustmenb to the opening balanoe of retained eamings. Follow by credit then debit items, in lhat order.
5. Show dividends for each dass and series of capital stock.
Line
No.
Item
(a)
Contra Primary
Account Afiecled
(b)
Cunent Quarter
Year to Date
Balance
(c)
Previous Ouarter
Yearto Date
Balance
(d)
UNAPPROPRIATED RETAINED EARNINGS
Balanc*Beginning of Period 403,295,872 375,'139,703
2 Chanoes (ldentifv bv orescribed retained earninos accounb)
3 Adiuslmenb to Retained Eamings (Aocount 439)
4 TOTAL Credib to Retained Eaminss (Account 439) (loohote details)43,925,664)8,16s,880)
5 TOTAL Debits to Retained Eamings (Account 439) (footnote details)
6 Balance Transfened from lncome (Acct 433 less Acct 418.1 )109,678,973 106,483,594
7 Aoorooriations of Retained Eaminos (Account 436)
I TOTAL Appropriations of Retained Eamings (Account 436) (footnote details)
9 Dividends Dedared-Prefened Stock (Account 437)
10 TOTAL Dividends Declared-Prefened Stock (Account 437) (footnote details)
11 Divklends Declared-Common Stock (Account 438)
12 TOTAL Dividends Declared{ommon Stoc* (Account 438) (footnote details)78.313.788 73.276.102
13 Transfers from Account 216.1, Unappropriated Undistibuted Subsidiary Earnings 102,252,013 2,114,557
14 Balance-End of Period (Total of lines 1, 4, 5, 6, 8, 10, 12, and 1 3)492,987,406 403,295,E72
15 APPROPRIATED RETAINED EARNINGS (Aocount 215)
16 TOTAL Appropriated Retained Eaminss (Account 215) (footnote details)
-
14.269.7ss 9.714.00'l
17 APPROPRIATED RETAINED EARNINGS-AMORTIZATION RESERVE, FEDERAL (Account
18 TOTAL Appropriated Retained Eaminqs-Amortization Reserve, Federal (Account
19 TOTAL Appropriated Retained Eamings (Accounts 215,215.1) (Total of lines 14,269,755 9,714,001
20 TOTAL Retained Eaminqs (Accounb 215, 215.1,216) fiotal of lines 14 and 1 507.257.',161 413.009,873
21 UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account 2'16.1 )
Report only on an Annual Basis no Quarterly
22 Balance-Beginning of Year (Debit or Credit)( 5,918,024)( 747,3371
23 Equity in Eaminqs for Year (Credit) (Account 418.1)82,361,715 4,593,239
24 (Less) Dividends Received (Debit]
25 Other Chanqes (Explain)92.102.2441 9,763,926)
26 Balance-End of Year ( 15,658,553)5,918,024)
FERC FORM NO. 2 (REV 0644)Page 118-119
This Page Intentionally Left Blank
Name oI Kesponoent
Avista Corporation
This Reoort ls:(1) fiAn original(2) l-lA Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End ot 20141Q4
Statement of Cash Flows
(1) Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long-term debt; (c) lnclude commercial paper; and (d) ldentify
separately such items as investments, fixed assets, intangibles, etc.
(2) lnformation 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: lnclude 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) lnvesting Ac{ivities: lnclude 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
lnstruction 20; instead provide a reconciliation of the dollar amount of leases capitalized with the plant cost.
rlll€Description (See lnstructions for explanation of codes)Current Year
to Date
QuarterfYear
Previous Year
to Date
QuarterA/ear
No.
(a)
1 Net Cash Flow from Operating Activities
2 Net lncome (Line 78(c) on page 1 16)192,040,688 111,076,833
3 Noncash Charges (Credits) to lncome:
4 Depreciation and Depletion 126.986.417 1't7.173,574
5 Amortization of defened power and gas msts, debt expense and exchange power ( 8,s25,668)( s,144,520)
6 Defened lncome Taxes (Net)123,968,809 20,846,650
7 lnvestrnent Tax Credit Adjustments (Net)( 229,5241 ( 226,027)
8 Net (lncrease) Decrease in Receivables 17,645,850 ( 30,s23,370)
I Net (lnoease) Decrease in lnventory ( 't9,413,226)2,417,981
10 Net (lncrease) Decrease in Allowances lnventory
11 Net lncrease (Decrease) in Payables and Accrued Expenses ( 40,1 91 ,'l 1 6)( 4,903,140)
12 Net (lncrease) Decrease in Oher Regulatory Assets 10,925,414 (899,982)
13 Net lncrease (Decrease) in Other Regulatory Liabilities 4,616,847 7,774,282
1A (Less) Allowance for Other Funds Used During Construction 8,678,360 6,065,628
15 (Less) Undistributed Eamings from Subsidiary Companies 82,361 ,715 4,593,239
16 Oher (footnote details):|ffiffi,ff{&ffi&ffilF
17 Net Cash Provided by (Used in) Operating Activities
18 (Total of Lines 2 thru '16)283,517,112 204,052,587
19
20 Cash Flows from lnvestment Aclivities:
2',1 Construction and Aquisition of Plant (including land):
22 Gross Additions to Utility Plant (less nuclear fuel)( 323,931,1s2)( 294,363,192)
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 Cash Outllows for Plant ffotal of lines22hru27\( 323,931,192)( 294,363,192)
29
30 Aquisition of Other Noncxtnent Assets (d)
31 Proceeds from Disposal of Noncurrent Assets (d)
2a Federal grant payments received 2,529,902 3,409,479
33 lnvestments in and Advances to Assoc. and Subsidiary Companies ( 4,891,325)
34 Contributions and Advances from Assoc. and Subsidiary Companies
35 Disposition of lnvestments in (and Advances to)
36 Associated and Subsidiary Companies
37 Cash paid for acquisition ( 4,697,090)
38 Purchase of lnvestment Securities (a)
39 Proceeds from Sales of lnvestment Securities (a)
FERC FORM NO.2 (REV 06-04)Page 120
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn Originat(2\ [-lA Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End of 2014/Q4
Statement of Gash Flows (continued)
Line
No.
Description (See lnstructions for explanation of codes)
(a)
Current Year
to Date
Quarter/Year
Previous Year
to Date
Quarterf/ear
40 Loans Made or Purchased
41 Colledions on Loans
42 Reskicted cash 94,098 481 ,170
43 Net (lncrease) Decrease in Receivables
44 Net (lncrease) Decrease in lnventory
45 Net (lncrease) Decrease in Allowances Held for Speculation
46 Net lncrease (Decrease) in Payables and Accrued Expenses
47 Changes in other property and investments ( 373,865)6,'167
48 Net Cash Provided by (Used in) lnvesting Activities
49 (Total of lines 28 thru 47)( 1 13,933,76e)( 295,357,701)
50
51 Cash Flows from Financing Activities:
52 Proceeds from lssuance of:
E2 Long-Term Debt (b)60,000,000 90.000.000
54 Prefened Stock
55 Common Stock 4,059,874 4,609,006
56 Other (footnote details):
57 Net lncrease in Short{erm Debt (c)
58 Cash received for settlement of interest rate swap agreements 5,429,000
59 Cash Provided by Outside Sources (Total of lines 53 thru 58)69,488,874 94,609,006
60
61 Paymenb for Retirement of:
dt Long-Term Debt (b)( 297,339)( 50,258,s86)
63 Prelened Stock
64 Common Stock ( 79,8s5,898)
65 Other ( 1 ,403,51 1)2,369,386
bb Net Decrease in Short-Term Debt (c)( 66,000,000)'| 19,000,000
67 Premium paid to repurchase long-term debl
68 Dividends on Prefened Stock
69 Dividends on Common Stock ( 78,313,788)( 73,276,102)
70 Net Cash Provided by (Used in) Financing Activities
71 (Total ol lines 59 thru 69)( 156,381 ,662)92,443,704
72
73 Net lncrease (Decrease) in Cash and Cash Equivalents
74 (Total of line 18, 49 and 7'l)13.201,681 1 ,1 38,590
75
76 Cash and Cash Equivalents at Beginning of Period 4,813,561 3,674,971
77
78 Cash and Cash Equivalents at End of Period 18,O15,242 4,813,561
FERC FORM NO.2 (REV 06-04)Page 120a
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t201'5
Year/Period of Report
2014tQ4
FOOTNOTE DATA
Change in other non-current assets and liabilities (7,470,522)
Power and naturalgas deferrals
Change in special deposits
Change in other current assets
Non-cash stock com pensation
Cash paid for foreign currency hedges
Allowance for doubtful accounts
Write-off of Reardan wind generation assets
Change in Coyote Springs 2 O&M LTSA
Power and natural gas deferrals
Change in special deposits
Change in other current assets
Non-cash stock compensation
Cash paid for foreign currency hedges
Allowance for doubtful accounts
Change in Coyote Springs 2 O&M LTSA
Prelim survey and investigation costs
Tax shortfalls from stock compensation
1,284,946
(16,072,800)
7,300,101
5,036,659
(30,270)
4,792,409
2,533,578
(1,376,514)
1,104,752
(23,301,320)
(5,671,849)
6,006,850
20,692
5,200,000
(1,082,230)
709,287
(513.385)
Prelim survev rnd inu
€Sne{glg ?pge!129__Line No.: 16 Column: b
Change in other non+urrent assets and liabilities (15,740,101)
'Scniaiie Pig Lii; N-o.: u cotumn: b
--
Notesreceivablefromsubsidiaries 15,444,378
Dividends received from subsidiaries 197,000,000
FERC FORM NO.2 552.1
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
20141Q4
Notes to Financial Statements
1. Provide important disclosures regarding the Balance Sheet, Statement of lncome 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 ac{ion initiated by the lnternal
Revenue Service involving possible assessment of additional income taxes of material amount, or a claim for refund of income taxes of a
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
as required by instruction no. 1 and, in addition, disclose for each individual plan the current yea/s cash contributions. Furnish details on
accounting for the plans and any changes in the method of accounting for them. lnclude details on the accounting for transition obligations
assets, gains or losses, the amounts deferred and the expected recovery periods. Also, disclose any current yea/s plan or trust curtailments,
transfers, or reversions of assets. Entities that participate in multiemployer postretirement benefit plans (e.9. parent company
sponsored pension plans) disclose in addition to the required disclosures for the consolidated plan, (1) the amount of cost recognized in the
respondent's financial statements for each plan for the period presented, and (2) the basis for determining the respondent's share of the total
plan costs.
4, Furnish details on the respondent's asset retirement obligations (ARO) as required by instruction no. 'l and, in addition, disclose the
recovered through rates to settle such obligations. ldentify 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. lnclude 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 1 89, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an
providing the rate treatment given these item. See General lnstruction 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
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
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 orgas purchases, and summarize the adjustments made to balance sheet, income, and
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
capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from
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 I. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Nature of Business
Avista Corporation (Avista Corp. or 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 Avista Corp.'s Noxon Rapids generating facility.
On July 1,2014, Avista Corp, completed its acquisition of Alaska Energy and Resources Company (AERC), and as of that date, AERC
FERC FORM NO. 2/3-Q (REV I 122.',|
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512015
Year/Period of Report
20141Q4
Notes to Financial Statements
is a wholly-owned subsidiary of Avista Corp. The primary subsidiary of AERC is Alaska Electric Light and Power Company
(AEL&P), comprising the regulated utility operations in Alaska. The results of AERC for only the flrnal six months of 2014 are
included in the overall results of Avista Corp. See Note 3 for information regarding the acquisition of AERC.
Avista Capital, Inc. (Avista Capital), a wholly owned subsidiary of Avista Corp., is the parent company of all of the subsidiary
companies, except Spokane Energy, LLC (Spokane Energy). During the first half of the year, Avista Capital's subsidiaries included
Ecova, Inc. (Ecova), which was an 80.2 percent owned subsidiary prior to its disposition on June 30,2014. Ecova was a provider of
energy efficiency and other facility information and cost management programs and services for multi-site customers and utilities
throughout North America. See Note 4 for information regarding the disposition of Ecova.
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 tlre 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) defened income taxes and (6) comprehensive
income.
Use of Estimates
The preparation of the financial statements in conformity with accounting principles generally accepted in the United States of
America (GAAP) requires management to make estimates and assumptions that affect the amounts reported for assets and liabilities
and the disclosure ofcontingent assets and liabilities at the date ofthe financial statements and the reported amounts ofrevenues and
expenses during the reporting period. Significant estimates include:
determining the market value of energy commodity derivative assets and liabilities,
pension and other postretirement benefit plan obligations,
contingent liabilities,
goodwi ll impairment testing,
. recoverability ofregulatory assets, and
r 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 rvith the uniform system of accounts
prescribed by the Federal Energy Regulatory Commission (FERC) and adopted by the state regulatory commissions in Washington,
Idaho, Montana, Oregon and Alaska.
Regulation
FERC FORM NO.2/3-Q 1 122.2
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512015
Year/Period of Report
2014tQ4
Notes to Financial Statements
The Company is subject to state regulation in Washington, Idaho, Montana, Oregon and Alrcka. 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.
Operating Revenues
Operating revenues related to the sale ofenerry are recorded when service is rendered or energy is delivered to customers. The
determination of the energy sales to individual customers is based on the reading of their meters, which occurs on a systematic basis
throughout the month. At the end of each calendar month, the amount of enerry delivered to customers since the date of the last meter
reading is estimated and the conesponding unbilled revenue is estimated and recorded. Our estimate of unbilled revenue is based on:
o the number of customers,
. cturent rates,
o meter reading dates,
. actual native load for electricity, and
. actual throughput for natural gas.
Any difference between actual and estimated revenue is automatically corrected in the following month when tlre actual meter reading
and customer billing occurs.
Accounts receivable includes unbilled energy revenues of the following amounts as of December 3 I (dollars in thousands):
2014 2013
Unbilled accounts receivable S 78,077 $ 81,059
Advertising Expenses
The Company expenses advertising costs as incurred. Advertising expenses were not a material portion of the Company's operating
expenses in2014 and 2013.
Depreciation
For utility operations, depreciation expense is estimated by a method of depreciation accounting utilizing composite rates for utility
plant. Such rates are designed to provide for retirements ofproperties at the expiration oftheir service lives. For utility operations, the
ratio of depreciation provisions to average depreciable propeay was as follows for the years ended December 3l:
2014 2013
Ratio of depreciation to average depreciable property 2.97% 2.90%
The average service lives for the following broad categories ofutility plant in service are (in years):
Avista Corp.
Electric thermaVother production 40
Hydroelectric production 79
Electric transmission 58
Electric distribution 35
Natural gas distribution properfy 46
Taxes Other Than Income Taxes
FERC FORM NO.2/3-Q 122.3
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
20141Q4
Notes to Financial Statements
Taxes other than income taxes include state excise taxes, city occupational and franchise taxes, real and personal property taxes and
certain other taxes not based on net income. These taxes are generally based on revenues or the value ofproperty. Utility related taxes
collected from customers (primarily state excise taxes and city utility taxes) are recorded as operating revenue and expense and totaled
the following amounts for the years ended December 31 (dollars in thousands):
2014 2013
Utility taxes 57,599 $55,565
Allowancefor Funds Used During Construction
The Allowance for Funds Used During Construction (AFUDC) represents the cost of both the debt and equity funds used to furance
utility plant additions during the construction period. As prescribed by regulatory authorities, AFUDC is capitalized as a part of the
cost of utility plant and the debt related portion is credited against total interest expense in the Statements of Income. The Company is
permitted, under established regulatory rate practices, to recover the capitalized AFUDC, and a reasonable retum thereon, through its
inclusion in rate base and the provision for depreciation after the related utility plant is placcd 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 effective AFUDC rate was the
following for the years ended December 31:
2014 2013
Effective AFUDC rate 7.640 7.64%
Income Taxes
A deferred income tax asset or liability is determined based on the enacted tax rates that will be in effect when the differences between
the financial statement carrying amounts and tax basis of existing assets and liabilities are expected to be reported in the Company's
consolidated 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. Deferred income tax liabilities and regulatory assets are
established for income tax benefits flowed through to customers as prescribed by the respective regulatory commissions.
Stock- B ased Compensation
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. See Note l6 for further information.
Cosh 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.
A llow ance fo r Do ubtful A cco unts
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.
Ufifiry Plant in Service
The cost of additions to utility plant in service, including an allowance for funds used during construction 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
FERC FORM NO.2/3-Q 12 122.4
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
20141Q4
Notes to Financial Statements
charged to accumulated depreciation.
Derivative Assets and Liabilities
Derivatives are recorded as either assets or liabilities on the Balance Sheets measured at estimated fair value. In certain defined
conditions, a derivative may be specifically desigaated as a hedge for a particular exposure. The accounting for a derivative depends
on the intended use ofsuch derivative and the resulting designation.
The UTC and the IPUC issued accounting orders authorizing Avista Corp. to offset energy commodity derivative assets or liabilities
with a regulatory asset or liabiliry. This accounting treafrnent is intended to defer the recognition of mark-to-market gains and losses on
energy commodity transactions until the period of delivery, The orders provide for Avista Corp. to not recognize the unrealized gain or
loss on utility derivative commodity instruments in the Statements of Income. Realized gains or losses are recognized in the periods of
delivery, subject to approval for recovery through retail rates. Realized gains and losses, subject to regulatory approval, result in
adjustments to retail rates through purchased gas cost adjustments, the ERM in Washington, the PCA mechanism in Idaho, and
periodic general rates cases. Regulatory assets are assessed regularly and are probable for 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 ofthe contract that is determined to be
other-than-temporary.
For interest rate swap agreements, each period Avista Corp. records all mark-to-market gains and losses as assets and liabilities and
records offsetting regulatory assets and liabilities, such that there is no income statement impact. This is similar to the treatment of
energy commodity derivatives described above. Upon settlement of interest rate swaps, the regulatory asset or liability (included as
part oflong-term debt) is amortized as a component ofinterest expense over the term ofthe associated debt.
Fair Value Measurements
Fair value represents the price that would be received to sell an asset or paid to transfer a liability (an exit price) in an orderly
transaction between market participants at the measurement date. Energy commodity derivative assets and liabilities, defened
compensation assets, as well as derivatives related to interest rate swap agreements and foreign currency exchange contracts, are
reported at estimated fair value on the Balance Sheets. See Note l4 for the Company's fair value disclosures.
Regulatory Deferred Chuges 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-parfy regulators,
o the regulated rates are designed to recover the cost ofproviding the regulated services, and
o 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 included 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. If at some point in the future the Company determines that it no longer meets the criteria for continued
application ofregulatory accounting practices for all or a portion ofits regulated operations, the Company could be:
o reguired to write offits regulatory assets, and
FERC FORM NO.2/3.Q 12-O7l 122.5
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
20141Q4
Notes to Financial Statements
. precluded from the future defenal of costs not recovered through rates at the time such costs are incurred, even if the
Company expected to recover such costs in the future.
See Note l9 for further details of regulatory assets and liabilities.
Investment in Exchange Power-Net
The investment in exchange power represents the Company's previous investment in Washinglon Public Power Supply System Project
3 (WNP-3), a nuclear project that was terminated prior to completion. Under a settlement agreement with the Bonneville Power
Administration in 1985, Avista Corp. began receiving power in 1987, for a32.5-year period, related to its investment in WNP-3.
Through a settlement agreement with the UTC in the Washinglon jurisdiction, Avista Corp. is amortizing the recoverable portion of its
investment in WNP-3 (recorded as investment in exchange power) over a 32.5-year period that began in 1987. For the Idaho
jurisdiction, Avista Corp. fully amortized the recoverable portion of its invesfinent in exchange power.
U n amo rtized D e bt Exp ens e
Unamortized debt expense includes debt issuance costs that are amortized over the life of the related debt.
Unamortlzed Loss on Reacquired Debt
For the Company's Washington regulatory jurisdiction and for any debt repurchases beginning in 2007 in all jurisdictions, premiums
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 costs are amortized over the life of the new debt. In the Company's other regulatory
jurisdictions, premiums paid to repurchase debt prior to2007 are being amortized over the average remaining maturity of outstanding
debt when no new debt was issued in connection with the debt repurchase. These costs are recovered through retail rates as a
component of interest expense.
App ropriated Relain ed Earnings
In accordance with the hydroelectric licensing requirements of section 1 0(d) of the Federal Power Act (FPA), the Company maintains
an appropriated retained eamings 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. The rate ofreturn on investment is specified in the various hydroelectric licensing
agreements for the Clark Fork River and Spokane River. 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 typically calculates the eamings in
excess ofthe specified rate ofreturn on an annual basis, usually during the second quarter.
The appropriated retained earnings amounts included in retained eamings were as follows as of December 3l (dollars in thousands):
2014 2013
Appropriated retained earnings $ 14,270 $ 9,714
Operating Leases
The Company has multiple lease arrangements involving various assets, with minimum terms ranging from I to forty-five years. Future
minimum lease payments required under operating leases having initial or remaining noncancelable lease terms in excess of one year
were not material as of December31,2014.
Equity in Earnings of Subsidiaries
FERC FORM NO. 2/3-Q (REV 1 122.6
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
20141Q4
Notes to Financial Statements
The Company records all the earnings from its subsidiaries under the equity method. The Company had the following equity in
earnings of its subsidiaries for the years ended December 3l (dollars in thousands):
2014
$ ?9,183
3,179
20t3
Avista Capital
Alaska Energy and Resources Company
Total equify in earnings of subsidiary companies
4,593
82,362 S 4,593
Avista Capital, a wholly owned subsidiary of Avista Corp., is the parent company of all of the subsidiary companies, except Spokane
Energy and AERC (and its subsidiaries). Avista Capital's subsidiaries and investrnents include sheet metal fabrication, venture fund
investments, real estate investments and Ecova prior to its disposition on June 30,2014.
AERC, a wholly-owned subsidiary of Avista Corp. acquired on July 1,2014, is the parent company to all the Alaska subsidiary
companies. The primary subsidiary of AERC is AEL&P, comprising the regulated utility operations in Alaska. Also, AERC owns AJT
Mining Properties, Inc., an inactive mining company holding certain properties.
Subsequenl Events
Management has evaluated the impact of events occurring after December 31,2014 up to February 25,2015, the date that Avista
Corp.'s U.S. GAAP financial statements were issued and has updated such evaluation for disclosure purposes through April 15, 2015.
These financial statements include all necessary adjustments and disclosures resulting from these evaluations.
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 losses that do not meet these conditions for accrual, if there is a reasonable possibility that a material loss
may be incurred. See Note 17 for further discussion of the Company's commitments and contingencies.
NOTE 2. NEW ACCOUNTING STANDARDS
In May 2074, theFASB issued ASU No. 2Ol4-Og, "Revenue from Contracts with Customers (Topic 606)," which outlines a single
comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current
revenue recognition guidance, including industry-specific guidance. The core principle of the revenue model is that an entity identifies
the various performance obligations in a contract, allocates the transaction price among the performance obligations and recognizes
revenue as the entify satisfies the performance obligations. This ASU is effective for periods beginning after December 15, 2016 and
early adoption is not permitted. However, while this ASU is not effective until 2017, it will require retroactive application to all
periods presented in the financial statements. As such, at adoption in 2017 , amounts in 201 5 and 20 l6 may have to be revised or a
cumulative adjustment to opening retained earnings may have to be recorded. The Company is evaluating this standard and cannot, at
this time, estimate the potential impact to its future financial condition, results of operations and cash flows.
In August 2014,the FASB issued ASU No. 2014-15, "Presentation of Financial Statements - Going Concem (ASC Subtopic
205-40): Disclosure of Uncertainties about an Entity's Ability to Continue as a Going Concem." The new standard provides guidance
around management's responsibility to evaluate whether there is substantial doubt about an entity's ability to continue as a going
concern within one year of the date the financial statements are issued. The Company must provide certain disclosures if conditions or
events raise substantial doubt about the Company's ability to continue as a going concern. The new standard is effective for periods
FERC FORM NO.2/3-Q v 12-A7 122.7
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
beginning after December 15,2016i however, early adoption is permitted. The Company evaluated this standard and determined that it
will not early adopt this standard. As such, there is no impact to the Company's financial condition, results of operations and cash flows
in the current year.
NOTE 3. BUSTNESS ACQUTSTTTONS
Alasks Energy and Resources Company
On July 1,2014, the Company completed its acquisition of AERC, based in Juneau, Alaska. As of July 1,2014 AERC is a
wholly-owned subsidiary of Avista Corp.
The primary subsidiary of AERC is AEL&P, a regulated utility which provides electric services to 16,394 customers in the City and
Borough of Juneau, Alaska. As ofDecember 31, 2014, AEL&P has 59 full-time employees. AEL&P has a firm retailpeak load of
approximately 68 MW. AEL&P owns four hydroelectric generating facilities, having a total present capacity of 24.7 MW, and has a
power purchase commitment for the output of the Snettisham hydroelectric project, having a present capacity of 78 MW, for a total
hydroelectric capacity of 102.7 MW. AEL&P is not interconnected to any other electric system. AEL&P also has 93.9 MW of diesel
generating capacity to provide back-up service to firm customers when necessary.
In addition to the regulated utility, AERC owns AJT Mining, which is an inactive mining company holding certain properties.
The purpose of the acquisition was to expand and diversifr Avista Corp.'s energy assets and deliver long-term value to its customers,
communities and investors.
In connection with the closing, on July 1,2014 Avista Corp. issued 4,500,014 new shares of common stock to the shareholders of
AERC based on a contractual formula that resulted in a price of $32.46 per share, reflecting a purchase price of $170.0 million, plus
acquired cash, less outstanding debt and other closing adjusfrnents.
The $32.46 price per share of Avista Corp. common stock was determined based on the average closing stock price of Avista Corp.
common stock for the I 0 consecutive trading days immediately preceding, but not including, the trading day prior to July 1 , 20 14. This
value was used solely for determining the number of shares to issue based on the adjusted contract closing price (see reconciliation
below). The fair value of the consideration transferred at the closing date was based on the,closing stock price of Avista Corp. common
stock on July l, 2014, which was $33,35 per share.
On October 1,2014, a working capital adjustment was made in accordance with the agreement and plan of merger which resulted in
Avista Corp. issuing an additional 1,427 shares of common stock to the shareholders of AERC. The number of shares issued on
October l, 2014 was based on the same contractual formula described above. The fair value of the new shares issued in October was
$30.71 per share, which was the closing stock price of Avista Corp. common stock on that date.
The contract acquisition price and the fair value of consideration transferred for AERC were as follows (in thousands, except "per
share" and number ofshares data):
July I , 2014
Contract acquisition price (using the calculated $32.46 per share common stock price)
Gross contract price
Acquired cash
Acquired debt (excluding capital lease obligation)
Other closing adjustments (including the working capital adjustment)
Total adjusted contract price
Fair value of consideration transferred
170,000
19,704
(3 8,832)
(s8)
150,814
FERC FORM NO. 2/3-Q (REV 12-07 122.8
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Avista Corp. common stock (4,500,014 shares at $33.35 per share)
Avista Corp. common stock (1,427 shares at $30.71 per share)
Cash
Fair value oftotal consideration transferred
150,075
44
4,697
154,816
The assets acquired and liabilities assumed related to the AERC transaction are not included in the FERC Balance Sheets. The
information below is presented for information purposes only. The estimated fair value of assets acquired and liabilities assumed as of
July l, 2014 (after consideration of the working capital adjustment) were as follows (in thousands):
July I,2014
Assets acquired:
Current Assets:
Cash
Accounts receivable - gross totals $3,928
Materials and supplies
Other current assets
Total current assets
Utility Property:
Utility plant in service
Utility properfy under long-term capital lease
Construction work in progress
Total utility property
Other Non-current Assets:
Non-utility property
Electric plant held for future use
Goodwill
Other deferred charges and non-current assets
Total other non-current assets
Total assets
Liabilities Assumed:
Current Liabilities:
Accounts payable
Current pordon oflong-term debt and capital lease obligations
Other current liabilities
Total current liabilities
Long-term debt
Capital lease obligations
Other non-current liabilities and deferred credits
Total liabilities
Total net assets acquired
19,704
3,851
2,017
999
26,57 |
113,964
71,007
3,440
188,411
6,660
3,711
52,730
5,368
68,469
283,451
700
3,773
2,902
7,375
37,227
68,840
I 5,1 93
128,635
154,816
The goodwill associated with this acquisition is not deductible for tax purposes.
The majority of AERC's operations are subject to the rate-setting authority of the RCA and are accounted for pursuant to GAAP,
including the accounting guidance forregulated operations. The rate-seffing and cost recovery provisions currently in place for
FERC FORM NO.2/3.Q 1 122.9
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2015
Year/Period of Report
2014tA4
Notes to Financial Statements
AERC's regulated operations provide revenues derived from costs, including a return on investment, of assets and liabilities included
in rate base. Due to this regulation, the fair values of AERC's assets and liabilities subject to these rate-setting provisions are assumed
to approximate their carrying values, There rvere not any identifiable intangible assets associated with this acquisition. The excess of
the purchase consideration over the estimated fair values of the assets acquired and liabilities assumed was recognized as goodwill at
the acquisition date. The goodwill reflects the value paid for the expected continued growth of a rate-regulated business located in a
defined service area with a constructive regulatory environment, the attractiveness of stable, growing cash flows, as well as providing a
platform for potential future growth outside of the rate-regulated electric utility in Alaska.
NOTE 4. DISCONTINUED OPERATIONS
On May 29,2074, Avista Capital, the non-regulated subsidiary of Avista Corp., entered into a definitive agreement to sell its interest in
Ecova to Cofely USA Inc., an indirect subsidiary of GDF SUEZ, a French multinational utility company, and an unrelated party to
Avista Corp. The sales transaction was completed on June 30,2014 for a sales price of $335.0 million in cash, less the payment of debt
and other customary closing adjustments. At the closing of the transaction on June 30, 2014, Ecova became a wholly-owned subsidiary
of Cofely USA Inc. and the Company will have no further involvement with Ecova after such date.
The purchase price of $335.0 million, as adjusted, was divided among the security holders of Ecova, including minority shareholders
and option holders, pro rata based on ownership. Approximately $16.8 million (5 percent of the purchase price) will be held in escrow
for l5 months from the closing of the transaction to satisfu certain indemnification obligations under the merger agreement. An
additional $1.0 million is being held in escrow pending resolution of adjustments to working capital, which is expected to be resolved
in early 2015.
Avista Capital and Cofely USA Inc. agreed to make an election under Section 338(hxl0) of the InternalRevenue Code (Code) of
1986, as amended, with respect to the purchase and sale of Ecova to allocate the merger consideration among the assets of Ecova
deemed to have been acquired in the merger.
WhEn all escrow amounts are released, the sales transaction is expected to provide cash proceeds to Avista Corp., net of debt, payment
to option and minority holders, income taxes and transaction expenses, of $143.5 million (see reconciliation below) and result in a net
gain of $69.7 million. The Company expects to receive the full amount of its portion of the remaining escrow accounts; therefore, these
amounts were included in the gain calculation.
The summary of cash proceeds associated with the sales transaction are as follows (in thousands):
Reconciliation of Gross Proceeds
Contract price
Closing adjustments
Gross proceeds from sale (l )
Cash sold in the transaction
Avista Corp. portion of proceeds held in escrow
Gross proceeds from sale ofEcova, net ofcash sold
Reconciliation of expected net proceeds
Gross proceeds from sale (l)
Repayment of long-term borrowings under committed line of credit
Payment to option holders and redeemable noncontrolling interests
Payment to noncontrolling interests
Transaction expenses withheld from proceeds
Avista Corp. portion of proceeds held in escrow
s 335,000
3,914
338,914
(95,932)
( 13,079)
229,903
338,914
(40,000)
(20,871)
(54,179)
(5,390)
( I 3,079)
FERC FORM NO. 2/3-Q (REV 12-07 122.10
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014to'4
Notes to Financial Statements
Net proceeds to Avista Capital at transaction closing
Tax payments made n2014
Estimated tax payments to be made in 2015
Avista Corp. portion of proceeds held in escrow to be received in the future
Total net proceeds related to sales transaction
205,395
(74,842)
(172)
13,079
$ 143,460
( I ) Of this total amount, approximately $ I 6.8 million will be held in escrow for I 5 months from the transaction closing date for any
indemnity claims and an additional $ I .0 million is being held in escrow pending resolution of adjustments to working capital,
which is expected to be resolved in early 2015.
NOTE 5. DERIVATIVES AND RISK MANAGEMENT
Energy Commodily Derivotives
Avista Corp. is exposed to market risks relating to changes in electricity and natural gas commodity prices and ceftain other fuel prices.
Market risk is, in general, the risk of fluctuation in the market price of the commodiry 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, swaps and options in order to manage the various risks relating to these
commodity price exposures. The Company has an energy resources risk policy and control procedures to manage these risks. The
Company's Risk Management Committee establishes the Company's energy resources risk policy and monitors compliance. The Risk
Management Commiffee is comprised of certain Company officers and other members of management. The Audit Committee of the
Company's Board of Directors periodically reviews and discusses enterprise risk management processes, and it focuses on the
Company's material financial and accounting risk exposures and the steps management has undertaken to control them.
As part of the Company'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 the
Company's load obligations and the use of these resources to capture available economic value. The Company transacts in wholesale
markets by selling and purchasing electric capacity and enerry, 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 the related financial
risks. These transactions range from terms of intra-hour up to multiple years.
Avista Corp. makes continuing projections of:
o electric loads at various points in time (ranging from intra-hour to multiple years) based on, among other things,
estimates of customer usage and weather, historical dak and contract terms, and
. resource availability at these points in time based on, among other things, fuel choices and fuel markets, estimates of
streamflows, availability of generating units, historic and forward market information, contract terms, and
experience.
On the basis of these projections, the Company makes purchases and sales of electric capacity and energy, fuel for electric generation,
and related derivative instruments to match expected resources to expected electric load requirements and reduce exposure to
electricify (or fuel) market price changes. Resource optimization involves generating plant dispatch and scheduling available resources
and also includes transactions such as:
r purchasing fuel for generation,
o when economical, selling fuel and substituting wholesale electric purchases, and
r other wholesale transactions to capture the value of generation and transmission resources and fuel delivery capacity
contracts.
FERC FORM NO,2/3-Q 1 122.1'l
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
0411512015
YeariPeriod of Report
2014tQ4
Notes to Financial Statements
Avista Corp.'s optimization process includes entering into hedging transactions to manage risks. Transactions include both physical
energy contracts and related derivative financial instruments.
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 disribution system. However, daily variations in natural gas demand can be significantly different than monthly
demand projections. On the basis ofthese projections, Avista Corp. plans and executes a series oftransactions to hedge a significant
portion of its projected natural gas requirements through forward market transactions and derivative instruments. These transactions
may extend as much as four natural gas operating years (November through October) into ttre future. Avista Corp. also leaves a
significant portion of its natural gas supply requirements unhedged for purchase in short-term and spot markets.
Natural gas resource optimization activities include:
o wholesale market sales of surplus natural gas supplies,
. optimization of interstate pipeline transportation capacity not needed to serve daily load, and
. purchases and sales of natural gas to optimize use of storage capacity.
The following table presents the underlying energy commodity derivative volumes as of December 31,2014 that are expected to be
settled in each respective year (in thousands of MWhs and mmBTUs):
Purchases
Electric Derivatives Gas Derivatives Electric Derivatives Gas Derivatives
Physical (l) Financial (l)
MWH MWH
Physical (l) Financial (I) Physical (l) Financial (l)
mmBTUs mmBTUs MWH MWH
Physical (l) Financial (l)
mmBTUs mmBTUsYear
2015
2016
2017
2018
2019
Thereafter
522 2,547 21,111 120,780 326
397 1,071 2,505 70,480 287
2,951 3,428 99,023
1,634 910 56,520
290 15,420
286
158
397
397
235
675 24,230 286
3,020
1,900
(l ) Physical transactions represent commodity transactions where Avista Corp. will take delivery of either electricity or natural gas
and financial transactions represent derivative instruments with no physical delivery, such as futures, swaps or options.
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 settled and will be included in the various 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 Exch ange Controcts
A significant poftion 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 hansportation 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 contracts
when such commodity transactions are initiated. This risk has not had a material effect on the Company's financial condition, results of
operations or cash flows and these differences in cost related to currency fluctuations were included with natural gas supply costs for
FERC FORM NO.2/3.Q 124 122.12
Name of Respondent
Avista Comoration
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
0/.t15t2015
YeariPeriod of Report
2014tQ4
Notes to Financial Statements
ratemaking. The following table summarizes the foreign currency hedges that the Company has entered into as of December 31
(dollars in thousands):
2014 2013
Number of contracts
Notional amount (in United States dollars)
Notional amount (in Canadian dollars)
Balance Sheet Date
18 23
5,474 S 8,631
6,198 9,191
Mandatory Cash Seftlement
Number of Contracts Notional Amount Date
Interesl Rate Swap Agreements
Avista Corp. is affected by fluctuating interest rates related to a portion of its existing debt, and future borrowing requirements. The
Finance Committee of the Board of Directors periodically reviews and discusses interest rate risk management processes, and it
focuses on the steps management has undertaken to manage it. The Risk Management Committee also reviews the interest risk
management plan. Avista Corp. manages interest rate exposure by limiting the variable rate exposures to a percentage of total
capitalization. Additionally, interest rate risk is managed by monitoring market conditions when timing the issuance of long-term debt
and optional debt redemptions and through the use of fixed rate long-term debt with varying maturities. The Company also hedges a
portion of its interest rate risk with financial derivative instruments, which may include interest rate swaps and U.S. Treasury lock
agreements. These interest rate swaps and U.S. Treasury lock agreements are considered economic hedges against fluctuations in
future cash flows associated with anticipated debt issuances.
The following table summarizes the interest rate swaps that the Company has outstanding as of the balance sheet date indicated below
(dollars in thousands):
December 31 ,2014 5 S 75,000
5 95,000
3 45,000
9 205,000
2015
2016
20t7
201 8
December 31, 2013 2
2
2
I
4
50,000
45,000
40,000
15,000
95,000
2014
2015
2016
2017
2018
In October 2014, the Company cash settled two interest rate swap contracts (notional aggregate amount of $50.0 million) and received
a total of $5.4 million. The interest rate swap contracts were settled in connection with the pricing of $60.0 million of Avista Corp. first
mortgage bonds that were issued in December 20 I 4 (see Note l2). Upon settlement of interest rate swaps, the regulatory asset or
liability (included as part of long-term debt) is amortized as a component of interest expense over the term of the associated debt.
As of December 31, 2014, the fair value of the outstanding interest rate swaps decreased significantly compared to December 31,2013
(see the table below). The fair value decrease was the result of a net increase in the notional amount of outstanding swap agreements
and a decline in market interest rates below the rates that were fixed in the outstanding swaps. The Company enters into interest rate
swaps to reduce uncertainty related to the net effective interest cost for future long-term debt. The Company would be required to make
cash payments to settle the interest rate swaps if the fixed rates are higher than prevailing market rates at the date of settlement.
Conversely, the Company receives cash to seffle its interest rate swaps when prevailing market rates at the time of settlement exceed
the fixed swap rates.
Summary of Outstanding Derivative Instruments
FERC FORM NO.2/3-Q 't2-07 122.13
Name of Respondent
Avista Corooration
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2415
Year/Period of Report
2014tQ4
Notes to Financial Statements
Until May 2014, Avista Corp. had a master netting agreement that governed the transactions of multiple affiliated legal entities that
were parties to this agreement, This master netting agreement allowed for cross-commodity netting (i,e. neuing physical power,
physical natural gas, and financial transactions) and cross-affiliate netting for the parties to the agreement. Avista Corp. performed
cross-corrmodity netting for each legal entity that was a party to the master netting agreement for presentation in the Balance Sheets;
however, Avista Corp. did not perform cross-affiliate netting because the Company believed that cross-affiliate netting may not be
enforceable. Therefore, the requirements for cross-afiiliate netting under ASC 210-20-45 were not applicable to Avista Corp. As of
December 31,2013, all derivatives for each affiliated entity under this master netting agreement were in a net liability position;
therefore, there was no additional netting which required disclosure for the year 2013 . In May 20 14, this master netting agreement was
terminated and each affiliated legal entity is now under their own separate agreement. As of December 3 I , 20 I 4, the Company no
longer has any agreements that allow cross-affiliate netting. The Company has multiple agreements with a variety of entities that allow
for cross-commodity netting under ASC 8 1 5- I 0-45. The amounts recorded on the Balance Sheet as of Decemb er 37 , 2074 and 20 I 3
for these particular entities reflect the offsetting ofderivative assets and liabilities where a legal right ofoffset exists.
