2015Annual Report.pdf

THIS FILING IS
Item 1: [] An lnitial (Original) OR n Resubmission No. _
Submission
frVU' 6ro,^2 Approved
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FERC FINANCIAL REPORT
FERC FORM No.2: Annual Report of
Major Natural Gas Companies and
Supplemental Form 3-Q: Quarterly
Financial Report
OMB No.1902-0028
(Expires 0913012017)
Form 3-Q Approved
OMB No.1902-0205
(Expires 1113012016)
These reports are mandatory underthe Natural Gas Act, Sections 10(a), and 16 and 18
CFR Parts 260.1 and 260.300. Failure lo report may result in criminal fines, civil
penalties, and other sanctions as provided by law. The Federal Energy Regulatory
Commission does noi consider these reports to be of a confidential nature.
Exact Legal Name of Respondent (Company)
Avista Corporation
Year/Period of Report
End of 20151Q4
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 2015/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)
1411 East Mission Avenue, Spokane, WA 99207
05 Name of Contact Person
Ryan Krasselt
06 Title of Contact Person
VP, Controller, Prin. Acctg Officer
07 Address of Contact Person (Street, City, State, Zip Code)
141 1 East Mission Avenue, Spokane, WA 99207
08 Telephone of Contact Person, lncluding Area Code
509495-2273
This Report ls:
(1) [Rn Originat(2) f]A Resubmission
'10 Date of Report
(Mo, Da, Yr)
o4115t2016
ANNUAL CORPORATE OFFICER CERTIFICATION
The undersigned officer certifies that:
I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct
statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all
material respects to the Uniform System of Accounts.
11 Name
Ryan Krasselt
12 Title
VP, Controller, Prin. Acctg Officer
13 Sionature I I'*r"r''*,..r",, \("* L.Vr..*,r^*14 Date Signed
04115t2016
Title 18, U.S.C. 1001 , nldkes it a crime-for any person knowingly and willingly to make to any Agency or Department of the United States any
false, fictitious or fraudulent statements as to any matter within its jurisdiction.
FERC FORM NO.2/3Q (02-04)Page 1
Name of Respondent
Avista Corporation
This Reoort ls:(1) lxJAn original(2) l--lA Resubmission
Date of Report(Mo, Da, Yr)
o411512016
YeailPenoo oI Kepor
End of 2015/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.
Title of Schedule
(a)
Reference
Page No.
(b)
Date Revised
(c)
Remarks
(d)
GENERAL CORPORATE INFORMATION AND FINANCIAL STATEMENTS
1 General lnformation 10'l
2 Control Over Respondent 102
3 Corporations Controlled by Respondent 103
4 Security Holders and Voting Powers 107
5 lmportant Changes During the Year 108
6 Comparative Balance Sheet 110-113
7 Statemenl of lncome for the Year 114-116
8 Statement of Accumulated Comprehensive lncome and Hedging Activities 117
o Statement of Retained Earnings for the Year 'I 't8-119
10 Statements of Cash Flows 120-121
11 Notes to Financial Statements 122
BALANCE SHEET SUPPORTING SCHEDULES (Assets and Other Debits)
12 Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortizalion, and Depletion 200-201
13 Gas Plant in Service 204-209
14 Gas Property and Capacity Leased from Others 212
15 Gas Property and Capacity Leased to Others 213
16 Gas Plant Held for Future Use z',t4
17 Construclion Work in Progress-Gas 216
18 Non-Traditional Rale Treatment Afforded New Projects 2't7
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 Poperty Losses 230
26 Unrecovered Plant and Regulatory Study Costs 230
27 Other Regulatory Assets 232
28 Miscellaneous Delened Debits 233
29 Accumulated Defened lnmme Taxes 234-235
BALANCE SHEET SUPP0RTING SCHEDULES (Liabilities and Other Credib)
30 Capital Stock 250-251
31 Capital Stock Subscribed, Capital Stock Liability for Conversion, Premium on Capital Stock, and
lnstallments Received on Capital Stock 252
32 Other Paid-in Capital 253
33 Discount on Capital Stock 254
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 Reoort ls:(1) []Rn orisinat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
o4115t2016
Year/Period of Repon
End of 2015/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 Reacquired Debt 260
39 Reconciliation of Reported Net lncome with Taxable lncome for Federal lncome Taxes 261
40 Taxes Accrued, Prepaid, and Charged During Year 262-263
A'I Miscellaneous Cunent and Accrued Liabilities 268
42 Other Deferred Credits 269
43 Accumulated Deferred lnmme Taxes-Other Property 274-275
44 Accumulated Delened lnmme Taxes-Other 276-277
45 Other Regulatory Liabilities 278
INCOME ACCOUNT SUPPORTING SCHEDULES
46 Monthly Quantity & Revenue Data by Rate Schedule 299
47 Gas Operating Revenues 300-301
48 Revenues from Transportation of Gas of Others Through Gathering Facilities 302-303
49 Revenues from Transportation of Gas of Others Through Transmission Facilities 304-305
50 Revenues from Storage Gas of Others 306-307
51 Other Gas Revenues 308
52 Discounted Rate Services and Negotiated Rate Services 313
53 Gas Operation and Maintenance Expenses 3't7-325
54 Exchange and lmbalance Transactions 328
55 Gas Used in Utility Operations 331
56 Transmission and Compression of Gas by Others 332
57 Olher Gas Supply Expenses 334
58 Miscellaneous General Expenses-Gas 335
59 Depreciation, Depletion, and Amortization of Gas Plant 336-338
60 Particulars Concerning Certain lncome Deduction and lnterest Charges Accounts 340
COMMON SECTION
61 Regulatory Commission Expenses 350-351
62 Employee Pensions and Benefits (Account 926)352
63 Distribution of Salaries and Wages 354-355
64 Charges for Outside Professional and Other Consultative Services 357
65 Transactions with Associated (Atfiliated) Companies 358
GAS PLANT STATISTICAL DATA
66 Compressor Stations 508-509
67 Gas Storage Projects 5'1 2-513
68 Transmission Lines 514
69 Transmission System Peak Deliveries 518
70 Auxiliary Peaking Facilities 519
71 Gas Account-Natural Gas 520
72 Shipper Supplied Gas for the Cunent Quarter 521
73 System Map 522
74 Footnote Reference 551
75 Footnole Texl 552
76 Stockholde/s Reports (check appropriate box)
n
tr
Four copies will be submitted
No annual report to stockholders is prepared
FERC FORM NO. 2 (REV 12-07)Page 3
Name of Respondent
Avista Corporation
This Reoort ls:(1) []An orisinat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Repor
End of 2015/Q4
General lnformation
where any other corporate books of account are kept, if ditferent from that where the general corporate books are kept.
Ryan Krasselt, Vice President and Controller, Principal Accounting Officer
1411 E Mission Avenue
Spokane, WA 99207
2. Provide the name of the Stale under the laws of which respondent is inmrpomted and date of incorporation. lf incorporated under a special law, give reference to such law. lf nol
incorporated, state that fact and give the type ol organization and the date organized.
State of Washington, lncorporated March 15, 1889
the authority by which tre receivership or trusteeship was crealed, and (d) date when possession by receiver or trustee ceased.
Not Applicable
4. State lhe classes of utility and other services fumished 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 accountant to audit your fnancial slalemenh an accountant who is not the principal aocountant for your previous yea/s certified financial
statements?
(1 ) ! 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 oI Kesponoent
Avista Corporation
This Reoort ls:(1) [I]An original(2\ [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Corporations Controlled by Respondent
1, Report below the names of all corporations, business trusls, 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 jolntly 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. Direct 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 )Parent to the Company's 100 Nof usec/
2 subsidiaries
3 Avista Development Maintains investment portfolio incl Real
Estate.
100 No, r/sed
4 Avista Energy lnactive 100 ldol used
5 PenUer Corporation Parent of Bay Area Mfg and Penture
Venture Hldngs
100 A/ol used
6 Bay Area Manufacturing Holding co of AM&D dba MetalFX 100 /Voi used
7 Advanced Manufacturing & Developmenl Custom mfg of electronic enclosures 83 /Vof used
I dba MetalFX Nol usecl
I Qpgkale- Eqb€y, LLc D Owns an elec, capacity contrt. See
Footnote.
100 IVol r.rsed
10 Avista Capital ll D Affliliated business trust issue pref trusl
sec
100 tVof used
11 Avista Northwest Resources, LLC Owns an interest in a venlure fund
investment
100 tVol used
12 Steam Plant Square, LLC Commercial office and Retail leasing 85 IVoI used
13 Courtyard Oflice Center, LLC Commercial oflice and retail leasing 100 tvol r/sed
14 Steam Plant Brew Pub, LLC Restaurant Operations 85 lVot usec/
15
16 Alaska Energy and Resources Company D Parent company of Alaska operations 100 /Vol [,sed
17 Alaska Electric Light and Power Company Utiltiy operations based in the city and
borough
'100 Noi used
18 Of Juneau, AK
19 AJT Mining Properties, lnc lnactive mining company holding
certain properties
100 A/ot usec/
20 Snettisham Electric Company Holds certain rights to purchase the
Snettisham
100 l\lol r/sed
21 Hydroelectric project in the city &
borough of
22 Juneau, AK
23 Salix, lnc Liquefied Natural Gas Operations.
See Footnote
100 Nol used
24
25
FERC FORM NO. 2 (12-96)Page 103
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2A15lQ4
FOOTNOTE DATA
'$cneandFage:1og Line No.:g columnn
-_____)
Sookane Enerov was dissolved as of Julv. 23 2015. Notice of cancellation was sent to The State of Delaware.
a subsidiary of Avista Capital, launched in 2014 to explore markets that could be served with liquefied natural gas (LNG),
primarily in western North America.
FERC FORM NO. 2 (1 552.1
Name oI Kesponclent
Avista Corporation
This Reoort ls:(1) finn originat(2) nA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Repor
End of 2015/Q4
Security Holders and Voting Powers
1 . Give the names and addresses of the 10 security holders of the respondent who, at the date of the latest closing of the stock book
or compilation of list of stockholders of the respondent, prior to the end of the year, had the highest voting powers in the respondent,
and state the number of votes that each could cast on that date if a meeting were held. 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:
11t.1pt2015,
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 prory.
Total: 54563176
By Proxy: 54563176
Give the date and place of
such meeting:
May 7 ,2015
Spokane, Washington
Line
No.
Name (Title) and Address of
Security Holder
(a)
VOTING SECURITIES
4. Number of votes as of (date): 1111912015
Total Votes
(b)
Common Stock
(c)
Preferred Stock
/d)
Other
/e)
E TOTAL votes of all voting securities 62,358,017 62,358,017
b TOTAL number of security holders 8,81!8,819
7 TOTAL votes ol security holders listed below 1,031,78t 1 ,031,786
I Computershare Trust Company NA as escrow agent for:
I George Barclay Corbus, Arvada, CO 343,16t 343,168
10 William A Corbus, Juneau, AK 300,00(300,00c
11 Malcolm A Menzies, Juneau, AK 1 13,301 113,301
12 Gary Ely, Liberty Lake, WA 56,984 56,984
13 Mark T Thies, Spokane, WA 40,s94 40,59r
14 Marian Durkin, Spokane, WA 39,621 39,621
'15 Niels F Larsen & Wilhelmine J Larsen Jt Ten, Juneau, AK 39,31i 39,312
to Jane N MacKinnon, Juneau, AK 37,347 37,341
17 Dennis P Vermillion, Spokane, WA 29,381 29,381
18
19
20
FERC FORM NO. 2 (12-96)Page 107
Name of Respondent
Avista Corporation
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
20151Q4
FOOTNOTE DATA
107 Line No.:1 Column: 1
To pay the 1211512015 dividend.
FERC FORM NO. 2 (1 552.1
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original
(2\ _A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Report
2015tQ4
Important Changes During 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. lmportant leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendered: Give effective
dates, lengths of terms, names of parties, rents, and other conditions. State name of Commission authorizing lease and give reference to such
authorization.
5. 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 othenrise, giving location and approximate total gas volumes available, period of contracts, and other parties to any such
arrangements, etc.
6. Obligations incurred or assumed by respondent as guarantor for the performance by another of any agreement or obligation, including
ordinary commercial paper maturing on demand or not later than one year after date of issue: State on behalf of whom the obligation was
assumed and amount of the obligation. Cite Commission authorization if any was required.
7. Changes in articles of incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments.
8. State the estimated annual effect and nature of any important wage scale changes during the year.
9. State briefly the status of any materially important legal proceedings pending at the end of the year, and the results of any such proceedings
inated 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 descrlbe the significant events or transactions causing the proprietary capital ratio to be less than 30 percent, and the extent to which the
respondent has amounts loaned or money advanced to its parent, subsidiary, or affiliated companies through a cash management program(s).
, please describe plans, if any to regain at least a 30 percent proprietary ratio.
1. None
2. None
3. None
4. None
5. None
6. Avista Corp. has a committed line of credit with various financial institutions in the total amount of $400.0 million that
expires in April 2019.
Balances outstanding (including letters of credit) under the Company's revolving committed lines of credit were as
follows as of December 3 1, 2015 and December 31,2014 (dollars in thousands):
December 3 l, December 3 1,
2015 20t4
Balance outstanding at end of period
Letters of credit outstanding at end of period
$105,000 $105,000$44,595 $32,579
In December 2075, Avista Corp. issued $100.0 million of first mortgage bonds to five institutional investors in a private
placement transaction. The first mortgage bonds bear an interest rate of 4.37 percent and maturein2045. 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
FERC FORM NO.2 {12 1 08.1
Name of Respondent
Avista Corporation
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
lmportant Changes During the Quarter/Year
by regulatory commissions as follows:WUTC (Docket No. U-111176 Order 02) IPUC (Case No. AVU-U-l l-01 Order
No. 3233 8) and the OPUC (Docket UF 4294 Order No. I 5-305).
7. None
8. Average annual wage increases were 2.4oh for non-exempt employees effective February 23,2015. Average annual
wage increases were 3 .0%o for exempt employees effective February 23, 2015 . Officers received average increases of
3 .3%o effective February 23,2015 . Certain bargaining unit employees received increases of 3 .0% effective March 26,
201s.
9. Reference is made to Note 16 of the Notes to Financial Statements.
10. None
I l.
ll/ashington General Rate Cases
2014 General Rate Cases
In November 2014, the UTC approved an all-party settlement agreement related to Avista Corp.'s electric and natural gas
general rate cases filed in February 2014 and new rates became effective on January 1,2015. The settlement was
designed 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 was designed to increase annual
natural gas base revenues by $8.5 million, or 5.6 percent. The settlement agreement also included the implementation of
decoupling mechanisms for electric and natural gas and a related after-the-fact earnings test, which are discussed in
further detail in Note 17 of the Notes to Financial Statements.
Specific capital structure ratios and the cost of capital components were not agreed to in the settlement agreement. The
revenue increases in the settlement were not tied to the 7 .32 percent rate of return on rate base (ROR) used in conjunction
with the after-the fact earnings test. 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 thatthe 7.32
percent ROR will be used to calculate the AFUDC and other purposes.
2015 General Rate Cases
ln January 2016, the Company received an order (Order 05) that concluded its electric and natural gas general rate cases
that were originally filed with the UTC in February 2015. New electric and natural gas rates were effective on January
11,2016.
The UTC approved rates designed to provid e a 1 .6 percent, or $8.1 million decrease in electric base revenue, and a 7 .4
percent, or $ 10.8 million increase in natural gas base revenue. The UTC also approved an ROR on rate base of 7 .29
percent, with a common equity ratio of 48.5 percent and a 9.5 percent return on equity (ROE).
Throughout the rate case process, certain circumstances and costs changed, causing Avista Corp. to revise our overall
proposed rate requests downward, especially for our electric operations. The Company's need for electric rate relief was
reduced primarily due to the following:
o a decrease in power supply costs of approximately $24.0 million caused by the continuing decline in the price of
natural gas used to run the Company's natural gas-fired generation and lower contract costs associated with a
new PPA from Chelan PUD,
FERC FORM NO.2 108.2
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
lmportant Chanqes Durinq the Quarter/Year
. updated information related to federal tax adjustments and state allocations,
o the delay in the expected completion date of the Nine Mile hydroelectric generation project upgrade from late
2015 to late 2016, and
. a delay of the start date to begin amortization of existing electric meters from 2016 to a future year, associated
with Avista Corp.'s proposed AMI project.
The natural gas revenue increase approved by the UTC is related to the Company's ownership and operating costs to run
the natural gas business. Changes in the commodity costs of natural gas for natural gas customers are reflected in Avista
Corp.'s annual PGA, which is generally effective November lst each year. On November 1,2015 natural gas customers'
bills were reduced approximately l5 percent related to the decline in the market price of naturalgas.
ln responsive testirnony filed by the UTC Staff in July 2015 in the Company's electric and natural gas generalrate cases,
they recommended a disallowance of $12.7 million (Washington's share) of the costs associated with the replacement of
the Company's customer information and work management systems (Project Compass) primarily related to the delay in
the completion of the project. In the January 6,2016 UTC order, they approved the full recovery of Washington's portion
of Project Compass costs.
WC Issues Order Denying Industrial Customers of Northwest Utilities / Public Counsel Joint Motionfor
Clarification, WC Staff Motion to Reconsider ond UTC Staff Motion to Reopen Record
On February 19,2016, the UTC issued an order (Order 06) denying the Motions summarized below and affirmed
their original January 2016 order of an $8.1 million decrease in electric base revenue, thus finalizing Avista
Corp's 201 5 electric and natural gas general rate cases.
On January 19,2016, the lndustrial Customers of Northwest Utilities (ICNU) and the Public Counsel Unit of the
Washington State Office of the Attorney General (PC) filed a Joint Motion for Clarification with the UTC. In its
Motion for Clarification, ICNU and PC requested that the UTC clarifu the calculation of the electric attrition
adjustment and the end-result revenue decrease of $8.1 million. ICNU and PC provided their own calculations in
their Motion, and suggested that the revenue decrease should have been $19.8 million based on their reading of
the UTC's Order.
On January 19,2016, the UTC Staff, which is a separate party in the general rate case proceedings from the UTC
Advisory Staff that supports the Commissioners, filed a Motion to Reconsider with the UTC. ln its Motion to
Reconsider, the Staffprovided calculations and explanations that suggested that the electric revenue decrease
should have been a revenue decrease of $27 .4 million instead of $8.1 million, based on its reading of the UTC's
Order. Further, on February 4,2016, the UTC Staff filed a Motion to Reopen Record for the Limited Purpose of
Receiving into Evidence Instruction on Use and Application of Staff s Attrition Model, and sought to supplement
the record "to incorporate all aspects of the Company' Power Cost Update." Within this Motion, UTC Staff
updated its suggested electric revenue decrease to $19.6 million.
None of the parties in their Motions raised issues with the UTC's decision on the natural gas revenue increase of
FERC FORM NO,2 (12 108.3
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15120',16
Year/Period of Report
20151Q4
lmoortant Chanqes Durinq the Quarter/Year
$10.8 million.
PC Petitionfor Judicial Review
On March I 8, 20 I 6, PC filed in Thurston County Superior Court a Petition for Judicial Review of the UTC's
January 2016 Order 05 and February 2016 Order 06. Order 05 approved new electric and natural gas rates that
became effective on January 11,2016.
ln its March 2016 Petition for Judicial Review, PC seeks judicial review of five aspects of Order 05 and Order
06, alleging, among other things, that (l) the UTC exceeded its statutory authority by setting rates for Avista
Corp.'s natural gas and electric services based on amounts for utility plant and facilities that are not "used and
useful" in providing utility service to customers; (2) the UTC acted arbitrarily and capriciously in granting an
attrition adjustment for Avista Corp.'s electric operations after finding that the Company did not meet the newly
articulated standard regarding attrition adjustments; (3) the UTC ened in applying the "end results test" to set
rates for Avista Corp.'s electric operations that are not supported by the record; (4) the UTC did not correct its
calculation of Avista Corp.'s electric rates after significant errors were brought to its aftention; and (5) the UTC's
calculation of Avista Corp.'s electric rates lacks substantial evidence.
PC is requesting that the Court (1) vacate or set aside portions of the UTC's orders; (2) identifr the errors
contained in the UTC's orders; (3) find that the rates approved in Order 05 and reaffirmed in Order 06 are
unlawful and not fair, just and reasonable; (4) remand the matter to the UTC for further proceedings consistent
with these rulings, including a determination of Avista Corp.'s revenue requirement for electric and natural gas
services; and (5) find the customers are entitled to a refund.
The new rates established by Order 05 will continue in effect while the Petition for Judicial Review is being
considered. The Company believes the UTC's Order 05 and Order 06 finalizing the electric and natural gas
generalrate cases provide a reasonable end result for all parties. If the outcome of the judicial review were to
result in an electric.rate reduction greater than the decrease ordered by the UTC, it may not provide Avista Corp.
with a reasonable opportunity to earn the rate of return authorized by the UTC.
2016 General Rate Cases
On February 19,2016, Avista Corp. filed electric and natural gas general rates cases with the UTC. The Company's
proposal includes an I 8-month rate plan, with new rates taking effect on January l, 2017 and January I , 20 I 8. Under this
plan, the Company would not file a future rate case for new rates to be effective prior to July 1, 2018.
The 2017 increase, if approved, would increase overall base electric rates 7.8 percent (designed to increase annual
electric revenues by $38.6 million) and overallbase natural gas rates 5.0 percent (designed to increase annual natural gas
revenues by $4.a million).
In addition, the Company has requested a second step increase effective January 1,2018, which would increase overall
base electric rates by 3.9 percent (designed to increase annual electric revenues by $10.3 million) and overall base natural
FERC FORM NO.2 (12 108.4
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
lmportant Chanqes Durinq the Quarterf/ear
gas rates by 1.8 percent (designed to increase annual natural gas revenues by $0.9 million). Avista Corp. has proposed to
offset the electric increase, for the period January through June 2018, with available ERM dollars. As a result, customers
would not see an electric general rate case bill increase in 20 I 8 prior to July I , 201 8.
The requests are bas&d on a proposed ROR of 7 .64 percent with a common equity ratio of 48.5 percent and. a 9 .9 percent
ROE.
The UTC has up to I 1 months to review the filings and issue a decision.
Idaho General Rate Cases
2014 Rate Plan Extension
Avista Corp. did not file new general rate cases in Idaho in2014; instead, the Company developed an extension to the
2013 and 2014 rate plan and reached a settlement agreement with all interested parties.
ln September 2014, the IPUC approved the settlement, which reflected agreement among all interested parties, for a
one-year extension to the Company's current rate plan, which was set to expire on December 31,2014. Under the
approved extension, base retail rates remained unchanged through December 31, 2015.
The settlement provided an estimated $3.7 million increase in pre-tax income by reducing planned expenses in 2015 for
the Company's Idaho operations.
2015 General Rate Cases
In December 2015, the IPUC approved a settlement agreement between Avista Corp. and all interested parties related to
its electric and naturirl gas general rate cases, which were originally filed with the IPUC on June l, 2015. New rates were
effective on January 1,2016.
The settlement agreement is designed to increase annual electric base revenues by $1.7 million or 0.7 percent and annual
natural gas base revenues by $2.5 million or 3.5 percent. The settlement is based on a ROR of 7 .42 percent with a
common equity ratio of 50 percent and a 9.5 percent ROE.
The settlement agreement also reflects the following:
o the discontinuation of the after-the-fact earnings test (provision for earnings sharing) that was originally
agreed to as part ofthe settlement ofour 2012 electric and natural gas general rate cases, and
r the implementation of electric and natural gas Fixed Cost Adjustment mechanisms, as discussed in Note 17
of the Notes to Financial Statements.
Oregon General Rate Cases
2014 General Rate Case
In January 2015, Avista Corp. filed an all-party settlement agreement with the OPUC related to our natural gas general
rate case, which was originally filed in September 2014. On February 23,2015, the OPUC issued an order rejecting the
all-party settlement agreement. The OPUC expressed concems related to, among other things, various rate design issues.
In March 2015, Avista Corp. filed an amended all-party settlement agreement with the OPUC which addressed the
FERC FORM NO.2 (12.108.5
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
lmportant Changes Durins the Quarter/Year
OPUC's concerns regarding the initial settlement agreement. The amended settlement agreement was designed to increase
base natural gas revenues by $5.3 million. Included in this base rate increase is $0.3 million in base revenues that we are
already receiving from customers through a separate rate adjustment. Therefore, the net increase in base revenues was
$5.0 million, or 4.9 percent on a billed basis. The parties requested that new retail rates become effective on April 16,
20 1 5 . On April 9, 20 I 5, the OPUC issued an Order approving the amended settlement agreement as filed.
This settlement agreement provided for an overall authorized ROR of 7.516 percent with a common equity ratio of 51
percent and a 9.5 percent ROE.
2015 General Rate Case
On February 29,2016, the OPUC issued an order concluding the Company's natural gas general rate case, which was
originally filed with OPUC in May 2015. The OPUC order approved rates designed to increase overall billed natural gas
rates by 4.9 percent (designed to increase annual natural gas revenues by $4.5 million). New rates went into effect on
March 1,2016. The final OPUC order incorporated the two partial settlement agreements described in further detail
below.