The following table presents the fair values and locations of derivative instruments recorded on the Balance Sheet as of December 31,
2014 (in thousands):
Fair Value
Net Asset
(Liability)
in Balance Sheet
Derivative insffument liabilities -Hedges $
Derivative instrument assets -Hedges
Derivative instrument liabilities -Hedges
Long-term portion of derivative liabilities -
Hedges
Derivative instrument assets current
Long-term portion of derivative assets
Long-term portion of derivative liabilities
Total derivative instruments recorded on the balance sheet $ 99,045 $ (229,790)44,390 $(86,355)
The following table presents the fair values and locations of derivative instruments recorded on the Balance Sheet as of December 31,
2013 (in thousands):
Fair Value
Net Asset
(Liability)
in Balance Sheet
Collateral
Derivative Balance Sheet Location
Foreign currency
contracts
lnterest rate
conkacts
Interest rate
contracts
Interest rate
contracts
Commodity
contracts
Commodity
contracts
Commodity
contracts
2,063
66,421
29,594
(21) $
(s06)
(7,325)
(69,737)
(s38)
(97,586)
(54,077)
-$
28,880
1 3,1 20
2,390
(20)
460
(7,325)
(40,857)
1,525
(l 8,045)
(22,093)
966
Collateral
Derivative Balance Sheet Location
Foreig-lr currency
contracts
Interest rate
contracts
Interest rate
contracts
Commodity
contracts
Derivative instrument assets -Hedges $
Derivative instrument assets -Hedges
Long-term portion of derivative instrument
assets -Hedges
Derivative instrument assets current
$ (6)$ -$-
13,968
19,575
7
13,968
19,57 5
7,416 (4,394)3,022
FERC FORM NO.2/3-Q 1 122.14
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Commodity
contracts
Commodity
contracts
Commodity
contracts
Long-term portion of derivative assets
Derivative instrument liabilities current
Long-term portion of derivative liabilities
7,610
23,455
17,101
(6,7 56)
(37,306)
(41,213)
854
(10,875)
(t 8,356)
2,976
5,756
Total derivative instruments recorded on the balance sheet $ 8X13' 5re^6?'8,732 $8,1 89
Exposure to Demandsfor Collateral
The Company'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 the Company's credit
ratings or changes in market prices. In periods of price volatility, the level of exposure can change significantly. As a result, sudden
and significant demands may be made against the Company's credit facilities and cash, The Company actively monitors the exposure to
possible collateral calls and takes steps to mitigate capital requirements. As of December 3 I , 20 14, the Companl, had cash deposited as
collateral of $20.6 million and letters of credit of $14.5 million outstanding related to its energy derivative contracts. The Company
also had deposited cash in the amount of $28.9 million and letters of credit of $10.9 million as collateral for its interest rate swap
derivative contracts. The Balance Sheet at December 31,2014 reflects the offsetting of $44.4 million of cash collateml against net
derivative positions where a legal right of offset exists. As of December 3 I , 20 I 3, the Company had cash deposited as collateral of
$26.I million and letters of credit of $20.3 million outstanding related to its energy derivative contracts. The Balance Sheet at
December 31, 2013 reflects the offsetting of $8.7 million of cash collateral against net derivative positions where a legal right of offset
exists. As of December 31,2014 and December 31, 2013, the Company did not hold any cash as collateral from counterparties under
energy derivative contracts.
Certain of the Company's derivative instruments contain provisions that require the Company to maintain an "investment grade" credit
rating from the major credit rating agencies. If the Company'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 aggregate fair value of all derivative
instruments with credit-risk-related contingent features that were in a liability position as of December 31,2014 was $12.9 million. If
the credit-risk-related contingent features underlying these agreements were triggered on December 31,2014, the Company could be
required to post $16.2 million of additional collateral to its counterparties. The aggregate fair value of all derivative instruments with
credit-risk-related contingent features that were in a liability position as of December 31,2013 was $13.3 million. If the
credit-risk-related contingent features underlying these agreements had been triggered on December 31, 2013, the Company could
have been required to post $12.6 million of additionalcollateral to its counterparties.
Credit Risk
Credit risk relates to the potential losses that the Company would incur as a result of non-performance by counterparties of their
contractual obligations to deliver energy or make financial settlements. The Company often extends credit to counterparties and
customers and is exposed to the risk that it may not be able to collect amounts owed to the Company. Credit risk includes potential
counterparfy default due to circumstances:
o relating directly to it,
. caused by market price changes, and
o relating to other market participants that have a direct or indirect relationship with such counterparty.
Changes in market prices may dramatically alter the size of credit risk with counterparties, even when conservative credit limits are
FERC FORM NO. 2/3-O 12-071 122.15
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
established. Should a counterparty fail to perform, the Company may be required to honor the underlying commiunent or to replace
existing contracts with contracts at then-current market prices.
The Company enters into bilateral transactions with various counterparlies. The Company also trades energy and related derivative
instruments through clearinghouse exchanges.
The Company seeks to mitigate bilateral credit risk by:
. entering into bilateral contracts that specify credit terms and protections against default,
. applying credit limits and duration criteria to existing and prospective counterparties,
o actively monitoring current credit exposures,
. asserting our collateral rights with counterparties,
. carrying out transaction settlements timely and effectively, and
r conducting transactions on exchanges with fully collateralized clearing arrangements that significantly reduc.e
counterparty default risk.
The Company's credit policy includes an evaluation of the financial condition of counterparties. Credit risk management includes
collateral requirements or other credit enhancements, such as letters of credit or parent company guarantees. The Company enters into
various agreements that address credit risks including standardized agreements that allow for the netting or offsetting of positive and
negative exposures.
The Company has concentrations of suppliers and customers in the electric and natural gas industries including:
. electric and natural gas utilities,
. electric generators and transmission providers,
e natural gas producers and pipelines,
o financial institutions including commodiry clearing exchanges and related parties, and
. energy marketing and trading companies.
In addition, the Company has concentrations of credit risk related to geographic location as it operates in the western United States and
western Canada. These concentrations of counterparties and concentrations of geographic location may impact the Company's overall
exposure to credit risk because the counterparties may be similarly affected by changes in conditions.
The Company maintains credit support agreements with certain counterparties and margin calls are periodically made and/or received.
Margin calls are triggered when exposures exceed contractual limits or when there are changes in a counterparty's creditworthiness.
Price movements in electricity and natural gas can generate exposure levels in excess of these contractual limits. Negotiating for
collateral in the form of cash, letters of credit, or performance guarantees is common industry practice.
NOTE 6. JOINTLY OWNED ELECTRIC FACILITIES
The Company has a l5 percent ownership interest in a twin-unit coal-fred generating facility, the Colstrip Generating Project
(Colstrip) Iocated in southeastem Montana, and provides financing for its ownership interest in the project. The Company's share of
related fuel costs as well as operating expenses for plant in service are included in the corresponding accounts in the Statements of
Income. The Company's share of utility plant in service for Colstrip and accumulated depreciation were as follows as of December 3l
FERC FORM NO.2/3-Q 1 122.16
Name of Respondent
Avista Comoration
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4115t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
(dollars in thousands):
Utility plant in service
Accumulated depreciation
Asset retirement obligation at beginning of year
Liability settled
Accretion expense (income)
Asset retirement obligation at end of year
2014 2013
$ 350,518 $ 349,781
(239,845) (239,538)
NOTE 7. ASSET RETIREMENT OBLIGATIONS
The Company records the fair value of a liability for an asset retirement obligation (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 longJived
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. Upon retirement of the asset, the Company either settles the ARO for its recorded amount or incurs a gain or loss. 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. The regulatory assets do not earn a
rehrm.
Specifically, the Company has recorded liabilities for future asset retirement obligations to:
. restore ponds at Colstrip,
. cap a landfill at the Kettle Falls Plant,
. remove plant and restore the land at the Coyote Springs 2 site at the termination of the land lease,
. remove asbestos at the corporate office building, and
. dispose of PCBs in certain transformers.
Due to an inability to estimate a range of settlement dates, the Company cannot estimate a Iiability for the:
. removal and disposal of certain transmission and distribution assets, and
. abandonment and decommissioning of certain hydroelectric generation and natural gas storage facilities.
The following table documents the changes in the Company's asset retirement obligation during the years ended December 3l (dollars
in thousands):
2014 2013
$ 2,859 $ 3,168
(41) (263)
2to (46)
$ 3,028 $ 2,8s9
In addition to the AROs described above, on December 19,2014, the EPA issued its pre-publication version of a final rule regarding
the disposal of coal ash. This rule is expected to be published in the Federal Register in early 201 5 and the rule is not effective until six
months after it is published in the Federal Register; therefore, the Company does not have a revised legal obligation until the third
quarter of 20 I 5 when the rule is effective. The Company will continue to review the potential costs of complying with the new coal ash
rule and its impacts on the valuation of the Company's ARO at Colstrip to restore ponds to their original states. The Company cannot
currently estimate the cost impact of future regulation. If the Company incurs incremental costs as a result of these regulations, it would
seek recovery in customer rates.
FERC FORM NO. 2/3-Q (REV 122.17
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
NOTE 8. PENSION PLANS AND OTHER POSTRETIREMENT BENEFIT PLANS
The Company has a defined benefit pension plan covering the majority of all regular full+ime employees at Avista Corp.. 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.
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 $32.0 million in cash to the pension plan in 2014 and $44.3 million in 2013. The Company expects to contribute
$12.0 million in cash to the pension plan in 2015.
ln October 2013, the Company revised its defined benefit pension plan such that as of January 1, 2014 the plan is closed to non-union
employees hired or rehired by the Company on or after January 1 , 2014. Actively employed non-union employees that were hired prior
to January l, 2014 and who were at that date covered under the defined benefit pension plan will continue accruing benefits as
originally specified in the plan. A new and separate defined contribution 401(k) plan replaced the defured benefit pension plan for
non-union employees hired or rehired on or after January 1,2014. Under the new defined contribution plan, the Company provides a
non-elective contribution as a percentage of each employee's pay based on his or her age. This new defined contribution plan is in
addition to the existing a01 (k) plan in which the Company matches a portion of the pay deferred by each participant. In addition to the
changes above, the Company revised the lump sum calculation for non-union participants who retire under the defined benefit pension
plan on or after January 1,2014 to provide retiring employees the election of a lump sum amount equivalent to the present value of the
benefits based upon applicable discount rates. In April 2014, the local union in Oregon for the IBEW accepted the above plan changes
in the latest collective bargaining agreement, and the plan changes are effective for Oregon union workers hired or rehired on or after
April l, 2014. Employees subject to IBEW local agreements for Washington, Idaho and Montana are not affected by these changes
and they continue to be covered by the defined benefit pension plan and are not included in the new defined contribution plan.
For the estimated pension liability and pension costs as of December 31,2014, the Company adopted the Society of Actuaries'
mortality table that was published in 2014 as its base table, which reflects improved longevity of plan participants based on studies of
wide populations through 2007 (RP-2014). The Company also adopted a modified form of the Society of Actuaries' MP-2014
mortality improvement scale, which projects improvements to life expectancies after the RP-2014 historic period that ended in2007.
For years subsequent to 2007, the Company reviewed data from other sources, including the Human Mortality Database, maintained by
the University of Califomia, Berkley and the Max Planck Institute for Demographic Research, and the Trustee's Report provided by
the Social Security Administration. Based on data subsequent to2007,the mortality improvement scale included in the MP-2014 for
the three-year period immediately following its inception (2007) was shown to significantly overstate the actual mortality improvement
for those years. As such, the mortality improvement scale the Company adopted assumes a lower rate of improved life expectancy than
the MP-2014 scale as published.
The Company also has a Supplemental Executive Retirement Plan (SERP) that provides additional pension benefits to executive
off,rcers and ceftain key employees of the Company. The SERP is intended to provide benefits to individuals whose benefits under the
pension plan are reduced due to the application ofSection 415 ofthe Internal Revenue Code of 1986 and the deferral ofsalary 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):
201 5 2016 2017 201 8 2019 Total2020-2024
Expected benefit payments $ 27,938 $ 29,109 S 30,157 $ 31,407 $ 32,979 $184,794
The expected long-term rate ofretum on plan assets is based on past performance and economic forecasts for the types ofinvestnents
held by the plan. ln 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.
FERC FORM NO.2/3-Q v 12-07 122.18
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2015
Year/Period of Report
2014tA4
Notes to Financial Statements
The Company provides certain health care and life insurance benefits for the majority of its retired employees at Avista Corp.. The
Company accrues the estimated cost of postretirement benefit obligations dwing the years that employees provide services. In October
2013, the Company revised the health care benefit plan such that beginning on January 1,2020, the methods for calculating health
insurance premiums for non-union retirees under age 65 and active Company employees were revised to establish separate health
insurance premiums for each group. In addition, for non-union employees hired or rehired on or after January 1,2014, upon retirement
the Company will provide access to its retiree medical plan, but will no longer contribute towards their medical premiums and each
employee would pay the full cost of premiums upon retirement. In April 2014,uhe local union in Oregon for the IBEW accepted the
above plan changes in the latest collective bargaining agreement, and the plan changes are effective for Oregon union workers hired or
rehired on or after April 1, 2014.
The Company has a Health Reimbursement Arrangement 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 this plan are included as other postretirement benefits.
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 otler postretirement benefit plans will total (dollars in thousands):
2015
$ 7,13 8
20t6 2017 201 8 2019 Total2020-2024
Expected benefit payments 7,487 $7,475 $ 7,589 $7,767 $36,076
The Company expects to contribute $7. I million to other postretirement benefit plans in 2015, representing expected benefit payments
to be paid during the year. The Company uses a December 3l measurement date for is pension and other postretirement benefit plans.
The following table sets forth the pension and other postretirement benefit plan disclosures as of December 3 I , 2014 and 20 I 3 and the
components ofnet periodic benefit costs for the years ended December 3 l, 2014 and 2013 (dollars in thousands):
Pension Benefits
Other Post-
retiremcnt Benefits
2014 2013 20t4 2013
Change in benefit obligation:
Benefit obligation as of beginning of year
Service cost
Interest cost
Actuarial (gain)/loss
Plan change
Transfer of accrued vacation
Benefits paid
Benefit obligation as of end of year
Change in plan assets:
Fair value ofplan assets as ofbeginning ofyear
Actual retum on plan assets
Employer contributions
Benefits paid
634,674 S 527,004 $127,989 $108,249
527,004
15,757
26,224
97,128
(31,439)
584,619 $
19,045
23,896
(78,234)
277
(22,599)
108,249
1,844
5,226
18,714
437
(6,481)
t32,541
4,144
5,216
(18,017)
(10,788)
1,189
(6,036)
481,502 $
55,974
32,000
(30, I 65)
406,061 $
52,502
44,263
(21,324)
29,732
1,580
25,288
4,444
FERC FORM NO.2/3-Q ,l 122.19
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014to.4
Notes to Financial Statements
Fair value ofplan assets as ofend ofyear
Funded status
Unrecognized net actuarial loss
Unrecognized prior service cost
Prepaid (accrued) benefit cost
Additional Iiability
Accrued benefit liability
Accumulated pension benefit obligation
Accumulated postretirement benefit obligation:
For retirees
For fully eligible employees
For other participants
$ 539.31r $ 481.502s (9s,363) $ (4s,s02)
s 31.312 $ 29.732s (96,677) $ (78,517)
(10,379)
56,885
(707)
t75,596
256
107,043
278
80,489
(175,852)
61,819
(107,321)
(24,635)
(72,042)
(22,339)
(56,178)
(95,363) $(45,502) $(96,677) $(78,517)
5sl,6ls $464,432
$
$
s
58,276
3 1,843
37,8',70
-
52,384
24J20
31,545
$
$
$
FERC FORM NO.2/3-Q 1 122.20
Name of Respondent
Avista Corooration
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Pension Benefits
Other Post-
retirement Benefits
2014
Included in accumulated other comprehensive loss (income) (net of tax):
Unrecognized prior service cost
Unrecognized net actuarial loss
Total
Less regulatory asset
Accumulated other comprehensive loss (income) for unfunded
benefit obligation for pensions and other postretirement
benefit plans
2013 2014 2013
s 166
I 14,138
180 s
69,578
(6,747) $
53,574
(7,472)
43,988
114,304
(106,484)
69,7 58
(64,925\
46,827
(46,7 59)
36,516
(37,1 l6)
7,820 $4,833 $68$(600)
Pension Benefits
Other Post-
retirement Benefits
2013
Weighted ayerage assumptions as of December 31:
Discount rate for benefit obligation
Discount rate for annual expense
Expected long-term return on plan assets
Rate of compensation increase
Medical cost trend pre-age 65 - initial
Medical cost trend pre-age 65 - ultimate
Ultimate medical cost trend year pre-age 65
Medical cost trend post-age 65 - initial
Medical cost trend post-age 65 - ultimate
Ultimate medical cost trend year post-age 65
4.21%
5.t0%
6.60%
4.87%
5.10%
4.15%
6.60%
4.96%
4.16%
5.02o/o
6A0%
7.00%
5.00%
2021
7.00%
5.00o/o
2022
5.02%
4.15%
6.35%
7.00%
s.00%
2020
7.s0%
5.000/o
2021
Pension Benefits Other Post-retirement Benefi ts
2013 2014 2013
Components of net periodic benefit
cost:
Service cost $
lnterest cost
Expected return on plan assets
Transition obligation recognition
Amortization of prior service cost
Net loss recognition
15,757
26,224
(32,131)
22
4,731
t9,045 S
23,896
(27,671)
319
13, I 99
1,844 $
5,226
(1,903)
(1,116)
4,289
4,144
5,216
(1,606)
(14e)
5,674
Net periodic benefit cost $ r4r03 28,788 $8,340 $ 13,279
Plan Assets
The Finance Committee of the Company's Board of Directors approves investment policies, objectives and strategies that seek an
appiopriate 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 managing/monitoring the individual investment
FERC FORM NO. 2/3-Q 1 122.2'.1
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t't5t2015
Year/Period of Report
2014tQ4
Notes to F3nancial Statements
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,
absolute return and commodity funds. In seeking to obtain the desired return to fund the pension plan, the investment consultant
recommends allocation percentages by asset classes. These recommendations are reviewed by the internal benefits commiftee, which
then recommends their adoption by the Finance Committee. The Finance Committee has established target investment allocation
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:
2014 2013
Equity securities
Debt securities
Real estate
Absolute retum
Other
Cash equivalents
Fixed income securities:
U.S. government issues
Corporate issues
Intemational issues
Municipalissues
27%
58%
6%
9%
-%
47o/o
31%
6%
12%
4%
The market-related value of pension plan assets invested in debt and equity securities was based primarily on fair value (market
prices). The fair value ofinvestment 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, are fair-valued by the
investment manager based upon other inputs (including valuations of securities that are comparable in coupon, rating, maturity and
industry). Investments in commor/collective trust funds are presented at estimated fair value, which is determined based on the unit
value of the fund. Unit value is determined by an independent trustee, which sponsors the fund, by dividing the fund's net assets by its
units outstanding at ttre valuation date. The fair value of the closely held investments and partnership interests is based upon the
allocated share ofthe fair value ofthe underlying assets as well as the allocated share ofthe undistributed profits and losses, including
realized and unrealized gains and losses.
The market-related value of pension plan assets invested in real estate was determined by the investment manager based on three basic
approaches:
. properties are externally appraised on an annual basis by independent appraisers, additional appraisals may be
performed as warranted by specific asset or market conditions,
. property valuations are reviewed quarterly and adjusted as necessary, and
o loans are reflected at fair value.
The market-related value of pension plan assets was determined as of December 31,2014 and2013.
The following table discloses by level within the fair value hierarchy (see Note 14 for a description of the fair value hierarchy) of the
pension plan's assets measured and reported as of December 31,2014 at fair value (dollars in thousands):
Level I Level 2 Total
$ -s 3,138$- $ 3,138
19,681
104,959
19,935
10,550
19,68 r
104,959
19,935
2,762 7,788
Level 3
FERC FORM NO. 2/3-Q (REV 1 't22.22
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
0/.t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Mutual funds:
Fixed income securities
U.S. equity securities
lnternatioual equity securities
Absolute retum (l)
Common/collective trusts :
Real estate
Partnership/closely held investments :
Absolute return (l)
Private equity funds (3)
Real estate
Total
l5'1,415
103,203
40,838
15,334
21,303
36,114
73
6,760
464,127 $10,934 $64,250 $539,31 I
8 157,423
103,203
40,838
15,334
21,303
36,114
73
6,760
FERC FORM NO. Z3.Q 122.23
Name of Respondent
Avista Corooration
This Report is:
(1)X An Original
(2) _ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
The following table discloses by level within the fair value hierarchy (see Note l4 for a description of the fair value hierarchy) of the
pension plan's assets measured and reported as of December 3 I , 201 3 at fair value (dollars in thousands):
lrvel I l-evel 2 Level 3 Total
Mutualfunds:
Fixed income securities
U.S. equity securities
International equity securities
Absolute return (1)
Commoilcollective trusts:
Fixed income securities
Real estate
Parfnership/closely held investments:
Absolute return (l)
Private equity tunds (3)
Commodities (2)
Real estate
Total
Balance, as ofJanuary 1,2014
Realized gains
Unrealized gains (losses)
Purchases, net
Balance, as of December 31,2014
Balance, as ofJanuary 1,2013
Realized gains (losses)
Unrealized gains (losses)
Purchases (sales), net
86,481 $
152,83 I
85,942
23,599
3r0 $
55,872
-$
19,735
34,1 5 r
86,791
I 52,83 I
85,942
23,599
55,872
19,735
34,151
3lt
18,331
3,873
r8,3;
377
$ 74,513 $ 58,136
(l)
(2)
348,853 481,502
This category invests in multiple shategies to diversifo 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 neural strategies.
This investment is in derivatives linked to commodity indices to gain exposure to the commodity markets. These positions are
fully collateralized with debt securities.
(3) This category includes private equity funds that invest primarily in U.S. companies.
The table below discloses the summary of changes in the fair value of the pension plan's Level 3 assets for the year ended
December 31,2014 (dollars in ttrousands):
Common/collective trusts Partnership/closely held investments
Absolute Private equity Real
estate
19,735 $
24
1,097
447
34,1 5 1
1,963
377
(304)
3,873
595
(644)
2,936
21,303 $36,114 $73$6,760
The table below discloses the summary of changes in the fair value of the pension plan's Level 3 assets for the year ended
December 3 l, 20 l3 (dollars in thousands):
Common/col lective trusts Partnership/closely held investments
Absolute
retum
Private equity Realfunds estate
Real
estate
17,596 $
2,139
17,755 $
2,396
14,000
660 $
(323)
345
(305)
113
3,760
FERC FORM NO. 2/3-Q (REV 12-07 122.24
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Balance, as of December 3 1, 20 13 s 19.735 S 34.1-{l s 377 S 3.873
The market-related value of other postretirement 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 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 or for which market prices do not represent the value at the time of pricing, 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 secwities in both 2014
and 2013.
The market-related value of other postretirement plan assets was determined as of December 3 I , 2074 and 20 1 3.
The following table discloses by level within the fair value hierarchy (see Note l4 for a description of the fair value hierarchy) of other
postretirement plan assets measured and reported as of Decemb er 31,2014 at fair value (dollars in thousands):
Level I level 2 Level 3 Total
Cash equivalents
Mutual funds:
Fixed income securities
U.S. equity securities
International equity securities
Total
Cash equivalents
Mutual funds:
Fixed income securities
U.S. equity securities
lnternational equity securities
Total
-$
I 1,968
13,210
6,131
3$-$3
I1,968
13,210
6,13 I
-$31,312
The following table discloses by level within the fair value hierarchy (see Note l4 for a description of the fair value hierarchy) of other
postretirement plan assets measured and reported as of December 31, 2013 at fair value (dolldrs in thousands):
Level I l*vel2 kvel 3
31,309 $3$
-$
11,645
I 1,83 I
6,252
4$-s 4
11,645
I 1,83 I
6,252
29,728 S 4$-$29,732
Assumed health care cost trend rates have a significant effect on the amounts reported for the health care plans, A one-percentage-point
increase in the assumed health care cost trend rate for each year would increase the accumulated postretirement benefit obligation as of
December 31,2014 by $5.2 million and the service and interest cost by $0.4 million. A one-percentage-point decrease in the assumed
health care cost trend rate for each year would decrease tle accumulated postretirement benefit obligation as of Decemb er 31, 2074 by
$4.1 million and the service and interest cost by $0.3 million.
401(k) Plsns and Executive Deferral Plan
Avista Corp. has a salary deferral40l(k) plans that is a defined contribution plans and cover 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 3l (dollars in thousands):
20t4 2013
FERC FORM NO, 2/3-Q (REV 1 122.25
Name of Respondent
Avista Corporation
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2015
Year/Period of Report
20141Q4
Notes to Financial Statements
Employer 40 I (k) matching contributions $ 6,741 $ 6,157
The Company has an Executive Defenal 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 defened compensation liabilities on the Balance Sheets of the following amounts as of December 3l (dollars
in thousands):
2014 2013
Deferred compensation assets and liabilities
NOTE 9. ACCOUNTING FOR INCOME TAXES
8,677 $
Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for
financial reporting purposes and the amounts used for income tax purposes and tax credit carryforwardsAs of December 31, 2014, the
Company had $I L3 million of state tax credit carryforwards, State tax credits expire from 2019 to 2028. The Company recognizrs the
effect ofstate tax credits generated from utility plant as they are utilized.
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.
The Company and its eligible subsidiaries file consolidated federal income tax returns. The Company also files state income tax returns
in certain jurisdictions, including ldaho, Oregon and Montana. Subsidiaries are charged or credited with the tax effects of their
operations on a stand-alone basis. The Intemal Revenue Service (IRS) has completed its examination of all tax years through 201 I and
all issues were resolved related to these years. The IRS has not completed an examination of the Company's 2012 and 2013 federal
income tax returns. The Company believes that any open tax years for federal or state income taxes will not result in adjustments that
would be significant to the financial statements.
The Company did not incur any penalties on income tax positions in 2014 or 2013.
The Company had net regulatory assets related to the probable recovery of certain deferred income tax liabilities from customers
through future rates as of December 3l (dollars in thousands):
20t4 2013
Regulatory assets for deferred income taxes
Regulatory liabilities for deferred income taxes
100,412 $
14,534
71,421
9,203
FERC FORM NO. Z3.Q 1 122.26
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial StatemenB
NOTE IO. ENERGY PURCHASE CONTRACTS
Avista Corp. has conffacts 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 termination dates of the contracts range from one month to the year
2042. 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 3l (dollars in thousands):
2014 2013
Utiliry power resources 556,915 $524,810
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):
20t5 2016 2017 201 8 2019 Thereafter
$ 144,4U $ 13239? $ n$' $ 860J3r $ 1Js0,113
57,379 52,936 49,304 455,975 754,982
Power resources
Natural gas resources
Total
$ 277,474 $ 209,255
82,884 56,504
$ 360,358 $ 265,759 $ 201,803 $ 185,833 $ 174,636 $ 1,316,706 $ 2,505,095
These energy purchase contracts were entered into as part ofAvista Corp.'s obligation to serve its retail electric and natural gas
customers' enerry 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 ofthe 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 ouput 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 ,2014 (principal and interest) was $59.4 million,
In addition, Avista Corp. has operating agreements, settlements and other contractual obligations related to its generating facilities and
transmission and distribution services. The following table details future contractual commitrnents under these agreements (dollars in
thousands):
201 5
Contractual obligations $ r%t33
2016 2017
$ ,&r89
2018 2019 Thereafter Total
35,692 25,659 $28,969 $ 193,734 S 341,376
NOTE I1. NOTES PAYABLE
Avista Corp. has a committed line of credit with various financial institutions in the total amount of $400.0 million. In April 2014,the
Company amended this committed line of credit agreement to extend the expiration date to April 2019. The amendment also provides
the Company the option to request an extension for an additional one or two years beyond April 2019, provided, l) there are no default
events prior to the requested extension, and 2) the remaining term of agreement, including the requested extension period, does not
exceed five years. The amendment did not change the amount of the committed line of credit.
The committed line of credit is secured by non-transferable first moftgage bonds of the Company issued to the agent bank that would
FERC FORM NO. 2/3-O 1 122.27
Name of Respondent
Avista Corooration
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Flnancial Statements
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 agrcement 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, 2074,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 3l (dollars in thousands):
2014 2013
$-iT'i6oo- 5-]ilp'oo-
$ 32,579 $ 27,434
0.93%1.02%
As of December 31, 2014 and 2013, the borrowings outstanding under Avista Corp.'s committed line of credit were classified as
short-term borrowings on the Balance Sheet.
NOTE 12. BONDS
The following details long-term debt oustanding as of December 31 (dollars in thousands):
Balance outstanding at end of period
Letters ofcredit outstanding at end ofperiod
Average interest rate at end of period
MaturityYear Description
lnterestRate 2014 2013
2016
2018
20r8
2019
2020
2022
2023
2028
2032
2034
2035
2037
2040
2041
2044
2047
First Mortgage Bonds
First Mortgage Bonds
Secured Medium-Term Notes
First Mortgage Bonds
First Mortgage Bonds
First Mortgage Bonds
Secured Medium-Term Notes
Secured Medium-Term Notes
Secured Pollution Control Bonds (l)
Secured Pollution Control Bonds (l)
First Mortgage Bonds
First Mortgage Bonds
First Mortgage Bonds
First Mortgage Bonds
First Mortgage Bonds (2)
First Mortgage Bonds
Total secured bonds
Settled interest rate swaps (3)
Secured Pollution Control Bonds held by Avista
Corporation (l)
Total long-term debt
0.84%
5.95%
7.39%-7.45%
5.45%
3.89%
5.13%
7.18%-7.54%
6.37%
(l)
(1)
6.25%
5.70%
5.55%
4.45Yo
4,n%
4.23%
90,000 $
250,000
22,500
90,000
52,000
250,000
13,500
25,000
66,700
I7,000
150,000
150,000
35,000
85,000
60,000
80,000
90,000
250,000
22,500
90,000
52,000
250,000
13,500
25,000' 66,700
17,000
150,000
150,000
35,000
85,000
80,000
1,436,700 1,376,700
(17,541) (23,560)
(83,700) (83,700)
$ 1,335,459 $ 7,269,440
(l)In December 2010,$66.7 million and $17.0 million of the City of Forsyth, Montana Pollution Control Revenue Refunding
FERC FORM NO.2/3-Q 1 122.28
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2015
YeariPeriod of Report
20141Q4
Notes to Financial Statements
Bonds (Avista Corporation Colstrip Project) due in 2032 and2034, respectively, which had been held by Avista Corp. since
2008 and 2009, respectively, were refunded by new 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 maiket 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 December 20 14, Avista Corp. issued $60.0 million of frst mortgage bonds to three institutional investors in a private
placement transaction. The first mortgage bonds bear an interest rate of 4.1I percent and mature in2044. The total net
proceeds from the sale of the new bonds were used to repay a portion of the borrowings outstanding under the Company's
$400.0 million committed line of credit and for general corporate purposes.
(3) Upon settlement ofinterest rate swaps, these are recorded as a regulatory asset or liability and included as part oflong-term
debt above. They are amortized as a component ofinterest expense over the life ofthe associated debt and included as a part
of the Company's cost of debt calculation for ratemaking purposes,
The following table details future long-term debt maturities including advances from associated companies (see Note l3) (dollars in
thousands):
20r 5 2016 20t7 20r 8 2019 Thereafter Total
Debt maturities -$90,000 $- $ 272,s00 $90,000 $ 952,047 $1,404,547
Substantially all utility properties owned by Avista Corp. are subject to the lien of the Avista Corp.'s mortgage indenture. Under the
Mortgage and Deed of Trust securing the Company's First Mortgage Bonds (including Secured Medium-Term Notes), the Company
may issue additional First Mortgage Bonds in an aggregate principal amount equal to the sum of:. 1) 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 2) an equal principal amount of retired First Mortgage Bonds which have not previously been made the basis of any
application under the Mortgage, or 3) deposit of cash. However, the Company may not issue any additional First Mortgage Bonds
(with cenain exceptions in the case of bonds issued on the basis of retired bonds) unless the Company's "net earnings" (as defined in
the Mortgage) for any period of 12 consecutive calendar months out of the preceding 18 calendar months 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 31,2014, property additions and retired bonds would have allowed, and the net eamings
test would not have prohibited, the issuance of $ I .0 billion in aggregate principal amount of additional first mortgage bonds at Avista
Corp.
See Note 1 I for information regarding first mortgage bonds issued to secure the Company's obligations under its committed line of
credit agreement.
NOTE 13. ADVANCES FROM ASSOCIATED COMPANIES
ln 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
Prefened 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 3l:
Low distribution rate
High distribution rate
Distribution rate at the end of the year
1.10%
t.1t%
1.11%
l.ttvo
1.19%
t.1t%
20t4 20t3
FERC FORM NO.2/3.Q 122.29
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Concurrent with the issuance of the Preferred Trust Securities, Avista Capital II issued $1.5 million of Conrmon Trust Securities to the
Company. These debt securities may be redeemed at the option of Avista Capital II on or after June 1,2007 and mature on June 1,
2037.|n 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 14. FAIR VALUE
The carrying values ofcash 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 I measurement) and the lowest priority to unobservable inputs (Level 3
measurement).
The three Ievels of the fair value hierarchy are defined as follows:
Level I - 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.
Level2 - Pricing inputs are other than quoted prices in active markets included in Level l, 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 indus@-standard models that consider various assumptions, including quoted forward
prices for commodities, time value, volatilify 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.
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 Iiabilities 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 3 I (dollars in thousands):
2014 2013
Carrying Estimated Carrying EstimatedValue Fair Value Value Fair Value
$ 951,000 $ 1,118,972 $ 951,000 S 1,054,512Bonds (Level 2)
FERC FORM NO. 2/3-Q (REV 1 122.30
Name of Respondent
Avista Corooration
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Bonds (Level 3)
Advances from associated companies (Level 3)
December 31,2014
Assets:
Enerry commodity derivatives
Level 3 enerry commodity derivatives:
Natural gas exchange agreements
Foreign currency derivatives
Interest rate swaps
Deferred compensation assets:
Fixed income securities (2)
Equity securities (2)
Total
Liabilities:
Enerry commodity derivatives
Level 3 energy commodity derivatives:
Natural gas exchange agreement
Power exchange agreement
Power option agreement
Interest rate swaps
Foreign curency derivatives
Total
402,000
51,547
432,728
38,582
342,000
51,547
329,581
37,114
These estimates of fair value 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 74.85 to l3 1.21, where a par value of 100.00 represents the carrying value recorded on the Balance Sheets.
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 31,2014 and 20 I 3 at fair value on a recurring basis (dollars in thousands):
Level I Level2
Counterparty
and Cash
Collateral
Level 3 Netting (l) Total
1,793
6,074
460
-s
-$
96,729 $
I
966
-$
1,349
(95,204)
(1,349)
(t)
(s06)
t,525
1,793
6,074
7,867 $97,696 $1,349 $(97,060) $9,852
127,094 $
77,568
2l
-$
1,384
23,299
424
(l10,714)
(1,3?
(29,386)
(1)
16,380
35
23,299
424
48,182
20
-$204,683 $25,107 $ (141,450) $88,340
FERC FORM NO,2/3.Q v'12-071 122.31
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Level I Level 2 Level 3
Counterparty
and Cash
Collateral
Netting (l)Total
December 31, 2013
Assets:
Enerry commodity derivatives
Level 3 energy commodity derivatives:
Power exchange agreement
Forei gn currency derivatives
Interest rate swaps
Deferred compensation assets:
Fixed income securities (2)
Equity securities (2)
Total
Liabilities:
Enerry commodity derivatives
Level 3 enerry commodiry derivatives:
Natural gas exchange agreement
Power exchange agreement
Power option agreement
Forei gn curency derivati ves
Total
8,430 $88,793 $339 $(s l,712) $45,850
-$72,895 $
1,960
6,470
-$55,243 $
7
33,543
-$(51,367)
(33e)
:,
3,876
I
33,543
1,960
6,470
339
6
-$
1,219
14,780
,:
(60,099) $
(33e)
(6)
12,796
1,219
14,441
775
-$72,901 $16,774 $(60,444) $29,231
( I ) The Company is permitted to net derivative assets and derivative liabilities with the same counterparty when a legally enforceable
master netting agreement exists. In addition, the Company nets derivative assets and derivative liabilities against any payables and
receivables for cash collateral held or placed with these same counterparties.
Avista Corp. enters into forward contracts to purchase or sell a specified amount of enerry at a specified time, or during a specified
period, in the future. These contracts are entered into as part of Avista Corp.'s management of loads and resources and certain
contracts are considered derivative instruments. The difference between the amount of derivative assets and liabilities disclosed in
respective levels and the amount of derivative assets and liabilities disclosed on the Balance Sheets is due to netting arrangements with
certain counterparties. The Company uses quoted market prices and forward price curves to estimate the fair value of utility derivative
commodity instruments included in Level 2. In particular, electric derivative valuations are performed using broker quotes, adjusted
for periods in between quotable periods. Natural gas derivative valuations are estimated using New York Mercantile Exchange
(NYMEX) pricing for similar insffuments, adjusted for basin differences, using broker quotes. Where observable inputs are available
for substantially the full term of the contract, the derivative asset or liability is included in Level 2.
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 $0.8 million as of December3l,2014 and $0.7 million as of December3l,2013.
Level3 Fair Value
For the power exchange agreement, the Company compares the Level 2 brokered quotes and forward price curves described above to
an intemally developed forward price which is based on the average operating and maintenance (O&M) charges from four surrogate
nuclear power plants around the country for the current year. Because the nuclear power plant O&M charges are only known for one
FERC FORM NO.2/3.Q 12-071 122.32
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
year, all forward years are estimated assuming an annual escalation. In addition to the forward price being estimated using
unobservable inputs, the Company also estimates the volumes of the transactions that will take place in the future based on historical
average transaction volumes per delivery year (November to April). Significant increases or decreases in any of these inputs in
isolation would result in a significantly higher or lower fair value measurement. Generally, a change in the current y,ear O&M charges
for the surrogate plants is accompanied by a directionally similar change in O&M charges in future years. There is generally not a
correlation between external market prices and the O&M charges used to develop the internal forward price.
For the power commodity option agreement, the Company uses the Black-Scholes-Merton valuation model to estimate the fair value,
and this model includes significant inputs not observable or corroborated in the market. These inputs include I ) the strike price (which
is an internally derived price based on a combination ofgeneration plant heat rate factors, natural gas market pricing, delivery and
other O&M charges, 2) estimated delivery volumes for years beyond 20 I 5, and 3) volatility rates for periods beyond December 201 7.
Significant increases or decreases in any of these inputs in isolation would result in a significantly higher or lower fair value
measurement. Generally, changes in overall commodity market prices and volatility rates are accompanied by directionally similar
changes in the strike price and volatility assumptions used in the calculation.
For the natural gas commodity exchange agreement, the Company uses the same Level 2 brokered quotes describeci 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 changgs 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 31,2014 (dollars in thousands):
Fair Value
(NeQ at
December 31, Valuation2014 Technique Unobservable Input Range
Power exchange agreement (23,299) Surrogatefacility
pricing
O&M charges
Escalation factor
Transaction volumes
$30.66-$ss.s6a4wh (r)
3% - 2015 to 2019
184,077 - 397,1l6 MWhs
Power option agreement (424) Black-Scholes-
Merton
Strike price
Delivery volumes
Volatility rates
s4l.20a4wh - 20ls
s64.09/MWh -2019
157,517 - 287,147 MWhs
0.20 (2)
Natural gas exchange
agreement
(35) lnternallyderived
weighted average
cost ofgas
Forward purchase
prices
Forward sales prices
Purchase volumes
Sales volumes
$2.32 - $2.57lmmBTU
$2.56 - $3.53/mmBTU
280,000 - 310,000 mmBTUs
279.990 - 365.1l8 mmBTUs
(l) The average O&M charges for the delivery year beginning in November 2014 were $42.90 per MWh. For ratemaking purposes the
average O&M charges to be included for recovery in retail rates vary slightly between regulatory jurisdictions. The average O&M
FERC FORM NO. 2/3.Q (REV 1 122.33
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
chargesforthedeliveryyearbeginningin20l4 were$43.11forWashingtonand$42.90 forldaho.
(2) The estimated volatility rate of 0.20 is compared to actual quoted volatility rates of 0.45 for 201 5 to 0.2 I in December 201 7.
Avista Corp.'s risk management team and accounting team are responsible for developing the valuation methods described above and
both groups report to the Chief Financial Officer. The valuation methods, significant inputs and resulting fair values described above
are reviewed on at least a quarterly basis by the risk management team and the accounting team to ensure they provide a reasonable
estimate of fair value each reporting period.
The following table presents activity for energy commodiry derivative assets (liabilities) measured at fair value using significant
unobservable inputs (Level 3) for the years ended December 3l (dollars in thousands):
Natural Gas Power
Exchange Exchange Power Option
Agreement Agreement Total
Year ended December 31,2014:.
Balance.as of January 1,2014
Total gains or losses (realized./unrealized):
Included in net income
Included in other comprehensive income
Included in regulatory assets/liabilities (l)
Purchases
Issuance
Settlements
Transfers toifrom other categories
Ending balance as of December 3l ,2014
Year ended December 31, 2013:
Balance as ofJanuary 1,2013
Total gains or losses (realized/unrealized):
Included in net income
Included in other comprehensive income
Included in regulatory assets/liabilities (l)
Purchases
Issuance
Settlements
Transfers from other categories
Ending balance as of December 31, 2013
$ (1,219) $ (14,441) $(77s) $ (16,435)
3,873
(2,689)
(10,002)
1,144
$ (23,299)
(1,545)
35r (5,778)
(3s)(424) $ (23,7s8)
(1,480) $ (22,55r)
4,020
2,096
(r,219) $(14,441) S (77s) $ (16,43s)
The UTC and the IPUC issued accounting orders authorizing Avista Corp. to offset 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. The orders provide for Avista Corp. to not recogrize the
unrealized gain or loss on utility derivative commodity instruments in the Statements of Income. Realized gains or losses are
recognizeC in the period ofdelivery, subject to approval for recovery through retail rates. Realized gains and losses, subject to
regulatory approval, result in adjustments to retail rates through purchased gas cost adjustments, the ERM in Washinglon, the
PCA mechanism in Idaho, and periodic general rates cases.