The OPUC order provides for an overall authorized ROR of 7.458 percent with a common equity ratio of 50 percent and
a 9.4 percent ROE.
In November 2015, Avista Corp. and all parties to the natural gas general rate case reached agreement on certain issues,
and a partial settlement agreement was filed with the OPUC on November 6,2015. The partial settlement agreement
reduced the requested natural gas revenue increase from $8.6 million to $6,7 million or 6.3 percent (on a billed basis).
The partial settlement resolved a number of issues including the calculation of state income taxes for rate-making
purposes, wages and salaries, the revenue forecast for the rate period, and working capital.
In addition, the November partial settlement agreement included a provision for the implementation of a decoupling
mechanism, similar to the Washington and Idaho mechanisms described in Note l7 of the Notes to Financial Statements.
The Decoupling Mechanism has an initialterm concluding in September 2019.
On January 19,2016, the Company entered into an additional all-party partial settlement to further reduce the revenue
increase request to $6.1 million or 5.7 percent (on a billed basis), related to updated information related to deferred taxes
and its effect on rate base. These agreements did not resolve the remaining issues, such as, the appropriate ROE and
capital structure, the appropriate level of additions to rate base, and medical and pension expenses.
In addition, the OPUC staff filed testimony which included a recommendation to disallow $1.2 million (Oregon's share)
of Project Compass costs primarily related to the delay in the full completion of the project. In the February 29,2016
OPUC order, the OPUC approved the full recovery of Oregon's portion of Project Compass costs, as well as the capital
investment included in the Company's case. The reductions to the Company's revenue requirement related to employee
incentives, pension expense, and the reduction in the Company's proposed cost of capital.
12. Effective February 2015, 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.
Effective October 1,2015, Christy Burmeister-Smith, former Vice President, Controller and Principal Accounting Officer
retired. Ryan Krasselt, formerly the Director of Risk Management was selected to fill Christy's role upon her retirement.
FERC FORM NO.2 (12-96)108.6
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
lmportant Chanqes Durinq the Quarter/Year
Ryan has previously held various other finance and accounting management and staff positions with the Company for 14
years.
On September 8, 2015, Ed Schlect, was appointed Vice President and Chief Strategy Officer. Ed was the former
Executive Vice President of Corporate Development at Ecova, Avista Corp.'s former unregulated subsidiary. Roger
Woodworth, previously Vice President and Chief Strategy Officer was promoted to President of Avista Development, an
Avista Corp. subsidiary, in support of economic development within the Company's utility seryice areas.
On December 1, 2015, Don Kopcrynski, Vice President, Energy Delivery and Customer Service retired. Heather
Rosentrater, formerly Avista's Director of Electrical Engineering and Grid Modernization, was selected to fill Don's role
upon his retirement. Heather has previously held various other management and staff positions with the Company for 19
years.
13. Proprietary capital is not less than 30 percent.
FERC FORM NO. 2 (1 108.7
This Page fntentionally Left Blank
Name of Respondent
Avista Corporation
This RerJ(1) 12!(2\ r
ort ls:
An Original
A Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Comparative Balance Sheet (Assets and Other Debits)
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year End of
QuarterfYear Balance
(c)
Prior Year
End Balance
12131
(d)
1 UTILITY PLANT
2 Utility Plant (101-106, 114)200-201 4,923,194,978 4.5',t3,148,224
3 Construction Work in Progress (107)200-201 190,108,665 223,330,993
4 TOTAL Utility Plant (Iotal of lines 2 and 3)200-201 5,1 13,303,643 4,736,479,217
5 (Less) Accum. Provision for Depr., Amort., Depl. ('108, 111, 115)1,680,907,938 1,573,767 ,832
o Net Utility Plant (Total of line 4 less 5)3,432,395,705 3,162,71 1,385
7 Nuclear Fuel (120.1 thru 120.4, and 120.6)0 0
8 (Less) Accum. Provision for Amort., of Nuclear Fuel Assemblies (120.5)0 0
9 Nuclear Fuel (Total of line 7 less 8)0 0
'10 Net Utility Plant (Total of lines 6 and 9)3,432,395,705 3,162,7'r,385
11 Utility Plant Adjustments (116)122 0 0
12 Gas Stored-Base Gas (117.1)220 6,992,076 6,992,076
'13 System Balancing Gas (117.2)220 0 0
14 Gas Stored in Reservoirs and Pipelines-Noncurrent (117.3)220 0 0
15 Gas Owed to System Gas (117.4)220 0 0
16 OTHER PROPERTY AND INVESTMENTS
17 Nonutility Property (12'l)2,740,379 5,288,635
18 (Less) Accum. Provision for Depreciation and Amortization (122)201 ,768 194,91 1
19 lnvestments in Associated Companies (123)222-223 1 1,547,000 12,047,000
20 lnvestments in Subsidiary Companies (123. 1)224-225 157,5't 5,280 148.255,851
21 (For Cost of Account'123.1 See Footnote Page224,line 40)
22 Noncurrent Portion of Allowances 0 0
23 Other lnvestments (1 24)222-223 23.760.324 11.525,386
24 Sinking Funds (125)0 0
25 Depreciation Fund (1 26)0 0
lo Amortization Fund - Federal (127)0 0
27 Other Special Funds (128)20,755,670 11,488,865
28 Long-Term Portion of Derivative Assets (175)22,687 0
29 Long-Term Portion of Derivative Assets - Hedges (176)0 0
30 TOTAL Other Property and lnvestments (Total of lines 17-20,22-29)216,139,572 188,4 1 0,826
31 CURRENT AND ACCRUED ASSETS
32 Cash (131)2,O74,149 't,535,172
33 Special Deposits (1 32-1 34)'t4,430,708 6,832,649
34 Working Funds (135)691,896 97',t,206
35 Temporary Cash lnvestments (136)222-223 204,231 15,508,864
36 Notes Receivable (141)0 0
37 Customer Accounts Receivable (1 42)160,488,098 163,095,696
38 Other Accounts Recelvable (143)5.500,743 5,091,552
39 (Less) Accum. Provision for Uncollectible Accounts - Credit (144)4,469,344 4.828.572
40 Notes Receivable from Associated Companies ('t45)0 0
41 Accounts Receivable from Associated Companies (146)469,096 401 ,126
42 Fuel Stock (151)3,293,585 4,1'.16,727
43 Fuel Stock Expenses Undistributed (152)0 0
FERC FORM NO. 2 (REV 06-04)Page 110
Name of Respondent
Avista Corporation
This Rer(1) uL(2) T
rort ls:
An Original
A Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2016
Year/Period of Report
End of 2015/Q4
Comparative Balance Sheet (Assets and Other Debits)(continued)
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year End of
Quarter/Year Balance
(c)
Prior Year
End Balance
12131
(d)
44 Residuals (Elec) and Extracted Products (Gas) (153)0 0
45 Plant Materials and Operating Supplies (154)33.931,771 29,419,472
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
51 Stores Expense Undistributed (1 63)0 0
52 Gas Stored Underground-Current (164.1 )220 12,774,487 28,731,498
53 Liquefied Natural Gas Stored and Held for Processing (164.2 thru 164.3)220 0 0
54 Prepayments (,l65)230 10,580,934 '13,368,084
55 Advances for Gas ( 1 66 thru 1 67)0 0
56 lnterest and Dividends Receivable (171)39,738 31,080
57 Rents Receivable (172)1,749,949 1,740,695
58 Accrued Utility Revenues (173)0 0
59 Miscellaneous Current and Accrued Assets (174)527,051 614,449
60 Derivative lnstrument Assets (1 75)706,117 1.524.582
61 (Less) Long-Term Portion of Derivative lnstrument Assets (175)22,687 0
62 Derivative Instrument Assets - Hedges (175)0 460,316
63 (Less) Long-Term Portion of Derivative lnstrument Assests - Hedges (176)0 0
64 TOTAL Current and Accrued Assets (Total of lines 32 thru 63)242.970.522 268,614,596
65 DEFERRED DEBITS
66 Unamortized Debt Expense (181)11,527,001 12,476,292
67 Extraordinary Property Losses (1 82. 1 )230 0 0
68 Unrecovered Plant and Regulatory Study Costs (182.2)230 0 0
69 Other Regulatory Assets (182.3)232 573,031,070 576,247,558
70 Preliminary Survey and lnvestigation Charges (Electric)(183)467,080 165,866
71 Preliminary Survey and lnvestigation Charges (GasX183.1 and 183.2)0 0
72 Clearing Accounts (1 84)527 28,145
73 Temporary Facilities (1 85)0 0
74 Miscellaneous Deferred Debits (1 86)233 26.759,597 '11,803,983
75 Deferred Losses from Disposition of Utility Plant (187)0 0
76 Research, Development, and Demonstration Expend. (188)0 0
77 Unamortized Loss on Reacquired Debt (189)15.520.432 17,356,781
78 Accumulated Deferred lncome Taxes (190)234-235 1 36,036,1 1 9 123.261 ,474
79 Unrecovered Purchased Gas Costs (191)( 17,880,236)( 3,921,214)
80 TOTAL Deferred Debits (Total of lines 66 thru 79)745,461,590 737,418,885
81 TOTAL Assets and Other Debits (Total of lines 10-1 5,30,64,and 80)4,643,959,465 4,364,147,768
FERC FORM NO. 2 (REV 06-04)Page 111
Name of Respondent
Avista Corporation
This Rer(1) 1-I-(2) T
,ort Is:
lnn originat
lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2016
Year/Period of Report
End of 2015/Q4
Comparative Balance Sheet (Liabilities and Other Credits)
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year
End of
Quarter/Year
Balance
Prior Year
End Balance
12t31
(d)
1 PROPRIETARY CAPITAL
2 Common Stock lssued (201)250-251 984,603,843 984,400,740
3 Preferred Stock lssued (204)250-251 0 0
4 Capital Stock Subscribed (202, 2O5)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 (208-211)253 ( 9,506,476)( 9,520,161)
I 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 ( 2s,238,213)( 25,079,123)
11 Retained Earnings (21 5, 21 5.1, 216)118-119 536,821,476 507,257,161
12 Unappropriated Undistributed Subsidiary Earnings (21 6. 1 )118-119 ( 5,881 ,61e)( 15,658,553)
13 (Less) Reacquired Capital Stock (217)250-251 0 0
14 Accumulated Other Comprehensive lncome (219)117 ( 6,649,771)( 7,887,881)
15 TOTAL Proprietary Capital (Total of lines 2 thru 14)1,528,625,666 1,483,670,429
16 LONG TERM DEBT
17 Bonds (221 )256-257 1,536,700,000 1,435,700,000
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
21 Unamortized Premium on Long-Term Debt (225)258-259 177,666 '186,550
22 (Less) Unamortized Discount on Long-Term Debt-Dr (226)258-259 1 ,134,563 1,s08,604
23 (Less) Current Portion of Long-Term Debt 0 0
24 TOTAL Long-Term Debt (Total of lines 17 thru 23)1 .503.590,103 1.403.424.946
25 OTHER NONCURRENT LIABILITIES
26 Obligations U nder Capital Leases-Noncu rrent (227\3,274,583 0
27 Accumulated Provision for Property lnsurance (228.1)0 0
28 Accumulated Provision for lnjuries and Damages (228.2)239,910 240,000
29 Accumulated Provision for Pensions and Benefits (228.3)201,453,549 189,489,100
30 Accumulated Miscellaneous Operating Provisions (228.4)0 0
31 Accumulated Provision for Rate Refunds (229)11,476,706 5,855,845
FERC FORM NO. 2 (REV 05-04)Page 112
Name of Respondenl
Avista Corporation
This Rer(1) 12!(2) l--
rort ls:
An Original
A Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Comparative Balance Sheet (Liabilities and Other Credits)(continued)
Line
No.
Title of Account
(a)
Reference
Page Number
(b)
Current Year
End of
Quarter/Year
Balance
Prior Year
End Balance
12t31
(d)
32 Long-Term Portion of Derivative lnstrument Liabilities 52.248,445 22,093,1 66
33 Long-Term Portion of Derivative lnstrument Liabilities - Hedges 0 40,857,456
34 Asset Retirement Obligations (230)15,996,704 3,028.39't
35 TOTAL Other Noncurrent Liabilities (Total of lines 26 thru 34)284,689,897 261,563,958
36 CURRENT AND ACCRUED LIABILITIES
37 Current Portion of Long-Term Debt 0 0
38 Notes Payable (231)105,000,000 105,000,000
39 Accounts Payable (232)109,244.954 111,077,010
40 Notes Payable to Associated Companies (233)22,177,680 9,934,843
41 Accounts Payable to Associated Companies (234)18,798 714,039
42 Customer Deposits (235)3,273,927 4,977,259
43 Taxes Accrued (236)262-263 7,1 86,818 ( 10,725,297)
44 lnterest Accrued (237)14,179,517 13,595,667
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)1,759,040 50,226
49 Miscellaneous Current and Accrued Liabilities (242)268 57,577,117 57,483,998
50 Obligations Under Capital Leases-Current (243)87'1,667 4,193,852
51 Derivative lnstrument Liabilities (244)85,797,553 40,'t38,121
52 (Less) Long-Term Portion of Derivative lnstrument Liabilities 52,248,445 22,093,166
53 Derivative lnstrument Liabilities - Hedges (245)0 48,202,046
54 (Less) Long-Term Portion of Derivative lnstrument Liabilities - Hedges 0 40,857,456
55 TOTAL Current and Accrued Liabilities (Total of lines 37 thru 54)3s4,838,626 321,691,142
56 DEFERRED CREDITS
57 Customer Advances for Construction (252)2,161,687 1,864,508
58 Accumulated Deferred lnvestment Tax Credits (255)1 2.639,187 12,157,507
59 Deferred Gains from Disposition of Utility Plant (256)0 0
60 Other Deferred Credits (253)269 39,790,303 21,269,740
51 Other Regulatory Liabilities (254)278 40,976,484 48,834,355
62 Unamortized Gain on Reacquired Debt (257)260 1,966,507 2,096,044
63 Accumulated Deferred lncome Taxes - Accelerated Amortization (281)0 0
64 Accumulated Deferred lncome Taxes - Other Property (282)646,870,366 582,721,352
65 Accumulated Deferred lncome Taxes - Other (283)227,810,639 224,853,787
66 TOTAL Deferred Credits (Total of lines 57 thru 65)972,215,173 893,797,293
67 TOTAL Liabilities and Other Credits (Total of lines 15,24,35,55,and 66)4,643,959,465 4,364,147,768
FERC FORM NO. 2 (REV 06-04)Page 'l 13
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2016
Year/Period of Report
End of 2015/Q4
Statement of lncome
Quarterly
1. Enter in column (d) the balance for the reporting quarter and in column (e) the balance for the same three month period for the prior year.
cther utility function for the current year quarter.
llher 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 (f)
5- Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased to Others, in another utility columnin a similar manner to a utility department.
Spread the amount(s) over lines 2 thru 26 as appropriate. lnclude these amounts in columns (c) and (d) totals.
7. Report amounts in account 414, Other Utility Operating lncome, in the same manner as accounts 412 and 413 above.
B. Report data for lines 8, 10 and 1 1 for Natural Gas companies using accounts 404.1 , 404.2, 404.3, 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 concerning unsettled rate proceedings where a contingency exists such that refunds of a material amount may need to be made to the utilitys
lustomers or which may resull 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
'espect to power or gas purchases.
eceived or costs incurred for power or gas purches, and a summary of the adjustments made to balance sheet, income, and expense accounts.
12. lt any notes appearing in the report to stokholders are applicable to the Statement of lncome, such notes may be included at page 122.
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 effect of such changes.
14. Explain in a footnote if the previous yea/s/quarter's figures are different from that reported in prior reports.
Title of Account
Line (a)
No.
Reference
Page
Number
(b)
Total
Currenl Year lo
Date Balance
for Ouarter/Year
(c)
Total
Prior Year lo Date
Balance
lor Quarterffear
(d)
Cunent Three
Months Ended
Quarterly Only
No Fourth Ouarter
(e)
Prior Three
Months Ended
Quarterly Only
llo Fourth Ouarter
(0
1 JNL]TY OPERATING INCOME
2 3as operating Revenues (400)30G301 1,530,543,739 1,572,976,14 0
3 )perating Expenses
4 Operation kpenses (401)317-325 980,245,U 1,0y,794,124 0 0
5 Maintenance Expenses (402)317-325 64,022,751 65,573,481 0 0
6 Depreciation Expense (403)33G338 122.488.70t 112,562,200 U 0
7 Depreciation Expense for Asset Relirement Costs (403.1 )33e$8 0 0
8 Amortization and Depletion of Utility Plant (404405)336-338 21,5M,04 16,874,247 n
I Amortization of Utility Plant Acu. Adjustment (406)33&338 99,04 99,047
10 Amo(. of Prop. Losses, Unrecovered Plant and Reg. Study Costs (407.1)0
11 Amorlization of Conversion Expenses (407.2)0 0
12 Regulatory Debits (407.3)1,619,42 1,871,414 0
13 (Less) Regulaiory Credits (407.4)12,818,90r 10,536,841 0
14 Taxes Other than lncome Taxes (408.1)262-263 9s,109,791 93.076.918 0
15 lnmme Taxes-Federal (,109. 1)262-263 5,601,40 ( 55,133,870)0
16 lncome Taxes-Other (409. 1)262-263 91 9,1 4l (1,858,807)0
17 Provision of Defened lncome Taxes (410.1)2*235 65,371,80r 135,547,906 0
18 (Less) Provision for Defened lncome Taxes-Credit (41 L1)2*235 2,423,02,4,060,583 0
19 lnvestment Tax Credil Adjuslment-Net (411.4)48r,68(2n,524\0
20 (Less) Gains from Disposition ot Utility Plant (41 1.6)0 0
21 Losses from Disposition of Utility Plant (411.7)0 0
22 (Less) Gains from Dispsition of Allowances (411.8)0 0
23 Losses from Disposition of Allot ances (411.9)0 0
24 Accretion Expense (411,10)U 0
25 TOTAL Utility Operating Expenses (Total of lines 4 thru 24)1342.2il.m 1,388,579,712 0
26 Net Utility Operating lncome (Total of lines 2 less 25) (Carry forward to page 1 16,
ne27\1ffi,282,44"184,396,429 0
FERC FORM NO. 2 (REV 06-04)Page 114
Name of Respondent
Avista Corporation
This Reoort ls:(1) IXJAn Original(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
Statement of lncome
Line
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)
(i)
Other Utility
Current
Year to Date
(in dollars)
(k)
Other Utility
Previous
Year to Date
(in dollars)
(t)
2 '1,006,140,061 1,015,103,873 524,403,678 557,872,268 0 0
4 567,238,063 584,239,618 413,007,383 450,554,506 0 0
5 s0,'r48,482 51,160,378 13,874,274 14,413,'103 0 0
6 95,895,1 30 89,097,411 26,593,579 23,464,789 0 0
7 0 0 0 0 0 0
8 16,519,997 13,008,487 5,024,007 3,865,760 U 0
9 99,047 99,047 0 0 0 0
10 0 0 0 U 0 0
11 0 0 n 0 0 0
12 2,650,525 1,535,950 1,031,098)335,464 0 0
13 12,146,367 10,1 08,656 672,542 428,185 0 0
14 72,133,173 69,580,534 22,976,62s 23,496,384 0 0
15 10,884,847 27,894,913)5,283,443)27.238.957\0 0
16 936,622 716,972)17,473\1,141,83s)0 0
17 54,'107,931 94,097,395 11,263,878 41,450,511 0 0
't8 2,s99,36s 4,203,362 176,341\142.779\0 U
19 511,740 ( 195,52E)30,060)33,996)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
25 856,379,825 859,699,389 485,881,471 528,880,323 0 0
26 149,760,236 155,404,484 38,522,207 28,991,945 0 0
FERC FORM NO.2 (REV 06-04)Page 115
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) l-lA Resubmission
Date of Reporl(Mo, Da, Yr)
04t15t2016
Year/Period of Reporl
End of 2015/Q4
Statement of lncome(continued)
Line
No.
Title ofAccount Reference
page
Number
(a)
(b)
Total Total
Current Year to Prior Year to Date
Date Balance Balance
for QuarterlYear for 0uarler/Year
(c) (d)
Currenl Three
Months Ended
0uarterly Only
No Fourth ouarter
(e)
Prior Three
lvlonths Ended
Ouarterly Only
No Fourlh Quarter
(f)
27 Net Utility Operating lncome (Canied foruard from page 114)188.282.44:'184.396,429 0
2a )THER II{COME AND DEDUCTIONS
29 )ther lncome
30 Nonutility Operating lncome
31 Revenues form Merchandising, Jobbing and Contract Work (415)0 0
32 (Less) Costs and Expense of Merchandising, Job & Contract Work (416)0 0
33 Revenues from Nonutility Operations (417)( 17,s31)0
34 (Less) Expenses of Nonutility Operations (417.1)9,566,84(9,837,245 0
35 Nonoperating Rental lncome (418)939 ( 1,100)0 0
36 Equity in Earnings ol Subsidiary Companies (418.1)119 1 1,164,781 82,361,715 0 0
37 lnterest and Dividend lncome (419)645,401 1,845,367 0
38 Allor/ance for other Funds Used During Construclion (419.1)7,961,55:8,678,360 n
39 Miscellaneous Nonoperating lncome (421)795,42,0 0
40 Gain on Disposition of Property (421.1 )142,55:290,479 0
41 TOTAL Other lncome (Total of lines 31 thru 40)1 1.141.93;83,320,045 0
42 )her lncome Deductions
43 Loss on Disposition ol Proprty \421.21 38,668 0 0
44 Miscellaneous Amortization (425)0 n 0
45 Donations (426.1)340 3.208.02'3,879,397 0 0
46 Life lnsurance (426.2)3,079,99,2,060,570 0 0
47 Penalties (426,3)70,31 (| 24,718\U 0
48 Expenditures for Certain Civic, Political and Related Activities (426.4)1.625.65(1.679.329 U 0
49 other Deductions (426.5)1,386,50(3,295,1 62 0 0
50 TOTAL Other lncome Deductions (Total of lines 43 thru 49)340 9,370,48'.10,928,408 0 0
51 'axes Applic. to other lncome and Deductions
52 Taxes Other than lncome Taxes (408.2)262-263 202,51 150,614 U
53 lncome Taxes-Federal (409.2)262-263 71 5,329 (314,356)0
54 lncome Taxes-Other (409.2)262-263 ( 886,632 2,s79,615 0
55 Provision for Deferred lncome Taxes (410,2)23+235 1,006,93{( 1,467,880)0
56 (Less) Provision lor Defened lncome Taxes-Credit (4 1 1.2)23+23s 5,7U,73 6,039,386 0
57 lnvestrnent Tax Credil Adjustments-Net (41 1.5)0 0
58 (Less) lnvestment Tax Credits (420)0 0
59 TOTAL Taxes on Other lncome and Deductions ftotal of lines 52-58)( 6,097,243 ( s,091,393)0
60 Nel Other lncome and Deductions (Total of lines 41, 50, 59)7,868,70 77,483,030 0
61 NTEREST CHARGES
62 lnterest on Long-Term Debt (427)69,747,76r 67,341,1 70 0
63 Amortization of Debt Disc. and Expense (428)258-259 419,9't,424.830 0
64 Amortization of Loss on Reacquhed Debt (428.1)3,004,191 3,219,369 0
65 (Less) Amortization of Premium on DebtCredit (429)258-259 8,88i 8,883 0
66 (Less) Amortization ol Gain on Reacquired Debt-Credit (429.1)0 0
67 lnleresl on Debl to Associaled Companies (430)340 605,27 0 0
68 Other lnterest Expense (431)340 2.636.22 2.037,957 0
69 (Less) Allowance lor Borrowed Funds Used During Construction-Credit (432)3,480,39r 3,91 1,170 0
70 Net lnterest Charges (Total of lines 62 thru 69)72,924,10 69,103,273 0
71 lncome Before Extraordinary ltems (Total of lines 27,60 and 70)123,227,04 192,776,186 0
72 IXTRAORDINARY ITEMS
73 Exlraordinary lncome (434)0 0
74 (Less) Exkaordinary Deductions (435)0 n
75 Net Extraordinary ltems (Total of line 73 less line 74)0 U
/b lncome Taxes-Federal and Other (409,3)262-263 0 0
77 Exhaordinary ltems afler Taxes (Total of line 75 less line 76)0 0
78 Net lncome (Tolal of lines 71 and 77)123,221,04 1 92,776,186 0
FERC FORM NO. 2 (REV 06-04)Page 116
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) 5]en originat(2) TIA Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2016
Year/Period of Report
End of 20151Q4
Statement o'Accumulated Comorehensive lncome and Hedqino 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 (0 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.