FERC FORM NO.2/3.Q 12-07l 't22.34
(2,379) S
2,2;
tr,r:gl
(18,692) S
1,0;
3,2;
70s
(l)
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
NOTE 15. COMMON STOCK
The Company has a Direct Stock Purchase and Dividend Reinvestment Plan under which the Company's shareholders may
automatically reinvest their dividends and make optional cash payments for the purchase of the Company's common stock at current
market value.
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,
r the hydroelectric licensing requirements of section 10(d) of the FPA (see Note l), and.
. certain requirements under the OPUC approval of the AERC acquisition. After the initial year, the OPUC does not
permit one-time or special dividends from AERC to Avista Corp. and does not permit Avista Corp.'s total equity to
total capitalization to be less than 40 percent, without approval from the OPUC. However, the OPUC approval does
allow for regular distributions of AERC earnings to Avista Corp. as long as AERC remains suffrciently capitalized
and insured.
The Company declared the following dividends for the year ended December 3l:
Dividends paid per common share
20t4 2013
$ 1.27 $ 1.22
Under the covenant applicable to the Company's committed line of credit agreement, which does not permit the ratio of "consolidated
total debt" to "consolidated total capitalization" to be greater than 65 percent at any time, the amount of retained earnings available for
dividends at December 31,2014 was limited to approximately $295.0 million.
Under the requirements of the OPUC approval of the AERC acquisition as outlined above, the amount available for dividends at
December 31,2014 was limited to approximately $145.0 million.
In August 2012, the Company entered into two sales agency agreements under which the Company may sell up to 2,726,390 shares of
its common stock from time to time. There were no shares issued under these agreements during 2014 and 2013 and as of
December 31,2074, the Company had 1,795,199 shares available to be issued under these agreements.
The Company has l0 million authorized shares of preferred stock. The Company did not have any preferred stock outstanding as of
December 31,2014 and 2013.
Stock Repurchase Programs
On June 13,2014, Avista Corp.'s Board of Directors approved a program to repurchase up to 4 million shares of the Company's
outstanding common stock, assuming the closure of the Ecova transaction (2014 program). Repurchases of common stock under this
program commenced on July 7,2014 and the program expired on December 31,2014. Repurchases were made in the open market or
in privately negotiated transactions. Through December 31,2014, the Company repurchased 2,529,615 shares at a tolal cost of $79.9
million and an average cost of $3 1.57 per share. The Company did not make any repurchases under this program subsequent to
October 2014. All repurchased shares reverted to the status ofauthorized but unissued shares.
FERC FORM NO, Z3.Q 1 122.35
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
0411512015
Year/Period of Report
2014tQ4
Notes to Financial Statements
On December 76,2014, Avista Corp.'s Board of Directors approved the repurchase of up to 800,000 shares of the Company's
outstanding comflon stock, commencing on January 2,2015, and continuing through March 31,2015 (first quarter 2015 program).
The number of shares repurchased through the first quarter 20 I 5 program is in addition to the number of shares repurchased under the
2014 program, which expired on December 31,2014. The parameters of the first quarter 2015 program are consistent with the
parameters of the 2014 program. AII repurchased shares, if any, will revert to the status of authorized but unissued shares.
NOTE 16. STOCK COMPENSATION PLANS
Avista Corp.
1998 Plan
ln 1998, the Company adopted, and shareholders approved, the Long-Term Incentive PIan (1998 Plan). Underthe 1998 Plan, certain
key employees, officers and non-employee directors of the Company and its subsidiaries may be granted stock options, stock
appreciation rights, stock awards (including restricted stock) and other stock-based awards and dividend equivalent rights. The
Company has available a maximum of 4.5 million shares of its common stock for grant under the 1998 Plan. As of December 37,2014,
0.4 million shares were remaining for grant under this plan.
2000 Plan
In 2000, the Company adopted a Non-Officer Employee Long-Term Incentive Plan (2000 Plan), which was not required to be
approved by shareholders. The provisions ofthe 2000 Plan are essentially the same as those under the 1998 Plan, except for the
exclusion of non-employee directors and executive officers of the Company. The Company has available a maximum of 2.5 million
shares of its cornmon stock for grant under the 2000 Plan. However, the Company currently does not plan to issue any further options
or securities under the 2000 Plan. As of December 31, 2014, 1.9 million shares were remaining for grant under this plan.
Slock Compensation
The Company records compensation cost relating to share-based payment transactions in the financial statements based on the fair
value of the equity or liability instruments issued. 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 3 I
(dollars in thousands):
2014 2013
Stock-based compensation expense
Income tax benefits
$ 6,007 $ 5,037
2,102 1,763
Stock Oplions
There are no longer any stock options outstanding as of December 37,2014 and the Company does not have any plans to issue
additional stock options in the near future.
The following summarizes stock options activity under the 1998 Plan and the 2000 Plan for the year ended December 31,2013:
2013
Number of shares under stock options:
Options outstanding at beginning of year
Options ganted
Options exercised
Options canceled
3,000
(3,000)
FERC FORM NO.2/3-Q 12-0 122.36
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Options outstanding and exercisable at end of year
Weighted average exercise price:
Options exercised
Options canceled
Options outstanding and exercisable at end ofyear
Cash received from options exercised (in thousands)
Intrinsic value of options exercised (in thousands)
lnfinsic value of options outstanding (in thousands)
Unvested shares at beginning ofyear
Shares granted
Shares canceled
Shares vested
Unvested shares at end ofyear
Weighted ayerage fair value at grant date
Unrecognized compensation expense at end ofyear (in thousands)
Intrinsic value, unvested shares at end ofyear (in thousands)
lntrinsic value, shares vested during the year (in thousands)
$
$
$
$
$
s
12.41
37
40
Restricled Shares
Restricted share awards vest in equal thirds each year over a three-year period 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, the Company must meet a return on equity target
in order for the CEO's restricted shares to vest. During the vesting period, employees are entitled to dividend equivalents which are
paid when dividends on the Company's common stock are declared. Restricted stock is valued at the close of market of the Company's
common stock on the grant date. The weighted average remaining vesting period for the Company's restricted shares outstanding as of
December 31,2014 was 0.7 years.
The following table summarizes restricted stock activity for the years ended December 3l:
2014 2013
104,416
62,075
( I ,550)
(52,899)
I l7,l l8
44,556
(1,802)
(55,456)
112,042 104,416
$
$
$
$
28.37 $
7,349 $
3,961 $
1,473 $
26.04
1,199
2,943
1,363
P erfo rmanc e and M a r ket- B used Aw ords
The Company has two types of awards that fall under this category, Total Shareholder Return (TSR) awards, which are market-based
awards and Cumulative Eamings Per Share (CEPS) awards, which are performance awards. Both types of awards vest after a period of
three 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 ofawards 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.
Both types of awards entitle the grantee to shares of Avista Corp. common stock or cash payable once the service condition is satisfied
and provided that the market or performance conditions are achieved. All TSR awards $anted have two conditions, the service
condition of three years and a market-based condition, which is the Company's TSR performance over a three-year period as compared
against other utilities. CEPS awards began in 2014 and they also have two conditions, the service condition of three years and a
performance condition, which is the Company's CEPS performance over a three-year period. CEPS is a performance condition based
FERC FORM NO.2/3-O 12-071 122.37
Name of Respondent
Avista Corooration
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
ut15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
solely on internal metrics and it is used to determine whether an award vests or not. The level of payout for both the TSR and CEPS
awards is based on the level of attainment of the market and performance conditions, respectively.
TSR awards are equity awards with a market-based condition, which results in the compensation cost for these awards being
recognized over the requisite service period, provided that the requisite service period is rendered, regardless of when, if ever, the
market condition is satisfied. CEPS awards are equity awards with a performance condition based solely on internal Company metrics;
therefore, compensation cost for these awards is recognized over the requisite service period, provided that the requisite service period
is rendered. However, if the CEPS performance metric is not met, all compensation cost for these awards is reversed as these awards
are not considered vested.
The Company measures (at the grant date) the estimated fair value of the shares awarded. The fair value of each TSR award was
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. Expected volatility was based on the historical volatility of Avista Corp. common stock over
a three-year period. The expected term of the TSR awards is three years based on the performance cycle. The risk-free interest rate was
based on the U.S. Treasury yield at the time of grant. The compensation expense on these awards will only be adjusted for changes in
forfeitures.
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, Iess the net present value of the estimated dividends over the three-year period. The combined fair
value of the equity and dividend components of CEPS awards is equal to the share price of Avista Corp. common stock on the date of
grant.
The following summarizes the weighted average assumptions used to determine the fair value of TSR and CEPS awards and related
compensation expense as well as the resulting estimated fair value of awards granted:
2014 2013
TSR assumptions
fusk-free interest rate
Expected Iife, in years
Expected volatility
Dividend yield
Weighted average grant date fair value (per share)
CEPS assumptions
Weighted average share price on date of grant
Annual dividends per share
Risk-free interest rate
Weighted average grant date fair value of equity component (per share)
The weighted average grant date fair value above for TSR awards includes both the equity component and dividend equivalent rights.
The following summarizes TSR and CEPS share activity:
2014 2013
0.7%
3
17.9%
4.5o/o
24.64 $
28.09 $
1.22
0.7%
24.48 $
0.4%
J
t9.t%
4.6%
23.30
TSR Awards
Opening balance ofunvested TSR shares
TSR shares granted
TSR shares canceled
TSR shares vested
344,684
I 17,550
(6,816)
(167,584)
359,700
175,000
(13,298)
(176,718)
FERC FORM NO.2/3-Q v 12-07 122,38
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
Ending balance ofunvested TSR shares
Intrinsic value ofunvested performance shares (in thousands)
Unrecognized compensation expense (in thousands)
CEPS Awards
Opening balance of unvested CEPS shares
CEPS shares granted
CEPS shares canceled
CEPS shares vested
Ending balance ofunvested CEPS shares
Intrinsic value ofunvested performance shares (in thousands)
Unrecognized compensation expense (in thousands)
TSR shares vested based on service condition
Impact of market condition on shares vested
Shares of common stock earned
Intrinsic value of common stock eamed (in thousands)
287.834 344.684
$ 10,175 S 9,717
s 2,833 S 3,651
59.025
( 1,008)
58,017
2,051 $
1,577 S
$
$
The weighted average remaining vesting period for the Company's TSR shares outstanding as of December 31,2014 was 1.4 years.
The weighted average remaining vesting period for the Company's CEPS shares outstanding as of December 31,2014 was 2 years.
Unrecognized compensation expense as of December 31,2014 includes only the amount attributable to the equity portion of the
awards and willbe recognized during 2015 and2Ol6.
The following summarizes the impact of the market condition on the TSR shares that met the service vesting condition (no CEPS
awards vested in 2014):
2014 20t3
167,584 176,718
(70,385) (176,7 t8)
97,199
3,436 $
Shares earned under this plan are distributed to participants in the quarter following vesting.
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 31,2014 and 2013, the Company had recognized cumulative compensation expense and a liability of $1.3 million and $0.9
million, respectively, related to the dividend component on the outstanding and unvested share grants.
NOTE I7. COMMITMENTS AND CONTINGENCIES
In the course of its business, the Company becomes involved in various claims, controversies, disputes and other contingent matters,
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 ofincurred costs through the ratemaking process.
Federal Energlt Regulotory Commission Inquiry
In April 2004, the Federal Energy Regulatory Commission (FERC) approved the contested Agreement in Resolution of Section 206
FERC FORM NO.2,'3-Q 12 122.39
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
Ml1512015
Year/Period of Report
20141Q4
Notes to Financial Statements
Proceeding (Agreement in Resolution) which stated that there was: (l) no evidence that any executives or employees of Avista Corp.
or Avista Energy knowingly engaged in or facilitated any improper trading strategy during 2000 and 2001 ; (2) no evidence that Avista
Corp. or Avista Energy engaged in any efforts to manipulate the western energy markets during 2000 and 2001; and (3) no finding that
Avista Corp. or Avista Energy withheld relevant information from the FERC's inquiry into the western enerry markets for 2000 and
2001 (Trading Investigation). In May 2004,the FERC provided notice that Avista Energy was no Ionger subject to an investigation
reviewing certain bids above $250 per lvlW in enerry markets operated by the California Independent System Operator (CalISO) and
the California Power Exchange (CalPXXBidding Investigation). Appeals of the FERC's decisions are pending before the United
States Court of Appeals for the Ninth Circuit (Ninth Circuit).
On March 7,2014, Avista Corp. and Avista Energy filed at FERC a settlement with Pacific Gas & Electric (PG&E), Southem
California Edison, San Diego Gas & Electric, the California Attorney General (AG), the Califomia Department of Water Resources
(CERS), and the California Public Utilities Commission (together, the "California Parties") that resolves both the Trading
Investigation and the Bidding Investigation. The settlement was approved by the FERC and is final so there is no longer any potential
liability.
Califo rnia Refund Proceeding
In July 200 I , the FERC ordered an evidentiary hearing to determine the amount of refunds due to Califomia enerry buyers for
purchases made in the spot markets operated by the CallSO and the CaIPX during the period from October 2,2000 to June 20,2001
(Refund Period). Petitions for review of the FERC's decisions are still pending in the Ninth Circuit. In August 2006, the Ninth Circuit
remanded to the FERC its decision not to consider a Federal Power Act (FPA) section 309 remedy for tariffviolations prior to October
2,2OOO. During the FERC hearing on the remandin2Ol2,the Presiding Administrative Law Judge (ALJ) issued a partial initial
decision granting Avista Corp.'s motion for summary disposition. On November 2,2012, the FERC issued an order affrrming the
partial initial decision and dismissing Avista Corp. from the proceeding. On February I 5, 20 I 3, the ALJ issued an Initial Decision that
may have subjected Avista Energy to additional refund liability.
On March 7,2014, Avista Corp., Avista Energy and the California Parties filed a settlement at the FERC that fully resolved these
matters. Because Avista Energy had not been paid for all of its sales during the Refund Perioil, substantial funds have been held in
escrow accounts pending resolution of this proceeding. The settlement returned $15.0 million of Avista Energy's receivable to Avista
Energy, with the balance of the Avista Enerry receivable flowing to the purchasers associated with the hourly transactions at issue. The
settlement funds were received on June 23,2014 and recorded as a reduction to other operating expenses within the non-utility
operating expenses section of the Statements of Income. There is no admission of wrongdoing on the part of the settling parties and no
part of the refund payment by Avista Energy constitutes a fine or a penalty. The settlement resolves all claims for alleged overcharges
in the California Refund Proceeding, and in the Pacific Northwest Refund Proceeding (for sales made to CERS). The settlement also
includes settlement of the Trading Investigation, the Bidding lnvestigation and the California Attorney General Complaint (the
"Lockyer Complaint"). The sefflement was approved by the FERC and is final so there is no longer any potential liability.
California Attornqt General Comphint (the "Lockyer Complaint")
In May 2002, the FERC dismissed a complaint filed in March 2002by the California AG that alleged violations of the FPA by the
FERC and all sellers (including Avista Corp. and its subsidiaries) of electric power and energy into Califomia. The cornplaint alleged
that the FERC's implementation of market-based rate authority was flawed and, as a result, individual sellers should refund the
difference between the rate charged and a just and reasonable rate. In May 2002,the FERC issued an order dismissing the complaint.
In September 2004, the Ninth Circuit upheld the FERC!s market-based rate authority, but held that the FERC ened in ruling that it
lacked authorify to order refunds for violations of its reporting requirement. The Court remanded the case for furttrer proceedings,
which ultimately resulted in summary disposition at the FERC in favor of Avista Corp. and Avista Energy. The proceeding is now
before the Ninth Circuit.
On March 7,2014, Avista Corp., Avista Enerry and the Califomia Parties filed a settlement at the FERC that resolves this matter. The
FERC FORM NO,2/3-Q 12-071 122.40
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t20't5
Year/Period of Report
2014tQ4
Notes to Financial Statements
settlement was approved by the FERC and is final so there is no longer any potential liability.
Pacilic Northwest Refund Proceedin g
In July 2001, the Federal Energy Regulatory Commission ('FERC" or "Commission") initiated a preliminary evidentiary hearing to
develop a factual record as to whether prices for spot market sales of wholesale energy in the Pacific Northwest between December 25,
2000 and June 20, 2001 were just and reasonable. In June 2003, the FERC terminated the Pacific Northwest refund proceedings, after
finding that the equities do not justif-y the imposition of refunds. In August 2007,the Ninth Circuit found that the FERC had failed to
take into account new evidence of market manipulation and that such failure was arbitrary and capricious and, accordingly, remanded
the case to the FERC, stating that the FERC's findings must be reevaluated in light of the new evidence. The Ninth Circuit expressly
declined to direct the FERC to grant refunds. On October 3, 201l, the FERC issued an Order on Remand. On April 5,2}l3,the FERC
issued an Order on Rehearing expanding the temporal scope of the proceeding to permit parties to submit evidence on transactions
during the period from January I , 2000 through and including June 20, 200 L The Order on Remand established an evidentiary,
trial-type hearing before an ALJ, and reopened the record to p€rmit parties to present evidence of unlawful market activity. The Order
on Remand stated that parties seeking refunds must submit evidence demonstrating that specific unlawful market activity occurred, and
must demonstrate that such activity directly affbcted negotiations with respect to the specific contract rate about which they complain.
Simply alleging a general link between the dysfunctional spot market in California and the Pacific Northwest spot market would not be
sufficient to establish a causal connection between a particular seller's alleged unlawful activities and the specific contract negotiations
at issue. The hearing was conducted in August through October 2013. The City of Seattle, Washington (Seattle) and the
California AG (on behalf of CERS) fited petitions for review of FERC's Order on Remand in the 9th Circuit Court of
Appeals, which petitions were stayed pending completion of the FERC proceeding.
On July 1l , 2012 and March 28, 2013 , Avista Energy and Avista Corp. filed settlements of all issues in this docket with regard to the
claims made by the City of Tacoma and the California AG (on behalf of CERS). The FERC approved the settlements and they are
final. The remaining direct claimant against Avista Corp. and Avista Energy in this proceeding is Seattle.
With regard to the Seattle claims, on March 28,2014, the Presiding ALJ issued her Initial Decision finding that: l) Seattle failed to
demonstrate that either Avista Corp. or Avista Energy engaged in unlawful market activity and also failed to identif any specific
contracts at issue; 2) Seattle failed to demonstrate that contracts with either Avista Corp. or Avista Energy imposed an excessive
burden on consumers or seriously harmed the public interest; and that 3) Seattle failed to demonstrate that either Avista Corp. or Avista
Energy engaged in any specific violations ofsubstantive provisions ofthe Federal Power Act or any filed tariffs or rate schedules.
Accordingly, the ALJ denied all of Seattle's claims under both section 206 and section 309 of the Federal Power Act. Briefs on and
opposing exceptions have been filed and the Initial Decision is pending before the FERC.
The 9th Circuit by Order dated February 17 , 2Ol5 issued on its own motion, lifted the stay of the 20 I 3 interlocutory petitions for
review of the FERC Order on Remand and established a briefing schedule for those petitions, including Seattle's petition challenging
the scope of the Remand Order. Any decision by the 9th Circuit adverse to the Company could only result in a further remand to FERC
to conduct further proceedings, the scope of which cannot be predicted at this time. The Company does not expect that this matter will
have a material adverse effect on its financial condition, results of operations or cash flows.
Sicrra Club and Monlana Environmental Informalion Center Complaint Against the Owners of Colstrip
On March 6,2013, the Siena Club and Montana Environmental Information Center (MEIC) (collectively "Plaintiffs"), filed a
Complaint in the United States District Court for the District of Montana, Billings Division, against the Owners of the Colstrip
Generating Project ("Colstrip"). Avista Corp. owns a l5 percent interest in Units 3 & 4 of Colstrip. The other Colstrip co-Owners are
PPL Montana, Puget Sound Energy, Portland General Elecfic Company, NofthWestern Energy and PacifiCorp. The Complaint
alleges certain violations of the Clean Air Act, including the New Source Review, Title V and opacity requirements. The Plaintiffs
FERC FORM NO. 2/3-Q (REV 12-07 122.41
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2) _A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
request that the Court grant injunctive and declaratory relief impose civil penalties, require a beneficial environmental project in the
areas affected by the alleged air pollution and require payment of Plaintiffs'coss of litigation and attorney fees.
On September 12,2013, the Plaintiffs filed Plaintiffs' First Motion for Partial Summary Judgment on the Applicable Method for
Calculating Emission Increases from Modifications Made to Colstrip.
On September 27,2013, the Plaintiffs filed an Amended Complaint, The Amended Complaint withdrew from the original Complaint
fifteen claims related to seven pre-January l,2001 Colstrip maintenance projects, upgrade projects and work projects and claims
alleging violations of Title V and opacity requirements. The Amended Complaint alleges certain violations of the Clean Air Act and
the New Source Review and adds claims with respect to post-January l, 2001 Colstrip projects. The Plaintiffs request that the Court
grant injunctive and declaratory relief, order remediation of alleged environmental damage, impose civil penalties, require a beneficial
environmental project in the areas affected by the alleged air pollution and require payment of Plaintiffs' costs of Iitigation and
attorney fees. The Colstrip Owners filed a Motion to Dismiss, seeking dismissal of all of Plaintiffs' claims contained in the Amended
Complaint.
On May 22,2014, the Magistrate Judge filed his Findings and Recommendations as to the motions and recommended that l) the
Colstrip Owners' Motion to Dismiss be granted as to the Plaintiffs'Best Available Control Technology claims and the injunctive relief
sought regarding two of the claims, but denied the Motion in all other respects; and 2) the Plaintiffs'Motion for Partial Summary
Judgment be denied. Plaintiffs'filed Objections to Findings and Recommendations of Magistrate Judge and the Colstrip Owners filed
their response to Plaintiffs' objections.
On August 27,2014, the Plaintiffs filed a Second Amended Complaint. The Second Amended Complaint withdraws from the
Amended Complaint five claims and adds one new claim. The Second Amended Complaint alleges certain violations of the Clean Air
Act and the New Source Review. The Plaintiffs request that the Court grant injunctive and declaratory relief, order remediation of
alleged environmental damages, impose civil penalties, require a beneficial environmental project in the areas affected by the alleged
air pollution and require payment of Plaintiffs' costs of litigation and attorney fees.
The Court has set the trial date for November 2015.
Management believes that it is reasonably possible that this matter could result in a loss to the Company. However, due to uncertainties
conceming this matter, Avista Corp. cannot estimate the outcome or determine whether it would have a material impact on the
Company.
Spokane River Licensing
The Company owl'ts and operates six hydroelectric plants on the Spokane River. Five of these (Long Lake, Nine Mile, Upper Falls,
Monroe Street, and Post Falls) are regulated under one 50-year FERC license issued in June 2009 and are referred to as the Spokane
River Project. The sixth, Liftle Falls, is operated under separate Congressional authority and is not licensed by the FERC. The license
incorporated the 4(e) conditions that were included in the December 2008 Settlement Agreement with the United States Department of
Interior and the Coeur d'Alene Tribe, as well as the mandatory conditions that were agreed to in the Idaho 401 Water Quality
Certifications end in the amended Washington 401 Water Quality Certification.
As part of the Settlement Agreement with the Washington Department of Ecology (Ecology), the Company has participated in the
Total Maximum Daily Load (TMDL) process for the Spokane River and Lake Spokane, the reservoir created by Long Lake Dam. On
May 20,2010, the EPA approved the TMDL and on May 27,2010, Ecolory filed an amended 401 Water Quality Certification with
the FERC for inclusion into the license. The amended 401 Water Quality Certification includes the Company's level of responsibility,
as defined in the TMDL, for low dissolved oxygen levels in Lake Spokane. The Company submitted a draft Water Quality Attainment
Plan for Dissolved Oxygen to Ecology in May 2012 and this was approved by Ecology in September 2012. This plan was subsequently
approved by the FERC. The Company began implementing this plan in 2013, and management believes costs will not be material. On
July 16, 2010, the City of Post Falls and the Hayden Area Regional Sewer Board filed an appeal with the United States District Court
FERC FORM NO. Z3.Q (REV 12-07 122.42
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
20141Q4
Notes to Financial Statements
for the District of Idaho with respect to the EPA's approval of the TMDL. The Company, the City of Coeur d'Alene, Kaiser Aluminum
and the Spokane River Keeper subsequently moved to intervene in the appeal. In September 201 l, the EPA issued a stay to the
litigation that will be in effect until either the permits are issued and all appeals and challenges are complete or the court lifts the stay.
On February 19,2015, the Court dismissed the case as stipulated to by all parties.
During 2013, through a collaborative process with key stakeholders, a decision was reached to not move forward with a specific capital
project to add oxygen to Lake Spokane. At the time of such decision, the Company had expended $ 1.3 million on the discontinued
project. The Company obtained regulatory Orders from the UTC and IPUC during the second half of 2013, allowing regulatory
treatment of the costs from the discontinued project.
The UTC and IPUC approved the recovery of licensing costs through the general rate case settlements in 2009. The Company will
continue to seek recovery, through the ratemaking process, of all operating and capitalized costs related to implementing the license for
the Spokane River Project.
Cabinet Gorge Total Dissolved Gas Abatement Plan
Dissolved atmospheric gas levels in the Clark Fork River exceed state of Idaho and federal water quality standards downstream of the
Cabinet Gorge Hydroelectric Generating Project (Cabinet Gorge) during periods when excess river flows must be diverted over the
spillway. Under the terms of the Clark Fork Settlement Agreement as incorporated in Avista Corp.'s FERC license for the Clark Fork
Project, Avista Corp. has worked in consultation with agencies, tribes and other stakeholders to address this issue. In the second
quarter of 20 I I , the Company completed preliminary feasibility assessments for several alternative abatement measures. ln 2012,
Avista Corp., with the approval of the Clark Fork Management Committee (created under the Clark Fork Settlement Agreement),
moved forward to test one of the alternatives by constructing a spill crest modification on a single spill gate. Based on testing in 2013,
the modification appears to provide significant Total Dissolved Gas reduction. Ongoing design improvements have been made, and the
Company expects to continue spill crest modifications over the next several years, in ongoing consultation with key stakeholders. The
Company will continue to seek recovery, through the ratemaking process, of all operating and capitalized costs related to this issue.
Fish Passage at Cabinet Gorge and Noxon Rapids
In 1999, the United States Fish and Wildlife Service (USFWS) listed bull trout as threatened under the Endangered Species Act. The
Clark Fork Sefflement Agreement describes programs intended to help restore bull trout populations in the project area. Using the
concept of adaptive management and working closely with the USFWS, the Company evaluated the feasibility of fish passage at
Cabinet Gorge and Noxon Rapids. The results of these studies led, in part, to the decision to move forward with development of
permanent facilities, among other bull trout enhancement efforts. Fishway designs for Cabinet Gorge are still being finalized.
Construction cost estimates and schedules will be developed after several remaining issues are resolved, related to Montana's approval
of fish transport from Idaho and expected minimum discharge requirements. Fishway design for Noxon Rapids has also been initiated,
and is still in early stages.
In January 20 10, the USFWS revised its 2005 designation of critical habitat for the bull trout to include the lower Clark Fork River as
critical habitat. The Company believes its ongoing efforts through the Clark Fork Settlement Agreement continue to effectively address
issues related to bull trout. The Company will continue to seek recovery, through the ratemaking process, of all operating and
capitalized costs related to fish passage at Cabinet Gorge and Noxon Rapids.
Keale Falls Generation Slation - Diesel Spill Investigalion and Remediation
In December 201 3, the Company's operations staff at the Kettle Falls Generation Station discovered that approximately 10,000 gallons
of diesel fuel had leaked underground from the piping system used to fuel heavy equipment. Avista Corp. made all proper agency
notifications and worked closely with Ecology during the spill response and investigation phase. The Company installed ground water
monitoring wells and there is no indication that gound or surface water is threatened by the spill.
FERC FORM NO.2/3-Q ,|122.43
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
There is no indication that Ecolory is considering any enforcement action and the Company initiated a voluntary cleanup action with
the installation of a recovery system.
As of December 31, 2014,the Company has recorded an estimated remediation liability and the Company will continue to monitor the
remediation activities and will adjust any estimated remediation liability if necessary as new information is obtained. The Company
does not expect that this matter will have a material effect on its financial condition, results of operations or cash flows.
C o llective B argainin g A g reements
The Company's collective bargaining agreements with the IBEW represents approximately 45 percent of all of Avista Corp.'s
employees. The agreement with the local union in Washington and Idaho representing the majority (approximately 90 percent) of the
Avista Corp.'s bargaining unit employees expired in March 2014. A new two-year agreement with this group was approved in January
2015 and has an expiration of March 2016. A new three-year agreement in Oregon, which covers approximately 50 employees, was
approved in April20l4.
Other Contingencies
ln 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 analyses 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 or AEL&P's operations, the Company seeks, to the
extent appropriate, recovery ofincurred costs through the ratemaking process.
The Company has potential liabilities under the Endangered Species Act for species of fish 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 ratemaking process, of all operating and
capitalized costs related to this issue.
Under the federal licenses for its hydroelectric projects, the Company is obligated to protect its property rights, including water rights.
The state of Montana is examining the status of all water right claims within state boundaries. Claims within the Clark Fork fuver basin
could adversely affect the enerry 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. In addition, the state of Washington has indicated an interest in initiating adjudication for the Spokane River
basin in the next several years. The Company is and will continue to be a participant in these 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.
NOTE 18. INFORMATION SERVICES CONTRACTS
The Company has information services contracts that expire at various times through 2017. The largest of these contracts provides for
increases due to changes in the cost of living index and further provides flexibility in the annual obligation from year-to-year. Total
FERC FORM NO.2/3.Q V1 122.44
Name of Respondent
Avista Corooration
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014t44
Notes to Financial Statements
payments under these contracts were as follows for the y,ears ended December 31 (dollars in thousands):
20t4
Information service contract payments 13,022 S 12,647
following table details minimumThe majority of the costs are included in other operating expenses in the Statements of Income. The
future contractual commitments for these agreements (dollars in thousands):
2015 2016 2017 201 8 2019 Thereafter Total
Contractual obligations S 9,047 S 9,141 $9,237 $-$-s -$)1 A)\
NOTE 19. REGULATORY MATTERS
Power Cost Deferrals and Recovery Mechanisms
Deferred power supply costs are recorded as a deferred charge on the Balance Sheets for future prudence review and recovery through
retail rates. The power supply costs deferred include certain differences between actual net power supply costs incured by Avista
Corp. and the costs included in base retail rates. This difference in net power supply costs primarily results from changes in:
o short-term wholesale market prices and sales and purchase volurnes,
o the level and availability ofhydroelectric generation,
r the level and availabiliry of thermal generation (including changes in fuel prices), and
. retail loads.
In Washington, the ERM allows Avista Corp. to periodically increase or decrease electric rates with UTC 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. Total net deferred power
costs under the ERM were a liability of $ 14.2 million as of December 31,2014, and these defened power cost balances represent
amounts due to customers. As part of the approved Washington general rate case settlement in December 2012, during 2013 there was
a one-year credit designed to refurn to customers $4.4 million from the existing ERM deferral balance which reduced the net average
electric rate increase impact to customers in 2013. Additionally, during 2014 there was a one-year credit designed to return $9.0
million to electric customers from the ERM defenal balance, so the net average electric rate increase impact to customers effective
January 1,2014 rvas also reduced. The credits to customers from the ERM balances do not impact the Company's net income.
Under the ERM, the Company absorbs the cost or receives the benefit from the initial amount of power supply costs in excess of or
below the level in retail rates, which is referred to as the deadband. The annual (calendar year) deadband amount is $4.0 million. The
Company will incur the cost of, or receive the benefit from, 100 percent of this initial power supply cost variance, The Company shares
annual power supply cost variances between $4.0 million and $10.0 million with customers. There is a 50 percent customers/S0
percent Company sharing ratio when actual power supply expenses are higher (surcharge to customers) than the amount included in
base retail rates within this band. There is a 75 percent customers/25 percent Company sharing ratio when actual polver supply
expenses are lower (rebate to customers) than the amount included in base retail rates within this band. To the extent that the annual
power supply cost variance from the amount included in base rates exceeds $10.0 million, there is a 90 percent customers/I0 percent
Company share ratio of the cost variance.
The following is a summary of the ERM:
Deferred for Future
Surcharge or Rebate
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2015
Year/Period of Report
20141Q4
Notes to Financial Statements
Annual Power Supply Cost Variability to Customers
within +/- $0 to $4 million (deadband)
higher by $4 million to $10 million
lower by $4 million to $10 million
higher or lower by over $ l0 million
0%
50%
7s%
90%
100%
500,6
25%
10%
Avista Corp. has a PCA mechanism in Idaho that allows it to modify electric rates on October I 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. These annual October I 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 a
regulatory asset of $8.3 million as of December 31,2014 compared to a regulatory asset of $5.I million as of December 3 l, 2013.
Naturul Gas Cost Deferrats and Recovery Mechanisms
Avista Corp. files a PGA in all three states it serves to adjust natural gas rates for: l) 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. These annual PGA filings in Washington and Idaho provide for the deferral, and recovery or "
refund, of 100 percent of the difference between actual and estimated commodity and pipeline transportation costs, subject to
applicable regulatory review. The annual PGA filing in Oregon provides for deferral, and recovery or refund, of 100 percent of the
difference between actual and estimated pipeline transportation costs and commodity costs that are fixed through hedge transactions.
Commodity costs that are not hedged for Oregon customers are subject to a sharing mechanism whereby Avista Corp. defers, and
recovers or refunds, 90 percent ofthe difference between these actual and estimated costs. Total net deferred natural gas costs to be
refundpd to customers were a liabiiity of $3.9 million as of December 31,2014 compared to a liability of $12.1 million as of
December 31,2013.
ll/asltington General Rate Cases
201 2 General Rate Cases
In December 2012,the UTC approved a settlement agreement in the Company's electric and natural gas general rate cases filed in
April 2012. The settlement, effective January 1,2013, provided that base rates for Washinglon electric customers increased by an
overall 3.0 percent (designed to increase annual revenues by $13.6 million), and base rates for Washington natural gas customers
increased by an overall 3.6 percent (designed to increase annual revenues by $5.3 million). Under the settlement, there was a one-year
credit designed to retum $4.4 million to electric customers from the ERM deferral balance so the net average electric rate increase
impact to the Company's customers in 201 3 was 2.0 percent. The credit to customers from the ERM balance did not impact the
Company's earnings.
The approved settlement also provided that, effective January 1,2014, base rates increased for Washington electric customers by an
overall 3.0 percent (designed to increase annual revenues by $14.0 million), and for Washington natural gas customers by an overall
0.9 percent (designed to increase annual revenues by $ I .4 million). The settlement provided for a one-year credit designed to retum
$9.0 million to electric customers from the ERM deferral balance, so the net average electric rate increase to customers effective
January 1,2014 was 2.0 percent. The credit to customers from the ERM balance did not impact the Company's earnings. The ERM
balance as of December 31,2014 was a liability of $14.2 million.
The settlement agreement, provided for an authorized return on equiry of 9.8 percent and an equity ratio of 47.0 percent, resulting in an
overall rate of return on rate base of 7.64 percent.
The December 2012 UTC Order approving the settlement agreement included certain conditions.
(l) The new retail rates that became effective on January 1,2014 were temporary rates, and on January l, 2015, electric and
FERC FORM NO. 2/3-Q (REV 12-07)122.46
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
natural gas base rates were scheduled to revert back to 201 3 levels absent any intervening action from the UTC. The original
settlement agreement had a provision that the Company would not file a general rate case in Washington seeking new rates to
take effect before January 1,2015. In November 2014,the UTC approved a settlement agreement to the Company's
Washington general rate cases which were originally filed in February 201 4 with rates effective on January I , 201 5 (see
further discussion below).
(2) In its Order, the UTC found that much of the approved base rate increase was justified by the planned capital expenditures
necessary to upgrade and maintain the Company's utility facilities, If these capital .projects are not completed to a level that
was contemplated in the settlement agreement, this could result in base rates which are considered too high by the UTC. The
Company is required to file capital expenditure progress reports with the UTC on a periodic basis so that the UTC can
monitor the capital expenditures and ensure they are in line with those contemplated in the settlement agreement. Total utility
capital expenditures among alljurisdictions were $294.4 million and $323.9 million for 2013 and2014 respectively. The
Company expects utility capital expenditures to be about $375 million for 2015 and $350 million in2016, which are above
the capital expenditures contemplated in the settlement agreement.
20I4 General Rate Cases
ln November 2014,the UTC approved an all-party settlement agreement related to the Company's electric and natural gas general rate
cases filed in February 2014 and new rates became effective on January 1,2015. The settlement is desigrred to increase annual electric
base revenues by $12.3 million, or 2.5 percent, inclusive of a $5.3 million power supply update as required in the settlement agreement
(explained below). The settlement is desigrred to increase annual natural gas base revenues by $8.5 million, or 5.6 percent.
Expiring and New Rebates and ERM
The parties agreed in the settlement that a credit of $8.3 million (including the $5.3 million power supply update) from the
ERM deferral balance will be returned to electric customers to help offset the 2015 rate increase. This ERM balance represents
lower net power supply costs in recent years than the costs embedded in base retail rates, which are being retumed to
customers in the form of a rebate. This rebate will not increase or decrease the Company's net income. Total net deferred
power costs under the ERM were a liability of $ 14.2 million as of December 31,2014, compared to a liability of $ 17.9 million
as of December 31,2013, and these deferred power cost balances represent amounts due to customers.
In addition, the Company's electric customers were receiving benefits from two rebates that expired at the end of 2014 and
which reduced monthly energy bills by 2.8 percent during 2014. The parties agreed in the settlement that the Company will
provide a rebate to customers of $8.6 million over an l8 month period related to the sale of renewable energy credits, which
will partially replace the expiring rebates and reduce customers' rnonthly bills by I .2 percent. beginning January 1 , 20 I 5. The
net effect of the expiring rebates and the new rebate will result in an increase of approximately 1.6 percent beginning January
l, 2015. These rebates are passed through to customers and do not increase or decrease the Company's net income.
The overall change in customer billing rates from the approved settlement agreement, including the expiring and new rebates,
is 2.5 percent for electric customers and 5.6 percent for natural gas customers effective January 1, 2015.
Power Supply Update and Customer Information and Work Management Systems Deferral
The settlement agreement included a provision that required the Company to update base power supply costs on November l,
2014. This update to power supply costs was reflected in the overall electric revenue increase effective January 1,2015, and
reset the base power supply costs for the ERM calculations effective January 1,2015. The amount of the updated power supply
costs was a $5.3 million increase. The increase to customers from the power supply update was offset with the available ERM
deferral balance for the calendar year 2015. The use ofthe ERM deferral balance for the offset will not increase or decrease the
Company's net income.
The parties also agreed that the natural gas revenue requirement associated with the Company's investment in the Customer
FERC FORM NO,2/3-Q 't2-07 122,47
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
lnformation and Work Management Systems capital project (Project Compass) for 2015 will be deferred for regulatory
purposes for recovery in retail rates through a future general rate case, based on the actual costs of the project at the time it
goes into service. Project Compass went into service in February 2015. The future recovery of these costs and return on
investment, estimated to be S2,0 million on a pre-tax basis, will be recognized in the future recovery period.
Decoupling
The parties agreed that the Company will implement electric and natural gas decoupling mechanisms for a five-year period
beginning January 1 , 20 1 5. Decoupling is a mechanism designed to sever the link between a utility's revenues and consumers'
energy usage. The Company's actual revenue, based on kilowatt hour and therm sales will vary, up or down, from the level
established in a general rate case, This could be due to changes in weather, conservation or the economy, Per the terms of the
settlement agreement and the decoupling mechanisms included therein, generally, electric and natural gas revenues will be
adjusted each month to be based on the number of customers, rather than kilowatt hour and therm sales. The difference
between revenues based on sales, and revenues based on the number ofcustomers will be deferred and either surcharged or
rebated to customers beginning in the following year. Electric and natural gas decoupling surcharge rate adjustments to
customers are limited to 3 percent 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 will be made for the prior calendar year. These eamings tests will reflect actual decoupled
revenues, normalized power supply costs, and other normalizing adjustments.
o If there is a decoupling rebate balance for the prior year and Avista Corp. earns in excess of a 7 .32 percent rate of return
(ROR), the rebate to customers would be increased by 50 percent of the earnings in excess of the 7 .32 percent ROR.
o If there is a decoupling rebate balance for the prior year and Avista Corp. earns a7.32 percent ROR or less, only the base
amount of the rebate to customers would be made.
o If there is a decoupling surcharge balance for the prior year and Avista Corp. earns in excess of a7.32 percent ROR, the
surcharge to customers would be reduced by 50 percent of the earnings in excess of the 7 .32 percent ROR (or eliminated).
o If there is a decoupling surcharge balance for the prior year and Avista Corp. eams a7.32 percent ROR or less, the base
amount of the surcharge to customers would be made.
Original Request
The Company's original request filed with the UTC in February 2014 included a base electric rate increase of 3.8 percent
(designed to increase annual electric revenues by $ 18.2 million). The Company also requested a base natural gas rate increase
of8.l percent (designed to increase annual natural gas revenues by $12.1 million). Specific capital structure ratios and the cost
of capital components were not agreed to in the settlement agreement, and the revenue increases in the seftlement were not tied
to the 7.32 percent ROR referenced above. The electric and natural gas revenue increases were negotiated numbers, with each
party using its own set of assumptions underlying its agreement to the revenue increases. The parties agreed that the 7 .32
percent ROR will be used to calculate the Allowance for Funds Used During Construction (AFUDC) and other purposes.
2015 General Rate Cases
In February 2015, the Company filed electric and natural gas general rates cases with the UTC. The Company has requested an overall
increase in base electric rates of 6.6 percent (designed to increase annual electric revenues by $33.2 million) and an overall increase in
base natural gas rates of 7.0 percent (designed to increase annual natural gas revenues by $12.0 million). The Company's requests are
based on a proposed ROR on rate base of 7 .46 percent with a common equity ratio of 48 percent and a 9.9 percent return on equity.
The major driver of these general rate case requests is to recover the costs associated with the ongoing need to maintain, replace and
FERC FORM NO.2/3-Q v 12-07 122.48
Name of Respondent
Avista Corporation
This Report is:
(1)X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
invest in the Company's facilities and equipment. Several significant capital investrnents the Company has made and is currently
making, that are included in the filing are:
o the ongoing and multi-year redevelopment of the Little Falls Powerhouse on the Spokane River,
o the continuing rehabilitation of the Nine Mile Powerhouse on the Spokane River,
o information technology upgrades that include the replacement of the Company's customer information and work management
systems (which were implemented in February 2015),
o the ongoing project to systematically replace portions of Aldyl-A natural gas distribution pipe, and
o technology investments for deploying Advanced Metering Infrastructure in Washington, including installation of advanced
meters, beginning in 2016.
The UTC has up to I I months to review the filings and issue a decision.
Iduho General Rate Cases
2012 General Rate Cases
In March 2013, the IPUC approved a seftlement agreement in the Company's electric and natural gas general rate cases filed in
October 2012. As agreed to in the settlement, new rates were implemented in two phases: April l, 2013 and October l,2}l3.
Effective April 1, 20 13, base rates increased for the Company's Idaho natural gas customers by an overall 4.9 percent (designed to
increase annual revenues by $3.1 million). There was no change in base electric rates on April l, 2013. However, the settlement
agreement provided for the recovery of the costs of the Palouse Wind Project, subject to the 90 percent customers/I0 percent Company
sharing ratio, through the PCA mechanism until these costs are reflected in base retail rates in the next general rate case.
The settlement also provided that, effective October 1,2013, base rates increased for ldaho natural gas customers by an overall 2.0
percent (designed to increase annual revenues by $ I .3 million). A credit resulting from defened natural gas costs of $ 1 .6 million was
returned to the Company's Idaho natural gas customers from October I , 201 3 through December 3l ,2014, so the net annual average
natural gas rate increase to natural gas customers effective October l, 2013 was 0.3 percent.
Further, the settlement provided that, effective October 1,2013, base rates increased for Idaho electric customers by an overall 3.1
percent (designed to increase annual revenues by $7.8 million). A 53.9 million credit resulting from a payment to be made to Avista
Corp. by the Bonneville Power Administration relating to its prior use of Avista Corp.'s transmission system was retumed to Idaho
electric customers from October 7,2073 through December 31,2014, so the net annual average electric rate increase to electric
customers effective October 1,2013 was 1.9 percent.
The $1.6 million credit to Idaho natural gas customers and the $3.9 million credit to Idaho electric customers did not impact the
Company's net income.
The settlement agreement provided for an authorized return on equity of 9.8 percent and an equity ratio of 50.0 percent.
The settlement also included an after-the-fact eamings test for 2013 and 2014, such that if Avista Corp., on a consolidated basis for
electric and natural gas operations in ldaho, earns more than a 9.8 percent retum on equity, Avista Corp. will share with customers 50
percent of any earnings above the 9.8 percent. ln 2013, the Company's retums exceeded this level and $3.9 million was deferred for
future ratemaking treatment for Idaho electric customers and $0.4 million for Idaho natural gas customers. Of the electric deferral
amount, $2.0 million was recorded in 2013 and $1.9 million was recorded in the first quarter of 2014 based on a revision of the
allocation of costs between Idaho and Washington for regulatory purposes. The ratemaking treatment for these deferrals is addressed in
the 2014 rate plan extension request explained below.
[n2014, the Company's returns exceeded a 9.8 percent return on equity and the Company deferred for future ratemaking teatment
FERC FORM NO.2/3-Q ,|122.49
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2015
Year/Period of Report
2U4lA4
Notes to Financial Statements
$7.5 million (including the $1.9 million related to 2013 that was recorded in2014) for Idaho electric customers and $0.2 million for
Idaho natural gas customers. The period over which these amounts will be retumed to customers has not yet been determined by the
IPUC.
2014 Rate Plan Extension
The Company did not file new generalrate cases in ldaho in2014, instead, it developed an extension to the 2013 and2014 rate plan
and reached a settlement agreement with all interested parlies.
In September 2014, the IPUC approved the settlement, which reflects agreement among all interested palties, for a one-year extension
to the current rate plan, which was set to expire on December 31,2014. Under the approved extension, base retail rates will remain
unchanged through December 3 l, 201 5.
The settlement will provide an estimated $3.7 million increase in pre-tax income by reducing planned expenses in 2015 for Idaho
operations, resulting from:
o the delay of the beginning of the amortization of the 2013 previously deferred operations and maintenance costs pertaining to
the Colstrip and Coyote Springs 2 thermalgenerating facilities from 2015 to 2016, and
o deferred accounting, for later review and recovery, of the majority of the costs associated with Project Compass, which was
implemented in February 2015,
The settlement agreement establishes an ROE deadband between the currently authorized ROE of 9.8 percent and a 9.5 percent ROE.
Under the settlement agreement, the Company will be allowed to use any 2014 Idaho after-the-fact earnings test deferral (described
above under "2012 General Rate Cases") to support an actual earned ROE in 2015 up to 9.5 percent. For 2014, the Company deferred
a total of $7.7 million for the 201 4 after-the-fact eamings test, which includes the $ I .9 million recorded in 2014 related to ttre 2013
earnings test. During 2015, if the Company earns more than the 9.8 percent ROE, 50 percent of the earnings above 9.8 percent will be
shared with customers through future ratemaking.
As part of the settlement, the Company agreed not to file a general rate case in 2014, and would file no earlier than May 3 I , 20 I 5 for
new electric or natural gas base retail rates to become effective on or after January 1,2016. In addition, the settlement replaced two
rebates, which expired on January l, 2015, that were reducing customers' monthly enerry bills by 1.3 percent for electric and 1.7
percent for natural gas. The rebates were replaced for a one-year period, through December 3 l, 201 5, using existing deferral balances
due to customers, which will have no impact on the Company's net income. This provision does not preclude the filing of other rate
adjustments such as the PGA.
Oregon General Rate Cases
2013 General Rate Case
In January 2014, the OPUC approved a settlement agreement to the Company's natural gas general rate case (originally filed in August
2013). As agreed to in the settlement, new rates were implemented in two phases: February 1,2014 and November 7,2074. Effective
February 1,2014, rates increased for Oregon natural gas customers on a billed basis by an overall 4.4 percent (designed to increase
annual revenues by $3.8 million). Effective November 1,2014, rates for Oregon natural gas customers were to increase on a billed
basis by an overall l.6 percent (designed to increase annual revenues by $1.4 million).
The billed rate increase on November 1 ,2014 was dependent upon the completion of Project Compass and the actual costs incurred
through September 30,2014, and the actual costs incurred through June 30,2014 related to the Company's Aldyl A distribution
pipeline replacement program. As noted elsewhere, Project Compass was completed in February 2015. The November 1,2014 rate
increase was reduced from $ I .4 million to $0.3 million due to the delay of Project Compass.
FERC FORM NO.2/3-Q 1 122.50
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
The approved settlement agreement provides for an overall authorized rate of retum of 7 .47 percent, with a common equity ratio of 48
percent and a 9.65 percent return on equity.
2014 General Rate Case
ln January 2015, the Company filed an all-party settlement agreement with the OPUC related to the Company's natural gas general rate
case, which was originally filed in September 2014. The settlement agreement was designed to increase base natural gas revenues by
6.1 percent or $6.1 million. This base rate increase was offset by $0.3 million for a separate rate adjustment that the Company is
already receiving from customers and it was offset by a $0.8 million credit to customers related to having an early implementation date
for the revenue increase (prior to the full l0 months allowed in Oregon for the OPUC to make a decision on the case and new rates to
take effect). The net increase to the Company after the two offsets was $5.0 million. The parties to the settlement agreement had
requested a decision from the OPUC prior to March l, 201 5, such that new retail rates could be effective on March 1, 2015.
This settlement agreement provided for an overall authorized rate of return of 7.52 percent with a common equity ratio of 5l percent
and a 9.5 percent return on equity.
The original request was for an overall increase in base natural gas rates of9.3 percent (designed to increase annual natural gas
revenues by $9.1 million) and it was based on a proposed rate of return of 7 .77 percent with a common equity ratio of 5l percent and a
9.9 percent retum on equity.
On February 23,2015, the OPUC issued an order rejecting the all.party settlement agreement filed with the OPUC by the paties on
January 21,2015. The OPUC expressed concerns related to three issues: 1) the proposed early rate implementation credit; 2) the
combination ofproposed rate increases and rate decreases across the customer classes (rate spread); and 3) the customer count tracking
mechanism. With regard to the early rate implementation credit, the order stated, among other things, that there was no evidence in the
record that explains the derivation of the rate credit amount, or why the credit would be applied to all customer classes. On rate spread,
the OPUC's order expressed concern aboutproposed increases to rates for some customer classes, and decreases for other customer
classes, absent more compelling evidence. And finally, the OPUC expressed concern that the customer count tracking mechanism is
contrary to standard ratemaking.
The OPUC's order directed the Administrative Law Judge to convene a prehearing conference to schedule further proceedings in a
manner that will allow for the timely completion of the case. The OPUC's order also encouraged the parties to come back with a
partial stipulation that encompasses these issues. Furthernore, the OPUC stated that its order does not preclude the parties from
reaching a global settlement of all issues that addresses the concerns identified by the OPUC.
Bonneville Power Administration Reimbursement and Reardan Wind Generotion Project
In May 20 I 3, the UTC approved the Company's Petition for an order authorizing certain accounting and ratemaking treatment related
to two issues. The first issue relates to transmission revenues associated with a settlement between Avista Corp. and the BPA, whereby
the BPA reimbursed the Company $l 1.7 million for Bonneville's past use of Avista Corp,'s transmission system. The second issue
relates to $4.3 million of costs the Company incurred over the past several years for the development of a wind generation project site
near Reardan, Washington, which has been terminated. The UTC authorized the Company to retain $7.6 million of the BPA settlement
payment, representing the entire portion of the settlement allocable to the Washington business. However, this amount was deemed to
first reimburse the Company for the $2.5 million of Reardan project costs that were allocable to the Washington business, leaving $5.1
million to be retained for the benefit of shareholders.
The BPA agreed to pay $3.2 million annually for the future use of Avista Corp.'s transmission system. The Company separately
tracked and deferred for the customers' benefit, the Washington portion of these revenue payments in 2013 and2014 ($2. I million
annually). The Company implemented a one-year $4.2 million rate decrease for customers effective January 1,2014 to partially offset
the electric general rate increase effective January 1,2014. To the extent actual revenues from the BPA in 2013 and 2014 differ from
FERC FORM NO. 2/3-Q (REV 122.51
Name of Respondent
Avista Corooration
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Notes to Financial Statements
those refunded to customers in 2014, the difference will be added to or subtracted from the ERM balance. In ldaho, under the terms of
the approved rate case settlement, 90 percent of the portion of the BPA settlement allocable to the Idaho business ($4.1 million) was
credited back to customers over l5 months, beginning October 2013, and the Company is amortizing the Idaho portion of Reardan
costs ($ I .7 million) over a two-year period, beginning April 20 I 3.
NOTE 20. SUPPLEMENTAL CASH FLOW INFORMATION (in thousands):
2014 201\
Cash paid for interest
Cash paid for income taxes
$69,693 $70,444
$41,1s4 $42,497
FERC FORM NO.2/3.Q I 122.52
Name oI KesPonoenl
Avista Corporation
tnts Keoon ts:(1) [XlAn Original(2\ l-lA Resubmission
uate ()r raePgil,
(Mo, Da, Yr)
04115t2015
I ealrrglruu ot l1'gP(,It
End of 2014/Q4
Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization and Depletion
Line
No.
Item
(a)
Total Company
For the Current
Quarterl/ear
1 UTILITY PLANT
2 ln Service
e Plant in Service (Classified)4.501.741.499
4 Property Under Capital Leases 6,442,U9
5 Plant Purchased or Sold
b Completed Construction not Classified
7 Experimental Plant Unclassifi ed
I TOTAL Utility Plant (Iotal of lines 3 thru 7)4,508,183,848
I Leased to Others
10 Held for Future Use 4,964,376
11 Construction Work in Progress 223,330,993
12 Acquisition Adjustments
13 TOTAL Utility Plant (Total of lines 8 thru 12)4,736,479,217
14 Accumulated Provisions for Depreciation, Amortization, & Depletion 1,573,767,832
't5 Net Utility Plant (Total of lines 13 and 14)3,162,711,385
16 DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17 ln Service:
18 Depreciation 1,531,197,363
'19 Amortization and Depletion of Producing Natural Gas Land and Land Rights
20 Amortization of Underground Storage Land and Land Rights
21 Amortization of Other Utility Plant 42,570,469
22 TOTAL ln Service (Total of lines 18 thru 21)'t,573,767,832
23 Leased to Others
24 Depreciation
25 Amortization and Depletion
26 TOTAL Leased to Others (Total of lines 24 and 25)
27 Held for Future Use
28 Depreciation
29 Amortization
30 TOTAL Held for Future Use (Total of lines 28 and 29)
31 Abandonment of Leases (Natural Gas)
32 Amortization of Plant Acquisition Adjustment
33 TOTAL Accum. Provisions (Should agree with line 14 above)(Total of lines 22, 26, 30, 31, and 32)1,573,767,832
FERC FORM NO.2 (12-96)Page 200
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2\ l--'lAResubmission
Date of Report
(Mo, Da, Yr)
o4115t2015
Year/Period of Report
End of 20141Q4
Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization and Depletion (continued)
Line
No.
Electric
(c)
Gas
(d)
Other (specify)
(e)
Common
(0
3 3.325.688,469 889,870,069 286,182,961
4 858,864 5,583,485
5
6
7
8 3.325.688,469 890,728,933 291,766,446
9
10 4.773.791 190,585
1't 112,974,359 11,625,968 98,730,666
12
13 3,443,436,619 902,545,486 390,497.112
14 '1,196,318,690 298,791 ,678 78.657.464
15 2,247,117,929 603.753.808 31 t.839.648
18 1,181,974,217 296.850.488 52.372.658
2',1 '14,344,473 1 .941 .1 90 26.284.806
22 1 ,196,318,690 298.791.678 78.657.464
24
25
to
?8
29
30
32
33 1,196,318,690 298,791,678 78,657,4U
FERC FORM NO.2 (12-96)Page 201
Name oT Kesponqenl
Avista Corporation
tnts Keoon ts:(1) fiAn Original(2) l-lA Resubmission
uale oT Kepon
(Mo, Da, Yr)
04t15t2015
Yearrenoo oI Kepon
End ot 2O14lQ4
Gas Plant in Service (Accounts 10'1,102,103, and 106)
1. Report below the original cost of gas plant in service according to the prescribed accounts.
2. ln 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. lnclude 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 acc,ounts.
5. ClassifyAccount 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. lnclude also in column (d) reversals of tentative distributions of prior year's unclassified retirements.
Attach suoolemental statement showino the account distributions of these tentative classifications in columns (c) and (d).
Line
No.
Aerount
(a\
Balance at
Beginning of Year
/h\
Additions
/n)
1 INTANGIBLE PLANT
2 301 Orqanization
3 3O2 Franchises and Consents
4 303 MiscellaneouslntanqiblePlant 3,745,299 540,214
5 TOTAL lntangible Plant (Enter Total of lines 2 thru 4)3,745,299 540,214
6 PRODUCTION PLANT
7 Natural Gas Production and Gathering Plant
I 325.1 Producinq Lands
I 325.2 Producing Leaseholds
10 325.3 Gas Riqhts
'tl 325.4 Rights-of-Way
12 325.5 Other Land and Land Riohts
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 Producinq Gas Wells-Well Construction
'18 331 Producinq Gas Wells-Well EquiDment
19 332 Field Lines
20 333 Field Compressor Station Equipment
21 334 Field Measurinq and Requlatinq Station Equipment
22 335 Drilling and Cleaning Equipment
23 336 PurificationEquipment
24 337 Other Equipment
25 338 Unsuccessful Exploration and Development Costs
26 339 Asset Retirement Costs for Natural Gas Production and
27 TOTAL Production and Gathering Plant (Enter Total of lines 8
28 PRODUCTS EXTRACTION PLANT
29 340 Land and Land Rights
30 341 Structures and lmprovements
31 342 Extraction and Refining Equipment
32 343 Pioe Lines
33 344 Extracted Products Storage Equipment
FERC FORM NO.2 (12-96)Page 2M
Name of Respondent
Avista Corporation
This Reoort ls:(1) fien originat(2) l-lA Resubmission
uale oI Kepon(Mo, Da, Yr)
04t1st2015
Year/Period of Report
End ot 2O14lQ4
Gas Plant in Service (Accounts 101, 102, 103, and 1 06) (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 'l 01 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. lnclude also in column (f) the additions or reductions of primary account
classifications arising from distribution of amounts initially recorded in Account 102. ln 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 1 02, state the property purchased or sold, name of vendor or purchaser,
and date of transaction. lf proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give date of
such filinq.
Line
No.
Retirements
{d)
Adjustments
/e'l
Transfers
/fl
Balance at
End of Year
(o)
Z
3
4 214,892 4,070,621
5 2't4.892 4,070,62'.1
8
9
10
11
12
13
14
15
15
17
18
19
20
21
22
23
24
25
26
27
29
30
31
32
33
FERC FORM NO. 2 (12-96)Page 20s
Name oI Kesponoenl
Avista Corporation
I nts KeDon ls:(1) ffiRn Originat(2) [-lA Resubmission
uate ot Kepon
(Mo, Da, Yr)
04115t2015
Yea/l'efloo ol Kepon
End of 2014/Q4
Gas Plant in Service (Accounts 101 102,103, and 106) (continued)
Line
No.
Account
1a\
Balance at
Beginning of Year
rht
Additions
/c)
34 345 ComoressorEouioment
35 346 Gas Measuring and Regulating Equipment
Jb 347 Other Equipment
37 348 Asset Retirement Costs for Products Extraction Plant
38 TOTAL Products Extraction Plant (Enter Total of lines 29 thru 37)
39 TOTAL Natural Gas Production Plant (Enter Total of lines 27 and
40 Manufactured Gas Production Plant (Submit Supplementary 7.628
41 TOTAL Production Plant (Enter Total of lines 39 and 40)7,628
42 NATURAL GAS STORAGE AND PROCESSING PLANT
43 Underoround Storaoe Plant
44 350.1 Land 407.111
45 350.2 Riqhts-of-Way 59,812
46 351 Structures and lmprovements 1 ,537, 105 145,585
47 352 Wells 13,535,439 145,585
48 352.1 Storaqe Leaseholds and Riohts 254,354
49 352.2 Reservoirs 1,667,492
50 352.3 Non-recoverable Natural Gas 5,810,31'1
51 353 Lines 1 ,106,781
52 354 Compressor Station Equipment 14,511,062 145,585
53 355 Other Equipment 314,043 145,585
54 356 PurificationEouioment 403,712
55 357 Other Equipment 1,640,767 145.585
56 358 Asset Retirement Costs for Underoround Storaoe Plant
57 TOTAL Underground Storage Plant (Enter Total of lines 44 thru 41,247,989 727.925
58 Other Storaoe Plant
59 360 Land and Land Rights
60 361 Structures and lmprovements
61 362 Gas Holders
62 363 PurificationEouioment
63 363.'l Liouefaction Eouioment
64 363.2 Vaoorizino Eouioment
65 363.3 Compressor Equipment
65 363.4 Measurino and Reoulatino Eouioment
67 353.5 Other Equipment
68 363.6 Asset Retirement Costs for Other Storaqe Plant
69 TOTAL Other Storase Plant (Enter Total of lines 58 thru 68)
70 Base Load Liquefied Natural Gas Terminaling and Processing Plant
71 364.1 Land and Land Rights
72 364.2 Structures and lmorovements
73 364.3 LNG Processing Terminal Equipment
74 364.4 LNG Transoortation Eouioment
75 364.5 Measuring and Regulating Equipment
76 364.6 Comoressor Station Eouioment
77 364.7 Communications Equipmeni
78 364.8 Other Equipment
79 354.9 Asset Retirement Costs for Base Load Liquefied Natural Gas
80 TOTAL Base Load Liquefied Nat'l Gas, Terminaling and
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) TIA Resubmission
Date oI Hepon(Mo, Da, Yr)
04115t2015
Year/Period of Report
End of 2014/Q4
Gas Plant in Service (Accounts 101,102,103, and 106) (continued)
Line
No.
Retirements
(d)
Adjustments
(e)
Transfers
(fl
Balance at
End of Year
(o)
34
35
5b
37
38
39
40 7,628
41 7,628
44 407,111
45 59.812
46 1.682,690
47 13,681 ,024
48 254,354
49 1,667,492
50 5,810,31 1
51 1,106,781
52 14,656,647
53 't,443 458,'t85
54 403,712
55 11,366 1,774,986
56
57 12,809 41 ,963,105
59
60
61
52
63
64
65
bb
67
68
69
71
72
73
74
75
76
77
78
79
80
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
tnts I
(1)
(2)
ePort ls:
!lAn Original
lA Resubmission
lJale oI Kepon(Mo, Da, Yr)
o4t15t2015
Iearrefloq oI Kepon
End of 2014/Q4
Gas Plant in Service (Accounts 101,102,103, and 106) (continued)
Line
No.
Account
/a\
Balance at
Beginning of Year
/hl
Additions
/c\
81 TOTAL Nat'l Gas Storage and Processing Plant (Total of lines 57,41,247.989 727.925
82 TRANSMISSION PLAN
83 365.1 Land and Land Rights
84 365.2 Riohts-of-Wav
85 366 Structures and lmprovements
86 367 Mains
87 368 Compressor Station Equipment
88 369 Measuring and Regulating Station Equipment
89 37O Communication EouiDment
90 37'l Other Equipmenl
91 372 Asset Retirement Costs for Transmission Plant
92 TOTAL Transmission Plant (Enter Totals of lines 83 thru 91)
93 DISTRIBUTION PLANT
94 374 Land and Land Riqhts 780.729 75,006
95 375 Structures and lmorovements 1,141,789 16,2U
96 376 Mains 409,791,253 18,075,372
97 377 Compressor Station Equipment
98 378 Measurinq and Reoulatino Station Eouioment-General 9,863,765 467,543
99 379 Measuring and Regulating Station Equipment-City Gate 7.503,298 390,972
00 380 Services 226,710,782 29,405,297
01 381 Meters 10't.655,044 4,048,526
02 382 Meterlnstallations
03 383 House Regulators
04 384 House Requlator lnstallations
05 385 lndustrial Measuring and Requlating Station Equipment 4,406,009 282,386
06 386 Other Propertv on Customers'Premises
07 387 Other Eouioment 539
08 388 Asset Retirement Costs for Distribution Plant
09 TOTAL Distribution Plant (Enter Total of lines 94 thru 108)761,853,208 52,761,306
10 GENERAL PLANT
11 389 Land and Land Riohts 1,18',t,407
12 390 Structures and lmprovements 5.759.022 227.494
13 391 Office Furniture and Eouioment 476,825 155,203
14 392 Transportation Equipment 1 1 ,1 31 ,766 1,580,708
15 393 Stores Eouioment 141,498
16 394 Tools, Shop, and Garage Equipment 5,057,321 979,671
17 395 LaboratoryEquipment 360,271 246,667
18 396 Power Operated Equipment 4,653,823 337,770)
19 397 CommunicationEquipment 3j24,201 355,593
20 398 MiscellaneousEouioment 2,367
2t Subtotal (Enter Total of lines 111 thru 120)31 .928.501 3,207,566
22 399 Other Tanqible ProDertv
23 399.1 Asset Retirement Costs for General Plant
24 TOTAL General Plant (Enter Total of lines 121 , 122 and 123)31,928,501 3,207,566
25 TOTAL (Accounts 101 and 106)838,782,625 57,237,011
26 Gas Plant Purchased (See lnstruction 8)
27 (Less) Gas Plant Sold (See lnstruction 8)
28 Experimental Gas Plant Unclassified
29 TOTAL Gas Plant ln Service (Enter Total of lines 125 thru 128)838,782,625 57 ,237,01',1
FERC FORM NO.2 (12-96)Page 208
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn originat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04115120',t5
Year/Period of Report
End of 2014/Q4
Gas Plant in Service (Accounts 101 , 102, 1 03, and 1 06) (continued)
Line
No.
Retirements
(d)
Adjustments
(e)
Transfers
(fl
Balance at
End of Year
(o)
81 12,809 41,963,105
83
84
85
86
87
88
89
90
91
92
94 41 8)855,317
95 22,428 1 ,135,565
96 1,969,012 425,897,613
97
98 1 32,1 90 10,199,118
99 13,512 7,880,758
r00 629,1 63 255,486,916
01 1,551,381 1 04,1 52,1 89
02
103
04
05 4,688,395
06
07 539
08
09 4,317,686 4',t8)810,296,410
11 145,622 't,327,029
12 79,1 95 ( 145,622)5.761.699
13 7,388 624,640
14 459,38s 12,253,089
15 141,498
16 121 ,448 5,955,544
17 76,354 530,584
18 4,3'16,053
19 1,128 3,478,666
20 2,367
21 744,898 34,391,169
22
23
24 744,898 34,391 , 169
25 5,290,285 ( 418)890,728,933
26
27
128
t29 5,290,285 ( 418)890,728,933
FERC FORM NO.2 (12-96)Page
Name oI Hesponoent
Avista Corporation
This Reoort ls:(1) fiAn original(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Repor
End of 2014/Q4
Gas Plant Held for Future Use (Account 105)
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.
Line
No.
Description and Location
of Property
(a)
Date Originally lncluded
in this Account
(b)
Date Expected to be Used
in Utility Service
(c)
Balance at
End of Year
(d)
1 Gas Distribution Mains and Services 03t01t2007 159,823
2 located in Coeur d'Alene, ldaho
3 Gas Distribution Mains and Services 07101t2011 30,762
4 located in Coeur d'Alene, ldaho
5
6
7
8
I
10
11
12
13
14
15
16
17
18
19
20
2'l
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45 Total 1 90,585
FERC FORM NO. 2 (12-96)Page 214
(1) lX lAn Orisinal
Construction Work in Progress-Gas (Account 107)
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.
Construction Work in
Progress-Gas
(Account 107)
(b)
Estimated Additional
Cost of Project
Construct Chase Rd Gate Stn Post Falls lD
Minor Projects under $1,000,000
Estimated additional cost amounts represent a five year
FERC FORM NO. 2 (12-96)Page 216
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2015
Year/Period of Report
2014to,4
General Description of Construction Overhead Procedure
1. Foreachconstructionoverheadexplain: (a)thenatureandextentofwork,etc.,theoverheadchargesareintendedtocover,(b)thegeneral
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
lnstructions 3 (17) ofthe Uniform System ofAccounts.
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.
lConstmction costs with a direct relationship to new construction and capital replacement activities that
lcannot be clearly identified with specific projects are charged to overhead pools. The established
[pools are:
I Construction Overhead North Gas
I Constntction Overhead South Gas
lPool costs are allocated monthly to gas construction projects on a percent rate applied to direct project costs, excluding AFUDC.
lEach pool's rate is calculated separately and applied only to the related gas construction projects for allocation.
I
I
lAllowance for funds used during construction is calculated system wide using a rate that is equivalent to
Ithe allowed rate of return approved in the latest rate order from the company's primary state commission (Washington state).
lFor 2014 Avista used a rate of 7.640/o which is the allowed Rate of Return contained in the Washington Utilities and Transportation
bommission
lFinal Order 09 dated December 26,2}l2for consolidated Dockets UE-l2O436and UG-120437.
I
218.1FERC FORM NO.2
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiAn Originat(2) TIA Resubmission
Date of Report(Mo, Da, Yr)
o4t1512015
Year/Period of Reporl
End of 2014/Q4
General Description of Gonstruction Overhead Procedure (continued)
COMPUTATION OF ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION MTES
1. For line (5), olumn (d) below, enter the rate granted in the last rate proceeding. lf not available, use the average rate eamed during the preceding 3 yeam.
2. ldentr'fu, in a foohote, the specific entity used as the source for the capital structure fgures.
3. lndicate, in a footnote, if the reported rate of refum is one hat has been approved in a rate case, black-box settlemenl rate, or an ac{ual three-year average rate.
1. Components of Formula (Derived from actual book balances and actual cost rates):
Line
No.
Title
(a)
Amount
(b)
Capitalization
Ration (percent)
(c)
Cost Rate
Percentage
(d)
1) Average Short-Term Debl S
(2) Short-Term lnterest s
(3) Lonq-Term Debt D d
(4) Prefened Stock P p
(5) Common Equity C c
(6) Total Capitalization
(7) Averaqe Consfuclion Work ln Proqress Balance W
2. Gross Rate for Bonowed Funds s(SM/) + d[(D(D+P+C)) (1-(SM/))]
3. Rate for Other Funds t1-(SA /)l [p(P/(D+P+C)) + c(C/(D+P+C))l
4. Weighted Average Rate Actually Used for the
a. Rate for Borowed Funds -
b. Rate for Other Funds -
Year:
3.05
4.59
FERC FORM NO.2 (REV 12-O7l Page
Name of Respondent
Avista Corporation
I nrs KeDon ls:(1) fiRn Originat(2) l-lA Resubmission
uate ol KeDon(Mo, Da, Yi)
M,t15t2015
Year/Period of Reporl
End ot 2O14lQ4
Accumulated Provision for Depreciation of Gas Utility Plant (Account 108)
1. Explain in a footnole 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 Arcounts require that retirements of depreciable plant be recorded when
such plant is removed from service. lf 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. ln addition, include all costs included in retirement work in progress at year end in the appropriate
functional classifi cations.
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.9., 7.01 , 7.02, etc.
Line
No.
Item
(a)
Total
(c+d+e)
(b)
Gas Plant in
Service
(c)
Gas Plant Held
for Future Use
(d)
Gas Plant Leased
to Others
(e)
I Balance Beginning of Year 281,4s1,295 281,4s1,295
2 (403) Depreciation Expense 19,09s,624 19,09s,624
4 (403.1 ) Depreciation Expense for Asset Retirement Cosb
5 (41 3) Expense of Gas Plant Leased to Othea
6 Transportation Expenses - Clearing 1,624,'t9t 1,624,192
7 Other Clearing Accounts
I Other Clearing (Specify) (footnote details):31,58i 31,s82
9
10 TOTAL Deprec. Prov. for Year (Total of lines 3 thru 8)20,7s1,39t 20,751,39{
12 Book Cost of Plant Retired ( s,032,674 ( 5,032,674
13 Cost of Removal 498,333 ( 498,333
14 Salvage (Credit)
15 TOTAL Net Chrgs for Plant Ret. Ootal of lines '12 thru 14)( 5,531,007 ( 5,s31,007
16 Other Debit or Credit ltems (Describe) (footnote details):178,80i
17
18 Book Cost of Asset Retirement Costs
19 BalanceEndof Year(Total of lines 1,10,15,16and 18)296,850,48t 296,850,48t
Section B. BALANCES AT END OF YEAR ACCORDING TO
FUNCTIONAL CLASSIFICATIONS
2',1 Productions-Manufactured Gas
22 Production and Gahering-Natural Gas
23 Producb Extraction-Natural Gas
24 Underground Gas Storage 14,104,07!14,104,07!
25 Other Storage Plant
26 Base Load LNG Terminaling and Processing Planl
27 Transmission
28 Distribution 269,810,87S 269,810,87!
29 General 12,93s,53(12,935,53(
30 TOTAL (Total of lines 21 thru 29)296,850,48t 296,850,48t
FERC FORM NO. 2 (12-96)Page 219
Name of Respondent
Avista Corooration
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
20141Q4
FOOTNOTE DATA
lncludes:
RemovalWork in Progress $168,370
Transfer $10,432
l$cteaute ?age: ile Line l,!o.: S Column: c i
lncludes:
Reverse 1213112013 Ending Balance miscellaneous adjustment of $-31,582
FERC FORM NO.2 (1 552.1
This Page Intentionatly Left Blank
Name oI Kespondent
Avista Corporation
This Report ls:(1) ffien originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2015
Year/Period of Reporl
End of 20141Q4
Gas Stored (Accounts 1'17.1,117.2, 117.3, 117.4, 164.1,164.2, and 164.3)
1. lf during the year adjustments were made to the stored gas inventory reported in columns (O), (D, (S), and (h) (such as to correcl 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).
_tnt
No
Description
(a)
(Account
'117.1)
(b)
(Account
117.2)
(c)
Noncurrent
(Account
117.3)
(d)
(Account
117.4)
(e)
Current
(Account
1 64.1 )
(0
LNG
(Account
164.2)
(s)
LNG
(Account
164.3)
(h)
Total
(i)
)alance at Beginning of 6,992,07r 13,028,71 20,020,786
ias Delivered to Storage 38,924,87 38,924,873
?ias Vvithdra^,n from 23,222,08 23.U2.085
4 )ther Debits and Credits
5 lalance at End of Year 6,992,07r 28,731,49 35.723.574
6 )th 1,253,06r 7.379,59 E,632.652
7 \nEunt Per Dth 5.580r 3.E93 4.1382
FERC FORM NO. 2 (REV 04-04)Page 220
Name or Kesponoenl
Avista Corporation
This Reoort ls:(1) []Rn orisinal(2\ l_lA Resubmission
uate ot Hepon(Mo, Da, Yr)
04t15t2015
YeailPenod or Kepon
End ol 2O14lQ4
lnvestments (Account 123,'124, and 136)
1, ReportbelowinvestrnentsinAccounbl23, lnvestmenBinAssociatedCompanies, l24,Otherlnvesfrnents,andl36,TemporaryCashlnvestmenb.
2. Provide a subheading for each accounl and list thereunder the information called for:
includedinAccountl24,Otherlnvestmenb) statenumberofshares,class,andseriesofstock. MinorinvestmenEmaybegroupedbyclasses. lnvesfnenbincludedinAcmuntl36,
Temporary Cash lnvestrnents, also may be grouped by classes.
subject to current repayment in Account 145 and '!46. With respect to each advance, show whether the advance is a note or open account.
Line
No.
Descdption of lnvestrnent
(a)(b)
Book Cost at Beginning of Year
(lf book mst is difierent from
cost to respondent, give cost to
respondent in a footnote and
explain difference)
(c)
Purchases or
Additions
During the Year
(d)
1 lnvestment in Spokane Energy (123000)500,000
2 lnvestment in Avista Capital ll (123010)11,547,000
3 Other lnvestrnent - WZN Loans Sandpoint (124350)61,177
4 Other lnvestrnent - Coli Cash Value (124600)'1 6,1 95,1 38
5 Other lnvestmenl - Coli Bonowings (1 2461 0)( 16,'l 95,1 38)
o Other lnvestment - WZN Loans Oregon (1 24680)36,346
7 Other lnvestment - WNP3 Exchange Power (1 24900)79,626,000
8 Other lnvestmenl - AMT WNP3 Exciange (1 24930)( 65,742,88s)
I Temp Cash lnvestments (136000)
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
20
40
FERC FORM NO.2 (12-s6)Page 222
Name of Respondent
Avista Corporation
This Reoort ls:(1) []An orisinat(2) [-lA Resubmission
Date of Reoort(Mo, Da, Yi)
o4t15t2015
Yeailrenoo or Kepon
End of ZQllUQul
lnvestments (Account 123,124, and 136) (continued)
3, Designate with an asterisk in column (b) any securities, noles or accounts that were pledged, and in a footnote state the name of pledges and purpose of the pledge.
number.
5. Report in column (h) interest and dividend revenues from investmenb including such revenues from securities disposed of during the year.
6. ln column (i) report for each investment disposed of during the year the gain or loss represented by the difierence between cost of the investnent (or the olher amount at which
canied in the books of account if different from cost) and lhe selling price thereof, not induding any dividend or interest adjustrnent includible in column (h).
Line
No,
Sales or Other
Dispositions
During Year
(e)
Principal Amount or
No. of Shares at
End of Year
(0
Book Cost at End of Year
(lf book cost is different from cost
to respondent, give cost to
respondent in a footnote and
explain difference)
(s)
Revenues for
Year
(h)
Gain or Loss from
lnvestrnent
Disposed of
0
1 500,000
2 11,547,000
3 61,177
4 ( 1 ,682,616)17,877,754
5 1,682,616 ( 17,877,754)
6 5,221 31,125
7 79,626,000
8 2,450,031 ( 68,1s2,916)
I ( 15,s08,864)15,508,864
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
2S
30
31
32
33
34
35
36
37
38
39
40
FERC FORM NO.2 (12-96)Page 223
Name of Respondent
Avista Corporation
lnrs KeDon ls:(1) []Rn Orisinat(2) nA Resubmission
uale oI Kepon(Mo, Da, Y0
04t15t2015
YeailPenoo oI Kepon
End of 20141Q4
lnvestments in Subsidiary Companies (Account 123.1)
1. ReportbelowinvestrnentsinAccountl23.l,lnvestmenbinSubsidiaryCompanies.
2. Provide a subheading for each company and list thereunder the information called lor below, Sub-total by company and give a total in columns (e), (f), (g) and (h).
(a) lnvestrnent in Securities-List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate.
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. Repo(separatelytheequityinundistributedsubsidiaryeamingssinceacquisition. Thetotalincolumn(e)shouldequaltheamountenteredforAccount4lS.l.
Line
No.
Description of I nvestrnent
(a)
Date
Aquked
(b)
Date of
Maturity
(c)
Amount of
lnveslment at
Beginning of Year
(d)
1 Avista Capital - Common Stock 01to1t1997 206,225,548
2 Avista Capital - Equity in Eamings ( s8,061,002)
1 OCl lnvestrnent in Subs ( 1,s85,855)
4 Avista Capiital - Other Changes in Nel lnvestment 5,653,413
(Alaska - Equity in Eamings
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 Cost of Account 123.'l $TOTAL 1',t2,232,104
FERC FORM NO. 2 (12-96)Page 224
Name of Respondent
Avista Corporation
This Reoort ls:(1) [ts]An orisinal(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
YearlPeriod of Report
End of 20'14/Q4
lnvestments in Subsidiary Companies (Account 123.1) (continued)
4. Designateinafootnote,anysecurities,notes,oraccountstlratwerepledged,andstatethenameofpledgeeandpurposeofthepledge.
docket number.
6. Report in column (f) interest and dlyidend revenues from investnenB, including such revenues from securities disposed of during the year.
7. ln column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between mst of the investment (cr the other amount at which
canied in the books of account if different hom cost), and the selling price thereof, not induding interest adjustmenb includible in column (f).
8. Report on Line 40, column (a) the total cost of Account'l 23.'1.
Line
No.
Equity in Subsidiary
Eamings for Year
(e)
Revenues for Year
0
Amount of lnvestment
at End ofYear
(s)
Gain or Loss from
lnvestnent
Disposed of
(h)
1 86,577 206,138,971
2 79,182,513 130,000,213 ( 148,878,702)
3 ( 1,585,8s5)
4 5,653,413
5 3,179,202 (.r..1.8J;P1$,3€o)90,995,582
6
7
I
I
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 82,361,715 46,337,968 148.255,851
FERC FORM NO. 2 (12-96)Page 225
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da. Yr)
04t15t2015
Year/Period of Report
2014tQ4
FOOTNOTE DATA
$87,816,380 revenue from Alaska consists of:
($67,000,000) Dividends received
$'1 54,81 6,380 Acquisition Costs
Total shares issued 4,501,441
FERC FORM NO.2 552.1
Name of Respondent
Avista Corporation
This Reoort ls:(1) []An original(2\ l-lA Resubmission
Date of Reoort
(Mo, Da, Yi)
04t15t2015
Year/Period of Report
End of ZUI3lQz!
Prepayments (Acct 165), Extraordinary Property Losses (Acct 182.1), Unrecovered Plant and Regulatory Study Costs (Acct182.2l
PREPAYMENTS (ACCOUNT 1 65)
1. Report below the particulars (details) on each prepayment.
Line
No.
Nature of Payment
(a)
Balance at End
ofYear
(in dollars)
tbl
Prepaid lnsurance 1,s72,436
2 Prepaid Rents 10,740
3 Prepaid Taxes
4 Prepaid lnterest
5 Miscellaneous Prepayments 11,784,908
6 TOTAL 13,368,084
FERC FORM NO.2 (12-95)
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn Originat(2\ l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Repor
End ot 2O14lQ4
Other Regulatory Assets (Account 182.3)
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 Accounl 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.9. Commission Order, state
commission order, court decision),
Line
No.