Line
No.llem
(a)
Unrealized Gains
and Losses on
available{or-sale
securities
(b)
Minimum Pension
liabililty Adjustment
(net amount)
(c)
Foreign Cunenry
Hedges
(d)
Other
Adjustmenb
(e)
1 Balance ofActount 219 at Beginning of Preceding
Year ( 1,s8s,855)( 4,234,075)
2 Preceding Quarter/Year to Date Reclassifications
from Account 21 9 to Net lncome 460,497
Preceding Quarterffear to Date Changes in Fair
Value 1 ,'l 25,358 ( 3,653,806)
Total (lines 2 and 3)1,585,855 ( 3,653,806)
Balance of Account 21 9 at End of Preceding
Ouarter/Year ( 7,887,881)
Balance of Account 219 at Beginning of Cunenl Year ( 7,887,881)
Cunent Quarter/Year to Date Reclassifications from
Account 21 I to Nel lncome
8 Cunent QuarteriYear to Dale Changes in Falr Value 1 ,238,1 1 0
o Total (lines 7 and 8)1,238,110
10 Balance of Account 219 at End of Cunent
Quarterffear ( 6,649,771)
FERC FORM NO. 2 (NEW 06-02)Page 117
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiAn Originat(2) ;-1A Resubmission
Date of Report(Mo, Da, Yr)
04t15t2416
Year/Period of Report
End of 20151Q4
Statement of Accumulated Comprehensive lncome and Hedqinq Activities(continued)
_tne
No.
Other Cash Flow Hedges
lnterest Rate Swaps
(0
Other Cash Flow Hedges
(lnsert Category)
(s)
Totals Jor each
category of
items recorded in
Account 219
(h)
Net Income
(Carried Forward
fromPage116,
Line 78)
(i)
Total
Comprehensive
lncome
0)
1 ( 5,819,930)
2 460,497
( 2,528,448)
( 2,067,951)192,040,688 189.972.737
( 7,887,881)
( 7,887,881)
1 ,238,1 1 0
1 .238,1 1 0 123,227,041 124,465,151
1 ( 6,649,771)
FERC FORM NO. 2 (NEW 06-02)Page 117a
Name of Respondent
Avista Corporation
This Rec(1) tr(2) Tl
ort ls:
An Original
A Resubmission
Date of Report
(Mo, Da, Yr)
o4t1512016
Year/Period of Report
End of 2015/Q4
Statement of Retained Earnings
1 . Report all changes in appropriated retained earnings, unappropriated retained earnings, and unappropriated undistributed subsidiary earnings for the year.
affected in column (b).
3. State the purpose and amount for each reservation or appropriation of retained earnings.
5. Show dividends for each class and series of capital stock.
Line
No.
Item
(a)
Contra Primary
Account Affected
(b)
Cunenl Quarter
Year to Date
Balance
(c)
Previous Quarter
Year to Date
Balance
(d)
UNAPPROPRIATED RETAINED EARNINGS
1 Balance-Beqinninq of Period 492,987,406 403,295,872
2 Changes (ldentify by prescribed retained eaminos accounts)
3 Adjustments to Retained Earnings (Account 439)
4 TOTAL Credits to Retained Earnings (Account 439) (footnote details)1,488,991)39,369,910)
5 TOTAL Debits to Retained Earnings (Account 439) (footnote details)
6 Balance Transfened from lnmme (Acct 433 less Acct 418.1)112,062,256 109,678,973
7 Appropriations of Retained Eamings (Account 436)( 5,158,174)( 4,555,754)
I T0TAL Apprcpriations of Retained Earnings (Account 436) (footnote details)
I Dividends Declared-Prefened Stock (Account 437)
10 T0TAL Dividends Declared-Prefened Stock (Account 437) (footnote details)
11 Dividends Declared-Common Stock (Account 438)
12 TOTAL Dividends Declared-Common Stock (Account 438) (footnote details)82,396,803 78,313,788
13 Transfens from Account 216.'1, Unappropriated Undistributed Subsidiary Eamings 1,387,851 102,252,013
14 Balance-End of Period (Total of lines 1,4, 5, 6, 8, 10, 12, and 13)522,551,719 497,s43,1 60
15 APPROPRIATED RETAINED EARNINGS (Account 2'l 5)
16 TOTAL Appropriated Retained Earnings (Account 215) (footnote details)19,427,931 14,269,755
17 APPROPRIATED RETAINED EARNINGS.AMORTIZATION RESERVE, FEDERAL (Account
18 TOTAL Appropriated Retained Eamings-Amortization Reserve, Federal (Account 5,1 58,1 74)( 4,555,754)
19 TOTAL Appropriated Retained Earninqs (Accounts 2'15, 215.1) (Total of lines 14,269,757 9,714,001
20 TOTAL Retained Eamings (Accounts 215, 215.1,216l,(Total of lines 14 and 1 536,82'1,476 507,257,161
21 UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account 21 6.1 )
Report only on an Annual Basis no Quarterly
22 Balance-Beoinnino of Year (Debit or Credit)15,658,553)5,918,024)
23 Equity in Earnings for Year (Credit) (Account 418.1)1 1,164,785 82,361,715
24 (Less) Dividends Received (Debit)
25 Other Chanqes (Explain)( 1 ,387,8s1)( 92,102,2441
26 Balance-End of Year 5,881,619)I 5,658,s53)
FERC FORM NO. 2 (REV 06-04)Page 118-119
This Page Intentionally Left Blank
Name oi Kespondent
Avista Corporation
This Reoort ls:(1) [xlAn original(2) [-lA Resubmission
Date of Reporl(Mo, Da, Yr)
0411512016
Year/Period of Report
End of 2015iQ4
Statement of Cash Flows
(1) Codes to be used:(a) Net Proceeds or Payments;(b)Bonds, debentures and other long{erm 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 Activities: 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.
Line
No.
Description (See lnstructions for explanation of codes)Current Year
to Date
QuarterA/ear
Previous Year
to Date
QuarterlYear(a)
1 Net Cash Flow from Operating Activities
2 Net lncome (Line 78(c) on page '1 16)123,227,041 192,040,688
2 Noncash Charges (Credits) to lncome:
4 Depreciation and Depletion 138,235,780 126,986,417
5 Amortization of defened power and gas costs, debt expense and exchange power 27,223,055 ( 8,525,668)
6 Defened lncome Taxes (Net)53,931,102 '123,968,809
7 lnvestment Tax Credit Adjuslments (Net)481,680 ( 229,524)
I Net (lncrease) Decrease in Receivables ( 3,884,715)17,645,850
9 Net (lncrease) Decrease in lnventory 12,267,853 ( 1s,413,226)
'10 Net (lncrease) Decrease in Allowances lnventory
11 Net lncrease (Decrease) in Payables and Accrued Expenses 6,880,544 ( 40,191,1 16)
12 Net (lncrease) Decrease in Other Regulatory Assets ( 4,114,779)10,925,414
1a Net lncrease (Decrease) in Other Regulatory Liabilities 2,007,784 4,616,847
14 (Less) Allowance for Other Funds Used During Construction 7,961 ,552 8,678,360
15 (Less) Undistributed Eamings from Subsidiary Companies 11.164,785 82,361 ,715
16 Other (footnote details):i;.;.;,i;Lir'99;?9"?89$)
17 Net Cash Provided by (Used in) Operating Activities
18 (Total of Lines 2 thru 1 6)353,153,455 283,517,112
19
20 Cash Flows from lnvestment Activities:
21 Construction and Aquisition of Plant (including land):
22 Gross Additions to Utility Plant (less nuclear fuel)( 381,174,406)( 323,931,192)
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 Outflows for Plant (Total of lines 22 thru 27)( 381 ,174,406)( 323,9s1,1 92)
29
30 Acquisition of Other NoncurrentAssets (d)
31 Proceeds from Disposal ol Noncunent Assets (d)272,897
32 Federal and state grant payments received 2,730,'166 2,529,902
33 lnvestments in and Advances to Assoc. and Subsidiary Companies
34 Contributions and Advances from Assoc. and Subsidiary Companies ,1;,r :,"1J'4,'! 8F ;5, 71,:l.i*ii,:M ?,! ? i*.4,$.s"zq
35 Disposltion of lnvestments in (and Advances to)
36 Associated and Subsidiary Companies
Cash paid lor acquisition ( 94,643)( 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 Report ls:(1) [Rn Originat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Statement of Cash Flows (continued)
Line
No.
Description (See lnstructions for explanation of codes)
(a)
Current Year
to Date
QuarterA'ear
Previous Year
to Date
Quarterfr/ear
40 Loans Made or Purchased
41 Collections on Loans
42 Restricted cash ( 62,284\94,098
43 Net (lncrease) Decrease in Receivables
44 Net (lncrease) Decrease in lnventory
45 Net (lncrease) Decrease in Allowances Held for Speculation
46 Net Increase (Decrease) in Payables and Accrued Expenses
47 Changes in other property and investrnents ( 7,992,961)( 373,865)
48 Net Cash Provided by (Used in) lnvesting Activities
49 (Total of lines 28 thru 47)( 372,135,660)( 1 13,933,76s)
50
51 Cash Flows from Financing Activities:
52 Proceeds from lssuance of:
53 Long-Term Debt (b)100,000,000 60,000,000
54 Preferred Stock
55 Common Stock 1,559,840 4.059,874
56 Other (footnote details):
57 Net lncrease in Short{erm Debt (c)
58 Cash received lor settlement of interest rate swap agreements 5,429,000
59 Cash Provided by Outside Sources (Total of lines 53 thru 58)101,559,840 69,488,874
60
61 Paymenh for Retirement of:
62 Long-Term Debt (b)( 734,802)( 2e7,33e)
63 Prefened Stock
64 Common Stock ( 2,91e,781)( 79,855,898)
65 Other 1;, 1,;1. J,r,5,7!,,?.1 Z)r.n ; :aot;9,1..t1
bb Net Decrease in Short-Term Debt (c)( 66,000,000)
67 Premium paid to repurchase long{erm debt
68 Dividends on Prefened Stock
69 Dividends on Common Stock ( 82,396,801)( 78,313,788)
70 Net Cash Provided by (Used in) Financing Activities
71 (Total of lines 59 thru 69)3,937,239 ( 156,381,662)
72
73 Net lnoease (Decrease) in Cash and Cash Equivalents
74 (Total ol line'18,49 and 71)( 15,044,956)13.201,681
75
76 Cash and Cash Equivalents at Beginning of Period 18,9',t5,242 4,813.561
77
78 Cash and Cash Equivalenh at End of Period 2,970,276 18.O'.t5,242
FERC FORM NO. 2 (REV 06-04)Page 120a
Name of Respondent
Avista Corooration
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Report
2015tQ4
FOOTNOTE DATA
S;hedule Paqq 120 Line Nc-: 16 Column: c __l
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 other non-current assets and liabilities
Change in Coyote Springs 2 O&M LTSA
Prelim survey and investigation costs
1,104,752
(23,301,320)
(5,671,849)
6,006,850
20,692
5,200,000
(15,740,101)
(1,082,230)
709,287
Line No.: 16 Column: b
Tax shortfalls from stock 513
Power a natural gas deferrals
Change in special deposits
Change in other current assetsNon-cash stock compensationOther non-current asseLs and liabifitiesAllowance for doubtful accountsAmortization of Spokane Energy contract
Change in Coyote Springs 2 O&M LTSAPreliminary survey and investigation costsGain on sale of properLy and eguipmentOther
L, L2l,2g7(13,301 ,265)
2 ,956 ,640
6 ,91_3 ,6L9
5,891_,691
5 ,7 49 ,995
9 ,499 ,494
(2 ,260 , 66t)(30l.,2L4)
(]-42 ,552)
(2 ,587 )
: 120 Line No.:34 Column: c
Notes receivable from subsidiaries
Dividends received from subsidiaries
15,444,378
197.000.000
120 :34 Column: b
Notes receivable from subsidiaries
Dividends received from subsidiaries
12,185,571
2.000.000
Minimum tax withholdings for share based compensation
Cash paid for settlement of interest rate swap
Long-term debt issuance costs
Excess tax benefits
(1,831,678)
(9,326,000)
(5e3,e69)
180,430120 Line No.:65 Column: c
Long-term debt issuance costs
Excess tax benefits
(1,510,532)
107,021
FERC FORM NO.2 (12-96)552.1
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2) A Resubmission
Date of Report
(Mo, Da, Yr)
0411512016
Year/Period of Report
2015tQ4
Notes to Financial Statements
1. Provide important disclosures regarding the Balance Sheet,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 action initlated 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
material amount initiated by the utility. Also, briefly explain any dividends in arrears on cumulative preferred stock.