Description and Purpose of
Other Regulatory Assets
(a)
Balance at
Beginning
Cunenl
Quarterffear
(b)
DebiB
(c)
Written ofi During
Quarterffear
Account
Charyed
(d)
Written off
During Period
Amount Recovered
(e)
Written off
During Period
Amount Deemed
Unrecoverable
(0
Balance at End of
Cunent
Quarterffear
(s)
1 leg Asset Post Ret Liab 156.9M,29(78,773,80',235,758,10:
2 Reg Asset FAS 109 Utility Plant 62,885,00r 283 18,1 11,883 44,773,12
3 Reg Asset Lancaster Gneration 2.606,66;+07 r,360,00(1,246,66i
4 Reg Asset FAS 109 DSIT Non Planl 1,257,59 46,765,18'48,022,78
5 Reg Asset FAS 109 DFIT State Tax 3,182,06{1,056,54i 4,2fi,61i
b Reg Asset FAS 109 WNP3 4,178,85t 283 737,482 3,441,37i
7 Reg Asset Spokane River Relicense 543,62(407 78,73t 464,89(
I Reg Asset Spokane River PM&E 502,57'557 73,311 4n,26i
I Reg Asset Lake CDA Fund 9,226,53 407 21 1,06r 9,01s,46(
10 Reo Asset Lake CDA IPA Fund 2,000,00(2,000,00(
11 Reg Asset Spokane River TDG 468.89i 468,89:
12 Reg Asset Decouplings surchage 7,56(242 2.1U 5,46(
13 Reg Asset Lake CDA DEF Cosb 1,310,141 407 32,711 1,277,42i
14 Reg Asset BPA Residential Exchange 1,105,80:283 1.105.80'
15 Req Asset CNC Transmission 230,63'407 230.63'
16 DEF CS2 & Colsrip 5,81 3,051 407 8,73t 5,804,311
17 Lidar O&M Reg DEF 67,36i 407 67,361
'18 Reardan Wind Generation 852,64:407 682,1 1 !170,s2!
'19 lD Wind Gen AFUDC 230,85r 407 184,687 46,171
20 Reg Asset Wartisila Un'rb 414,02 407 260,87i 1 53,1 5(
21 IVITM St Regulatory Asset r0,829,41 r 18,810,95(29,640,37l
22 MTM Lt Regulatory Asset 23.257.56i 1,225,61(24,483,17t
23 Req Asset FAS 143 2,1 1 0,23:191,02'2,fi1.251
24 teg Asset AN CDA 35.400,26:t07 884,08(34,516,1 7t
25 leq Asset WA CDA '! ,0s2,15:407 152,1 lt 900,03
26 leg Asset Worken Comp 2,486,93'107 292,s$t 2,1 94,34i
27 ]S2 Lev Ret 408,99!107 408,99!
28 teq Asset lD PCA Def 2 5,065,23r 6.21 1.80;i57 5,065,23t 6,21'1,80i
29 leq Asset lD PCA Def 3 2,078,99't57 2,078,991
30 Spokane River TDG 371,1&871.1&
31 nterest Rate Swap Asset 36,525,85r 2.56'1.32'1 33,964,s3(
32 )SM Assel 9,576,20 4,603,41r t07 9,576,20;4,603,41t
33 ]WAPS On FMBS 77,062,51 t07 77,cf,2,51
34 Misc Reg Assets 129,701 103,53(129,70f 103,53(
35
36
37
38
39
t0 Total 38r,58r,93r 236,883,39'{2,217,77i 576r17,55t
FERC FORM NO. 2/3Q (REV 12-07)Page 232
Name of Respondent
Avista Corporation
This Reoort ls:(1) fien originat(2) [-lA Resubmission
uale oI Kepon(Mo, Da, Yr)
04t15t2015
YeariPerioc, of Reporl
End of 201uUQzl
Miscellaneous Deferred Debits (Account 186)
1.Report below the details called for concerning miscellaneous defened debits,
For any deferred debit being amortized, show period of amoriization in column (a),
Mrnor items (less than $250,000) may be grouped by classes.
2,
Line
No.
Description of Miscellaneous
Defened Debits
(a)
Balance al
Beginning
of Year
(b)
Debib
(c)
Credits
Account
Charged
(d)
Credib
Amount
(e)
Balance at
End ofYear
(0
1
2 Colstrip Common Fac.1,1 10,999 406 1.1 10.999
3 Regulatory Asset-Mt Lease Pymt 991,881 540 360,684 631,1 97
4 Regulatory Asset-Mt Lease Pymt 2,029,848 540 676,63i 1,353,216
5 Colstrip Common Fac,2,355,642 2,355,642
6 Prepaid Airplane Lease LT 171,693 931 147,16!24,528
7 Misc DD- Airplane Lease 81,591 59,89!21,692
I Plant Alloc of Clearing Jrl 3,064,335 466,007 3,530,342
9 Misc Posting Suspense 33,63s 9,502 var 43,137
10 Renewable Energy-Cert Fees 1't5,25C 557 47,56i 67,688
11 Nez Perce Settlement 155,537 557 5,211 150,325
12 Reg Asset lD-Lake CDA 209,081 506 30,97r 178,106
13 Credit Union Labor & Exp 38,795 2,321 36,474
14 Misc Work Orders <$50,000 147,095 var 256,3'ti (109,222\
15 Subsidiary Billings 'r99,887 233,721 var 433,608
16 "Null" Projects directly to 186 1,353 1,35:
17 Regulatory Assets Consv 1,712,608 165,627 1,878,235
'18 Noxon 230 KV Sub permits 107,860 107,86(
19 Optional Wind Power ( 175,295)909 39,761 ( 215,056)
20 Gas Telemetry equip 59,051 52,54t 6,503
21 Misc deffered debits/Res Acct 901,446 676,08a 225,361
22 Mutual Aid Response PGE 81,208 81,208
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39 Miscellaneous Work in Progress
r0 Total 13,312,292 956,065 2,461,374 1'1,803,983
FERC FORM NO. 2 (12-96)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn Originat(2) l-lA Resubmission
Date of Report
(Mo, Da, Yr)
o4t't5t2015
Year/Period of Report
End of 2014/Q4
Accumulated Deferred lncome Taxes (Account t90)
1. Report he information called for below conceming the respondents accounting lor defened income taxes.
2. At Other (Specify), include defenals relating to olher income and deductions.
3. Provide in a foohote a summary of the type and amounl of delened inmme taxes reported in tre beginningof-year and endof-year balanes for defened income
taxes hat the respondent estimates muld be included in the development of lurisdictional recouse rates,
Line
No.
Aocount Subdivisions
(a)
Bahnce at
Beginning
ofYear
(b)
Changes During
Year
Amounb Debited
to Account 410.1
(c)
Changes During
Year
Amounb Credited
toAccount411.1
(d)
2 Elec{ric 5,183,280 ( 3,s25,531)291,886
3 Gas 991,860 58,213 ( 98,841)
4 Oher (Define) (foohote details)64,064,282 ( 29,633,458)1,953,937
5 Total fiotal of lines 2 thru 4)70,239,422 ( 33,100,776)2,146,982
t)Oher (Specify) (footnote details)
7 TOTAL Acoount 190 (Iotal of lines 5 hru 6)70,239,422 ( 33,100,776)2,146,982
I Federal lncome Tax 70,239,422 ( 33,100,776)2,146,982
10 State lncome Tax
11 Local lncome Tax
FERC FORM NO.2 (REV 12-071 Page 234
Name of Respondent
Avista Corporation
This Reoort ls:(1) []An orisinal
(21 l-lA Resubmission
uate or Kepon(Mo, Da, Yr)
04115t20',t5
Year/Period of Report
End of 2014/Q4
Accumulated Deferred lncome Taxes (Account 190) (continued)
Line
No.
Changes During
Year
Amounts Debited
to Account 410.2
(e)
Changes During
Year
Amounts Credited
to Account 41 1.2
(fl
Adjustments
Debib
Account No.
(o)
Adjustrnents
Debits
Amount
(h)
Adjustments
Credits
Acmunt No.
(i)
Adjustmenb
Credits
Amount
(i)
Balance at
End ofYear
(k)
2 115,715 8,884.982
3 312,838 1,147 ,644
4 1,256.774 299,863 18,534,082 113,228,848
5 1,372.489 299,863 18,846,920 123,261,474
6
7 1,372.489 299,863 18,846,920 123,261,474
I 1,372,489 299,863 18,846,920 123,261,474
10
11
FERC FORM NO.2 (REV 12-O7l Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn orisinat(2\ l_lA Resubmission
Date of Report(Mo, Da, Y0
04t15t2015
Year/Period of Report
End of 2014/Q4
Capital Stock (Accounts 201 and 204)
prefened 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 conceming shares of any class and series of stock authorized lo be issued by a regulatory commission which have not yet been issued.
Line
No.
Class and Series of Stock and
Name of Stock Exchange
(a)
Number of Shares
Authorized by Charter
(b)
Par or Stated Value
per Share
(c)
Call Price at
End of Year
(d)
1 Acct. 201 - Common Stock lssued:
2 No ParValue 200,000,000
e Restriced shares
4 TOTAL Common 20c,000,000
5
6
7 Account 204 - Prefened Stock lssued 10,000,000
8
I Total Prefened 1 0,000,000
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
?o
40
FERC FORM NO. 2 (12-96)Page 250
Name of Respondent
Avista Corporation
This Reoort ls:(1) []an orisinat(2) l-lA Resubmission
Date(Mo,of Report
Da, Yr)
o4t15t2015
Yea/lJenoo oI Hepon
End of @!@[
Capital Stock (Accounts 201 and 204)
4. The identification of each class of prefened stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
5. State in a ioohote if any capital stock that has been nominally issued is nominally oubtanding at end ol year.
purpose of pledge.
Line
No.
Outshnding per Bal, Shee
(total amt oubtanding
without reduction for amb
held by respondent)
Shares
(e)
Outstanding per Bal.
Sheet
Amount
0
Held by
Respondent
As Reacquired
Stock (Actt 217)
Shares
(s)
Held by
Respondent
As Reacquired
Stock (Accl 217)
Cost
(h)
Held by
Respondent
ln Sinking and
O,ther Funds
Shares
0
Held by
Respondent
ln Sinking and
Other Funds
Amount
(i)
1
2 62,243,371 984,400,740
112,042.00 3,178,632.00
4 62,243,371 984,400,740 112,042,00 3,'178,632.00
5
b
7
8
I
10
11
12
13
14
15
16
17
18
19
20
2l
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
20
40
FERC FORM NO. 2 (12-95)Page 25'.l
Name of Respondent
Avista Comoration
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
FOOTNOTE DATA
During 2014, the Company executed a stock repurchase program. Through 1,2131-114, the Company repurchased
2,529,6L5 shares. All repurchased shares under the program were retired and reverted to the status of authorized,
but unissued shares. The amounts in account 214 applicable to the retired shares were written off due to the stock
repurchase.
FERC FORM NO. 2 (1 P 552.',|
Name of Respondent
Avista Corporation
This Reoort ls:(1) Enn originat(?) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512rJ15
Year/Period of Reporl
llnd of 20'14/Q4
Other Paid-ln Capital (Accounts 208-2111
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 accouniing 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-ln Capital (Account 21 1) - 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.
Line
No.
Item
(a)
Amount
(b)
1 Equity transactions of subsidiaries ( e,s20,161)
2
3
4
5
6
7
I
I
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 ( 9,520,16'l )
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Report ls:(1) fiRn Originat(2) l-]A Resubmission
Date of Report(Mo, Da, Yr)
04t1st2015
YearPefloo or Hepon
End of 20147Q4
DrscouNT oN GAPTTAL 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.
during he year and specify the accouni chaqed.
Line
No.
Class and Series of Stock
(a)
Balance at
End of Year
(b)
1
2
3
4
5
o
7
8
I
10
11
12
13
1A
TOTAL
CAP|TAL STOCK EXPENSE (ACCOUNT 214)
1 . Report the balance at end of year of capital slock 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.
of capital stock expense and specity the account charged.
Line
No,
Class and Series of Stock
(a)
Balance at
End ofYear
(b)
16 Common stock- no par ilrl: rii,te{fl rii ?t,p. iJ; i ?.9)
17
18
19
20
21
22
23
24
25
26
27
28
TOTAL ( 2s,079,123)
FERC FORM NO. 2 (12-95)Page
Name of Respondent
Avista Comoration
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2015
Year/Period of Report
2014tQ4
FOOTNOTE DATA
5-cheau
'Beginning Balance
lssuance of Common Stock
Repurchase and Retirement of Common Stock
Tax Benefit-Options Excercised
Excess Tax Benefits on stock compensation
Stock Compensation Accrual
Ending Balance
(19,561,527)
493,330
900,72L
406,364
357,913
(7,675,9221
125,O79,1231
During 2014, the Company executed a stock repurchase program. Through Lzl3llL4, the Company repurchased
2,529,6L5 shares. All repurchased shares under the program were retired and reverted to the status of authorized,
but unissued shares. The amounts in account 214 applicable to the retired shares were written off due to the stock
repurchase.
FERC FORM NO,2 (1 552,1
s
s
s
s
S
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
Securities lssued or Assumed and Securities Refunded or Retired During the Year
'l . Furnish a supplemental statement briefly describing security financing and transactions during the year and the accounting
the securities, discounts, premiums, expenses, and related gains or losses. ldentify 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
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. lnclude 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 lnstruction 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. lf any unamortized discount, premiums, expenses, and
or losses were taken over onto the respondent's books, furnish details of these amounts with amounts relating to refunded securities
clearly earmarked
In December 2014, Avista Co.p. issued $60.0 million of first mortgage bonds to three institutional investors in
a private placement transaction. The first mortgage bonds bear an interest rate of 4.11 percent and mature in
2044. The total net proceeds from the sale of the new bonds were used to repay a portion of the borrowings
outstanding under the Company's $400.0 million committed line of credit and for general corporate purposes.
The new issuance is based on the following state commission orders:
1. Order of the Washington Utilities and Transportation Commission entered July 13,2011, as amended on
August 24,2011 in Docket No. U-l11176;
2. Order of the ldaho Public Utilities Commission, Order No. 32338, entered August 25,2011;
3. Order of the Public Utility Commission of Oregon, Order No. 11334, entered August 26,2011;
Order of the Public Service Commission of the State of Montana, Default Order No. 4535
In2074, we issued 5154.2 million (net of issuance costs) of common stock, which includes $150.1 million
associated with the acquisition of AERC and the remainder under the dividend reinvestment and direct stock
purchase plan, and employee plans.
The new issuance is based on the following commision orders:
1. Order of the Washington Utilities and Transportation Commission, Order No. 1, entered December 12,2013
in Docket No. UE-132218,UG-132219, andU-132222 ;
2. Order of the Idaho Public Utilities Commission, Order No. 32991, entered March 5,2014;
3. Order of the Public Utility Commission of Oregon, Order No. 14112, entered April 1 ,2014;
FERC FORM NO.2 255.1
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
YearlPeriod of Report
2014tQ4
Securities lssued or Assumed and Securities Refunded or Retired During the Year
During 2014,the Company executed a stock repurchase pro$am. Through 12/31/14, the Company repurchased 2,529,615 shares. All
repurchased shares under the program were retired and reverted to the status of authorized, but unissued shares. The amounts in
account 214 applicable to the retired shares were written offdue to the stock repurchase.
FERC FORM NO. 2 (r2-96)255.2
Name of Respondenl
Avista Corporation
ThiS
(1)
(2)
ieport ls:
ffiRn ortginat
I_lA Resubmission
Date of Report
(Mo, Da, Y0
04t15t2015
Year/Period of Report
End of 2O14lQ4
Long-Term Debt (Accounts 221, 222, 223, and 2241
1. ReportbyBalanceSheetAccountthedetailsconceminglong-termdebtincludedinAccount22l,Bonds,2Z2,ReaquiredBonds,223,AdvancesfromAssociatedCompanies,and
224, Other Long-Term Debl.
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. lnclude in mlumn (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 mu( order under which such certificates were issued.
Line
No.
Class and Series of Obligation and
Name of Stock Exchange
(a)
Nominai Date
of lssue
(b)
Date of
Maturity
(c)
Ouhhnding
(Total amount
outstanding without
reduclion for amh
held by respondent)
(d)
1 FI/BS - SERTES A -7.530/0 DUE 05/05/202 05/06/1 993 05t05t2023 5,500,000
Z FMBS - SERIES A - 7,54% DUE 5IO5I2O23 05t07t1993 a5t05t2023 1,000,000
?FMBS - SERTES A - 7.39% DUE 5/'11/2018 05/'1111993 05t11t2018 7,000,000
4 FMBS - SERTES A -7.45%DUE 6/1 1/2018 06/09/1 993 o6t11t2018 I 5,500,000
I FMBS - SERIES A.718%DUE8I11I2O23 08t12t1993 08t11t2023 7,000,000
b ADVANCE ASSOCIATED-AVISTA CAPITAL,II $oPRS)06/03/1 997 06t01t2037 5 1,547,000
7 FMBS.6,37% SERIES C 06/1 9/1 998 06t19t2028 25,000,000
8 FMBS.5-45% SERIES 11t18t2004 12tO112019 90,000,000
9 FMBS.6.25Ol" SERIES 11t17t2005 12101t2035 150,000,000
10 FMBS.5,7O% SERIES 12t1512006 01t01t2037 1s0,000,000
11 FMBS.5.95O/O SERIES 04t0212008 06t01t2018 250,000,000
12 FMBS - 5.125% SERIES 09t22t2009 o4t01t2022 250,000,000
13 COLSTRIP 2010A PCRBs DUE 2032 1211512010 10t01t2032 66,700,000
14 COISTRIP20I0B.PCRBsDU-E2034.,:.;;,'lr"i,1r'r :''il. r: I' i'.r:::t:r,':ii:,'',1r;l''r, ;12t15t2010 03t01t2034 17,000,000
15 FMBS.3.89% SERIES 12t20t2010 12t2012020 s2,000,000
to FMBS - 5,55% SERIES 12120t2010 12t20t2040 35,000,000
17 4.45% SERTES DUE 12-14-2041 12t14t2011 12114t2041 85,000,000
18 4.23% SERTES OUE 11-29-2047 11t30t2012 11t29t2047 80,000,000
19 FMBS. O.84% SERIES 08114t2013 0811412016 90,000,000
20 FMBS.4.,I1% SERIES 12118t2014 12t0'U2044 60.000.000
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40 TOTAL 1,488,247,000
FERC FORM NO. 2 (12-96)Page 256
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn Originat(2) nA Resubmission
uate or Kepon(lvlo, Da Yr)
04t15t2015
YeailPenoo or Kepon
End of a)lUQzl
Long-Term Debt (Accounts 221, 222, 223, and 224)
5. ln
princil
6.I
of the
7, fi
8. rf
difiere
9,G
a supplemental statement, give explanatory details for Accounb 223 and 224 of net changes during the year. Wilh respeot to long-term advances, show for each mmpany: (a)
,al advanced during year (b) interest added to principal amount and (c) principal repaid during year. Give Commission authoization numbers and dates.
he respondent has pledged any of ib long-teirn debt securities, give particulars (details) in a foohote, including name
pledgee and purpose of the pledge.
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,
interest expense was incured during the year on any obligations retired or reaquired before end of year, include such interest expense in column (f). Explain in a footnote any
nce between the total of column (f) and the total Account 427, lnterest on Long-Term Debt and Acmunt 430, lnterest on Debt to Associated Companies.
ve details conceming any long-term debt authorized by a regulatory commission but not yet issued
Line
No.
lnterest for
Year
Rate
(in o/o)
(e)
lnterest for
Year
Amount
0
Held by
Respondent .
Reaquired Bonds
lAcr,,,222)
h)
Held by
Respondent
Sinking and
Other Funds
(h)
Redempiion Price
per $100 at
End of Year
(D
1 7.530 414,4s0
2 7,540 75,400
3 7.390 517,300
4 7.450 1,154,750
5 7.180 s02,600
6 1120 i'."i:ri,r l: r., , ,hrl 449,576
7 6.370 1,592,500
8 5.450 4,90s,000
9 6.250 9,375,00C
10 5.700 8,550,000
'11 5.950 14,875.00C
12 5.125 12,812,50C
13 0,271 180,510 66,700,00c
14 ' 0,271 46,007 17,000,000
15 3.890 2,022,800
16 5.550 1,942,500
17 4.450 3,782,50C
't8 4.230 3,384,000
19 0.840 756,000
20 4.110 89,0s0
21
22
23
24
25
26
27
28
29
30
31
5t
33
34
3s
36
37
38
20
40 67,427,443 83,700,000
FERC FORM NO. 2 (12-96)Page 257
Name of Respondent
Avista Corooration
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
0/.t15t2015
Year/Period of Report
2014tQ4
FOOTNOTE DATA
9SbeCglg&99;256 _Line No.: 6 Column: f
Upon issuance Avista Capital ll issued $1.5 millio nof Common Trust Securities to the Company. ln December 2000, the
Company purchased $10.0 million of these Preferred Trust Securities. The interest for the yeai diclosed in the column (i)
reflects the net amount owed to third parties.
'S;heAnte Pawi i
Upon issuance Avista Capital ll issued $1.5 millio nof Common Trust Securities to the Company. ln December 2000, the
Company purchased $10.0 million of these Preferred Trust Securities. The interest for tite year diclosed in the column (i)
reflects the net amount owed to third parties.
The Company reacquired this debt in 2010. These bonds have not been retired or canceled; the pany plans, based on
liquidity needs and market conditions, to remarket these bonds at a future date.
{sf "drtElas"il16.l No.:14 Column: a
rnGEffi-any-iEacqrbacquired this debt in 2010. These bonds have not been retired or canceled; the Company p'lans, based on
[l#i,ft'?litr,+'"1iffifi--'
The new issuance is based on the following state commission orders:
1. Order of the Washington Utilities and Transportation Commission entered July 13,2011, as
amended on August 24,2011 in Docket No. U-1 11176;
2. Order of the ldaho Public Utilities Commission, Order No. 32338, entered August 25,2011;
3. Order of the Public Utility Commission of Oregon, Order No. 1 1334, entered August 26,2011;
Order of the Public Service Commission of the State of Montana, Default Order No. 4535
FERC FORM NO.2 (1 552.1
This Page Intentionally Left Blank
Name oI Kespondent
Avista Corporation
This Reoort ls:(1) fiAn originat(2\ l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
YeaTPenoo or Kepon
End of !QI3UQ{
Unamortized Debt Expense, Premium and Discount on Long-Term Debt (Accounts 1 ,22s,2261
1 , Report under separate subheadings for Unamortized Debt Expense, Unamortized Premium on Long-Term Debt and Unamortized Discount on Long-Term Debt, details ol expense,
premium or discount applicable to each class and series of long{erm debl
2. Show premium amounb by enclosing tre figures in parentheses.
3. ln column (b) show he principal amount of bonds or other long-term debt originally issued.
4, ln column (c) show the expense, premium or discount with respecl to the amount of bonds or other long-term debt originally issued.
Line
No.
Designation of
Long-Term Debt
(a)
Principal Amount
of Debt lssued
(b)
Total Expense
Premium or
Discount
(c)
Amortization
Period
Date From
(d)
Amortization
Period
Date To
(e)
1 FMBS - SERTES A - 7.s3% DUE 05/05/2023 5,500,00(42,7|i 0s/06/1993 05t05t2023
2 FMBS - SERIES A - 7 .54O/O DUE 5IO5I2O23 '1,000,00(7,76t 0s/07/1 993 05/052023
FMBS - SERIES A - 7.390/o DUE 5/11/2018 7,000,00(54,364 0s/1 1/1993 05/1't/2018
4 FMBS - SERTES A - 7.4570 DUE 6t11t2018 15,500,00(170,597 06/09n 993 06/1'l/2018
(FMBS. SERIES A - 7.18% DUE 811112023 7,000,00(54,364 08/1?1993 08t11t2023
6 ADVANCE ASSOCIATED-AVISTA CAPITAL ll (ToPRS)51,547,00(1,296,08(06/03/1 197 06/01/2037
7 FMBS.6,370lO SERIES C 2s,000,00(158,304 06/'19/1998 06t19n028
FMBS.5,45OlO SERIES 90,000,00c 1,432,081 11118t2004 12t01t2019
I FMBS.6.250l" SERIES 150,000,00(2,1 80,431 11t171200t 12t01t2035
10 FMBS.5,7OOIO SERIES 150,000,00(4,924,304 12115t200t 07101t2037
11 FMBS - 5.950/6 SERIES 250,000,00(3,081,4'1r 04t0212008 06/01/20'18
12 FMBS.5.125% SERIES 250,000,00(2,859,78[09t22t2009 04t0112022
'13 FMBS.3.89% SERIES 52,000,00(385,12!12t20t201t 12t20t2020
14 FMBS.5.55% SERIES 35,000,00(258,834 12t20t201C 1A20t2040
15 Short-Term Credit Facility 3,959,44!12n4nM1 0a10nu7
16 4.45% SERTES DUE 12-14-2041 85,000,00c 692,83:1211412011 12t14t2041
17 4.23% SERTES DUE 11-29-2047 80,000,000 730,831 1180t2012 11129t2047
18 0.84% Series Due 08-14-2016 90,000,00c 51 5,36!08t14nua 08t1412016
19 4.11% Seires Due 12-1-2044 60,000,000 381,51i 1U1812014 12,Ut2044
20 Rathrum 2005 71,64t 09/30/200I 12t011203s
21 Debt Strategies 56,76(08/01/203a 08/01/2005
22 WKSI Shelf Registration Statement 16,06r $Mt201i 03t0112018
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
FERC FORM NO.2 (12-96)Page 258
Name of Respondenl
Avista Corporation
This Report ls:(1) ffien Originat(2\ l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
YearHenoo or Kepon
End ot 20141Q4
Unamortized Debt Expense, Premium and Discount on Long-Term Debt (Accounts 181 225,2261
the date of the Commission's authorization of treafnent other than as specified by the Uniform System of Accounts.
6. ldentify sepantely undisposed amounb applicable to issues which were redeerned in prior yeaa.
Debt-Credit.
Line
No.
Balan€ al
Beginning
of Year
(0
Debits During
Year
(s)
Credib During
Year
(h)
Balance at
End of Year
(i)
13,407 1,424 1 1,983
2 2,438 259 2,179
3 9,604 2,175 7,429
4 30,708 6,824 23,884
5 17,517 1,812 15,70s
b 329,348 14,015 315,333
7 76,513 5,277 71,236
6 536,324 98,947 437,377
I 1,596,516 72,569 1,523,947
10 3,797,663 161,032 3,636,631
11 1,338,649 3C3,090 1,035,559
12 '1,896,338 227,561 1,668,777
'13 268,355 1,790 38,430 231,715
14 232,958 8,628 224,330
15 1,759,415 I ,088,198 537/77 2,309,836
16 646,910 23,104 623,806
17 708,387 20,886 687,501
t8 461,616 3,230 174,252 290,594
t9 381,512 38'1,512
20 52,107 2,368 49,739
21 I,133 541 592
22 13,547 3,671 9,876
23
24
25
26
27
28
29
30
31
32
33
34
35
Jb
37
38
20
40
FERC FORM NO.2 (12-96)Page 259
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
0411512015
Year/Period of Report
2014tQ4
FOOTNOTE DATA
Expenses nge as more invoices relatsed to Lhis ssuance
FERC FORM NO.2 (12-96)552.',|
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) [A Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Repor
End oJ 20141Q4
Unamortized Loss and Gain on Reacquired Debt (Accounts '189, 257)
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. lf gain or loss resulted from a refunding
transaction, include also the maturity date of the new issue.
2. ln column (c) show the principal arnount of bonds or other long-term debt reacquired.
3. ln column (d) show the net gain or net loss realized on each debt reacquisition as computed in accordance with General lnstruction
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 debiied to Account 428.1, Amortization of Loss on Reacquired
Debt, or credited to Account 429.1, Amortization of Gain on Reacquired Debt-Credit.
Line
No.
Designation of
Long-Term Debt
(a)
Date
Reacquired
(b)
Principal
of Debt
Reacquired
(c)
Net Gain or
Loss
(d)
Balance at
Beginning
of Year
(e)
Balance at
End of Year
(f)
1 Misc Debt Repurchases I 05/1 0/1 993 ( 4,69s,395 ( 1,050,7241 ( 871,75s)
2 ADVANCE ASSOCIATED.AVISTA CAPITAL II
(ToPRS)12t18t2000 10,000,00(1,769,12t 1j42i14 1,094,0'tI
3 Misc 2002 Repurchase 12t31t2002 10,000,00(2,228,154 724,943 672,851
4 Misc 2003 Repurchase 12t31t2003 25,330,00(1,368,61i 79,713 106,861
5 Misc 2004 Repurchase 12t3112004 36,590,00(( 7,244,895 1,524,021 ( 1,083,632)
6 Misc 2005 Repurchase 12131t2005 26,000,00(( 1,700,371 786,586)( 687,94s)
7 Misc 2006 Repurchase 12131t2406 6,875,00(( 483,582 64,663)( 48,698)
8 Misc 2008 Repurdrase Cosb 12t3',U2008 43,1 3:27,098 24,400
I AVA Capital Trust ltl (2022)04101t2009 60,000,00(2,875,817 1,910,621 1,681,347)
10 COLSTRIP 2010A PCRBs DUE 2032 1211412010 66,700,00(3,709,174 2,931,743]|2,776,075)
11 COLSTRIP 20'l0B PCRBs DUE 2034 12114t2010 17,000,00(1,916,297 1,666,9s7)1,584,463)
12 FMBS - 7.259; SERTES (2040)12120t2010 30,000,00(6,273,664 4,391,56s)3,7M,199)
'13 FMBS - 6.12s% SERTES (2020)12120t2010 45,000,00(5,263,822 4,737,439)4,561,979)
14 KETTLE FALLS P C REV BONDS DUE 14 (2047)06t28t2012 4,100,00(105,020 ( 101,770)( 98,76e)
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
FERC FORM NO.2 (12-96)Page 260
Name of Respondenl
Avista Corporation
This Reoort ls:(1) fiRn originat(2) l-lA Resubmission
uate oI Kepon(Mo, Da, Y0
0411512015
YeailHenoo oI Kepor
End ot 20141Q4
Reconciliation of Reported Net lncome with Taxable lncome for Feder lncome Taxes
1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal lncome Tax accruals
and show computation of such tax accruals. lnclude 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. lndicate
clearly the nature of each reconciling amount.
2. lf 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.
Line
No.
Details
(a)
Amounl
(b)
1 Net lncome for the Year (Page 1 16)192,040,688
2 Reconciling ltems for the Year
3
4 Taxable lncome Not Reported on Books
5 ( 149,986,684)
6
7
8 TOTAL ( 149,986,684)
9 Deductions Recorded on Books Not Deducted for Return
't0 '146,365,191
11
12
13 rOTAL 't46,365,191
14 lncome Recorded on Books Not lncluded in Return
15 7,183,31 I
'16
17
18 TOTAL 7,183,319
19 Deductions on Return Not Charged Against Book lncome
20 ( 252,358,072)
21
22
23
24
25
26 TOTAL ( 252,358,072)
27 Federal Tax Net lncome ( 69,292,404\
28 Show Computation of Tax:
29 Federal lax Net lncome
30 State Tax @2o/o,less ldaho ITC ( 1,858,807)
3l Federal Tax Net lncome, Less State Tax ( 71,151,211)
32 Federal Tax @35%( 24,902,924)
33 Prior Year True Ups ( 29,198,41s)
34 Cabinet Gorge Tax Credits ( 185,265)
35 Total Federal Tax Expense ( 54,286,6M)
FERC FORM NO.2 (12-96)Page 261
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiAn Orlginal(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2015
YearPenoo or Kepon
End of 20141Q4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
1 . Give details of the mmbined prepaid and accrued hx 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 accounb to which the taxed material was charged. lf the actual or estimated amounts of such taxes are known, show the amounb in a
footnote and designate whether estimated or actual amounts.
balancing of this
page is not aftected by the inclusion of these taxes.
3. lnclude in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accred, (b) amounb credited to the
portion of prepaid taxes charged to cunent 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.
Kind of Tax
(See lnstruction 5)
(a)
Balance at
Beg. of Year
Taxes Accrued
(b)
Balance at
Beg. of Year
Prepaid Taxes
(c)
1 FEDEML:
2 lncome Tax 2010 162,519
3 lncome Tax 201 1 2,697,260
4 lncome Tax 201 2 2,014,W
5 lncome Tax 201 3 3,666,967)
6 lncome Tax (Cunent)
7 Prior Retained Eaminos (2010)1.352.677\
8 Prior Retained Earninos (20'l 1)( 2,070,474)
I Prior Retained Eaminos (2012)2124,050\
10 Prior Retained Eamings (2013)( 483,2s7)
11 Cunent Retained Eaminos
12 Total Federal ( 4,863,102)
13
14 STATE OF WASHINGTON
15 Property Tax (2012)405
'16 Property Tax (2013)I 2,098,968
17 Prope0 Tax (2014)
18 Excise Tax (2010)( 22,495)
19 Excise Tax (201 3)2,862.373
20 Excise Tax (2014)
21 Natural Gas Use Tax 9,107
22 Municipal Occupation Tax 3,052,429
23 Sales & Use Tax (201 2)10,661 )
24 Sales & Use Tax (201 3)103,048
25 Sales & Use Tax (2014)
26 Total Washinoton 18,093,174
27
28 STATE OF IDAHO:
29 lncome Tax (20'13)( 63,461)
30 lnmme Tax (2014)
31 Property Tax (2012)352,996
32 Prooertv Tax (2013)3,319,617
33 Prope0 Tax (2014)
34 Sales & Use Tax (2013)4,M3
35 Sales & Use Tax (2014
36 KWH Tax (2012)1
37 KWH Tax (2013)'t9,184
38 KWH Tax t2014)
39 Franchise Tax (201 3)1,573,957
FERC FORM NO. 2 (REV 12-07)Page 262a
Name of Respondent
Avista Corporation
This Reoort ls:(1) []nn originat(2) nA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End of 2014lQ4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
6. Enter all adjustments of the accrued and prepaid tax accounts in column (f) and explain each adiustrnent in a footnote. Designate debit adiustmenb by parenheses.
authority.
number of the appropriate balance sheet plant account or subaccount.
9. For any tax apportioned to more than one ulility department or account, state in a footnote the basis (necessity) of apportioning such tax.
1 0, ltems under $250,000 may be grouped.
1 1. Report in column (q) the applicable effective state income tax rate.
Line
No.
Taxes Charged
During Year
(d)
Taxes Paid
During Year
(e)
Adjustmenb
(0
Balance at
End of Year
Taxes Accrued
(Account 236)
(s)
Balance at
End of Year
Prepaid Taxes
(lncluded in Acct 165)
0)
1
2 89,714 2,219,209\1,392,677)1,078,764
a 661,662 ( 2,070,474)34,876)
4 2,014,544
5 3,666,967)
o ( 58,137,587)23,33s,818)470,244 34,331,525)
7 1,392,677
I 2,070,474
q 2,1 24,050)
't0 483,257)
11 470,244)( 470,244)
12 ( s8,047,873)24,893,365)38,017,61 1)
13
14
15 40s)
16 96,763)12,002,205
17 14,264,301 14.?64,301
18 22,495\
19 19,36s)2,843,932 924
20 25,985,628 23,217,121 2-,768,507
21 5,250 4,600 (8,348)1,409
22 23,805,376 23,904,238 2,953,568
23 ( 10,661)
24 103,365 318
25 907,51 5 834,948 317)72,250
26 64,851,537 62,899,748 7.4231 20,037,541
27
28
29 1 04,681 41,220
30 294,500 181,220 1 1 3,280
31 3s2,996)
32 't3.2351 3,307,10'l 719)
33 6,783,896 3,386,321 3,397,575
34 4,043
35 169,667 164,0s0 5,617
Jb
37 134)19,050
38 438,004 410,861 27,143
20 1,577,085 3,128)
FERC FORM NO.2 (REV 12-071 Page 263a
Name of Respondent
Avista Corporation
This Rel(1) tr(2) T
rort ls:
An Original
A Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
YeailPefloo ol Kepon
End ot 20141Q4
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 accounb and show the total taxes charged to operations and other accounts during the year. Do not indude gasoline and
other sales taxes which have been charged to the accounB to which the taxed material was charged. lf the actual or estimated amounb of such taxes are known, show he amounB in a
footnote and designate whether estimated or actual amounts.
balancing of this
page is not affected by the inclusion of these taxes.
3. lnclude in column (d) taxes charged during the year, taxes charged to opemtions and oher accounB through (a) accruals credited to taxes accrued, (b) amounb credited to the
portion of prepaid taxes charged to cunent year, and (c) taxes paid and charged direct to openations or acmunts olher than accrued and prepaid tax accounts.
4. List the aggregate ol each kind ol tax in such manner that the total tax for each State and subdivision can readily be ascertained.
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
Line
No.
Electric
(Account 408,1,
409.1 )
(D
Gas
(Account 408,1,
409.1)
(j)
Other Utility Dept.
(Accounl 408.1,
409.1)
(k)
Olher lncome and
Deductions
(Account 408.2,
409,2)
(|)
1
2 89,714
3
4
5
b ( 5,279,512\( 18,131,2s4)( 32,895,113)
7
8
I
10
11
12 5,279,5121 ( 18,131,254)( 32,80s,399)
13
14
15 (405)
16 148,364)32,352 19,595
17 1 1,286,939 2,941,362 36,000
'18
19 21,4s3)(3,248)5,336
20 1 9,708,s37 6,203,448 73,645
21 5,250
22 1 7,690,449 6,009,596
23
24
25
26 48,520,953 15,'183,510 1 34,576
27
28
29 83,745 20,936
30 377,935 83,435)
31 ( 350,376)2,620],
32 ( 13,23s)
33 5,483,1 17 1,336,720 '15,004
34
35
36
37 (134)
38 438,6s2
39
FERC FORM NO. 2 (REV 12-07)Page
Name of Respondent
Avista Corporation
This Report ls:(1) fiRn Original(2) nA Resubmlssion
Date of Report(Mo, Da, Yr)
04115t2015
Year/Period of Report
End of &LilQzl
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
5. lf 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 adiustmenh of the accrued and prepaid tax accounB in mlumn (f) and explain each adjustment in a footnote, Designate debit adjustments by parentheses,
authority.
8. Show in columns (i) hr (p) how the taxes acmunts were distributed. Show both the utility departmenl and number of account charged. For taxes charged to utility plant, show he
number of lhe 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. ltems under $250,000 may be grouped.
11. Report in column (q) the applicable efieciive state income tax rate,
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
Line
N0.
Extraordinary ltems
(Account 409.3)
(m)
Other Utility Opn.
lncome
(Account 408.1,
409.1)
(n)
Adiustmenl to Ret.
Eamings
(Account 439)
(o)
Other
(p)
State/Local
lnmme Tax
Rate
(q)
1
2
3
4
5
b 1,831 ,708)
7
I
I
10
11
12 ( '1,831 ,708)
13
14
15
16 346)
17
18
19
20 (2l
21
22 105,331
23
24
25 907,51 5
26 1 ,012,498
27
28
29
30
31
32
33 50,945)
34
35 169,667
36
37
38 648)
39
FERC FORM NO.2 (REV 12-O7l Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn Orisinal(2) nA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End of 20141Q4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Kind ofTax
(See lnstruction 5)
(a)
Balance at
Beg. ofYear
Taxes Accrued
(b)
Balance at
Beg. of Year
Prepaid Taxes
(c)
Franchise Tax (2014)
2 Total ldaho 5,206,337
a
4 STATE OF MONTANA
E lnmme Tax (201'1 & Prior)
6 lnmme Tax (2012)68,01 1)
7 lnmme Tax (2013)183,678
6 lncome Tax (2014)
I Property Tax (2012)431
10 Property Tax (201 3)4,071,297
11 Property Tax (201 4)
12 Colstrip Generatin Tax
13 KWH Tax (2013)166,901
14 KWH Tax (2014)
15 Consumer Council Tax 11
16 Public Commission Tax 43
17 Total Montana 4,354,350
18
't9 STATE OF OREGON
20 lncome Tax (2012)25,001)
21 lncome Tax (2013)786,066
22 lncome Tax (2014)
23 Property Tax (20'13)( 2,086,107)
24 PropeO Tax (2014)
25 BETC Credit (2010)17 483'
26 BETC Credit (2011)( 29,9621
27 BETC Credit (2012)57,7891
28 Glendate Requlatory Cr. 2009 ( 34,91 1
29 Franchise Tax (20't0)s13
30 Franchise Tax (20'12)24,531
31 Franchise Tax (201 3)889,814
32 Franchise Tax (2014)
33 Total Oreoon 550,3291
34
35 STATE OF CALIFORNIA
36 lncome Tax (2011)(800)
37 lncome Tax (2013)1.6001
38 lncome Tax (2014)
39 Total Califomia 2,400)
FERC FORM NO. 2 (REV 12-071 Page 262a.1
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiAn Orlginat
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Balance at
End of Year
Taxes Accrued
(Account 236)
(s)
Balance at
End of Year
Prepaid Taxes
(lncluded in Acct 165)
(h)
Taxes Charged
During Year
(d)
Taxes Paid
During Year
(e)
Adjustrnents
(f)
( 34,91 1)
FERC FORM NO.2 (REV 12-071 Page 263a.1
Name of Respondenl
Avista Corporation
lnts Ker(1) LI.](2) T
ron ls:
An Original
A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End of 20'l4lQ4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
Line
No.
Eleclric
(Account 408.1,
409.1 )
(i)
Gas
(Account 408,1,
409.1)
0)
Other Utility Dept.
(Account 408.1,
409.1)
(k)
Other lncome and
Deductions
(Account 408.2,
409.2)
(t)
1 3,368,298 1,297,418
2 9,388,002 2,571,639 12,384
J
4
5
6
7 469,60s)
I 348,731 )
0 431 )
10
11 8,465,757
12 1,538
13
14 1,175,493
15 48
16 165
17 8,824,234
18
19
20
21 221,511\664,550)
22 ( 138,799)( 416,386)
23
24 2,490,689 2,338,388
25
26
27
28
29 513)
30
31
32 3,340,860
33 2,'t30,373 4,597,799
34
35
36
37 1,600
38
?o 1,600
FERC FORM NO. 2 (REV 12-07)Page
Avista Corporation
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept v,rhere applicable and acct charged)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
State/Local
lncome Tax
Rate
(q)
Extraordinary ltems
(Account 409.3)
(m)
Other Utility Opn.
lncome
(Account 408.'1,
409.1 )
(n)
Adiustment to Ret.