3. Furnish details on the respondent's pension plans, poslretirement benefits other than pensions (PBOP) plans, and post-employment benefit
plans as required by instruction no. 1 and, in addition, disclose for each individual plan the current year's cash contributions. Furnish details on
the accounting for the plans and any changes in the method of accounting for them. 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,
terminations, 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. 1 and, in addition, disclose the
recovered through rates to settle such obligatlons. 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 189, Unamortized Loss on Reacquired Debt, and 257, Unamoiized Gain on Reacquired Debt, are not used, give an
explanation, providing the rate treatment given these item, See General lnstruction 1 7 of the Uniform System of Accounts.
8. Explain concisely any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
9. Disclose details on any significant financial changes during the reporting year to the respondent or the respondent's consolidated group that
directly affect the respondent's gas pipeline operations, including: sales, transfers or mergers of affiliates, investments in new partnerships, sales
of gas pipeline facilities or the sale of ownership interests in the gas pipeline to limited partnerships, investments in related industries (i.e.,
production, gathering), major pipeline investments, acquisitions by the parent corporation(s), and distributions of capital.
'10. Explain concisely unsettled rate proceedings where a contingency exists such that the company may need to refund a material amount to
the utility's customers or that the utility may receive a material refund with respect to power or gas purchases. State for each year affected the
gross revenues or costs to which the contingency relates and the tax effects and explain the major factors that affect the rights of the utility to
retain such revenues or to recover amounts paid with respect to power and gas purchases.
11. Explain concisely significant amounts of any refunds made or received during the year resulting from settlement of any rate proceeding
affecting revenues received or costs incurred for power or gas purchases, and summarize the adjustments made to balance sheet, income, and
expense accounts.
12. Explain concisely only those significant changes in accounting methods made during the year which had an effect on net income, including
the basis of allocations and apportionments from those used in the preceding year. Also give the approximate dollar effect of such changes.
13. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading.
Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
14. For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which
have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in
such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long{erm
contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from
business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though
a significant change since year end may not have occurred.
15. Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable
and furnish the data required by the above instructions, such notes may be included hereln.
NOTES TO FINANCIAL STATEMENTS
NOTE I. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Nature of Business
Avista Corp. 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 eastem Washington and northern Idaho. Avista Corp.
also provides natural gas distribution service in parts ofnortheastern 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. acquired AERC, and as of that date, AERC became a wholly-owned subsidiary of Avista Corp. The
FERC FORM NO.2/3-Q 12-0 122.1
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
primary subsidiary of AERC is AEL&P, comprising regulated electric utility operations in Juneau, Alaska. There are no AERC
earnings included in the overall results of Avista Corp. prior to July 1,2014. See Note 3 for information regarding the acquisition of
AERC.
Avista Capital, a wholly owned subsidiary of Avista Corp., is the parent company of all of the subsidiary companies except AERC.
During the first half of 2014 and prior, Avista Capital's subsidiaries included 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 ofthe Company and have been prepared in accordance
with the accounting requirements of the Federal Energy Regulatory Commission (FERC) as set forth in its applicable Uniform System
of Accounts and published accounting releases, which is a comprehensive basis of accounting other than accounting principles
generally accepted in the United States of America (U.S. GAAP). As required by the FERC, the Company accounts for its investment
in majority-owned subsidiaries on the equity method rather than consolidating the assets, liabilities, revenues, and expenses of these
subsidiaries, as required by U.S. GAAP. The accompanying financial statements include the Company's proportionate share of utility
plant and related operations resulting from its interests in jointly owned plants. In addition, under the requirements of the FERC, there
are differences from U.S. GAAP in the presentation of (l) 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 associated with accounts other
than utility properfy, plant and equipment, (6) comprehensive income, (7) unamortized debt issuance costs and (8) operating revenues
and resource costs associated with settled energy contracts that are "booked out" (not physically delivered).
Use of Estimates
The preparation of the financial statements in conformity with GAAP requires management to make estimates and assumptions that
affect the amounts reported for assets and liabilities and the disclosure ofcontingent assets and liabilities at the date ofthe financial
statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates include:
r determining the market value of energy commodity derivative assets and
. pension and other postretirement benefit plan obligations,
o contingent liabilities,
r goodwill impairment testing,
. recoverability ofregulatory assets, and
o 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 Accoants
The accounting records of the Company's utility operations are maintained in accordance with the uniform system of accounts
prescribed by the FERC and adopted by the state regulatory commissions in Washington, Idaho, Montana and Oregon.
Regulation
FERC FORM NO.2/3-Q 12-O7 122.2
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t151?016
Year/Period of Report
2U5tA4
Notes to Financial Statements
The Company is subject to state regulation in Washington, Idaho, Montana and Oregon. The Company is also subject to federal
regulation primarily by the FERC, as well as various other federal agencies with regulatory oversight of parlicular aspects of its
operations.
Operating Revenues
Operating revenues related to the sale of energy 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 energy delivered to customers since the date of the last meter
reading is estimated and the corresponding unbilled revenue is estimated and recorded. Our estimate of unbilled revenue is based on:
. the number of customers,
. current rates,
o rl€ter reading dates,
actual native load for electricity,
actual throughput for natural gas, and
o electric line losses and natural gas system losses.
Any difference between actual and estimated revenue is automatically corrected in the following month when the actual meter reading
and customer billing occurs.
Accounts receivable includes unbilled energy revenues of the following amounts as of December 3l (dollars in thousands):
2015 2014
Unbilled accounts receivable 59,405 $78,007
Depreciotion
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 of properties at the expiration of their service lives. For utility operations, the
ratio of depreciation provisions to average depreciable property was as follows for the years ended December 3 1:
20ls 2014
Ratio ofdepreciation to average depreciable property 3.09% 2.97%
The average service lives for the following broad categories of utility plant
Electric thermal/other production
Hydroelectric production
Electric transmission
Electric distribution
in service are (in years):
Avista Corp.
40
79
57
36
FERC FORM NO. 2/3-Q (REV 12-07)122.3
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
Year/Period of Report
2015tQ4
Notes to Financial Statements
Natural gas distribution properfy
Taxes Otlter Than Income Taxes
Taxes other than income taxes include state excise taxes, city occupational and franchise taxes, real and personal properly 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 3l (dollars in thousands):
2015 2014
Utility taxes $ 57,716 $ 57,599
Allowancefor Funds Used During Construction
The AFUDC represents the cost of both the debt and equity funds used to lurance 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 component is credited
against total interest expense in the Statements of Income in the line item "capitalized interest." The equity component of AFUDC is
included in the Statement of Income in the line item "other income-net." The Company is permitted, under established regulatory rate
practices, to recover the capitalized AFUDC, and a reasonable return thereon, through its inclusion in rate base and the provision for
depreciation after the related utility plant is placed in service. Cash inflow related to AFUDC does not occur until the related utility
plant is placed in service and included in rate base. The effective AFUDC rate was the following for the years ended December 3 l:
20tS 2014
Effective AFUDC rate 7.32%7.64%
Income Taxes
A defened 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 retums. 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. The Company recognizes the effect of state tax credits, which are
generated from utility plant, as they are utilized. The Company did not incur any penalties on income tax positions in 20 I 5 or 2074.
The Company would recognize interest accrued related to income tax positions as interest expense and any penalties incurred as other
income deductions.
Stock-B ased Comp ensation
The Company cunently issues three types of stock-based compensation awards - restricted shares, market-based awards and
performance-based awards. Historically, these stock compensation awards have not been material to the Company's overall financial
results. Compensation cost relating to share-based payment transactions is recognized in the Company's financial statements based on
the fair value of the equity or liabilify instruments issued and recorded over the requisite service period.
The Company recorded stock-based compensation expense (included in other operating expenses) and income tax benefits in the
Statements of Income of the following amounts for the years ended December 3l (dollars in thousands):
45
20t5 2014
FERC FORM NO.2/3.Q 1 122 4
Name of Respondent
Avista Corporation
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tA4
Notes to Financial Statements
Stock-based compensation expense
Income tax benefits
Restricted Shares
Shares granted during the year
Shares vested during the year
Unvested shares at end ofyear
Unrecognized compensation expense at end ofyear (in thousands)
TSR Awards
TSR shares granted during the year
TSR shares vested during the year
TSR shares earned based on market metrics
Unvested TSR shares at end ofyear
6,974 $
2,420
6,007
2,102
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. Restricted stock is valued at the close of market of the Company's common stock on
the grant date.
Total Shareholder Retum (TSR) awards are market-based awards and Cumulative Eamings Per Share (CEPS) awards are performance
awards. CEPS awards were frst granted in20l4. 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 seftlement is at the discretion of the Company and
historically the Company has settled these awards through issuance of Avista Corp. common stock and intends to continue this
practice. Both types of awards entitle the recipients to dividend equivalent rights, are subject to forfeiture under certain circumstances,
and are subject to meeting specific market or performance conditions. Based on the level of attainment of the market or performance
conditions, the amount of cash paid or common stock issued will range from 0 to 200 percent of the initial awards granted. Dividend
equivalent rights are accumulated and paid out only on shares that eventually vest and have met the market and performance
conditions.
For both the TSR awards and the CEPS awards, the Company accounts for them as equity awards and compensation cost for these
awards is recognized over the requisite service period, provided that the requisite service period is rendered. For TSR awards, ifthe
market-condition is not met at the end of the three-year service period, there will be no change in the cumulative amount of
compensation cost recognized, since the awards are still considered vested even though the market metric was not met. For CEPS
awards, at the end of the three-year service period, if the internal performance metric of cumulative earnings per share is not met, all
compensation cost for these awards is reversed as these awards are not considered vested.
The fair value of each TSR award is estimated on the date of grant using a statistical model that incorporates the probability of meeting
the market targets based on historical returns relative to a peer group. The estimated fair value of the equity component of CEPS
awards was estimated on the date of grant as the share price of Avista Corp. comrnon stock on the date of grant, less the net present
value of the estimated dividends over the three-year period.
The following table summarizes the number of grants, vested and unvested shares, earned shares (based on market metrics), and other
pertinent information related to the Company's stock compensation awards for the years ended December 3l:
201 5 2014
58,302
(60,379)
106,091
1,705 $
116,435
222,734
223,697
62,075
(52,899)
112,042
1,349
I 17,550
97,199
287,834
(171,334) (167,584)
FERC FORM NO. 2/3-Q (REV 122.5
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
Unrecognized compensation expense (in thousands)
CEPS Awards
CEPS shares granted during the year
Unvested CEPS shares at end ofyear
Unrecognized compensation expense (in thousands)
3,219 $
58,259
I I 1,887
1,840 s
2,833
59,025
58,017
1,577
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
December3l,20l5 and2014,theCompanyhadrecognizedcumulativecompensationexpenseandaliabilityof$l.5millionand$1.3
million, respectively, related to the dividend component on the outstanding and unvested share grants.
Cash and Cash Equivalents
For the purposes of the Statements of Cash Flows, the Company considers all temporary investments with a maturity of three months or
less when purchased to be cash equivalents.
A llow an ce fo r Do u btful Ac c o unls
The Company maintains an allowance for doubtful accounts to provide for estimated and potential losses on accounts receivable. The
Company determines the allowance for utility and other customer accounts receivable based on historical write-offs as compared to
accounts receivable and operating revenues. Additionally, the Company establishes specific allowances for certain individual accounts.
Utility Plant in Service
The cost of additions to utility plant in service, including an allowance for flrnds used during construction and replacements of units of
properry and improvements, is capitalized. The cost of depreciable units of property retired plus the cost of removal less salvage is
charged to accumulated depreciation.
Ass el Ret irement O b lig ttt io ns
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 long-lived
asset. The liability is accreted to its present value each period and the related capitalized costs are depreciated over the useful life of
the related asset. In addition, if there are changes in the estimated timing or estimated costs of the AROs, adjustments are recorded
during the period new information becomes available as an increase or decrease to the liability, with the offset recorded to the related
long-lived asset. Upon retirement of the asset, the Company either settles the ARO for its recorded amount or 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 (see Note 7 for further discussion of the
Company's asset retirement obligations).
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 designated as a hedge for a particular exposure. The accounting for a derivative depends
FERC FORM NO.2/3.Q 12-O 122.6
Name of Respondent
Avista Corooration
This Report is:
(1)X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015to,4
Notes to Financial Statements
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 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 recognize the unrealized gain or
loss on utility derivative commodity instruments in the Statements of Income. Realized gains or losses are recogrized 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. Upon seftlement 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. While the Company has not received any formal accounting orders from the various state commissions
allowing for the offset of interest rate swap assets and liabilities with regulatory assets and liabilities, the Company has deemed this
accounting treatment appropriate and future recovery probable due to the regulatory precedents set in prior general rate cases and the
fact that the state commissions view interest rate swap derivatives as risk management tools similar to energy commodity derivatives.
As of December 3 I , 20 15, the Company has multiple master netting agreements with a variety of entities that allow for
cross-commodity netting of derivative agreements with the same counterparty (i.e. power derivatives can be netted with narural gas
derivatives) under ASC 815-10-45. The Company does not have any agreements which allow for cross-affiliate netting among multiple
affiliated legal entities. The Company nets all derivative instruments when allowed by the agreement for presentation in the Balance
Sheets.
Fair Value Messurements
Fair value represents the price that would be received when selling an asset or paid to transfer a liability (an exit price) in an orderly
transaction between market participants at the measurement date. Energy commodity derivative assets and liabilities, deferred
compensation assets, as well as derivatives related to interest rate swap agreements and foreign currency exchange contracts, are
reported at estimated fair value on the Balance Sheets. See Note 14 for the Company's fair value disclosures.
Regulatory Deferred Charges and Credits
The Company prepares its financial statements in accordance with regulatory accounting practices because:
. rates for regulated services are established by or subject to approval by independent third-party regulators,
r the regulated rates are designed to recover the cost ofproviding the regulated services, and
. in view of demand for the regulated services and the level of competition, it is reasonable to assume that rates can be
charged to and collected from customers at levels that will recover costs.
Regulatory accounting practices require that certain costs and/or obligations (such as incurred power and natural gas costs not
currently 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
FERC FORM NO. 2/3-Q (REV 1 't22 7
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4115t2016
Year/Period of Report
201slQ4
Notes to Financial Statements
revenues are recognized. The Company also has decoupling revenue deferrals, which began in 2015. As opposed to cost deferrals
which are not recognized in the Statements of Income until they are included in rates, decoupling revenue is recognized in the
Statements of Income during the period it occurs (i.e. during the period of revenue shortfall or excess due to fluctuations in customer
usage), subject to certain limitations, and a regulatory asseVliability is established which will be surcharged or rebated to customers in
furure periods. GAAP requires that for any alternative regulatory revenue program, like decoupling, the revenue must be collected
from customers within 24 months of the deferral to qualif, for recognition in the current period Statement of Income. Any amounts
included in the Company's decoupling program that won't be collected from customers within 24 months are not recorded in the
financial statements until the period in which revenue recognition criteria are met. This could ultimately result in more decoupling
revenue being collected from customers over the life of the decoupling program than what is defened and recognized in the current
period fi nancial statements.
If at some point in the future the Company determines that it no longer meets the criteria for continued application of regulatory
accounting practices for all or a portion ofits regulated operations, the Company could be:
o roQUired to write off its regulatory assets, and
. precluded fiom the future deferral ofcosts or decoupled revenues not recovered through rates at the time such
amounts are incurred, even if the Company expected to recover these amounts from customers in the future.
Investment in Exchange Power-Net
The investment in exchange power represents the Company's previous investment in Washington 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 investrnent in WNP-3.
Through a settlement agreement with the UTC in the Washington jurisdiction, Avista Corp. is amortizing the recoverable portion of its
investrnent in WNP-3 (recorded as investment in exchange power) over a 32.5-year period that began in I 987. For the Idaho
jurisdiction, Avista Corp. fully amortized the recoverable portion of its investment in exchange power.
Unamortized Debt Expense
Unamoftized debt expense includes debt issuance costs that are amortized over the life of the related debt.
Unamortized Loss on Reocquired Debt
For the Company's Washington regulatory jurisdiction and for any debt repurchases beginning in2007 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. ln 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 r op r iate d Reta ined E o rnings
In accordance with the hydroelectric licensing requirements of section l0(d) of the Federal Power Act (FPA), the Company maintains
an appropriated retained earnings account for any earnings in excess of the specified rate of return on the Company's investment in the
licenses for its various hydroelectric projects. Per section l0(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 inveshnent in
the licenses of the hydroelectric projects at the discretion of the FERC. The Company typically calculates the earnings in excess of the
specified rate ofretum on an annual basis, usually during the second quarter.
FERC FORM NO. 2/3-Q (REV 1 122.8
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
Year/Period of Report
20151Q4
Notes to Financial Statements
The appropriated retained earnings amounts included in retained earnings were as follows as of December 3l (dollars in thousands):
2015 2014
Appropriated retained earnings s 19,428 S 14,270
Operating Leases
The Company has multiple lease arrangements involving various assets, with minimum terms ranging from I to 45 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 December 3 1 , 20 I 5.
Equity in Earnings of Subsidiaries
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 31 (dollars in thousands):
2014
Avista Capital
Alaska Energy and Resources Company
Total equity in earnings of subsidiary companies
4,857 $
6,308
79,183
3,179
$ u,165 $82,362
Avista Capital, a wholly owned subsidiary of Avista Corp., is the parent company of all of the subsidiary companies, except AERC
(and its subsidiaries). Avista Capital's subsidiaries and investments include sheet metal fabrication, venture fund investments, real
estate investments, a company that explores markets that could be served with LNG 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.
Subsequent Events
Management has evaluated the impact of events occurring after December 31, 2015 up to February 24,2016, the date that Avista
Corp.'s U.S. GAAP financial statements were issued and has updated such evaluation for disclosure purposes through April 15, 2016.
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. As of December 3 I , 20 I 5, the Company has not recorded any significant amounts related to unresolved
contingencies. See Note l6 for further discussion of the Company's commitments and contingencies.
NOTE 2. NEW ACCOUNTING STANDARDS
In April 2014, theFASB issued ASU No. 2014-08, "Presentation of Financial Statements (Topic 205) and Property, Plant, and
FERC FORM NO. 2/3-Q (REV 12-07)122.9
Name of Respondent
Avista Corporation
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
20'l5lQ4
Notes to Financial Statements
Equipment (Topic 360): Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity," This ASU
amends the definition ofa discontinued operation and requires entities to provide additional disclosures about discontinued operations
as well as disposal transactions that do not meet the discontinued-operations criteria. ASU 20 l4-08 makes it more difficult for a
disposal transaction to qualifu as a discontinued operation. In addition, the ASU requires entities to reclassifu assets and liabilities ofa
discontinued operation for all comparative periods presented in the Balance Sheet rather thanjust the current period, and it requires
additional disclosures on the face of the Statement of Cash Flows regarding discontinued operations. This ASU became effective for
periods beginning on or after December 15,2014; however, early adoption was permitted. The Company evaluated this standard and
determined that it would not early adopt this standard. Since the disposition of Ecova occurred before the effective date of this
standard, and the Company did not early adopt this standard, there is no impact on the Company's financial condition, results of
operations and cash flows in the current year.
In May 2014,the FASB issued ASU No. 2014-09, "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 entity satisfies the performance obligations. This ASU was originally effective for periods beginning after December 15,
2016 and early adoption is not permitted. In August 2015, the FASB issued ASU 2015-14 Revenue from Contracts with Customers
(Topic 606): Deferral of the Effective Date," which deferred the effective date of ASU 2014-09 for one year, with adoption as of the
original date permitted. However, while this ASU is not effective until 2018, it will require retroactive application to all periods
presented in the financial statements. As such, at adoption in 20 I 8, amounts in 2016 and 2017 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 on its future financial condition, results of operations and cash flows.
In February 201 5, the FASB issued ASU No. 2015-02, "Consolidation (Topic 8 I 0): Amendments to the Consolidation Analysis." This
ASU significantly changes the consolidation analysis required under GAAP, including the identification of variable interest entities
(VIE). The ASU also removes the deferral of the VIE analysis related to investments in certain investment funds, which will result in a
different consolidation evaluation for these lypes of invesffnents. This ASU is effective for periods beginning on or after December 15,
2015; however, early adoption is permitted. The Company evaluated this standard and determined that it will not early adopt this
standard. The Company is evaluating this standard and cannot, at this time, estimate the potential impact on its future financial
condition, results of operations and cash flows.
In April 20 15, the FASB issued ASU No. 20 I 5-05, "Intangibles - Goodwill and Other - Internal-Use Software (Subtopic 350-40):
Customer's Accounting for Fees Paid in a Cloud Computing Arrangement." This ASU provides guidance on how organizations should
account for fees paid in a cloud computing arrangement, including helping organizations understand whether their arrangement
includes a software license. If the arrangement includes a software license, the software license would be accounted for in a manner
consistent with internal-use software. If a cloud-computing arrangement does not include a software license, the customer is required to
account for the arrangement as a service contract. This ASU is effective for periods beginning on or after December 15,2015;
however, early adoption is permitted. The Company evaluated this standard and determined that it will not early adopt this standard.
Upon adoption, an entity can elect to apply this ASU prospectively or retroactively and disclose the method selected. The Company is
evaluating this standard and cannot, at this time, estimate the potential impact on its future financial condition, results of operations and
cash flows.
In May 2015, the FASB issued ASU No. 2015-07, "Fair Value Measurement (Topic 820): Disclosures for Investments in Certain
Entities That Calculate Net Asset Value per Share (or Its Equivalent)." This ASU removes, from the fair value hierarchy,
investments for which the practical expedient is used to measure fair value at net asset value (NAV). Instead, an entity is required to
include those investments as a reconciling line item so that the total fair value amount of investments in the disclosure is consistent
FERC FORM NO.2/3-Q 't2-07 122.10
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
with the amount on the balance sheet. Further, entities must provide certain disclosures for investments for which they elect to use the
NAV practical expedient to determine fair value. This ASU is effective for periods beginning on or after December 15,2015 and early
adoption is permitted. The Company evaluated this standard and determined that it will early adopt this standard as of December 3 l,
2015. As required, this ASU is being applied retrospectively to all periods presented. The adoption of this standard did not affect the
Company's future financial condition, results of operations and cash flows; however, it did affect the Company's disclosures. See Note
8 and l4 for the expanded disclosures surrounding the adoption of this ASU.
In February 2016, the FASB issued ASU 2016-02 "Leases (Topic 842)." This ASU introduces a new lessee model that brings most
leases on the balance sheet. The standard also aligns certain of the underlying principles of the new lessor model with those in ASC
606, the FASB's new revenue recognition standard. Furthermore, the ASU addresses other concems related to the current leases
model; for example, eliminating the required use of bright-line tests in current GAAP for determining lease classification (operating
leases versus capital leases). This ASU also includes enhanced disclosures surrounding leases. This ASU is effective for periods
beginning on or after December 15, 2018; however, early adoption is permitted. The Company evaluated this standard and determined
that it will not early adopt this standard as of December 31, 2015. Upon adoption, this ASU must be applied using a modified
retrospective approach. The modified retrospective approach includes a number of optional practical expedients that entities may elect
to apply. The Company is evaluating this standard and cannot, at this time, estimate the potential impact on its future furancial
condition, results of operations and cash flows.
NOTE 3. BUSINESS ACQUISITIONS
Alaska Energy and Resources Company
On July 1,2014, the Company acquired AERC, based in Juneau, Alaska, and as of that date, AERC became a wholly-owned subsidiary
of Avista Corp.
The primary subsidiary of AERC is AEL&P, a regulated utility which provides electric services to approximately 17,000 customers in
the City and Borough of Juneau (Juneau), Alaska as of December 3 I , 201 5. 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 diversif Avista Corp.'s energy assets and deliver long-term value to its customers,
communities and investors.
In connection with the closing, on July I ,2014 Avista Corp. issued 4,500,0 l4 new shares of common stock to the shareholders of
AERC based on a conkactual 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 adjustments.
The $32.46 price per share of Avista Corp. conunon stock was determined based on the average closing stock price of Avista Corp.
corlmon stock for the I 0 consecutive trading days immediately preceding, but not including, the trading day prior to July l, 2014. 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 1,2014, 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 1,2074 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 hansferred for AERC were as follows (in thousands, except "per
share" and number ofshares data):
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)
04t1512016
Year/Period of Report
2015tQ4
Notes to Financial Statements
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 adjustrnent)
Total adjusted contract price
Fair value of consideration transferred
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
Assets acquired:
Current Assets:
Cash
Accounts receivable - gross totals S3,928
Materials and supplies
Other current assets
Total current assets
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(1)
Other deferred charges and non-current assets
170,000
19,704
(38,832)
37
1s0,909
154,911
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 fair value of assets acquired and liabilities assumed as of July 1 ,
2014 (after consideration of the working capital adjustrnent and the income tax true-ups during the second quarter of 201 5) were as
follows (in thousands):
July 1,2014
150,075
44
4,792
19,704
3,851
2,017
999
26,571
113,964
71,007
3,440
I 88,41 I
6,660
3,711
52,426
5,368
FERC FORM NO. 2/3-Q 1 't22.12
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2) A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
Total other non-current assets
Total assets
Liabilities Assumed:
Current Liabilities:
Accounts payable
Current portion oflong-term debt and capital lease obligations
Other current liabilities (l )
Total current liabilities
Long-term debt
Capital lease obligations
Other non-current liabilities and deferred credits (l)
Total liabilities
Total net assets acquired
283,147
700
Jrl l)
2,80',7
7,280
37,227
68,840
14,889
128,236
154,91 r
(l) During the second quarter of 2015, AEL&P recorded a reduction to goodwill of approximately $0.3 million due to income tax
related adjustments. After consideration of the goodwill adjustment in the second quarter of 2015, the transaction resulted in a
total amount of goodwill of $52.4 million. 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 for regulated operations. The rate-setting and cost recovery provisions currently in place for
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 were 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 and potential additional utility investment.