Eamings
(Account 439)
(o)
FERC FORM NO. 2 (REV 12-07)Page 263b.1
Name of Respondent
Avista Corporation
lnts Keoon ls:(1) fiRn originat(2) l-lA Resubmission
uale oI Kepon(Mo, Da, Y0
04t15120'.15
Year/Perioc, of Report
End of 2O14lQ4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Kind of Tax
(See lnstruction 5)
(a)
Balance at
Beg, ofYear
Taxes Accrued
(b)
Balance al
Beg. of Year
Prepaid Taxes
(c)
I
2 MISCELLANEOUS STATES:
I lncome Tax (20'12)
4 lncome Tax (2013)( 122,613)
E lncome Tax (2014)
b Total Misc States ( 122,613)
7
I COUNIY & MUNICIPAL
I WA Renewable Enercy s61)
10 Misc,( 11,05s)
11 Total County 1 1,616)
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
3'l
32
33
34
35
36
37
38
?o
TOTAL 22,103,801
FERC FORM NO, 2 (REV 12-071 Page 262a.2
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) l-lA Resubmission
Date of Report
(Mo, Da, Yr)
04115t2015
Year/Period of Report
End of 2014lQ4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
Line
No.
Taxes Charged
During Year
(d)
Taxes Paid
Dudng Year
(e)
Adjusfnenb
0
Balance at
End ofYear
Taxes Accrued
(Account 236)
G)
Balance at' End ofYear
Prepaid Taxes
(lncluded in Accl 165)
(h)
1
2
3
4 122,614 1
(28,632 28,632
6 28,632 122,614 28,633
7
d
I 228,689)228,689)s61 I
10 76,066 72,434 7,421 2
11 152,623\1 56.255)7,421 s59)
12
13
14
15
16
17
18
19
20
21
22
23
24
25
to
27
28
29
30
31
32
33
34
35
36
37
38
39
TOTAL 34,351,694 67,180,792 3)10,725,2971
FERC FORM NO. 2 (REV 12-07)Page 263a.2
Name of Respondent
Avista Corporation
This Re((1) El(2) T
rort ls:
An Original
A Resubmission
uate oI Heoon
(Mo, Da, Yi)
04t15t2015
Year/Periocl of Report
End of &!ilQz!
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Gharged (Show utility dept where applicable and acct charged)
(continued)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
Line
No.
Electric
(Account 408.'1,
409.1)
0
Gas
(Account 408.'t,
409.1)
0
Other Utility Depl
(Account 408.1,
409.1 )
(k)
Other lnmme and
Deduc{ons
(Account 408.2,
409.2)
0)
2
4
5
6
7
8
9
10 3,654
11 3,654
12
13
14
15
16
17
18
19
20
21
22
23
24
25
t6
27
28
29
30
31
32
33
34
35
36
37
38
39 TOTAL 63,584,050 4,223,294 ( 32,654,785)
FERC FORM NO. 2 (REV 12-071 Page 262b.2
Name of Respondent
Avista Corporation
This ReDort ls:(1) []Rn orisinat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2015
Year/Period of Report
End of 2014/O4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
DISTRIBUTION OF TAXES CHARGED (Show utility department where applicable and account charged.)
Line
No.
Extraordinary ltems
(Account 409.3)
(m)
Other Utility Opn.
lncome
(Account 408.1,
409.1 )
(n)
Adjustrnent to Ret,
Earnings
(Account 439)
(o)
Other
(p)
State/Local
lncome Tax
Rate
(q)
1
2
4
28,632
h 28,632
7
8
o 228,689)
10 72,412
11 156,277\
12
13
14
15
16
17
18
't9
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
TOTAL 800,865)
FERC FORM NO.2 (REV 12-071 Page 263b.2
Name or Hesponoenl
Avista Corporation
This Reoort ls:(1) finn originat(2\ l--lA Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2015
Year/Period of Repor
End ol 2O14lQ4
Miscellaneous Current and Accrued Liabilities (Account 242)
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.
Line
No.
Item
(a)
Balance at
End of Year
(b)
Margin Call Deposit 470,000
2 Forest use Permits 3,469,667
3 Setttlement Payable 580,000
4 Mirabeau Accrued Rent 25,158
5 Clearing Accounts 't,602,856
6 FERC Admin Fee Acc 700,000
7 FERC ElecAdmin Charge I 35,1 36
8 Mt Lease Payments 4,622,400
9 Misc Non Mon Pwr exchange 1,531
10 Prepayments 325,253
11 Payroll EQLZTN 18,265,026
12 Low lncome Assist 2,629,937
13 Avista Grants Eng Sustain WSU 63,986
14 Mobius '150,000
15 Worke/s Comp Liability 2,194,343
16 Customer Accounts 8,258,144
17 Acct Payable Expense Accruals 1 ,016,858
18 Accrued Expenses Subs 3,318,922
19 Current Portion- Benefit Liability 6,147,423
20 Cash Overdraft 3,507,358
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45 Total 57,483,998
FERC FORM NO. 2 (12-96)Page 268
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn orisinat(2\ J-lA Resubmission
Date of Reporl(Mo, Da, Yr)
04t15t2015
Year/Period of Repor
End of &UQ4
Other Deferred Credits (Account 253)
1 Report below the details called for conceming other defened credits,
For any deferred credit being amortized, show the period of amortization.
Minor items (less than $250,000) may be grouped by classes.
2.
3.
Line
No.Description of Other
Delened Credib
(a)
Balance at
Beginning
ofYear
(b)
Debit
Contra
Account
(c)
Debit
Amount
(d)
Credib
(e)
Balance at
End of Year
(0
1 Defer Gas Exchange (253028)1,500,000 37s,010 1,124,990
2 Rathdrum Refund (2531 20)205,754 33,822 171,932
3 NE Tank Spill (253130)16,782 9.74t 26,s28
4 Bills Pole Rentals (253140)296,339 1s,301 31 1,640
5 cR-cs2 GE LTSA (253150)2,003,140 838,472 1,164,668
b Credit Resource Actg 901,446 676,085 225,361
7 DOC EECE Grant 271,380 94,098 177,282
8 Defer Comp Retired Execs (253900)36,255 25,926 10,329
o Defer Comp Aciive Execs (253910)9,170,452 493,566 8,676,886
10 Executive lncent Plan (253920)140,000 140,000
11 Unbilled Revenue (253990)1,048,274 374,016 674,258
12 WA Energy Recovery Mechanism 8,024,'194 8,024,194 4.224.011 4,224,011
13 Misc Deferred Credits 1 38,369 138,369 3,677,1 5t 3,677,156
14 REC Deferral '1,606,948 1,606,948
15 Kettle Falls Diesel Leak 664,69!664,699
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
t5 Total 25,359,333 12,680,506 8,590,913 21,?69,740
FERC FORM NO.2 (12-96)Page 269
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2015
Year/Period of Report
End of 2O14lQ4
Accumulated Deferred lncome Taxes0ther Property (Account 282)
1. Report he information called for below conceming the respondents amunting lor defened income taxes relating to property not subject to accelerated amortization.
2. At Oher (Specify), include defenals relating to other income and deductions.
Line
No.
Account SuMivisions
(a)
Balance at
Beginning
ofYear
(b)
Amounb
Debited to
Account 410.1
(c)
Amounb
Credited to
Account 411.'l
(d)
2 Electric 298,124,105 91,710,027
3 Gas 104,243,017 37,166,301
4 Other (Define) (footnote details)44,733,113 6,744,789
5 Total (Enter Total of lines 2 hru 4)447J00,235 135,621,117
6 Other (Specify) (footnote details)
.,TOTAL Acmunt 282 (Enter Total of lines 5 thr 447,',t00,235 135,621,117
9 Federal lncome Tax 436,033,912 131,984,301
'10 State lncome Tax I 1,066,323 3,636,816
11 Local lnmme Tax
FERC FORM NO.2 (REV 12-07)Page 274
Name of Respondent
Avista Corporation
This Report ls:(1) ffiRn Orlginat
(2') nA Resubmission
Date of Report(Mo, Da, Yr)
0411512015
Year/Period of Report
End of 2014lQ4
Accumulated Deferred lncome Taxes-Other Property (Account 282) (continued)
3. Provide in a foohote a summary of the type and amount of defened income taxes reported in he beginningotyear and endolyear balances for defened income taxes hat the
respondent estimates could be included in he development of jurisdiciional re@urse rates.
Line
No.
Changes during
Year
Amounb Debited
to Account 410.2
(e)
Changes during
Year
Amounts Creditred
to Account 41 1.2
(0
Adjustrnents
Debib
Accl. No.
(s)
Adjustments
Debits
Amount
(h)
Adjustments
Credib
Account No.
(i)
Adjusfnents
Credib
Amount
0)
Balance at
End of Year
(k)
2 389,834,132
3 141,409,318
4 51,477,902
5 582,721,352
6
7 582,721,352
I 568,018,213
10 14,703,1 39
11
FERC FORM NO. 2 (REV 12-O7l Page 275
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) l-lA Resubmission
Date of Reporl(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End of 2014/Q4
Accumulated Deferred lncome Taxes-Other (Account 283)
1. Report the information called for below mnceming the respondents accounting for defened income taxes relating to amounb remrded in Account 283.
2. At Oher (Specify), indude defenals relating to oher income and deductions.
Line
No.Account Subdivisions
(a)
Balance at
Beginning
ofYear
(b)
Changes During Year
Amounb
Debited to
Account 410.1
(c)
Changes During Year
Amounb
Credited to
Account 41 1.1
(d)
2 Elec'tric 19,241,501 ( 2,526,001)
3 Gas ( 3,856,614)3,085,379
4 Other (Define) (footnote details)146,459,547 ( 3,061,139)
5 Total (Total of lines 2 thru 4)161,844,434 ( 2,501,761)
6 Other (Spetify) (foohote details)
7 TOTAL Account 283 (Total of lines 5 thru 161,844,434 ( 2,501,761)
I Federal lncome Tax 161,8/,4,434 ( 2,501,761)
10 State lnmme Tax
11 Local lncome Tax
FERC FORM NO.2/sQ (REV 12-07)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) fian originat(2) l-lA Resubmission
uate ot KeDon(Mo, Da, Yi)
04115t2015
Year/Perlod of Report
End of 2014/Q4
Accumulated Deferred lncome Taxes-Other (Account 283) (continued)
3. Provide in a loofrote a summary of tre type and amount of defened income taxes reported in he beginningof-year and endof-year balances for defened income taxes that the
respondent estimates could be included in tre development ofjurisdiclional reoourse rates.
Line
No.
Changes during
Year
Amounb Debited
to Account 410.2
(e)
Changes durirq
Year
Amounb Credited
to Account 411 .2
(0
Adjusfrnenb
Deb'rts
Acc,t. No.
(s)
Adjustrnenb
Debib
Amount
(h)
Adjustmenb
Credib
Account No.
(i)
Adjusbnenb
Credib
Amount
0)
Balanoe at
End of Year
(k)
2 1,128,945 500,852 17,343,593
3 ( 62,4071 708,828)
4 5,739,597 ( 70,560,211)208,219,022
5 1,128,94s 5,739,597 ( 70,121,766)224,853/87
6
7 1,128,94s 5,739,597 ( 70,121,7ffi1 224,853,787
9 1,128,945 5,739,597 ( 70,121,766)224,853,787
10
11
FERC FORM NO.2/3Q (REV 12-07)Page
This Page Intentionatly Left Blank
rrar nE ur nt5P(Jnueilt
Avista Corporation
I ilts nc(1) E(2t T
,O]I lS:
An Original
A Resubmission
uatE ur nEPUrt(Mo, Da, Yr)
04t15t2015
Iear/renoo or r(ePor
End of 2014/Q4
Other Regulatory Liabilities (Account 254)
1. F
inclur
2.t
3, I'
4.t
c0mrl
leport below the details called for conceming other regulatory liabilities which are created through the ratemaking actions of regulatory agencies (and not
lable in other amounts).
ror regulatory liabilities being amortized, show period of amortization in column (a).
linor 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.
)rovide in a footnote, for each line item, the regulatory citation where the respondent was directed to refund the regulatory liability (e.9. Commission Order, state
tission order, courl decision).
Line
No.Description and Purpose of
Other Regulatory Liabilities
(a)
Balance at
Beginning of
Cunent
OuarteilYear
(b)
Written off during
Quarter/Period
Account
Credited
(c)
Written off
During Period
Amount
Refunded
(d)
Written off
During Period
Amount Deemed
Non-Refundable
(e)
Credits
0
Balance al
End of Cunent
QuarterlYear
G)
1 daho lnvestment Tax Credit 5,409,55 5,052,481 10,462,039
2 )regon BETC Credit s00,00 331.1 3t 831,1 38
3 loxon, ITC 3,293,86 190 s2,63:3.241,231
4 Settled lnt Rate Swaps 12.965.s9 3,457,96:16,423,552
5 Jnsettled lnt Rate Swaps 33.543.25 176 33.082.94:460,316
b )reoon Commercial Fee 1,94.,1,941
7 :AS109 lnvest Credit 82,20 190 18,30t 63,900
8 tlez Perce 660.35 557 22.001 638,348
o daho Earninqs Test 4.275,411 4,275,418
10 )reqon Senate Bill 407 73,35 73,357
11 )ecouolino Rebate 2.27 407 2.27.
12 3PA Parallel Cap 5,397,10 407 4 588 97r 808,136
13 IPA RES Exch &7 1.659.4si 1.659,457
14 Jnrealized Currencv Exchanqe 143 28.23 28,23i
15 daho PCA 9,879,39 9,879,39,9,962,091 9,962,091
16 loseburg/Medford 8.72 8.721 8.7X 8,7n
17
1E
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
'lo
40
41
42
43
44
45 Total 11,712,331 47,758,78;21,850,81i {E,E34,355
FERC FORM NO. 2/3Q (REV 12-07)Page 278
Name of Respondent
Avista Corporation
This
(1)
(2)
leoort ls:
f,lRn originat
flA Resubmission
Date of Reporl
(Mo, Da, Yr)
o4115t2015
Year/Period of Report
End of 2O14lQ4
Gas Operating Revenues
I . Report below nafural gas openting revenues for eadl prescribed account total. The amounts must be mnsistent with the detailed dab on succeeding pages.
2. Revenues in columns (b) and (c) include transition costs lrom upstream pipelines.
3. Oher Revenues in columns (f) and (g) include reservation drarges received by the pipeline plus usage charges, less revenues reflected in mlumns (b) trrough (e). lndude in
rolumns (0 and (q) revenues for Accounts 480495.
Line
No.
Title of Account
(a)
Revenues for
Transition
Cosb and
Takeor-Pay
Amount for
Cunent Year
(b)
Revenues for
Transition
Cosb and
TakeorPay
Amount for
Previous Year
{c)
Revenues for
GRI and ACA
Amount for
Cunent Year
(d)
Revenues for
GRI and ACA
Amount for
Previous Year
(e)
I 480 Residential Sales
2 481 Commercial and lndustrial Sales
3 482 Other Sales to Public Authorities
4 483 Sales for Resale
5 484 lnterdepartmental Sales
6 485 lntracompany Transfers
7 487 Forfeited Discounts
8 488 Miscellaneous Service Revenues
I 489.1 Revenues from Transportation of Gas of Othen
Through Gathering Facilities
10 489.2 Revenues from Transportation of Gas of Others
Through Transmission Facilities
11 489.3 Revenues from Transportation of Gas of Others
Through Distribution Facilities
12 489.4 Revenues from Storing Gas ofOthers
13 490 Sales of Prod. Ext. from Natural Gas
14 49'l Revenues from Natural Gas Proc. by Others
15 492 lncidental Gasoline and Oil Sales
16 493 Rentfrom Gas Property
17 494 lnterdeparfnental Rents
18 495 OtherGas Revenues
t9 Subtotal:
20 496 (Less) Provision for Rate Refunds
21 TOTAL:
FERC FORM NO. 2 (REV 12-071 Page 300
Name of Respondent
Avista Corporation
This
(1)
(2\
Eport ls:
I_lAn Original-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2015
YeailPenoo oI Kepon
End of 2014/Q4
Gas Operating Revenues
4.
5.
6.
lf increases or decreases from previous year are not derived from previously reported frgures, explain any inconsistencies in a footnote.
On Page 108, include information on ma,ior changes during the yeal new servioe, and important rate increases or decreases.
Report he revenue from tansportafron services tlrat are bundled witr storage services as hansporhtion service revenue.
Line
No.
Other
Revenues
Amount for
Cunent Year
0
Ofter
Revenues
Amount for
Previous Year
0)
Total
Operating
Revenues
Amount for
Cunenl Year
(h)
Total
Openting
Revenues
Amount for
Previous Year
(i)
Dekaherm ol
Natural Gas
Amount for
Cunent Year
0)
Dekaherm of
Natural Gas
Amountfor
Previous Year
(k)
1 203,373,340 206,329,739 203,373,U0 206,329,739 19,0't7,094 20,471J46
2 110,129,'t54 't08,505,217 1't0,129,154 't08,50s,217 '12,742,856 13,311,914
3
4 230,997,169 196,375,408 230,997,169 1 96,375,408 56,068,962 53,792,387
5 337,273 313,297 337,273 313,297 41,051 41,763
b
7
I 188,4s5 176,451 188,455 176,451
I
t0
11
7,735.097 7,576,1 18 7,735,097 7,576,1',t8 16,231,147 15,997,643
12
13
14
15
16 3,132 3,068 3,132 3,068
17
18 5,329,746 6,693,017 5,329,746 6,693,017
19 558,093,366 525,972,315 5s8,093,366 525,972,315
20 221,098 441,849 221,098 441,849
21 557,872,268 525,530,466 557,872,268 525,530,466
FERC FORM NO.2 (REV 12-07l,Page 301
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
YeailHenoo oI Kepon
End of P1!!Q4
Other Gas Revenues (Account 495)
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.
Line
No.
Description of Transaction
(a)
Amount
(in dollars)
(b)
1 )ommissions on Sale or Distribution of Gas of Others
2 )ompensation for Minor or lncidental Services Provided for Others
3 )rofit or Loss on Sale of Material and Supplies not Ordinarily Purchased for Resale
4 Sales of Stream, Water, or Electricity, including Sales or Tnansfers to Other Departments
E Miscellaneous Royalties
b levenues from Dehydration and Other Processing of Gas of Ottren except as provided for in the lnstructions to Account 495
7 levenues for Right andior Benefits Received from Othen which are Realized Though Research, Developmen! and Demonstration Ventures
I 3ains on Settlements of lmbalance Receivables and Payables
9 levenues from Penalties eamed Pursuant to Tariff Provisions, including Penaliies Associated with Cashout Settlements
10 levenues from Shipper Supplied Gas
11 )ther revenues (Specity):
12 Misc Bills 426,589
13 )efened Exchange Revenue 4,875,000
14 )SM Lost Margin (Oregon)28,157
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
Total 5,329,746
FERC FORM NO. 2 (12-95)Page 308
Name of Respondent
Avista Corporation
This Reoort ls:(1) frRn originat
(21 l-lA Resubmission
Date of Report(Mo, Da, Yi)
04t15t2015
Year/Period of Report
End of 2014/Q4
Gas Operation and Maintenance Expenses
Line
No.
Account
(a)
Amouni for
Current Year
(b)
Amount for
Previous Year
(c)
1 1. PRODUCTION EXPENSES
2 A. Manufactured Gas Production
3 Manufactured Gas Production (Submit Supplemental Statement)0 0
4 B. Natural Gas Production
5 81. Natural Gas Production and Gathering
b Operation
7 750 Operation Supervision and Engineering 0 0
8 751 Production Maps and Records 0 0
I 752 Gas Well Expenses 0 0
10 753 Field Lines Expenses 0 0
't1 754 Field Compressor Station Expenses 0 0
12 755 Field Compressor Station Fuel and Power 0 0
13 756 Field Measuring and Regulating Station Expenses 0 0
14 757 Purification Expenses 0 0
15 758 Gas Well Royalties 0 0
16 759 Other Expenses 0 0
17 760 Rents 0 0
18 TOTAL Operation Clotal of lines 7 thru 17)0 0
19 Maintenancc
20 761 Maintenance Supervision and Engineering 0 0
21 762 Maintenance of Structures and lmprovements 0 0
22 763 Maintenance of Producing Gas Wells 0 0
23 764 Maintenance of Field Lines 0 0
24 765 Maintenance of Field Compressor Station Equipment 0 0
25 766 Maintenance of Field Measuring and Regulating Station Equipment 0 0
26 767 Maintenance of Purification Equipment 0 0
27 768 Maintenance of Drilling and Cleaning Equipment 0 0
28 769 Maintenance of Other Equipment 0 0
29 TOTAL Maintenance (Total of lines 20 thru 28)0 0
30 TOTAL Natural Gas Production and Gathering (Total of lines 18 and 29)0 0
FERC FORM NO.2 (12-96)Page 317
Name of Respondent
Avista Corporation
This Reoort ls:(1) SRn Original(2) l-lA Resubmission
Date of Report
(Mo, Da, Yr)
04t1512015
Year/Period of Report
End of 2014/Q4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
31 82. Products Extraction
32 Operation
33 770 Operation Supervision and Engineering 0 0
34 771 Operation Labor 0 0
35 772 GasShrinkage 0 0
36 773 Fuel 0 0
37 774 Power 0 0
38 775 Materials 0 0
39 776 Operation Supplies and Expenses 0 0
40 777 Gas Processed by Others 0 0
41 778 Royalties on Products Extracted 0 0
42 779 Marketing Expenses 0 0
43 780 Products Purchased for Resale 0 0
44 781 Variation in Products lnventory 0 0
45 (Less) 782 Extracted Products Used by the Utility-Credit 0 0
46 783 Rents 0 0
47 TOTAL Operation (Total of lines 33 thru 46)0 0
48 Maintenance
49 784 Maintenance Supervision and Engineering 0 0
50 785 Maintenance of Structures and lmprovements 0 0
51 786 Maintenance of Extraction and Refining Equipment 0 0
52 787 Maintenance of Pipe Lines 0 0
53 788 Maintenance of Extracted Products Storage Equipmenl 0 0
54 789 Maintenance of Compressor Equipment 0 0
55 790 Maintenance of Gas Measuring and Regulating Equipment 0 0
56 791 Maintenance of Other Equipment 0 0
57 TOTAL Maintenance (Total of lines 49 thru 56)0 0
58 TOTAL Products Extraction (Total of lines 47 and 57)0 0
318FERC FORM NO.2 (12-e6)Page
Name of Respondent
Avista Corporation
lnrs ReDon ls:(1) fien originat
(21 l-lA Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2015
Year/Period of Report
End of 2014lQ4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Curent Year
(b)
Amount for
Previous Year
(c)
59 C. Exploration and Development
60 Operation
61 795 Delay Rentals 0 0
62 796 Nonproduc{ive Well Drilling 0 0
63 797 Abandoned Leases 0 0
64 798 Other Exploration 0 0
65 TOTAL Exploration and Development (Total of lines 61 thru 64)0 0
66 D. Other Gas Supply Expenses
67 Operation
68 800 Natural Gas Well Head Purchases 0 0
69 800.1 Natural Gas Well Head Purchases, lntracompany Transfers 0 0
70 801 Natural Gas Field Line Purchases 0 0
71 802 Natural Gas Gasoline Plant Outlet Purchases 0 0
72 803 Natural Gas Transmission Line Purchases 0 0
73 804 Natural Gas City Gate Purchases 416,O37,120 350,342,545
74 804.1 Liquefied Natural Gas Purchases 0 0
75 805 OtherGas Purchases 0 0
76 (Less) 805.1 Purchases Gas Cost Adjustments 8,065,460 ( 4,784,160)
77 TOTAL Purchased Gas (total of lines 68 thru 76)407,971,660 355,126,705
78 806 Exchange Gas 0 0
79 Purchased Gas Expenses
80 807.1 Well Expense-Purchased Gas 0 0
81 807.2 Operation of Purchased Gas Measuring Stations 0 0
82 807.3 Maintenance of Purchased Gas Measuring Stations 0 0
83 807.4 Purchased Gas Calculations Expenses 0 0
84 807.5 Other Purchased Gas Expenses 0 0
85 TOTAL Purchased Gas Expenses (Total of lines 80 thru 84)0 0
FERC FORM NO.2 (12-95)Page 319
Name of Respondent
Avista Corporation
This Reoort ls:(1) []An orisinat(2) l-lA Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2015
Year/Period of Report
End ot 20141Q4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
85 808.1 Gas Withdrawn from Storage-Debit 23,222,085 33,596,700
87 (Less) 808.2 Gas Delivered to Storage-Credit 38,924.873 29.U9.123
88 809.1 Withdrawals of Liquefied Natural Gas for Processing-Debit 0 0
89 (Less) 809.2 Deliveries of Natural Gas for Processing-Credit 0 0
90 Gas used in Utility Operation-Credit
91 810 Gas Used for Compressor Station Fuel-Credit 0 0
92 8'l 1 Gas Used for Products Extraction-Credit 1,602,046 1,386,785
93 812 Gas Used for Other Utility Operations-Credit 0 0
94 TOTAL Gas Used in Utility Operations-Credit (l-otal of lines g1 thru 93)1,602.046 1.386.785
95 813 Other Gas Supply Expenses 1,634,458 1,825,650
96 TOTAL Other Gas Supply Exp. Clotal of lines 77,78,85,86 thru 89,94,95)392,301,2U 359,813,147
97 TOTAL Production Expenses (l-otal of lines 3, 30, 58, 65, and 96)392,301,2U 359,813,147
98 2. NATURAL GAS STORAGE, TERMINALING AND PROCESSING EXPENSES
99 A. Underground Storage Expenses
100 Operation
'101 814 Operation Supervision and Engineering 9,776 25.291
102 815 Maps and Records 0 0
103 816 Wells Expenses 0 0
104 817 Lines Expense 0 0
105 818 Compressor Station Expenses 0 0
106 819 Compressor Station Fuel and Power 0 0
107 820 Measuring and Regulating Station Expenses 0 0
108 821 Purification Expenses 0 0
109 822 Exploration and Development 0 0
110 823 Gas Losses 0 0
111 824 Other Expenses 723,454 695,512
112 825 Storage Well Royalties 0 0
113 826 Rents 0 0
114 TOTAL Operation (l-otal of lines of '101 thru 113)733,230 720,803
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn Orisinal(2) [-lA Resubmission
Date of Report I Year/Period of Report(Mo, Da, Yr) |o6tlstzols I eno ot 2o14tQ4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
t15 Maintenance
't16 830 Maintenance Supervision and Engineering 0 0
17 831 Maintenance of Structures and lmprovements 0 0
118 832 Maintenanec of Reservoirs and Wells 0 0
119 833 Maintenance of Lines 0 0
120 834 Maintenance of Compressor Station Equipment 0 0
121 835 Maintenance of Measuring and Regulating Station Equipment 0 0
t22 836 Maintenance of Purification Equipment 0 0
123 837 Maintenance of Other Equipment 661,095 568,328
124 TOTAL Maintenance (Total of lines 116 thru 123)661,095 568,328
t25 TOTAL Underground Storage Expenses (Total of lines 1 14 and 124)1,394,325 1 ,289,131
t26 B. Other Storage Expenses
127 Operation
128 840 Operation Supervision and Engineering 0 0
129 841 Operation Labor and Expenses 0 0
t30 842 Rents 0 0
131 842.1 Fuel 0 o
132 842.2 Power 0 0
133 842.3 Gas Losses 0 0
tu TOTAL Operation (Total of lines 128 thru 133)0 0
r35 Maintenance
136 843.1 Maintenance Supervision and Engineering 0 0
t37 843.2 Maintenance of Structures 0 0
ls8 843.3 Maintenance of Gas Holders 0 0
39 843.4 Maintenance of Purification Equipment 0 0
40 843.5 Maintenance of Liquefaction Equipment 0 0
141 843.6 Maintenance of Vaporizing Equipment 0 0
42 843.7 Maintenance of Compressor Equipment 0 0
143 843.8 Maintenance of Measuring and Regulating Equipment 0 0
144 843.9 Maintenance of Other Equipment 0 0
45 TOTAL Maintenance (Total of lines 136 thru 144)0 0
146 TOTAL Other Storage Expenses (Total of lines 134 and 145)0 0
FERC FORM NO.2 (12-96)Page 321
Name oI Kesponoent
Avista Corporation
This Reoort ls:(1) fiRn original(2) l-lA Resubmission
Date of Reoort(Mo, Da, Yi)
o4t1st2015
Year/Period of Report
End ot 20141Q4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
147 C. Liquefied Natural Gas Terminaling and Processing Expenses
148 Operation
't49 844.1 Operation Supervision and Engineering 0 0
t50 844.2 LNG Processing Terminal Labor and Expenses 0 0
151 844.3 Liquefaction Processing Labor and Expenses 0 0
152 844.4 Liquefaction Transportation Labor and Expenses 0 0
153 844.5 Measuring and Regulating Labor and Expenses 0 0
!'54 844.6 Compressor Station Labor and Expenses 0 0
155 844.7 Communication System Expenses 0 0
155 844.8 System Control and Load Dispatching 0 0
't57 845.1 Fuel 0 0
158 845.2 Power 0 0
t59 845.3 Rents 0 0
160 845.4 Demurrage Charges 0 0
161 (less) M5.5 Wharfage Receipts-Credit 0 0
t62 845.6 Processing Liquefied or Vaporized Gas by Others 0 0
163 846.1 Gas Losses 0 0
154 846.2 Other Expenses 0 0
r65 TOTAL Operation (Total of lines 149 thru 164)0 0
166 Maintenance
t67 847.1 Maintenance Supervision and Engineering 0 0
168 847.2 Maintenance of Structures and lmprovements 0 0
t69 847.3 Maintenance of LNG Processing Terminal Equipment 0 0
170 847.4 Maintenance of LNG Transportation Equipment 0 0
171 847.5 Maintenance of Measuring and Regulating Equipment 0 0
t72 847.6 Maintenancc of Compressor Station Equipment 0 0
173 847.7 Maintenance of Communication Equipmenl 0 0
174 847.8 Maintenance of Other Equipment 0 0
175 TOTAL Maintenance (Total of lines '167 thru 174)0 0
176 TOTAL Liquefied Nat Gas Terminaling and Proc Exp (Total of lines 165 and 175)0 0
t77 TOTAL Natural Gas Storage (total of lines '125, 146, and 176)1,394,325 1,289,131
PageFERC FORM NO.2 (12-96)
Name of Respondent
Avista Corporation
This Reoort ls:(1) fien originat(2) l-lA Resubmission
uate oI Kepon(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End of 20141Q4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
178 3. TRANSMISSION EXPENSES
179 Operation
t80 850 Operation Supervision and Engineering 0 0
8'l 851 System Control and Load Dispatching 0 0
182 852 Communication System Expenses 0 0
t83 853 Compressor Station Labor and Expenses 0 0
184 854 Gas for Compressor Station Fuel 0 0
t85 855 Other Fuel and Power for Compressor Stations 0 0
86 856 Mains Expenses 0 0
187 857 Measuring and Regulating Station Expenses 0 0
88 858 Transmission and Compression of Gas by Others 0 0
189 859 Other Expenses 0 0
190 860 Rents 0 0
191 TOTAL Operation Cl-otal of lines 180 thru 190)0 0
192 Maintenance
t93 861 Maintenance Supervision and Engineering 0 0
194 852 Maintenance of Structures and lmprovements 0 0
195 863 Maintenance of Mains 0 0
'195 864 Maintenance of Compressor Station Equipment 0 0
197 865 Maintenance of Measuring and Regulating Station Equipment 0 0
198 866 Maintenance of Gommunication Equipment 0 0
't99 867 Maintenance of Other Equipment 0 0
200 TOTAL Maintenance flotal of lines 193 thru 199)0 0
201 TOTAL Transmission Expenses (Total of lines 191 and 200)0 0
202 4. DISTRIBUTION EXPENSES
203 Operation
204 870 Operation Supervision and Engineering 2,231,329 2332.982
205 871 Distribution Load Dispatching 0 0
206 872 Compressor Station Labor and Expenses 0 0
207 873 Compressor Station Fuel and Power 0 0
FERC FORM NO. 2 (12-95)Page
Name of Respondent
Avista Corporation
This Rer(1) lx-(2t T
rort ls:
lAn originat
lA Resubmission
Date of Reoort(Mo, Da, Yi)
0/.|15t2015
Year/Period of Report
End ot 20141Q4
Gas Operation and illaintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
208 874 Mains and Services Expenses 5,050,253 4,827,520
209 875 Measuring and Regulating Station Expenses-General 227,487 371,938
?.10 876 Measuring and Regulating Station Expenses-lndustrial 6,093 3,335
211 877 Measuring and Regulating Station Expenses-City Gas Check Station 168,066 194,405
212 878 Meter and House Regulator Expenses 821,734 1,621,726
213 879 Customerlnstallations Expenses 2,770.677 3,'t22,752
214 880 Other Expenses 2,956,344 2,889,859
215 881 Rents 50,086 45,023
216 TOTAL Operation (Iotal of lines 204 thru 215)14,282,069 15,409,540
217 Maintenance
218 885 Maintenance Supervision and Engineering 202,495 216,205
219 886 Maintenance of Structures and lmprovements 0 0
t20 887 Maintenance of Mains 3,689,559 2,860,335
t21 888 Maintenance of Compressor Station Equipment 0 0
r22 889 Maintenance of Measuring and Regulating Station Equipment-General 408,957 389,211
223 890 Maintenance of Meas. and Reg. Station Equipment-lndustrial 306,081 275,635
,-24 891 Maintenance of Meas. and Reg. Station Equip-City Gate Check Station 86,733 103,580
225 892 Maintenance of Services 2,624,504 2,081,398
426 893 Maintenance of Meters and House Regulators 2.473.195 2,099,190
227 894 Maintenance of Other Equipment 359,692 334,533
228 TOTAL Maintenance (Iotal of lines 218 thru 227)10,151,226 8,360,087
229 TOTAL Distribution Expenses (Total of lines 216 and 228)24.433.295 23,769,627
230 5. CUSTOMER ACCOUNTS EXPENSES
231 Operation
232 901 Supervision 288,098 315,307
233 902 Meter Reading Expenses 2,032,328 2.255,275
234 903 Customer Records and Collection Expenses 7.431.401 7.922.945
FERC FORM NO.2 (12-96)Page 324
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn originat(2) -A Resubmission
Date of Report(Mo, Da, Yr)
o411512015
Year/Period of Report
End of 2014/Q4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
235 904 Uncollectible Accounts 2,448,316 2,257,721
236 905 Miscellaneous Customer Accounts Expenses 175.445 211,704
237 TOTAL Customer Accounts Expenses (Total of lines 232 thru 236)12,375,588 12,962,952
238 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
239 Operation
240 907 Supervision 0 0
241 908 Customer Assistance Expenses 7,161 ,608 7,755,993
242 909 lnformational and lnstructional Expenses 920,194 1,023,410
243 910 Miscellaneous Customer Service and lnformational Expenses 158,451 179,059
244 TOTAL Customer Service and lnformation Expenses Clotal of lines 240 thru 243)8,240,253 8,958,462
245 7. SALES EXPENSES
246 Operation
247 911 Supervision 0 0
248 912 Demonstrating and Selling Expenses 0 4,797
249 9l 3 Advertising Expenses 0 0
250 916 Miscellaneous Sales Expenses 0 0
25l TOTAL Sales Expenses (Total ol lines 247 thru 250)0 4,757
252 8, ADMINISTRATIVE AND GENERAL EXPENSES
253 Operation
254 920 Administrative and General Salaries 9,505,163 9.156,633
255 921 Office Supplies and Expenses 1,766,312 1,535,967
256 (Less) 922 Administrative Expenses Transferred-Credit 20,731 17,30'.1
257 923 Outside Servie,es Employed 4,655,459 3,903,981
258 924 Property lnsurance 485,783 471,875
259 925 lnjuries and Damages 1,641,068 1,759,255
260 926 Employee Pensions and Benefits 719,807 345,783
261 927 Franchise Requirements 0 0
262 928 Regulatory Commission Expenses 2,081 ,530 2,257.020
263 (Less) 929 Duplicate Charges-Credit 0 0
2M 930.1General Advertising Expenses 73 3't
265 930.2Miscellaneous General Expenses 1 ,485,418 1,321 .552
266 931 Rents 302,200 288,924
267 TOTAL Operation Ootal of lines 254 thru 266)22,622,O82 21,023,720
268 Maintenance
269 932 Maintenance of General Plant 3,600,782 3,151,359
270 TOTAL Administrative and General Expenses (Total of lines 267 and 269)26,222,864 24.175,079
271 TOTAL Gas O&M Expenses (Total of lines 97,177,201 ,229,237,244,251 , and 270)464,967,609 430,973,1 95
FERC FORM NO. 2 (12-96)Page 325
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) [-lA Resubmission
uale ot Kepon(Mo, Da, Yr)
o4t't512015
Year/Period of Report
End of 2olzUQl
Gas Used in Utility Operations
1. Report below details of credits during the year to Accounts 810, 81 1, and 81 2.
2, lf 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.
Purpose for Which Gas
Was Used
(a)
Account
Charged
(b)
Natural Gas
Gas Used
Dth
(c)
Natural Gas
Amount of
Credit
(in dollars)
(d)
Natural Gas
Amounl of
Credit
(in dollans)
(d)
Natural Gas
Amount of
Credit
(in dollars)
(d)
1 810 Gas Used for Compressor Station Fuel - Credit 804 1,523,234
2 81 1 Gas Used for Products Extraction - Credit 811 2,373,781 1,602,04t
3 Gas Shrinkage and Other Usage in Respondents
Own Processinq
4 Gas Shrinkage, etc. for Respondents Gas
Processed bv Others
5 812 Gas Used for Other Utility Operations - Credit
(Report separately for each principal use. Group
minor uses.)
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25 Total 3,897,015 1,602,046
FERC FORM NO.2 (12-96)Page 331
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2015
Year/Period of Report
201410'4
FOOTNOTE DATA
I
Dollar value related to compressor fuel are not seperately recorded. These dollars are included in total gas purchase
costs.
FERC FORM NO.2 ('552.1
Name oI Kesponoent
Avista Corporation
This Reoort ls:(1) fiRn Originat(2\ l_lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End of 2014/Q4
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
to which any expenses relate, List separately items of $250,000 or more.
Line
No.
Description
(a)
Amount
(in dollan)
(b)
Gas Resource Manaqement
2 Labor 685,888
Labor Loadino 571,651
4 Other Expenses (Professional Services, Travel, Office Supplies, Tnining)136,65'l(
o Requlatory Affairs
7 Labor 48,865
8 Labor Loadino 43,454
q Other Expenses (Travel, Transportation, Gas Technoloqy lnstitute Paymenb)147,949
10
11
12
'13
14
15
16
17
18
'19
20
21
22
23
24
25 Total 1,634,458
FERC FORM NO. 2 (12-96)Page 334
Name of Respondent
Avista Corporation
This Reoort ls:(1) []nn original(2) [-lA Resubmission
Date of Report(Mo, Da, Y0
04t15t2015
YearF'enoo or Kepon
End of &[lUQ4
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.
Description
(a)
Amount
(in dollars)
(b)
1 lndustry association dues.339,772
2 Experimental and general research expenses.
a. Gas Research lnstitute (GRl)
b. Other
a Publishing and distributing information and reports to stockholders, trustee, registrar, and transfer
agent fees and expenses, and other expenses of servicing outstanding securities of the respondent 120,872
4 Other expenses
Community relations 11,539
b Director expenses 3s.l,248
7 Educational and information 20,933
8 Rating agency fees 66,751
I Aircraft operations and fees 61,291
10 Other miscbllaneous benbial eipenses 513,0'r2
11
12
'13
14
15
16
17
18
19
20
21
22
23
24
25 Total 1 ,485,418
FERC FORM NO.2 (12-96)Page 335
Name of Respondent
Avista Corooration
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
0411512015
Year/Period of Report
20141Q4
FOOTNOTE DATA
Echqdgbeage l W_J,ne Nq; !Q_ Cotumn: a
Other expenses, detail (vendors paid less than $5,000 grouped):
____l
Vendor
Various vendors < $5,000
Baker Bots LLP
Citibank
Citibank NA
Corp credit card
E Source Companies LLC
Enterprise Rent a Car
ET Environmental lnc.
Hanna & Associates lnc.
lntelliresponse System lnc.
Klundt Hosmer Design
Marketwire lnc.
Newsdata Corporation
Olsten
Raidious LLC
Sarah Dennison Leonard
Thackston, Jason R.
The Bank of New York Mellon
The Coeur d'Alene
The Davenport Hotel
Union Bank of California
Wilmington Trust Company
Wurts & Associates lnc.
Purpose
Miscellaneous
Misc.
Misc.
Misc.
Misc.
Misc.
Misc.
Misc.
Professional services
Misc.
Prof. svcs.
Misc.
Misc.
Workforce contract
Misc.
Misc.
Employee misc expenses
Misc.
Misc.
Misc.
Misc.
Misc.
Misc.
Amount
$ 238,441$ 37,500$ 4,598$ 16,163$ 41,768$ 2,081$ 1,609$ 12,841$ 61,395$ 22,537$ 6,722$ 2,965$ 6,866$ 9,265$ 5,468$ 1,579$ 3,900$ 2,526$ 4,339$ 3,796$ 14,929$ 1,436$ 10,288
FERC FORM NO,2 (1 552.1
This Page Intentionally Left Blank
Name oI Kespondent
Avista Corporation
tnrs KeDon ts:(1) [lAn Orisinal(2) nA Resubmission
Date of Report I Year/Perlocl of Report
(Mo, Da, Yr) |o4t1st2o1s I eno ot 2o14tQ4
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 404.1, 404.2, 404.3,405) (Except Amortization of
Acquisition Adjustments)
lubaccount or functional classifications other than hose pre-printed in column (a). lndicate in a foofrote the manner in which column (b) balances are
Section A. Summary of Depreciation, Depletion, and Amortization Charges
Lrne
No.Functional Classification
(a)
Depeciation
Expense
(Account 403)
6)
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)
Amortization of
Underground Storage
Land and Land
Rights
(Account 404,2)
(e)
1 lntangible plant 227
2 Production plant, manufaclured gas
2 Production and gathering plant, natural gas
4 P roducb extraclion plant
5 Underground gas storage planl 681,429
6 Other storage plant
7 Base load LNG terminaling and processing plant
I Transmission plant
o Distribution planl 17,677,004
10 General plant 737,191 2,355
11 Common plantgas 4,369,165 8,284
12 TOTAL 23,464,789 10,866
FERC FORM NO.2 (12-96)Page 336
Name of Respondent
Avista Corporation
This Reoort ls:(1) fien Originat(2\ l-lA Resubmission
Date of Reporl
(Mo, Da, Yr)
04t15t2015
YeaTPenoo oI Kepon
End of 20'14/Q4
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 404.1, 404.2,404.3,405) (Except Amortization of
Acquisition Adjustments) (continued)
depreciation charges, show in a footnote any revisions made to estimated gas reserves.
provisions and the plant items to which related.
Section A. Summary of Depreciation, Depletion, and Amortization Charges
Line
No.
Amortization of
Other Limited{erm
Gas Plant
(Account 404.3)
(0
Amortization of
Other Gas Plant
(Account 405)
(s)
Total
(b to g)
(h)
Functional Classification
(a)
1 481,24(481,473 lntangible plant
2 Produc{ion plant, manufaclured gas
3 Production and gahering plant, natural gas
Products extraclion plant
E 681,429 Underground gas storage plant
6 Other storage plant
7 Base load LNG terminaling and processing plant
8 Transmission plant
17,677,0U Distribution plant
'10 739,546 Genenl planl
11 3,373,64t 7,751,097 Common planlnas
12 3,854,894 27,330,s49 TOTAL
FERC FORM NO.2 (12-96)Page 337
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn orisinat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
YeaflPenoo oI Kepon
End of ![!j@[
Depreciation, Depletion and Amortization of Gas Plant (Accts 403, 404.1, 404.2,404.3,405) (Except Amortization of
Acguisition Adjustments) (continued)
4, Addrowsasnecessarytocompletelyreportall data. Numbertheadditional rowsinsequenceas2.01,2.02,3,01,3,02,etc,
Section B. Factors Used in Estimating Depreciation Charges
Line
No.Func{ional Classification
(a)
Plant Bases
(in thousands)
fh)
Applied Depreciation
or Amortization Rates
(percent)
Ic)
1 Produc{ion and Gatherinq Plant
2 Offshore (foohote details)
3 Onshore (footnote details)
4 Underground Gas Storaqe Plant (footnote details)
i Transmission Plant
6 Offshore (footnote details)
7 0nshore (footnote details)
I General Plant (footnote details)
I
10
11
12
13
14
15
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Report ls:(1) finn Original(2) [-lA Resubmission
uate oI Keoon(Mo, Da, Yi)
04t15t2015
YearPenoo or Kepon
End of 2014/Q4
Particulars Concerning Certain lncome Deductions and lnterest Charges Accounts
Report the information specified below, in the order given, lor the respective income deduclion and interest charges accounb.
period of amoriization.
may be grouped by classes within he above a@ounts.
(c) lnterest on Debt to Associated Companies (Account 430)-For each associated company thal incuned interest on debt during the year, indicate the amount and interest rate
whici interest was incuned during the year.
(d) Other lnterest Expense (Account 431) - Report details including the amount and interest rate for other interest charyes incuned during lhe year.
Line
No.
Item
(a)
Amount
(b)
I Acct. 425.00 - MISCELLANEOUS AMORTIZATIONS
2 Items Under $250,000
Total - 425.00
4 Acct. 426.10 - DONATIONS
5 Land Expressions - Huntington Park Renovation Donation to City of Spokane 675,154
o Items Under $250,000 3,204,243
7 Total 426.10 3,879,397
8 Acct.426.20 - LIFE INSURANCE
o fficers Life 47,321
10 SERP 2,144,885
11 Items Under $250,000 ( 131,636)
12 Total 426.20 2,060,570
13 Acct 426.30 - PENALTIES
14 Items Under $250,000 24,7181
15 Total426.30 ( 24,718l,
16 4cct.426.40 - ExPENDITURES FOR CERTAIN ClVlC, POLITICAL, AND RELATED ACTIVITIES
17 Items Under $250,000 1,679,329
18 Total 426.40 1,679,329
19 Acct 426.50 - OTHER DEDUCTIONS
20 Executjve Defened Compensation 75s,367
21 UBS Securities LLP - Advisory Services for Acquisition of Alaska Energy and Resy 433,160
22 Helveticka, lnc. - Marketino Services 317,705
23 Items Under $250,000 1,788,930
24 Total 426.50 3,295,162
25 Acct. 430.00 - INTEREST ON DEBT TO ASSOC. COMPANIES
to Avista Capital ll (lono{erm debt) (variable rate ranged fmm 1.10 to 'l .'l 1 7o)449,651
27 Avista Capital, lnc.285.847
28 Toh1430.00 735,498
29 AccL 431.00 - OTHER INTEREST EXPENSE
30 lnterest on elecldc defenals 599,935
31 lnteres! on natural qas defenals 169,520
32 lnterest on committed line of credit 1,005,868
33 Ofier 262,634
34 Total 431.00 2,037,9s7
35
FERC FORM NO. 2 (12-96)Page 340
Name of Respondent
Avista Corporation
tnrs KeDon ts:(1) $Rn Original(2) nA Resubmission
Date of Reoort
(Mo, Da, Yi)
o4t15t2015
Year/Period of Report
End ol 20141Q4
Regulatory Commission Expenses (Account 928)
or cases in which such a body was a party.
2. ln column (b) and (c), indicate whether the expenses were assessed by a regulatory body or were othemrise incuned by the utility.
Line
No.
Description
(Fumish name of regulatory commission
or body, the docket number, and a
description of the case.)
(a)
Assessed by
Regulatory
Commission
(b,|
Expenses
of
Utility
tc)
Total
Expenses
to Date
(d)
Defened in
Acmunt 182.3
at Beginning
of Year
(e)
1 Federal Energy Regulatory Commission
2 Charges include annual fee and license fee
3 for the Spokane River Project, the Cabinet
4 Gorge Project and Noxon Rapids Projecl
2,156,360 472,828 2,629,188
5
6 Washington Utilities and Transportation Commission
lncludes annual fee and various other electric dockets
997,195 909,098 1,906,293
8
9 lncludes annual fee and various other natural gas
dockets 314,536 282,397 596,933
10
11 ldaho Public Utilities Commission
12 lncludes annual fee and various other electric dockets
590,379 244,404 834,783
13
14 lncludes annual fee and various other natural gas
dockets 161,525 71,788 233,313
15
16 Public Utility Commission of Oregon
17 lncludes annual fee and various other dockets
549,812 415,815 965,627
18
19 Not directly assigned electric
710,928 710,928
20 Not directly assigned natural gas
285,657 28s,657
21
22
23
24
25 Total 4,769,807 3,392,915 8,162,722
FERC FORM NO. 2 (12-s6)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) []nn orisinat
(21 llA Resubmission
Date of Reoort(Mo, Da, Yi)
04t15t2015
YearPenoo or i(epon
End of p![@!
Regulatory Commission Expenses (Account 928)
3. Show rn mlumn (k) any expenses incuned in prior years that are being amortized. List in column (a) the period of amortization.
4. ldentify separately all annual charge adjustments (ACA).
5. List in column (f), (g), and (h) expenses incuned during year which were charges currently to income, plant, or other accounts.
6. Minor items (less than $250,000) may be grouped,
Line
No.
Expenses
lncuned
During Year
Charged
Cunently To
Department
(fl
Expenses
lncuned
During Year
Charged
Cunently To
Account No.
(o)
Expenses
lncuned
During Year
Charged
Cunently To
Amount
h)
Expenses
lncuned
During Year
Defened to
Account
182,3
fi)
Amortized
During Year
Contria
Account
(i)
Amortized
During Year
Amount
(k)
Defened in
Account 182.3
End of Year
fl)
1
2
3
4
Electric 928 2;629,1 88
5
6
7
Electric 928 1,906,293
I
9
Gas 928 596,933
10
11
12
Electric 928 834,783
13
14
Gas 928 233,31 3
15
16
17
Gas 928 965,627
'18
19
Electric 928 710,928
20
Gas 928 285,657
21
22
23
24
25 8,162,722
FERC FORM NO. 2 (12-96)Page 351
Name of Respondent
Avista Corporation
tnrs HeDon ts:(1) []Rn Originat(2) nA Resubmission
Date of Report(Mo, Da, Yr)
04t1512015
Year/Period of Repor
End of 2014/Q4
Employee Pensions and Benefits (Account 926)
1. Report below the items contained in Account 926, Employee Pensions and Benefits.
Line
No.
Expense
(a)
Amount
(b)
,|)ensions - defined benefrt plans 7't9,807
2 )ensions - other
3 )ost-retirement benefib other han pensions (PBOP)
4 )ost- employment benefit plans
5 )ther (Specity)
6
7
I
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
Total 719,807
FERC FORM NO.2 (NEW 12-07)Page 352
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn orisinal(2) l--lA Resubmission
Date of Report
(Mo, Da, Yr)
0/.t15t2015
Year/Period of Report
End ot 2O14lQ4
Distribution of Salaries and Waqes
and Other Accounb, and enter such amounb in the appropriate lines and mlumns provided. Salaries and wages billed to the Respondent by an afliliated ompany must be assigned to
he particular operating function(s) relating to fre expenses.
ln determining this segregation of salaries and wages originally charyed to clearing accounb, a mehod of approximation giving substantially coned resulb may be used. When
reporting detail of other accounB, enter as many rows as necessary numbered sequentially starting with 75.01, 75.02, etc.
Line
No.
Classification
{a)
Direci Payroll
Distribution
(b)
Payroll Billed
by Affiliated
Companies
(c)
Allocation of
Payroll Charged
lor Clearing
Accounb
(dl
Total
(e)
3 Production 10,113,212 10,113,212
4 Tnnsmission 2,951,554 2,951,554
5 Distribution 7,946,43'l 7,946,431
6 Customer Accounts 6,799,031 6,799,031
7 Customer Servie and lnformational 670,845 670,84s
8 Sales
9 Administrative and General 15,754,826 15,754,826
10 TOTAL Openation fiotal of lines 3 thru 9)44,235,899 44,235,899
12 Produclion 3,442,1U 3.442,1U
13 Transmission 1,139,15€1,1 39,1 56
14 Distribulion 4,148,919 4,148,919
15 Administrative and General 13,477,28t 13,477,288
16 TOTAL Maintenance (Total of lines 12 hru 15)8,730,25!13,477,28t 22.207.547
18 Production (Totalof lines 3 and 12)13,555,39€13,55s,396
19 Transmission fiohl of lines 4 and 13)4,090,71(4,090,710
20 Distribution Ootal of lines 5 and 14)12.095.35C 12,09s,350
21 CustomerAccounb (line 6)6,799,031 6,799,031
22 Customer Service and lnformational (line 7)670,84t 670,845
23 Sales (line 8)
24 Adminis$ative and General (Total of lines 9 and '15)'15,754,82t 13,477,28t 29,232,1',t4
25 TOTAL Ooeration and Maintenance fiotal of lines 18 thru 24)52,966,15t 13,477,28t 66,443,446
28 Prcduc{ion - Manufactured Gas
29 Prcduc,tion - Natural Gas(lncludino Exoloration and Develooment)
30 Oher Gas Supply 7U,75i 7U,753
31 Storaqe, LNG Terminalinq and Processin0 3,57:3,573
32 Tnansmission
33 Distribution 4,754,14(4,754,',t40
34 Cuslomer Accounts 2,746,08a 2,746,083
35 Customer Service and lnformational 313,75i 313,752
36 Sales
37 Administrative and General 5,981,587 5,981,587
38 TOTAL Operation (Total of lines 28 thru 37)14.533.88t 14,533,888
40 Production - Manufactured Gas
4',!Produclion - Natural Gas(lncluding Exploration and Development)
42 Oher Gas Suoolv
43 Storage, LNG Terminaling and Processing
44 Transmission 1.084.69(1,084,690
45 Distribution 3,472,26t 3,472,268
FERC FORM NO.2 (REVTSED)Page 354
Name of Respondent
Avista Corporation
This Reoort ls:(1) $An orlginat(2) TIA Resubmission
uate or Kepon(Mo, Da, Yr)
0411512015
Year/Period of Report
End ot 2O14lQ4
Distribution of Salaries and Wages (continued)
Line
No-
Classffication
(a)
Direci Payroll
Distribution
(b)
Payroll Billed
by Afiiliated
Companies
(c)
Allocation of
Payroll Charged
lor Clearing
Accounts
(d)
Total
(e)
46 Adminisfative and General 4,847,56t 4,847,56:
47 TOTAL Maintenance fiotal of lines 40 thru 46)4,556,95t 4,847,56t 9,404,52:
50 Produclion - Manufac{ured Gas fiotal of lines 28 and 40)
5'l Poduc{ion - Natural Gas (lncluding Expl. and Dev.)(ll. 29 and 41)
52 Ofier Gas Supply (Total of lines 30 and 42)7U,751 734,753
53 Stoage, LNG Terminaling and Processing (Total of ll. 3'l and 43)3,57:3,573
54 Transmission fiotalof lines 32 and 44]1,084,69(1.0M.69(
55 Distribution (Total of lines 33 and 45)8,226,40t 8.226.408
56 Customer Accounb Ootal of line 34)2,746,084 2,746,083
57 Customer Service and lnformational (Total of line 35)313.75i 313,752
58 Sales fiotal of line 36)
59 Administrative and General (Total of lines 37 and 46)5,981,587 4.847,561 10,829.152
60 Total Operation and Maintenance (Total of lines 50 thru 59)1S.090.84t 4,847,56t 23,938,411
6t Operation and Mainlenance
63 TOTAL ALL Utility Dept. (Total of lines 25, 60, and 62)72,057,004 18,324,85:90,381,8s7
65 Construction {Bv Utilitv Deoartmenb)
66 Elec{ric Planl 25,103,214 1 1,855,091 36,958,306
67 Gas Plant 5,564,96i 3,639,26i 9.204,229
68 Oher
69 TOTAL Consfuction (Total of lines 66 thru 68)30,668,18'l 15.494.31 46.162,535
71 Electric Planl 't,759,'ll 439,34/2.198,459
72 Gas Plant 109,17:27.26i 136,440
73 Other
74 TOTAL Plant Removal Ootal of lines 71 thru 73)1.858.281 466,61 2,334,899
75 Other Accounb (Specity) (footnote details)41,119,27i 34,285,8'15
76 TOTAL Other Accounts 41,119,27i 34.28s.81s 6,833,462
77 TOTAL SALARIES AND WAGES 145,712,75('t45.712.753
FERC FORM NO.2 (REVTSED)Page 355
Name of Respondent
Avista Comoration
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2015
Year/Period of Report
2014tQ4
FOOTNOTE DATA
Other accounts (specify):
Stores expense (163)
Unamortized debt expense (181)
Regulatory assets (182)
Preliminary survey and investigation (183)
Small tools expense (184)
Miscellaneous deferred debits (1 86)
Capital stock expense (214)
Merchandising expenses (416)
Non-operating expenses (41 7)
Expenditures of certain civic, political and related
(1,990,544)
(3,409,889)
activities (426) 937,340
Employee incentive plan (232380) 1 1,880,540
DSM tariff rider and payroll equalization liability (242600,242700) 18,779,293
lncentive / stock compensation (238000) 127,276
TOTAL Other Accounts 41,119,277 (34,285,815) 6,833,462
1,990,544
0
0
2,545
3,409,999
2,518,814
0
0
1,473,036
0
0
0
2,545
0
2,518,814
0
0
1,473,036
937,340(11,880,540) 0
(17,004,842) 1,774,451
127,276
FERC FORM NO.2 (1 Paoe 552.1
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This ReDort ls:(1) fiRn Originat
(21 [-]A Resubmission
uate or Kepon(Mo, Da, Yr)
04t15t2015
YearlPeriod of Report
End ol 2O14lQ4
Charges for Outside Professional and Other Consultative 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 servirrs.
(b) Total ciarges for the year.
2. Sum under a descdption "Ofier', all of the aforementioned services amounting to $250,000 or less.
3. Total under a desoiption Total', he total of all of the aforementioned servioes.
according to he instuctions for hat schedule.
Line
No.
Description
(a)
Amount
(in dollars)
(b)
1 AECOM TECHNICAL SERVICES INC 299,84s
2 ALDEN RESEARCH LABOMTORY INC 362,7s4
3 BAKER CONSTRUCTION & DEVELOPMENT INC 575,000
4 BLACK & VEATCH CORPORATION 644,345
5 CIRRUS DESIGN 315,785
6 COEUR D ALENE TRIBE 730,1',t7
7 COLUMBIA GRID 322,708
I DAVIS WRIGHT TREIi4AINE LLP 512,805
I DINERO SOLUTIONS LLC 561,684
10 DUCKS UNLIMITED 3,1 19,302
11 ERNST & YOUNG LLP 3,747,281
12 ET ENVIRONMENTAL INC 9'.12,175
13 FIVE POINT PARTNERS LLC 3,326,765
14 GILLESPIE PRUDHON & ASSOCIATES INC 254,908
l5 GOLDER ASSOCIATES INC 278,921
't6 HELVETICM INC 377,188
17 HICKEY BROTHERS RESEARCH LLC 289,s0s
18 HP ENTERPRISE SERVICES 1,762,429
19 IBM CORPORATION 5,181,260
20 IDAHO DEPT OF FISH & GAME 262,743
21 INTELLITECT 680,647
22 KLUNDT HOSMER DESIGN 418,640
23 LAND EXPRESSIONS 1,654,476
24 LANDAU ASSOCIATES 516,743
25 MAX J KUNEY COMPANY 563,189
26 MCKINSTRY ESSENTION INC 3,065,883
27 MOSAIC COMPANY 1,448,533
28 MWH AMERICAS INC 282,025
29 NEAL STRUCTUML REPAIR LLC 1,437,896
30 NORTHWEST HYDRAULIC CONSULTANTS LTD 285,900
31 NORTHWEST POWER POOL 267,969
32 ON MMP WIRELESS 273,250
33 OPOWER INC 279,887
34 PAINE HAMBLEN LLP 772,227
35 OTHER 20,533,247
FERC FORM NO.2 (REVTSED)Page 357
Name of Respondent
Avista Corporation
This Reoort ls:(1) []en originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2015
Year/Period of Report
End of 2014/Q4
Transactions with Associated (Affiliated) Companies
1, Report belour Sre information called for conceming all goods or services received from or provided to associabd (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", he total of all of the aforementioned goods and services.
4. Where amounb billed to or received from the associated (affiliated) company are based on an allocation process, explain in a footnote the basis of the allocation.
-rne
No.
Description of the Good or Service
(a)
Name of Associated/Affiliated Company
(b)
Account(s)
Charged or
Credited
(c)
Amount
Charyed or
Credited
(d)
2 Oher Steam Plant Square, LLC 93'1000 149,304
3 Oher Sookane Enemy LLC 456000 51,175
4 TOTAL 200,479
5
6
7
I
I
10
11
12
13
14
15
16
17
18
19
21 Corporate Service Suooort Salix lnc.146000 794,279
22 Other Alaska lnc.'t46000 110,121
23 Other Avisia Develooment lnc 146000 228,289
24 Other Avista Capital lnc.146000 107,661
25 Oher Avista Enemv lnc.146000 42,910
26 TOTAL 1,283,260
27
28
29
30
1
32
33
34
35
36
37
38
39
40
FERC FORM NO.2 (NEW 12-071 Page 358
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn Originat
(21 l-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2015
Year/Period of Reporl
End of 2014/Q4
Gas Storage Projects
1. Report injec{ions and withdrawals of gas for all storage projecls used by respondent
Line
No.
llem
(a)
Gas
Belonging to
Respondent
(Dth)
{b)
Gas
Belonging to
Others
(Drh)
{c)
Total
Amount
(Dth)
(d)
2 January
3 February
4 March
5 April
6 Mav 1,938,598 1,938,598
7 June 1,'t60,794 1,160,794
I July 1,649,683 1,649,683
9 Angust 2,345,391 2,345,391
10 September 1,250,097 1,250,097
1',!Oclober 194,507 194,507
12 November 650,868 650,868
13 December 701,545 701,545
14 TOTAL (Totalof lines 2 thru 13)9,891,483 9,89'1,483
16 January 1,182,256 1,182,256
17 February 2,486,824 2,486,824
18 Marctr 625,788 625,788
19 April 1,741 1,741
20 May
21 June 1,263 't,263
22 July 2,046 2,046
23 August 1.404 1,404
24 September 32,588 32,588
25 Oc{ober 3,560 3,560
26 November 939,473 939,473
27 December 1,537,239 1,537,239
28 TOTAL (Total of lines 16 thru 27)6,814,182 6,814.182
FERC FORM NO.2 (12-96)Page 512-
Name of Respondent
Avista Corporation
This Reoort ls:(1) fien originat(2) nA Resubmission
uate oI Keoon(Mo, Da, Yi)
04115t2015
Year/Period of Report
End of 2014lQ4
Gas Storage Projects
1. On line 4, enter the total storage capacity ertificated by FERC.
2. Report total amount in Dtr or oher unit, as applicable on lines 2, 3, 4, 7. lf quantity is converted from Mcf to Dh, provide convenion factor in a footrote.
Line
No.
Item
(a)
Total Amount
(b)
STORAGE OPERATIONS
1 Too or Workinq Gas End of Year 8,528,000
2 Cushion Gas (lncludino Native Gas)7,730,668
3 Tohl Gas in Reservoir fiotal of line 'l and 2)16,258,668
A Certificated Storaoe Caoacitv 16,258,668
5 Number of lniection - Withdrawal Wells 54
o Number of Observation Wells 48
7 Maximum Days' Withdrawal from Storaqe ffi*fWfffiF:iffiffiffidlU
I Date of Maximum Days'Withdrawal 02t06t2014
I LNG Terminal Companies (in Dth)
10 Number of Tanks
11 Caoacity of Tanks
12 LNG Volurne
13 Received at'Shio Rail'
14 Transfened to Tanks
15 Wihdrawn from Tanks
16 'Boil Off Vaporization Loss
FERC FORM NO.2 (12-s6)Page
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ) A Resubmission
Date of Report
(Mo, Da, Yr)
0/.t15t2015
Year/Period of Report
20141Q4
FOOTNOTE DATA
trc-Oeqnie_Pesij _iig. lap E -.;Z- _CeidruLU
Mcf converted to Dth using factor of 1.04
_-l
FERC FORM NO. 2 (1 552.1
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) [--]A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512015
Year/Period of Report
Endof U!!!9!
Auxiliary Peaking Facilities
inshllations, gas liquefaction plants, oil gas sets, etc.
2, For column (c), for underground storage projects, reporl he delivery capacity on Febrar 1 of the heating season overlapping the year€nd for which this report is submitted.
For other facilities, report the rated maximum daily delivery capacities.
separate plant as contemplated by general instruction 12 of the Uniform System of Accounts.
Line
No.
Location of
Facility
(a)
Type of
Facility
(b)
Maximum Daily
Delivery Capacity
of Facility
Dth
(c)
Cost of
Facility
(in dollars)
td)
Was Facility
Operated on Day
of Highest
Transmission Peak
Deliverv?
1
2 Chehalis, Washington Undeground Natural Gas 358,800 36,052,76s Yes
Storage Field
4 Washington & ldaho Supply
5
6 Chehalis, Washington Underground Natural Gas 39,867 5,910,342 Yes
7 Stonge Field
8 Oregon Supply
I
10 Chehalis, Washington Underpround Natural Gas 2,623 rril, : {., rit ::.ii'.:!ii', :r :l)No
'11 Storage Field
12 Oregon Supply
13
14 Rock Springs, Wyoming Underground Natural Gas 1 86,1 25 'i i tiri:ir: ,(iiti:ti:r;,{fi1)No
t5 Stonage Field
16 Washington & ldaho Supply
17
18 Rock Springs, Wyoming Underground Natural Gas 63,875 iri'.:;:,'' rir,:,'r I I't,:rl;i :i ll No
19 Storage Field
20 Oregon Supply
21
22
23
24
25
26
27
?8
29
30
FERC FORM NO.2 (12-95)Page 5't 9
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512015
Year/Period of Report
20fin;4
FOOTNOTE DATA
is a oarticipant in the facilities, not an owner and is a fee for demand delive
Respondent is a participant in the facilities, not an owner and is charged a fee for demand deliverability and capacity.
in the facilities, not an owner and is a fee for demand
FERC FORM NO.2 552.1
Name of Respondent
Avista Corporation
This Report ls:(1) fiAn Original(2) I-lA Resubmission
Date of Report(Mo, Da, Yr)
o4115t2015
Year/Period of Report
End ot 2O14lQ4
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 rneans eiher natural gas unmixed or any mixture of nalural and manufetured 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) he res@tive quarte/s Dth as reported in the schedules indicated for he items of receipts and deliveries.
5. lndicate in a footnote the quantities of bundled sales and transprtation gas and specity be line on which such quantities are listed.
6. lf he respondent operates two or more systems which are oot interconnected, submit separate pages for this purpose.
wore not transported hrough any interstate portion of the reporling pipeline.
8. lndicate in a footnote he specific gas purchase expense acount(s) and related to which the aggregate volurnes reported on line No. 3 relate.
reporting year, and (3) cootract storage quanliiies.
footnotes,
l-ine
No.
Item
(a)
Ref. Page No. of
(FERC Form Nos.
2t2-Al
(b)
Total Amounl
of Dth
Yearto Date
G)
Cunent Three
Monhs
Ended Amount of Dth
Quarterly Only
)l Name of System:
2 GAS RECEIVED
3 Gas Purchases (Accounb 800{05)92,463.861 26,721,124
4 Gas ofOhers Received for Gatherinq (Account 489.1)303
5 Gas of Others Received for Transmission (Account 489.2)305
6 Gas of Ofiers Received for Distibulion (Account 489.3)301 16,231,147 4,358,505
7 Gas of Othen Received for Confaci Storaqe (Account 489.4)307
I Gas of Others Received for Production/Extraction/Processinq (Account 490 and 491 )
I Exchansed Gas Reeived from Others (Account 806)328 12,03(1 't,649
'10 Gas Received as lmbalances (Account 806)328
11 Receipts of Respondenfs Gas Transported by Others (Account 858)332
12 Ofier Gas Withdrawn from Storage (Explain)( 3,082,702 9s6,133
13 Gas Received fom Shippers as Compressor Station Fuel
14 Gas Received from Shippen as Lost and Unacoounted for
15 Other Receiots {Soecifu) {footnote details)
16 Total Receipb (Total of lines 3 hru '15)105,624,341 32,047,411
17 GAS DELIVERED
't8 Gas Sales (Accounts 480484)87,869,964 27,137,213
19 Deliveries of Gas Gathered for O{hen (Amunt 489.1)303
20 Deliveries of Gas Transported for Others (Account 489.2)305
21 Deliveries of Gas Distributed for O$en (Account 489.3)301 16,231.14i 4,358,505
22 Deliveries of Contract Storage Gas (Account 489.4)307
23 Gas of Obers Delivered for Produc{ion/Extraclion/Processinq (Accounl 490 and 491)
24 Exchange Gas Delivered to Others (Account 806)328
25 Gas Delivered as lmbalanes (Account 806)328
26 Deliveries of Gas to Olhers for Transportation (Account 858)332
27 Other Gas Delivered to Slorage (Explain)
28 Gas Used for Comoressor Station Fuel s09 1,523,234 55't,693
29 Other Deliveries and Gas Used for Other Operations
30 Total Deliveries fiotal of lines 18 thru 29)105,624,34:32,047.411
31 GAS LOSSES AND GAS UNACCOUNTED FOR
32 Gas Losses and Gas Unaccounted For
33 TOTALS
34 Total Deliveries, Gas Losses & Unaccounted For (Total of lines 30 and 32)105,624,34r 32,047,411
FERC FORM NO. 2 (REV 0t-11)Page 520
Avista Corp.
'.'
2014
IDAHO
State Natural Gas Annual Report
(rc 61-405)
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Reporl
mm/dd|yyy
04-15-2015
Year / Period of Report
End of 2014 I Q4
STATEMENT OF UTILITY OPERATI t.IG I NCOi'IE . IDAHO
!nstructions
1. For each account below, report the amount attributable to the state of ldaho based on ldaho jurisdictional Results of Operations.
2. Provide any neoessary important notes regarding this statement of utility operating income in a footnote in the available space at the bottom of this page
Line
No.Account
(a)
Refer to
Form 2
Page
(b)
TOTAL SYSTEM - IDAHO
Cunent Year
(c)
Prior Year
(d)
1 UTILITY OPEMTING INCOME
2 Coeratino Revenues (400)300-301 441.237.507 455.520.663
3 Coeratino Exoenses
4 roeration Exoenses (401)3',t7-325 284.419.705 255.611.O27
5 l\raintenance Exoenses (402)317-325 21.375.618 19.652.814
6 DeDreciation ExDense (403)336-338 37.201.407 34.901.456
7 Depreciation Expense for Asset Retirement Costs (403.1 336-338
8 Amortization & Depletion of Utility Plant (404.405)336-338 4.088.551 3.303.423IAmortization of Utility Plant Acquisition Adiustment (406)33&338 67.3il 67.304
10 Amort. of Prooerlv Losses. Unrecov Plant and Reoulatorv Sludv Costs (407)
11 Amortization of Conversion Exoenses (407)
12 Reoulatorv Debits (407.3)(326.764'5.300.546
13 fless) Reoulatorv Credits (407.4)Q.626.407'(4.551.546)
11 faxes OtherThan lncome Taxes (408.1 262-263 16.323.848 16.302.615
15 lncome Taxes - Federal (409.1 262-263 (7.575.91(13.O22.062
16 - Other (409.1 262-263
17 Provision for Defened lncome Taxes (410.1 234-235 30,799,737 8.580.886
't8 lless) Provision for Deferred lncome Taxes-Cr. G11.1 234-235
19 lnvestment Tax Credit Adiustment - Net {41 'l -4)(a1.674 (85.270)
20 fless) Gains from Disoosition of Utilitv Plant (411 .6)
21 Losses from Disoosition Of Utilitv Planl G1'1.7\
22 [Less) Gains from Dlsoosition of Allowances (41 1.8)
23 -osses from Disposition of Allowances (411.9)
24 Accretion Exoense G1 1 -1O\
25 I-OTAL Utilitv Ooeratino Exoenses ffotal of line 4 throuoh 24)381.665.406 392.105.317
26 Net Utilitv Ooeratino lncome (Total line 2 less 25)62.572.101 63.415.346
G.tD.114-115IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)
Name of Respondent
Avlsta Corporatlon
This Report is: I Date of Report
lFl nn odsinal I mna@yyy
[] nResubmission I o+-ts-zots
Year / Period of Report
End of 2014 I Q4
I'IAIEMEI{I (,t- U!tl-tIY (,PEKAIilt(j tNU(,ttE - IUAH(J
lnstiuctlons
or in a separate schedule.
3. Explain in a footnote if the previous yea/s figures are different from those reported in prior reports.
ELECTRIC UTILITY GAS UTILITY OTHER UTILITY Line
Cunent Year
(6)
PriorYear
(0
Cunent Year
(o)
Prior Year
(h)
Cunent Year
fi)
Prior Year
fi)
No.
334.155.729 352.695.900 1 10.081 .778 102_424.763 2
r 99.CCZ.1 lro 216,407,227 84.867.569 79.203.800 4
17.974.892 17.112.701 3.400.726 2.540.113 5
31.796.,f45 29,855,837 5.404.962 5.045.619 6
7
3_309.953 2.715.282 778.598 588.141 I
67.304 67.304 9
10
11
ra26.76/.\5.300.546 12
G.626.407 (4.551.546)13
4.260 13,593,242 2.62S.588 2.709.373 11
(5.091.709 9.556.S0S Q.484.210'3.46s.153 15
16
21.249.A54 8.265.280 6.510.079 3't5.606 17
18
{69.OO21 (6,9.274)(12.672 (15.99t 19
20
21
22
23
24
280.570.766 298,253,508 101.094.640 93.85't.809 25
53.584.963 54,442,392 8.987.138 8.972.954 26
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 6I{05)G.|D.114-115
Name of Respondent
Avlsta Gorporatlon
This Report is:
lFl nn odsinat
fl n Resubmission
Date of Report
mm/ddfiyyy
o4-'t5-2015
Year / Period of Report
End of 2014 I Q4
SUMiIARY OF UTILITY PLANT AI{D ACCUiIULATED PROVISIONS FOR DEPRECIATION. AIIORTIZATIO}.I AND DEPLETION - IDAHO
lnetructlons
1. Report below the original cost of utility plant in service necessary to furnish ulility service to customers in the state of ldaho, and the
accumulated provisions for depreciation, amortization, and depletion attributable to that plant in service.
2. Report in column (c) the amount for electric function, in column (d) the amount for gas function, in columns (e), (0, and (g) report other (specify),
Lin€
No.Account
(a)
Total Company
End ofCunent Year
(b)
Electric
(c)
1 Utilitv Plant
2 ln Service
3 Plant in Service (Classified)'t.462.000.1s6 1.180.868.162
4 Prooerfu Undar Caoital Leases 363.241
5 Plant Purchased or Sold
6 oompleted Construction not Classified
7 Experimental Plant UnclassifiedITotal 0otal lines 3 throuqh 7)1.462.363.437 .'t80.868.162ILeased to Others
10 Held for Future Use 389.592 199.007
11 3onstruction Work in Prooress 76.183_744 40.471.528
12 Acouisition Adiustments
13 Iotal Utilitv Plant ffotal lines 8 throuqh 12)1.538.936.773 1 221 534697
11 Accumulated Provision for Deprecialion. Amortization, and Depletion 527.167.946 435.271.753
15 Net Utilitv Plant (Line 13 less line 14)1.011.768.827 786.266.944
16 Detail of Accumulated Provision for DeDreciation. Amortization. and Deoletion
17 ln Service
18 DeDreciation 516.142.674 431.896.304
19 Amortization and Deoletion of Producino Naiural Gas Lands / Land Riohts
20 Amortization of [Jnderoround Storaoe Lands / Land Riohts
21 Amortization of Other Utility Plant 11.O25.272 3375.149
22 Toial (Toial lines 18 throuoh 21)527.147.916 435.271.753
23 Leased to Others
21 Depreciation
25 Amortization and DeDletion
26 Iotal Leased to Others
27 Fleld for Future Use
28 Deoreciation
29 Amortization
30 fotal Held for Future Use
31 Abandonment of Leases (Natural Gas)
32 Amortization of Plant Acouisition Adiusimeni
33 l-otal Accumulaied Provision (Total lines 22 2A 30 31 32\527.167.946 435.271.753
G.tD.200-201IDAHO STATE NATURAL GAS ANNUAL REPORT (lC 61405)
Name of Respondent
Avlsta Gorporatlon
This Report is:
I en originat
I n Resubmission
Date of Report
mmlddrlyyy
04-1 5-201 5
Year / Period of Repofl
End of 2014 I Q4
SUTIIII'ARY OF UTILITY PLAI{T AND ACCU]f,ULATED PROVISIONS FOR DEPRECIATION. AIUIORTIZATION AND DEPLETION .IDAHO
lnstructlons
and in column (h) common function.
3. ln order to accurately reflect utility plant in service necessary to fumish utility service to customers in the state of ldaho, electric and gas
plant not directly assigned is allocated to the state of ldaho as appropriate and included in column (c) and (d).
Gas
(d)
Other (Specin
(e)
Other (Speci!)
(o
Other (Specify)
(o)
Common
(h)
Line
No.
192.139.129 88.992.905 3
272.243 90.998 4
5
6
7
192.411.372 89.083.903 8I
190.585 10
6.820.241 28.891.952 1
12
199.422.221 I 17 975 855 13
66.319.705 25.576.488 14
133.102.516 92.399.367 15
65.902.980 ,8.343.390 '18
19
20
416.725 7 233 098 21
66.319.705 25.576.488 22
24
25
26
28
29
30
31
32
66.319.705 25.576.444 33
IDAHO STArE NATURAL GAS ANNUAL REPORT (lC 61.40s)G.tD.200-201
Name of Respondent
Avlsta Corporatlon
This Report is:
lFl en orisinat
fl a Resubmission
Date of Report
mm/ddlyyw
04-15-2015
Year / Period of Report
End of 2014 I Q4
GAS PLANT lN SERVICE - IDAHO lAccount 1O1- 1O2.103 and 106l
lnstructlons
1. Report below the original cost of gas plant in service necessary to furnish natural gas utility service to customers in the state of ldaho.
lnclude gas plant not directly assigned as allocated to the state of ldaho.
2. ln 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. lnclude in column (c) or (d), as appropriate, corrections of addilions and retirements for the cunent or preceding year.
4. 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.
5. Enclose in parentheses credit adjustments ofplant accounts to indicate the negative effect ofsuch amounts.
6. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the enlries 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
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. lnclude also in column (d) diskibutions of
Line
No.Accounl
(a)
Balance
Beginning of Year
(b)
Additions
(c)
1 NTANGIBLE PLANT
2 301 Oroanization
3 302 Franchises and Consents
4 303 Miscellaneous lntanoible Plant 609.937 136.444
5 I'OTAL lntanqible Plant ffotal of lines 2. 3. and 4)609.937 136.444
6 ]RODUCTION PLANT
7 {atural Gas Production and Gatherino Plant
8 325.1 Producino Lands
I 325.2 Producinq Leaseholds
10 325.3 Gas Riqhts
1 325.4 Riqhts-of-Wav
12 325.5 Other Land and Land Riohts
13 326 Gas Well Structures
't4 327 Field Compressor Station Structures
15 328 Field Measurinq and Reoulatinq Station EquiDment
16 329 Other Structures
17 330 Producino Gas Wells-Well Construclion
18 331 Producino Gas Wells-Well EouiDment
19 332 Field Lines
20 333 Field Comoressor Station Eouiomeni
21 334 Field Measurino and Reoulatino Staiion Eouioment
22 335 Drillino and Cleanino Eouiomenl
23 336 PurificationEouiDment
24 337 Other Eouiomenl
25 338 Unsuccessful Exoloration and Develooment Costs
26 339 Asset Retirement Costs for Natural Gas Production and Galherino Planl
27 fOTAL Natural Gas Production and Gatherino Plant (Total of lines 8 throuoh 26)
28 Products Extraction Plant
29 340 Land and Land Riohts
30 341 Struclures and lmorovements
31 342 Extraction and Refinino EouiDmenl
32 343 PiDe Lines
33 344 Extracted Products Storaoe Eouioment
IDAHO STATE NATURAL GAS ANNUAL REPORT (|c 6T.405)G.tD.204-205
Name of Respondent
Avlsta Corporatlon
This Report is:
lx-l en originat
f] n Resubmission
Date of Report
mm/ddlyyyy
0/'-15-2015
Year / Period of Report
End of 2014 I Q4
GAS PLANT tN SERVICE - IDAHO tAccount tol. toz. 1I,3 and tOSt
lnstructlons
these tentative classifications in columns (c) and (d), including the reversals of the prior yea/s tentative account distributions of these amounts. Careful
observance of these instruc{ions 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.
7. Show in column (f) reclassifications or transfers within utility plant accounts. lnclude also in column (0 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 debiis or credits distributed in column (f) to primary
account classifi cations.
8. 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 classilication of such plant conforming to the requirement ot these pages.
9. For each account comprising the reported balance and changes in Account 1 02, state the property purchased or sold, name of vendor or purchase, and
date of transaclion. lf proposed joumal entries have been filed as required by the Uniform System of Accounts, give also the date of such filing.
Retirements
(d)
Adjustments
(e)
Transfers
(fl
Balance
End of Year
(o)
Line
No.
2
3
62.839 fi1.117]672.425 4
62.839 fi1.117'.672.425 5
I
I
10
1
12
13
14
15
16
17
18
t9
20
21
22
23
24
25
26
27
29
30
31
32
33
G.tD.204-205IDAHO STATE NATURAL GAS ANNUAL REPORT (lC 61.405)
Name of Respondent
Avista Corporatlon
This Report is:
IFI en originat
I a Resubmission
Date of Report
mm/dd/yyyy
04-1 5-201 5
Year / Period of Repod
End of 2014 I Q4
GAS PLANT lN SERVICE - IDAHO aAccount 1O1. 1O2- lO3 and l(16l aconianuedl
Linc
No.Account
(a)
Balance
Beginning of Year
(b)
Additions
(c)
34 345 ComoressorEouiDment
35 346 Gas Measurino and Requlatino Eouioment
36 347 Other Eouioment
37 348 Asset Retirement Costs for Products Extraction Plant
38 I'OTAL Producis Extraction Plant ffotal of lines 29 throuqh 37)
39 I'OTAL Natural Gas Production Plant fiotal lines 27 and 38)
40 Vlanufactured Gas Production Plant (Submit Suoplementarv Schedule)
41 I-OTAL Production Plant (Total lines 39 and 40)
42 {ATUML GAS STOMGE AND PROCESSING PLANT
43 Jnderoround Storaoe Plant
44 350.'l Land 120.999
45 350.2 Riohts-of-Wav 17.782
46 351 Structures and lmDrovements 446.893
47 352 Wells 3.753.701
48 352.1 Storaoe Leaseholds and Riohts 75.620
49 352.2 Reservoirs 60.450
50 352.3 Non+ecoverable Natural Gas 1.593.436
51 353 Lines 310.523
52 354 Comoressor Station EouiDment 3.457.717
53 355 Other Eouioment 88.429
54 356 PurificationEouiDment 't20.o24
55 357 Other Eouioment 481 .193
56 358 Asset Retirement Costs for Underoround Storaoe Plant
57 I-OTAL Underqround Storaoe Plant 10.526.767
58 )ther Storaoe Plant
59 360 Land and Land Riohts
60 361 Structures and lmDrovements
61 362 Gas Holders
62 363 Purification Eouioment
63 363.1 Liquefaction Eouioment
54 363.2 Vaporizinq Equipment
65 363.3 Compressor Equipment
66 363.4 Measurinq and Requlatinq Equipment
67 363.5 Other Equipmenl
68 363.6 Asset Retirement Costs for Other Storaqe Planl
69 IOTAL Other Storaoe Plant (Total of lines 58 throuoh 68)
70 Base Load Liouefied Nalural Gas Terminalino and Processino Plent
71 364.1 Land and Land Riohls
72 364.2 Structures and lmorovements
73 364.3 LNG Processino Terminal Eouioment
74 364.4 LNG TransDortation Eouiomeni
75 364.5 Measurino and Reoulatino Eouioment
76 364.6 ComoressorSlation Eouioment
77 364.7 Communications Eouiomenl
78 364.8 Other Eouioment
79 364.9 Asset Retirement Cosls for Base Load Liouefied Natural Gas
80
IOTAL Base Load Liquefied Natural Gas Terminaling and Processing Plant (total lines 71
lhrnrroh 7Ql
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.lD.206-207
Name o, Respondent
Avlsta Corporatlon
This Report is:
F-l en originat
I n Resubmission
Date of Report
mm/ddlyyyy
04-1$2015
Year / Period of Report
End of 2014 I Q4
GAS PLANT !il SERVICE - IDAHO (Account 101. 102. 103 anr l06l (Contlnuedl
Retirements
{d}
Adjustments
(e)
Transfers
(f)
Balance
End of Year
(o)
Line
No.
34
35
36
37
38
39
40
41
e320'118.679 44
(3401 17.442 45
29,788 476.68'l 46
(33.6121 3.720.089 47
(1.4501 74.170 48
1.1591 59.291 49
(30.5501 1.562.886 50
(5.9541 304.569 5'l
(28.3581 3.429.359 52
36.660 125.089 53
e.301 117.723 54
25.816 507.009 55
56
(13.7801 10.512.987 57
5g
60
61
62
63
64
65
66
67
68
69
71
72
73
74
75
76
77
78
79
80
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 6T405)G.tD.206-207
Name of Respondent
Avista Corporatlon
This Report is:
lFl nn originat
I n Resubmission
Date of Report
mm/dd/yyyy
04-15-2015
Year / Period of Report
End of 2014 I Q4
GAS PLANT lN SERVICE . IDAHO (Account 1O1. 1O2. {03 and 106l {Gontinued}
Line
No.Account
(a)
Balance
Beginning of Year
(b)
Additions
(c)
8'l TOTAL Natural Gas Storaoe and Processino Plant (Total of lines 57. 69 and 80)10.526.767
82 TRANSMISSION PLANT
83 365.1 Land and Land Riohts
84 365.2 Riohts-of-Wav
85 366 Structures and lmorovements
86 367 Mains
87 368 Comoressor Station Eouioment
88 369 Measurino and Reoulatino Station Eouioment
89 370 CommunicationEouioment
90 37'l Other EouiDmenl
91 372 Asset Reliremenl Costs for Transmission Planl
92 IOTAL Transmission Plant {Total lines 83 throuoh 91}
93 )ISTRIBUTION PLANT
94 374 Land and Land Riohts 87.805
95 375 Structures and lmDrovements 274.584 41.350
96 376 Mains 86.202.520 2.942.186
97 377 Comoressor Station Eouiomenl
98 a7A Mcaclrinn and Flenrrlalina Slalinn Fr rl-Genaral 2.1',t2.377 26.O29
99 ?7q Maacr rrinn and Penr rlalina Slalinn Fr 1t-(:ilv Grla 4.160.O2 't72.986
100 380 Services 51.583.60 s.028.566
101 381 Melers 22.097.60 176.670
102 382 Meler lnstallaiions
103 383 House Reoulators
104 384 House Reoulator lnstallations
105 385 lndustrial Measurino and Reoulatino Slation Eouioment 632.986 83.656
106 386 Other Prooertv on Customers' Premises
107 387 Other Eouioment
108 388 Asset Retirement Costs for Distribution Plant
109 IOTAL Distribution Plant (Tolal lines 94 throuoh 108)167.151.495 8.471.443
110 SENERAL PLANT
11 389 Land and Land Riohts
112 390 Structures and lmDrovements
113 391 Office Furniture and Eouioment 93.814 45.384
114 392 Transoortation EouiDment 1.968.747 368.934
115 393 Stores Eouioment
116 394 Tools. ShoD. and Garaoe Eouioment 790.928 244.517
17 395 LaboratorvEouioment 53.487 72,130
1a 396 Power ODerated EouiDment I .185.533 (138.720)
19 397 Communicalion Forrinmenl 678.832 71,968
120 398 MiscellaneousEouiDment
121 Subtoiel (Total of I ines 1 1 1 lhroudh 120)4.771.341 664,213
22 399 Other Tanqible Property
23 399.1 Asset Retirement Costs for General Plant
24 IOTAL General Plant (Total of lines 12 1 . '122 and 1231 4.77',\.341 664,213
25 IOTAL (Accounts 10'l and 106)183.059.540 I 272 1flrl
26 3as Plant Purchased (See lnstruction 8)
27 lLess) Gas Plant Sold (See lnskuction 8)
2A lxperimental Gas Plant Unclassified
29 I-OTAL Gas Plant in Service (Total of lines '125 throuqh 128)183.059,540 I 272 1tl0
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.tD.208-209
Name of Respondent
Avlsta Corporation
This Report is:
IFI nn orisinat
I a Resubmission
Date of Report
mm/dd/yyw
M,-15-20',15
Year / Period of Report
End of 2014 I Q4
GAs PLANT lN SERVIGE - IDAHO lAccount 1lJ1- 1o2- 1(,3 and t(}6l (Contanuedl
Retirements
(d)
Adjustments
(e)
Transfers
(0
Balance
End of Year
(s)
Line
No.
(13.780',10.512.987 81
83u
85
86
87
88
8S
s0
91
92
87.805 g4
978 (6.558'308.398 95
172.676 15.225 88.987.255 96
97
8.223 22,066 2.152.249 98
10.861 4.322_',t46 99
52.655 56.559.512 100
1 555.O12 22.829.284 101
102
103
104
716.612 105
106
107
108
245.393 30.7U 555 012 175.953.291 109
't12
2.160 (10.8851 126,153 113
66.785 17.674 2.288.570 111
115
31.356 (69.2501 934,839 116
14.O12 n2.421 99,184 117
11.851 1.058.604 118
1128 5.587 755.259 119
120
15.441 (57.444'.5.262.669 121
122
123
15.441 (57.444 5,262.669 124
423.673 (51.6071 555.O',t2 't92.411.372 125
126
127
12A
423.673 (51.6071 555.012 192 111 372 129
IOAHO STATE NATURAL GAS ANNUAL REPORT (IC 61"405)G.tD.20E-209
This Page Intentionally Left Blank
Name of Respondent
Avlsta Corporatlon
This Report is:
lFl an orisinat
E n Resubmission
Date of Reporl
nm/ddrlyyy
M-15-2015
Year / Period of Report
Endof 2OUlA4
GAS ST(IRED. IDAHO lccount8 117.1. 117.2. 1 17.3. 1 64.1. 164.2. and 1 64.31
!nstructlons
1. lf during the year adjustments were made to the stored gas inventory reported in columns (d), (0, (S), and (h) (such as to conect 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 acc,ount 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, 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).
Line
No.
Description
(a)
(Account
117.1)
(h)
(Account
117.2)
(c)
Noncunent
(Account
117.3)
(d)
(Account
117.4)
(e)
Current
(Account
164.1)
(fl
LNG
(Account
1U.2)
(o)
LNG
(Account
164.3)
ft)
Total
lil
1 Jalance at beoinnino of vear 1.772_474 5.978.646 7 751 124
2 3as delivered to storaoe I 1 _550.553 1 550 553
3 Gas withdrawn from sioraoe 6.',t17.',t53 6 117 153
4 Other debits and credits
5 Balance at end of vear 1.772.474 11 4120,46 13.184.524
6 Drh 317.648 2 930 671 3.248.322
7 Amount per Dth 5.58 389 4.06
(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.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 614{'5)G.tD.220
Name of Respondent
Avista Corporatlon
This Report is:
E An originat
I n Resubmission
Date of Report
mm/ddSyyy
04-15-2015
Year / Period of Report
End of 2014 / Q4
GAS OPERATING REVEIIUES. IDAHO
lnstructions
1. Report below natural gas operating revenues attributable to the slate of ldaho for each prescribed account total in accordance with jurisdictional
Results of Operations.
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). lnclude in columns (f) and (g) revenues forAccounts 480-495.
Line
No.Account
(a)
Revenues for
Transition Costs
and Take-or-Pav
Revenues for
GRI and ACA
Current Year
(b)
Previous Yeal
(c)
Cunent Year
(d)
Previous Year
(e)
1 lRO RFsidenlial Salaq
2 181 Commercial and lndustrial Seles
3 182 Other Sales to Public Authorities
4 183 Sales for Resale (1)
5 484 lnterdeDartmental Sales
6 485 lntracomDanv Transfers
7 487 Forfeited Discounts
8 488 Miscellaneous Service RevenuesI489.1 Revenues from Transportation of Gas for Others
throuqh Gatherinq Facilities
10 489.2 Revenues from Transportation of Gas for Others
throuqh Transmission Facilities
1',!489.3 Revenues from Transportation of Gas for Others
throuqh Distribution Facilities
12 489.4 Revenues from Storino Gas of Others
13 490 Sales of Products Extracted from Natural Gas
11 491 Revenues from Natural Gas Processed by Others
15 492 lncidental Gasoline and Oil Sales
16 493 Rentftom Gas Prooertv
17 494 lnterdeoartmental Rents
't8 495 OtherGas Revenues (1)
19 Subtotal
20 496 (Less) Provision for Rate Refunds
21 TOTAL
G.tD.300-301IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)
Name of Respondent
Avlsta Corporatlon
This Report is:
lFl nn orisinat
I e Resubmission
Date of Report
mm/dd/yyyy
04-1 5-201 5
Year / Period of Report
Endo 2014IQ4
IiAli (JPEI{Allt(i RIII,EIUEli - lIfAHtI
lnstructlons
4. lf increases or decreases from previous year are not derived from previously reported figures, explain any inconsistencies in a footnote in the
available spac€ at the bottom of this page or attached in a separate schedule.
5. See pages 108 in the FERC Form 2, lmportant Changes During the QuarlerA/ear, for infonnation 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.
Other
Revenues
Total
Operating
Flavanr req
Dekatherm of
Natural Gas Line
No.
Cunent Year
(0
Previous Year
(o)
Cunent Year
(h)
Previous Year
(D
Cunent Year
(i)
Previous Year
(k)
46.555.303 r{4.865.073 46.555.303 44.865.073 4.625.851 4.731.316 1
24.508.666 22.774.U7 24.508.666 22.774.847 2.990.189 2.947.351 2
3
37.(N5.393 33.112.850 37.045.393 33.112.850 9.162.131 8.975.001 4
38.760 34,130 38.760 34,130 4.629 4.412 5
6
7
10.120 12.102 10.120 12.102 8
I
10
472,720 439,240 472,720 439,240 4,078,737 4,269,837 11
12
13
14
15
52 52 t6
17
1.671.914 2.O28.318 1.671.914 2.028.318 18
110.302.876 103.266.612 110.302.876 103.266.612 't9
t221.O98 G41.8/9',ea.o98'l (441.8491 20
1't 0.081.778 '1o2.824.763 110.081.778 102.824.763 21
(1) Sales for Resale and Defened Exchange dollars are allocated based on the Washington / ldaho monthly commodity allocations used in
Results of Operations.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 6I{05)G.1D.300-301
Name of Respondent
Avlsta Corporatlon
This Report is:
lxl en originat
I n Resubmission
Date of Report
mm/dd/ywy
04-15-2015
Year / Period of Report
End of 2014 I Q4
GAS OPERATION AT{D iIAINTENANCE EXPENSES - IDAHO
lnstructlons
1. For eaci prescribed accrunl below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
ldaho.
2. lf the amount for previous year is not derived from previously reported figures, explain in a footnote.
Linr
No.Accounl
(a)
Amount for
Cunent Year
(b)
Amount for
Previous Year
(c)
1 1. PRODUCTIONEXPENSES
2
3 Manufae.tured Gas Prodlrajion (Suhmii Sllnnlamentel Slelemenll
4 B. Natural Gas Production
5 81. Natural Gas Production and Gatherino
6 Operation
7 750 ODeration SuDervision and Enoineerino
I 751 Production MaDs and Records
I 752 Gas Well Exoenses
10 753 Field Lines Exoenses
11 754 Field Compressor Station Exoenses
12 755 Field Compressor Station Fuel and Power
13 756 Field Measurino and Reoulatino Station ExDenses
14 757 PurificationExpenses
15 758 Gas Well Rovallies
t6 759 Other Exoenses
17 760 Rents
1E IOTAL ODeration (Total of lines 7 throuoh '17)
19 Maintenance
20 761 Maintenance Supervision and Enoineerinq
21 762 Maintenance of Structures and lmprovements
22 763 Maintenance of Producino Gas Wells
23 764 Maintenance of Field Lines
24 765 Maintenance of Field Comoressor Station Eouioment
25 766 Maintenance of Field Measurino and Reoulatino Slation Eouioment
26 767 Maintenance of Purification EouiDment
27 76E Maintenance of Drillino and cleanino EouiDment
28 769 Maintenance of Other Eouioment
29 TOTAL Maintenance (Total of lines 20 throuoh 281
30 rOTAL Natural Gas Produclion and Gatherino {Total of lines 18 and 29)
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 6I{05)
Name of Respondent
Avlsta Gorporation
This Report is:
lxl nn originat
I n Resubmission
Date of Report
mn/dd/yw
o4-15-2015
Year / Period of Report
End of 2014 I Q4
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
lnstructlonB
1. For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
ldaho.
2. lf the amount for previous year is not derived from previously reported figures, explain in a footnote.
Line
No.Account
(a)
Amount for
Cunent Year
(b)
Amount for
Previous Year
(c)
3t 12. Products Extraction
32 )oeration
33 770 ODeration Suoervision and Enoineerino
34 771 Ooeration Labor
35 772 GasShrinkaoe
36 773 Fuel
37 774 Panter
38 775 Materials
39 776 Operation Supplies and Expenses
40 777 Gas Processed by Others
41 778 Rovallies on Products Extracted
42 779 Markeiino Exoenses
43 780 Products Purchased for Resale
44 781 Variation in Products lnventorv
45 782 (Less) Extracted Products Used bv the Utilitv-Credit
46 783 Rents
47 TOTAL ODeration (Total of line 33 throuoh 46)
48 Vlaintenance
49 784 Maintenance Supervision and Enqineering
50 785 Maintenance of Structures and lmprovements
51 786 Mainienance of Exlraclion and Relinino EouiDment
52 787 Maintananna af Pina I inpq
53 788 Maintenance of Extracled Products Storaoe Eouioment
il 789 Maintenance of Comoressor EouiDment
55 790 Maintenance of Gas Measurino and Requlatinq Equipment
56 791 Maintenance of Other Eouipment
57 IOTAL Maintenance fiotal of lines 49 throuqh 56)
58 I'OTAL Products Extraction (Total of lines 47 and 571
IDAHO STATE NATURAL GAS ANNUAL REPORT (C 6t405)G.1D.318
Name of Respondenl
Avlsta Corporatlon
This Report is:
lFl nn orisinat
I n Resubmission
Date of Report
mm/dd/yyw
o4-15-2015
Year / Period of Report
End of 2014 I Q4
lnstructlons
1. For each pressibed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
ldaho.
2. lf the amount for previous year is not derived from previously reported figures, explain in a footnote.
Line
No.Account
(a)
Amount for
Cunent Year
(b)
Amount for
Previous Year
(c)
59 Exoloration and Develooment
60 Joeration
6'l 795 Delav Rentals
62 796 Nonoroductive Well Drillino
63 797 Abandoned Leases
64 798 Other Exoloration
65 IOTAL Exoloration and Develooment (Total of lines 61 throuoh 64)
66 f. OtherGas Suoolv Exoenses
67 Joeration
68 800 Natural Gas Well Head Purchases
69 800.1 Natural Gas Well Head Purchases. lnlracrmoanv Transfers
70 801 Natural Gas Field Line Purchases
71 802 Natural Gas Gasoline Plant Outlet Purchases
72 803 Natural Gas Transmission Line Purchases
73 8(X Natural Gas Citv Gate Purchases 79.162.447 68.230.361
74 804.1 Liouefied Nalural Gas Purchases
75 805 Other Gas Purchases
76 805.1 (Less) Purchased Gas Cosl Adiustments
77 I-OTAL Other Gas Suoolv Exoenses (Total of lines 68 throuoh 76)79.162.447 68.230.361
78 806 Exchanoe Gas
79 )urchased Gas Exoenses
80 807.1 Well Exoense-Purchased Gas
81 807.2 Ooeration of Purchased Gas Measurino Stalions
82 807.3 Maintenance of Purchased Gas Measurino Stations
83 807.4 Purchased Gas Calculations Exoenses
84 807.5 Other Purchased Gas ExDenses (5.244.2071 409.902
85 I-OTAL Purchased Gas ExDenses (Total of lines 80 throuoh 84)(5.284.207)409.902
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)
Name of Respondenl
Avista Corporation
This Report is:
lFl nn originat
! a Resubmission
Date of Report
mm/ddr!yyy
u-15-2015
Year / Period of Report
End of 2014 I Q4
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
lnstructlons
1. For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
ldaho.
2. lf the amount for previous year is not derived from previously reported ftgures, explain in a footnote.
Line
No.Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
86 808.1 Gas Withdrawn from Storaoe-Debit
87 808.2 (Less) Gas Delivered to Storaoe-Credil
88 809.1 \Mthdrawals of Liouelied Natural Gas for Proc€ssinq-Debil
89 809.2 (Less) Deliveries of Natural Gas for Processinq-Credit
90 3as Used in Utilitv Ooeralion-Credit
91 810 Gas Used for Comoressor Station Fuel-Credit
92 811 Gas Used for Products Extraction-Credit (361.288',(302.699)
93 812 Gas Used for Other Ulilitv ODerations-Credit
94 I-OTAL Gas Used in Utilitv Ooerations-Credit ffotal of lines 91 throuqh 93){361.288',(302.699)
95 813 Other Gas Suoolv Exoenses 349.436 390.020
96 I'OTAL Other Gas Suoolv Exoenses ffotal of lines 77 .78. 85.86 throuqh 89. 94. 95)73.866.828 68_727.584
97 I'OTAL Production Exoenses fiotal of lines 3. 30. 58. 65. and 96)73.866.828 68.727.5A4
98 2. NATURAL GAS STORAGE. TERMINALING AND PROCESSING EXPENSES
s9 \. Underoround Sloraoe Exoenses
100 Joeraiion
101 814 Ooeration Suoervision and Enoineerino 2.851 7,519
102 8'15 Mans and Records
'to3 816 Wells Exoenses
't04 817 Lines Ernense
105 818
106 819 ComDressor Slalion Fuel end Power
107 820 Measurino and Reoulatino Station Exoenses
l08 A'1 P r Fvna
10s 822 Exploration and Development
110 823 Gas Losses
824 Other Expenses 190.602 146 422
112 825 Storaqe Well Rovalties
113 826 Rents
114 fOTAL ODeration fiotal of lines 10'l throuqh 113)193.453 194.341
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 6{405)G.1D.320
Name of Respondent
Avlsta Corporation
This Report is:
lFl nn orisinat
E A Resubmission
Date of Report
mm/dd/yyw
o4-15-20',15
Year / Period of Report
End of 2014 I Q4
GAS OPERATION AND MAINTENANCE EXPENSES. IDAHO
lnstructlons
1. For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
ldaho.
2. lf the amount for previous year is not derived ftom previously reported figures, explain in a footnote.
Linr
No.Account
(a)
Amount for
Cunent Year
(b)
Amount for
Previous Year
(c)
115 \raintenance
116 830 Maintenance SuDervision and Enoineerino
117 831 Maintenance of Structures and lmDrovemenls
118 832 Maintenance of Reservoirs and Wells
119 833 Maintenance of Lines
124 834 Maintenance of Comoressor Station Eouioment
12',1 835 Maintenance of Measurino and Reoulalino Stalion Eouiomenl
122 836 Mainlenance of Purification Eouiomenl
123 837 Mainlenance of Other Eouioment 174,172 152.659
124 TOTAL Maintenance (Total of lines 116 throuoh 123)174.172 152.659
125 TOTAL Underoround Storaoe Exoenses (Total of lines 114 and 124\367.625 347.000
126 B. Other Storaoe Exoenses
127 Operation
128 840 Ooeration Suoervision and Enoineerino
129 U'l Ooeration Labor and Exoenses
130 842 Rents
131 842.'l Fuel
132 842.2 Power
133 842.3 Gas Losses
134 rOTAL Ooeration (Total of lines 128 throuoh 133)
135 Mainlenance
136 843.1 Maintenance Suoervision and Enoineerino
137 843.2 Maintenanc€ of Struclures
13 843.3 Maintenance of Gas Holders
139 843.4 Maintenance of Purification Eouioment
140 843.5 Maintenance of Liouefaction Eouiomenl
'141 843.6 Maintenance of Vaoorizino Eouioment
142 843.7 Maintenance of Comoressor Eouioment
143 E43.8 Maintenance of Measurino and Reoulatino Eouioment
111 843.9 Maintenance of Other Eouioment
115 IOTAL Maintenance (Total of lines 136 throuoh 144)
116 IOTAL Other Storaqe Exoenses (Total of lines 134 and '145')
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 6I{05)G.lD.s21
Name of Respondent
Avlsta Corporatlon
This Report is:
lFl nn orisinat
! I Resubmission
Date of Report
mm/dd/yyyy
04-1 5-201 5
Year / Period of Report
End of 2014 I Q4
GAS OPERATIOII AiID MAINTENANGE EXPENSES - IDAHO
lnstructlons
1. For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
ldaho.
2. lf the amount for previous year is not derived from previously reported figures, explain in a footnote.
Lin€
No.Account
(a)
Amount for
Cunent Year
(b)
Amount for
Previous Year
(c)
147 I N.ftrr.l Gre T and Proenssino FYnanses
148 )oeralion
149 844 'l Ooeration Suoeruision and Enoineerino
150 844.2 LNG Processinq Terminal Labor and Expenses
151 844.3 Liquefaction Processinq Labor and Expenses
't52 844.4 Liquefaclion Transportation Labor and Expenses
153 844.5 Measurino and Reoulatino Labor and Expenses
154 844.6 ComDressor Station Labor and Expenses
155 844.7 Communication Svstem Expenses
156 844.8 System Control and Load Dispatching
157 845.1 Fuel
158 845.2 Power
159 845.3 Rents
160 845.4 Demunaoe Charoes
161 845.5 (Less) Wharfaoe Receiots-Credit
162 845.6 Processino Liouefied or Vaoorized Gas bv Others
163 846.1 Gas Losses
164 846.2 Other Exoenses
165 IOTAL ODeration (Total of lines '149 throuoh 164)
166 Vlaintenance
167 847.1 Maintenance Suoervision and Enoineerino
168 847.2 Maintenance of Struc{ures and lmDrovements
169 847.3 Maintenance of LNG Processino Terminal EouiDment
170 847.4 Maintenance of LNG Transoortation EouiDment
171 847.5 Maintenance of Measurino and Reoulatino Eouioment
172 847.6 Maintenance of Comoressor Station EouiDment
173 847.7 Mainlenance of Communication Eouioment
174 847.8 Maintenance of Other Eouiomenl
175 IOTAL Maintenance (Total of lines 167 throuoh 1 74)
176 IOTAL Liouefied Nat Gas Terminalino and Proc Exo ffotal of lines '165 and 175)
177 IOTAL Natural Gas Storaoe fiotal of lines 125. 146. and 176)367.625 347.000
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.tD.322
Name of Respondent
Avlsta Corporatlon
This Report is:
[Fl en originat
I n Resubmission
Date of Report
mm/dd|yW
04-15-201s
Year / Period of Report
End of 20'14 I Q4
GAS OPERATIOI{ AND iIAINTENANCE EXPENSES - IDAI{O
lnstructlons
1 . For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
ldaho.
2. lf the amount for previous year is not derived from previously reported figures, explain in a footnote.
Line
No.Account
(a)
Amount for
Cunent Year
(b)
Amount for
Previous Yeal
(c)
178 3. TRANSMISSION EXPENSES
179 eration
180 850 Ooeration SuDervision and Enoineerino
181 851 Svstem Control and Load Disoatchino
182 852 Communication Svstem Exoenses
183 853 ComDressor Station Labor and Exoenses
1U 854 Gas for ComDressor Station Fuel
18s 855 Other Fuel and Power for Comoressor Stations
186 856 Mains Exoenses
187 857 Measurino and Reoulatino Station Exoenses
188 858 Transmission and ComDression of Gas bv Others
189 859 Other Exoenses
190 860 Rents
191 rOTAL Ooeration (Total of lines 180 throuoh 190)
192 Maintenance
193 861 Maintenance Suoervision and Enoineerino
194 862 Maintenance of Structures and lmorovements
195 863 Maintenance of Mains
't96 864 Maintenance of Comoressor Stalion Eouioment
197 865 Maintenance of Measurino and Reoulatino Slation Eouioment
198 866 Maintenance of Communication Eouioment
199 867 Maintenance of Other Eouioment
200 fOTAL Maintenance (Total of lines 193 throuoh 199)
201 TOTAL Transmission (Total of lines 191 and 200)
202 DISTRIBUTION EXPENSES
203 )peration
201 870 Ooeration Suoervision and Enoineerino 536.928 443.129
205 471 Dislribulion l oad Disnalchind
206 872 Comoressor Slation Labor and Fxoenses
207 873 Compressor Station Fuel and Power
G.1D.323IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405}
Name of Respondent
Avista Corporatlon
This Report is:
E-l nn originat
! n Resubmission
Date of Report
mm/dd/yyyy
o4-1 5-201 5
Year / Period of Report
End of 2014 I Q4
GAS OPERATION AND MAINTENANCE EXPENSES - IDAHO
lnstructions
1. For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state o,
ldaho.
2. lf the amount for previous year is not derived from previously reported figures, explain in a footnote.
Line
No.Account
(a)
Amount for
Cunent Year
(b)
Amount for
Previous Year
(c)
208 874 Mains and Services Exoenses 980.400 968,485
209 875 Measurino and Reoulatino Stalion Exoenses-General 30.667 62.164
2 0 R76 Maaerrrinn and Flaarrlalind Slalion Fvncnsec-lndrrslrial 1.671 e77l
2 1 877 Measurino and Reoulatino Stalion Exoenses-Citv Gas Check Slation v.224 103.210
2 878 Meter and House Reoulalor Exoenses 515.652 132.228
2 2 879 Customerlnslallations Exoenses 641_658 723,059
2 4 880 Other Exoenses 736.5()4 679.760
2 I 881 Renls 11 997 9.807
2 6 IOTAL Ooeration fTotal of lines 2(X throuoh 215)3.546 706 3.121.565
2 7 Maintenance
2 8 885 Maintenance SuDervision and Engineerinq 73.398 81.276
219 886 Mainlenance of Structures and lmprovements
220 887 Maintenance of Mains 619.644 461.&46
221 888 Maintenance of Comoressor Station Equipmenl
222 889 Maintenance of Measurino and Requlatinq Station Equipment-General 63.244 93.529
223 890 Maintenance of Measurino and Reoulatino Station Equioment-lndustrial 1 19.073 120.706
224 891 Maintenance of Meas. and Res. Station Equipment-City Gate Check Station 30.706 45.729
225 892 Maintenance of Services 826.277 406.407
226 893 Maintenance of Meters and House Requlators 713.858 499.297
227 894 Maintenance of Other Eouiomenl 63.840 57.272
228 IOTAL Maintenance {Total of lines 218 throuqh 227)2.510.040 't.765.862
229 IOTAL Distribution Exoenses ffotal of lines 216 and 2281 6.056.746 4.887.427
230 CUSTOMER ACCOUNTS EXPENSES
231 Jperation
232 901 Suoervision 68.081 74.233
233 902 Meter Readino Exoenses 187.1',t1 260.595
2U 903 Customer Records and Collec{ion Exoenses 1.663.379 1.799.747
|DAHO STATE NATURAL GAS ANNUAL REPORT (tC 61.405)G.tD.324
Name of Respondenl
Avlsta Corporatlon
This Report is:
E-l en originat
I n Resubmission
Date of Report
mm/ddfryyy
M-15-2015
Year / Period of Report
End of 2014 I Q4
GAS OPERATION AND MAII{TENANCE EXPENSES. IDAHO
lnstructlons
I . For each prescribed account below, report operation and maintenance expenses as allocated by the Results of Operations model to the state of
ldaho.
2. lf the amount for previous year is not derived from previously reported figures, explain in a footnote.
Line
No.Account
(a)
Amount for
Cunent Year
(b)
Amount for
Previous Year
(c)
235 904 UncollectibleAccounts 578.567 531.806
234 905 Miscellaneous Customer Accounts Expenses 41.460 49.U2
237 IOTAL Customer Accounts Exoenses fiotal of lines 232 throuoh 236)2.538.598 2.716.263
234 CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
239 Jperation
240 907 Supervision
241 908 CustomerAssistance Expenses 't23.267 141.462
242 909 lnformational and lnstructional Exoenses 188.335 228.835
243 910 Miscellaneous Customer Service and lnformational Exoenses 37.444 42.156
244 IOTAL Customer Service and lnformational Exoenses (Total of lines 240 throuoh 243)349.046 412.453
2{-5 SALES EXPENSES
246 )peration
247 911 Supervision
244 912 Demonstratinq and Sellino Exoenses 't.552
249 913 Advertisino ExDenses
250 916 Miscellaneous Sales Exoenses
25'l I'OTAL Sales ExDenses fiotal of lines 247 throuoh 250)1.552
252 ]. ADMINISTRATIVE AND GENERAL EXPENSES
25.3 Jperation
254 920 Administrative and General Salaries 1.943.470 1.795.985
255 921 Office Supplies and Exoenses 346.677 291.985
256 922 (Less) Administrative Exoenses Transfened-Credit {6.0621 G.812\
257 923 Outside Services Emoloved 940.638 763.226
258 924 Propertv lnsurance 98.065 92.O87
259 925 lniuries and Damades 252.164 382.500
260 926 Employee Pensions and Benefits 145.999 67,665
261 927 Franchise Reouirements
262 928 ReoulatorvCommission ExDenses 291.244 323,885
263 929 (Less'l Duolicate Charoes-Credil
264 930.1 General Adverlisino Exoenses 296,832 259.465
265 930.2 Miscellaneous General Exoenses
266 931 Rents 63.S11 58.056
267 |OTAL Ooeration (Total of lines 254 ihrouoh 266)4 372 934 4.O30.O12
268 tilainlenance
269 932 Maintenance of General Plant 716,514 621,592
270 IOTAL Administrative and General Expenses fiotal of lines 267 and 2691 5.089.452 4.651.634
271 I-OTAL Gas O&M Expenses (Total of lines 97 , 177 ,2O1 , 229,237 ,244, 251 , 2701 EE,268,295 81 ,743,913
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.tD.325
Name of Respondent
Avlsta Corporatlon
This Report is:
ll-l nn orisinat
f] e Resubmission
Date of Report
mm/dd/yyyy
04-15-2015
Year / Period of Report
End of 2014 I Q4
GAS TRANSTUIISSION MAINS . IDAHO
lnetr
1.
2.
uctlons
Reporl below the requested details of transmission mains in system operated by respondent at end of year in the state of ldaho.
Report separately any lines held under a title olher than full ownership. Designate such lines with an asterisk and in a footnote (in the available
space at the botlom 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 iointly owned.
Linc
No.
Kind of
Material
(a)
Diameter of
Pipe
in lnches
(b)
Total Length in Use
Beginning of Year
in Feet
(c)
Laid During Year
in Feet
/.1\
Taken Up
or Abandoned
During Year
in Feet
Total Length
in Use
End of Year
in Feet
/A
1
2
3
4
5
6
7
I
I
't0
't1
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:
ln 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)).
IDAHO STATE NATURAL GAS ANNUAL REPORT (C 6I{05)G.tD.s'r4
Name of Respondent
Avlsta Corporatlon
This Report is:
E An originat
I n Resubmission
Date of Report
nm/dd/yyyy
04-15-2015
Year / Period of Report
End of 2014 I Q4
GAS DISTRIBUTION TAINS . IDAHO
lnstructions
1 . Report below the requested details of distribution mains in system operated by respondent at end of year in the state of ldaho.
2. 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.
Linr
No.
Kind of
Material
(a)
Diameter of
Pipe
in lnches
(b)
Total Length in Use
Beginning of Year
in Feet
lcl
Laid During Year
in Feet
adt
Taken Up
or Abandoned
During Year
in Feet
Iel
Total Length
in Use
End of Year
in Feet
16
1 Steel WraDDed Less than 2"1.762.992 898 1.763.890
2 Steel Wraooed 2" lo 4"622,354 845 621.509
3 Steel Wraooed 4" to 8"400.382 1.194 411,576
4 Steel WraDDed 8" to 12"4.541 7.656 12.197
5 Steel Wraooed Over'12"
6
7
8 Plastic Less than 2"5.496.533 36.537 5.533.070IPlaslic2" lo 4"1.444.714 29.'t98 1.473.912
10 Plastic 4" to 8"614.',170 3,854 618.024
11 Plastic 8" to 12"
12 Plastic Oveill2"
13
14
15
16
17
18
19
20
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 6I{15}G_tD_5144
Name of Respondent
Avlsta Corporation
This Report is:
E Anoriginat
t] A Resubmission
Date of Report
mnndd/yyW
04-15-2015
Year / Period of Report
End of 20'14 I Q4
TERVICE PIPES. GAS. IDAHO
lnstructions
1. Report below the requested details of line service pipe in possession of the respondent at the end of the year in the state of ldaho
Lin€
No.
Type of
Material
(a)
Diameter of
Pipe
in lnches
(b)
Number of
Service Pipes
Beginning of Year
(c)
Added
During Year
/cl
Retired
During Year
I.ll
Number of
Service Pipes
End of Year
Average
Length
in Feet
/n
Steel Wraooed 1" or Less 11.440 42 11.398 rl )
2 Steel Wraooed 1" to 2"194 I 193 (1)
3 Steel Wraooed 2" to 4"7 7
4 Steel Wraooed 4" to 8"1 1
5 Steel Wraooed Ovar 8"('t )
6 Steel Wraooed [Jnknown 394 6 388 t't )
7I Plastic 1" or Less 58,012 1 131 59 143 1
9 Plastic 1" to 2"271 6 265 (1)
10 Plastic 2" !rja"10 11 1
11 Plaetic 4" to 8"2 2 1
12 Plastic Over 8"1
13 Plastic Unknown 2,593 244 2 345 1
14
15 Other lJnknown 52 54 106 h)
16
17
18
19
20
21
22
23
24
25
26
27
2A
29
30
31
32
33
34
35
36
37
38
39
40
('1) lnformation not available.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 614{15)G.tD.5148
Name of Respondent
Avista Corporatlon
This Report is:
lfl nn orisinat
E A Resubmission
Date of Report
mm/dd/yyyy
M-l5-2015
Year / Period of Report
End of 2014 I Q4
REGULATORS.GAS.IDAHO
lnstructlons
1. Report belowthe requested details ofgas regulators in possession ofthe respondent at the end ofthe year in the state of ldaho.
Lin(
No.
Size
(a)
Type
(b)
Make
(cl
Capacity
(d)
ln Service
Beginning of Year
/el
Added During
Year
,fl
Retired During
Year
ln Plant
End of Year
(hl
1
2 No Data available
3
4
5
6
7
I
o
10
12
13
14
15
16
't7
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40 Total
IDAHO STATE NATURAL GAS ANNUAL REPORT (lC 6T405)G.tD.514C
Name of Respondent
Avlsta Corporatlon
This Report is:
E An originat
E A Resubmission
Date of Reporl
mm/ddrlyyy
04-1 5-201 5
Year / Period of Report
End of 2014 I Q4
CUSTOiIER iIETERS - GAS - IDAHO
lnstructlonB
1 . Report below the requested details of gas customer meters in possession of the respondent at the end of the year in the state of ldaho
Linc
No.
Size
(eI
Type
Ib)
Make
lcl
Capacity
(d)
ln Service
Beginning of Year
lc)
Added During
Year
/fl
Retired During
Year
/d\
ln Plant
End of Year
thl
1 Ail AI Ail AI 77.488 1.189 78.677
2
3
4
5
6
7
8I
10
1',!
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
2A
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.
IDAHO STATE NATURAL GAS ANNUAL REPORT (lC 61405)G.tD.514D
Name of Respondent
Avlsta Corporatlon
This Report is:
IFI an orisinat
! a Resubmission
Date of Report
mm/dd/yyyy
04-15-2015
Year / Period of Report
End of 2014 lA4
G:AS A':(:r!IINT - llATIIPAI G:AS - INA}Irl
lnstructlons
1. The purpose of this schedule is to account for the guantity of natural gas received and delivered by the respondent for service in the state of ldaho.
2. Natural gas means eilher nalural gas unmixed or any mixture of natural and manufactured gas.
3. Enter in column (c) the year{o{ate Dth as reported in the schedules indicated for the items of receipts and deliveries.
4. lndicate 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 speciry the line on which such quantities are listed.
5. lf the respondenl operates two or more systems which are not interconnected, submit separate pages for this purpose.
6. lndicate 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
pipeline transporled 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
interstate market or that were not transported through any interstate portion of the reporting pipeline.
7. lndicate in a footnote the specific gas purchase expense account(s) and related to which the aggregate volumes report on line 3 relate.' 8. lndicate in a foolnote (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 yeat, (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 transporl in a future reporting year, and (3) contract
storage quantities.
9. 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 nec€ssary to the footnotes.
Line
No.Account
(a)
Refer to
Form 2
Page
(b'l
Amount of Dth
Year to Date
(c)
Amount of Dth
Current 3 Months Ended
Quailedy Only
(d)
1 Name of Svstem
2 GAS RECEIVED
3 Gas Purchases (Accounts 800-805)18.342.756
4 Gas of Others Received for Gatherinq (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 4.O78.737
7 Gas of Others Received for Contract Storaoe (Account 489.4)307
8 Exchanqed Gas Received from Others (Account 806)328IGas Received as lmbalances (Account 806)328 34,378
10 Receiots of Resoondent's Gas Transoorted bv Others (Account 858)332
11 Other Gas Withdrawn from Storaoe {Exolain'l {885_3't 3l
12 Gas Received from ShiDoers as Comoressor Station Fuel
13 Gas Received from ShiDDers as Lost and Unaccounted For
14 Other Receipts (Specify) (footnote details)
l5 Total Receiots ffotal of lines 3 throuoh 14)21.570.558
16 GAS DELIVERED
't7 Gas Sales (Accounts 480-4M)16.843.787
18 Deliveries of Gas Gathered for Others (Account 489.1 303
19 Deliveries of Gas Transoorted for Others (489.2'l 305
20 Deliveries of Gas Distributed for Others (Account 489.3)301 4.O78.737
21 Deliveries of Contract Storaoe Gas (Account 489.4)307
22 Exchanqe Gas Delivered io Others (Account 806)328
23 Gas Delivered as lmbalances (Account 858)328
24 Deliveries of Gas to Others for Transportation (Account 858)332
25 Other Gas Delivered to Storaoe (Exolain) (1)
26 Gas Used for Comoressor Station Fuel 509 648.034
27 Other Deliveries (Soecifv) (footnote details)
28 Total Deliveries (Total of lines 17 throuqh 27)21.570.558
29 GAS UNACCOUNTED FOR
30 Production System Losses
31 Gathering System Losses
32 fransmission System Losses
33 Distribution Svstem Losses
34 Storaoe Svstem Losses
35 Other Losses (SDecify) (footnote details)
36 fotal Gas Unaccounted For (Total of lines 30 throuoh 35)
37 Total Deliveries and Gas Unaccounted For (Total of lines 28 and 36)21.570,558
(1)Represents net gas withdrawals and injections.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 6I{05)