NOTE 4. DISCONTINUED OPERATIONS
On June 30,2014, Avista Capital, completed the sale of 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 price was $335.0 million in cash, less the
pa).rnent of debt and other customary closing adjustments. At the closing of the transaction on June 30,2074, Ecova became a
wholly-owned subsidiary of Cofely USA Inc. and the Company has not had and will not have any 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,
option holders and a warrant holder, pro rata based on ownership. Approximately $ 16.8 million (5 percent of the purchase price) was
held in escrow for l5 months from the closing of the transaction to satisfu certain indemnif,rcation obligations under the merger
agreement (Escrow). An additional $1.0 million was held in escrow pending resolution of adjustments to working capital. The
FERC FORM NO.2/3-Q 12 122.',t3
Name of Respondent
Avista Corporation
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
Year/Period of Report
2015tQ4
Notes to Financial Statements
indemnification escrow and the working capital adjustment escrow amounts above represent the full amounts to be divided among all
security holders pro rata based on ownership.
As expected, no claims were made against the Escrow as of September 30, 2015 (the end of the claims period) and accordingly, all
Escrow amounts were released in October 201 5 and the Company received its full portion of the Escrow proceeds together with the
remainder of the working capital adjustment escrow for a total amount of $13.8 million. After consideration of the escrow amounts
received, the sales transaction provided cash proceeds to Avista Corp., net of debt, payment to option and minority holders, income
taxes and transaction expenses, of $143.7 million and resulted in a net gain of $74.8 million. Almost all of the net gain was recognized
in 2014 with some true-ups during 201 5.
The summary of cash proceeds associated with the sales transaction are as follows (in thousands):
Reconciliation of Gross Proceeds
Contract price
Closing adjustments
Litigation settlement at Ecova
Gross proceeds from sale (l)
Cash sold in the transaction
Gross proceeds from sale ofEcova, net ofcash sold (2)
Reconciliation of total 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
Net proceeds to Avista Capital (prior to tax payments) (2)
Tax payments made in20l4
Tax payments made in 2015
Total net proceeds related to sales transaction
335,000
4,103
s88
339,691
(95,932)
243,759
339,691
(40,000)
(20,871)
(54,179)
(5,461)
219,180
(74,842)
(se0)
143,748
(l) Of this total amount, approximately $16.8 million was held in escrow for 15 months from the transaction closing date for any
indemnity claims and an additional $1.0 million was held in escrow pending resolution of adjustments to working capital. Both of
these escrow accounts were resolved during 2015.
(2) Of the total gross proceeds and total net proceeds received, approximately $229.9 million and $205.4 million was received in
2014, respectively, with the remainder being received in 2015.
NOTE 5. DERIVATIVES AND RISK MANAGEMENT
E n e r gy Co mmo digt D eriv at ives
Avista Corp. is exposed to market risks relating to changes in electricity and natural gas commodity prices and certain other fuel prices.
FERC FORM NO. 2/3-Q (REV 12-07 122.14
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Report
20151Q4
Notes to Financial Statements
Market risk is, in general, the risk of fluctuation in the market price of the commodity being traded and is influenced primarily by
supply and demand. Market risk includes the fluctuation in the market price of associated derivative commodity instruments. Avista
Corp. utilizes derivative instruments, such as forwards, futures, 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.
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 energy, fuel for electric generation, and derivative contracts related to capacity,
energy and fuel. Such transactions are part of the process of matching resources with load obligations and hedging the related financial
risks. These transactions range from terms of intra-hour up to multiple years.
As part of its resource procurement and management of its natural gas business, Avista Corp. makes continuing projections of its
natural gas loads and assesses available natural gas resources including natural gas storage availability. Natural gas resource planning
typically includes peak requirements, low and average monthly requirements and delivery constraints from natural gas supply locations
to Avista Corp.'s distribution system. However, daily variations in natural gas demand can be significantly different than monthly
demand projections. On the basis of these projections, Avista Corp. plans and executes a series of transactions to hedge a portion of its
projected natural gas requirements through forward market transactions and derivative instruments. These transactions may extend as
much as four natural gas operating years (November through October) into the future. Avista Corp. also leaves a significant portion of
its natural gas supply requirements unhedged for purchase in short-term and spot markets.
The following table presents the underlying energy commodity derivative volumes as of December 3 1 , 20 I 5 that are expected to be
settled in each respective year (in thousands of MWhs and mmBTUs):
Purchases
Electric Derivatives
Physical (l) Financial (1)
MWh MWh
Gas Derivatives Electric Derivatives Gas Derivatives
Physical (1) Financial (l)
mmBTUs mmBTUs
Physical (l) Financial (l)
MWh MWh
Physical (l) Financial (l)
mmBTUs mmBTUsYear
2016
2017
20r8
2019
2020
Thereafter
407 1,954
397 97
397
235
17,252 142,693 280
675 49,200 255
l5,l 18 286
305 6,935 158
45s 905
2,656 3,182 112,233
483 1,360 26,965
1,360 2,738
1,345
1,430
1,060
(1) Physical transactions represent commodity transactions in which Avista Corp. will take or make delivery of either electricity or
natural gas; financial transactions represent derivative instruments with delivery of cash in the amount of gain or loss but with
no physical delivery of the commodity, such as futures, swaps, options, or forward contracts.
The electric and natural gas derivative contracts above will be included in eitherpower 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 Exchange Contracls
A significant portion of Avista Corp.'s natural gas supply (including fuel for power generation) is obtained from Canadian sources.
FERC FORM NO. 2/3-O (REV 12-07 122.15
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Report
20't5tQ4
Notes to Financial Statements
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 ffansactions and long-term Canadian transportation contracts are committed based on Canadian curency prices and settled
within 60 days with U.S. dollars. Avista Corp. hedges a portion of the foreign currency risk by purchasing Canadian currency exchange
contracts when such commodify 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 ratemaking. The following table summarizes the foreign currency hedges that the Company has entered into as of December
3 I (dollars in thousands):
2015 2014
Number of contracts
Notional amount (in United States dollars)
Notional amount (in Canadian dollars)
Balance Shest Date
24 18
1,463 $ 5,474
2,002 6,198
Mandatory Cash Settlement
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
Company 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, 2015 6 I 15,000
3 45,000
11 245,000
30,000
20,000
2016
2017
2018
2019
2022
2
I
December 31,2014 5
5
J
9
75,000
95,000
45,000
205,000
2015
2016
2017
2018
During the third quarter 2015, in connection with the execution of a purchase agreement for bonds that the Company issued in
December 2015, the Company cash-settled five interest rate swap contracts (notional aggregate amount of $75.0 million) and paid a
total of $9.3 million. The interest rate swap contracts were settled in connection with the pricing of $100.0 million of Avista Corp. first
mortgage bonds that were issued in December 2015 (see Note l2). Upon settlement of interest rate swaps, the regulatory asset or
liability is amortized as a component of interest expense over the term of the associated debt.
The fair value of outstanding interest rate swaps can vary significantly from period to period depending on the total notional amount of
swaps outstanding and fluctuations in market interest rates compared to the interest rates fixed by the swaps. 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
FERC FORM NO. 2/3-Q (REV 12-07 122.16
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t1st2016
Year/Period of Report
2015t44
Notes to Financial Statements
settlement. Conversely, the Company receives cash to settle its interest rate swaps when prevailing market rates at the time of
settlement exceed the fixed swap rates.
S ummary of Outstanding D erivative Instruments
The amounts recorded on the Balance Sheet as of December 3 I , 20 I 5 and December 31 ,2014 reflect the offsetting of derivative assets
and liabilities where a legal right of offset exists.
The following table presents the fair values and locations of derivative instruments recorded on the Balance Sheet as of December 3 I ,
2015 (in thousands):
Fair Value
Collateral
Net Asset
(Liability)
in Balance
SheetDerivativeBalance Sheet Location
Foreigl currency
contracts
Interest rate
contracts
Interest rate
contracts
Interest rate
contracts
Commodity
contracts
Commodity
contracts
Commodity
contracts
2S
23
r 18
1,407
1,236
67,466
6,613
(le) $
(23,262)
(62,236)
(553)
(85,409)
(39,033)
-$
3,880
30,1 50
3,675
10,851
(17)
23
(19,264)
(30,679)
683
(t4,268)
(21,569)
Derivative instrument liabilities current
Long-term portion of derivative assets
Derivative instrument liabilities current
Long-term portion of derivative instrument
liabilities
Derivative instrument assets current
Derivative instrument liabilities current
Long-term portion of derivative liabilities
Totalderivative instruments recorded on the balance sheet $ 76,865 $ (210,512) $ 48,556 $ (35,091)
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
Gross Gross Collateral
Net Asset
(Liability)
in Balance
SheetDerivativeBalance Sheet Location
Foreign currency
contracts
Interest rate
contracts
Derivative instrument liabilities -Hedges
Derivative instrument assets -Hedges
l$
966
(21) $
(so6)
-$(20)
460
FERC FORM NO.2/3.Q 1 122.17
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
Interest rate
contracts
Interest rate
contracts
Commodity
contracts
Commodity
contracts
Commodity
contracts
Derivative instrument liabilities -Hedges
Long-term portion of derivative liabilities -
Hedges
Derivative insffument assets current
Long-term portion of derivative assets
Long-term portion of derivative Iiabilities
2,063
66,421
29,594
(7,325)
(69,737)
(53 8)
(97,586)
(54,077)
28,880
13,120
2,390
(7,325)
(40,857)
1,525
(18,045)
(22,093)
Total derivative instruments recorded on the balance sheet 99,045 $ (229,790) S 44,390 $(86,3ss)
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. ln 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.
The following table presents the Company's collateral outstanding related to its derivative instruments as of as of December 31 (in
thousands):
201 5 20t4
Energy commodity derivatives
Cash collateral posted
Letters of credit outstanding
Balance sheet offsetting (cash collateral against net derivative positions)
Interest rate swaps
Cash collateral posted
Letters of credit outstanding
Balance sheet offsetting (cash collateral against net derivative positions)
28,716 $
28,200
14,526
34,030
9,600
34,030
20,565
14,500
I 5,5 10
28,880
10,900
28,880
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 following table presents the aggregate fair value of all derivative instruments with credit-risk-related contingent features that are in
a liability position and the amount of additional collateral the Company could be required to post as of December 31 (in thousands):
FERC FORM NO. 2/3-Q (REV 1 122.18
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
201 5 2014
Energy commodity derivatives
Liabilities with credit-risk-related contingent features
Additional collateral to post
Interest rate swaps
Liabilities with credit-risk-related contingent features
Additional collateral to post
7,090 $
6,980
12,911
16,227
77,568
19,404
85,498
18,750
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
counterparty default due to circumstances:
. relating directly to it,
. saused by market price changes, and
r 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
established. Should a counterparty fail to perform, tle Company may be required to honor the underlying commitrnent or to replace
existing contracts with contracts at then-current market prices.
The Company enters into bilateral transactions with various counterparties. The Company also transacts in enerry and related
derivative insffuments through clearinghouse exchanges.
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 Iimits 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 indusky practice.
NOTE 6. JOINTLY OWNED ELECTRIC FACILITIES
The Company has a l5 percent ownership interest in a twin-unit coal-fired generating facility, Colship, located in southeastern
Montana, and provides funancing 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 3 I (dollars in thousands):
2015 2014
Utility plant in service $ 362,199 $350,518
FERC FORM NO.2/3.Q 122.19
Name of Respondent
Avista Corporation
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
Accumulated depreciation
NOTE 7. ASSET RETIREMENT OBLIGATIONS
See Note I for a discussion of the Company's accounting policy associated with AROs.
Specifically, the Company has recorded liabilities for future AROs to:
(243,363) (239,845)
. restore coal ash containment ponds at Colsffip,
. 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, and
. dispose of PCBs in certain transformers.
Due to an inability to estimate a range of settlement dates, the Company cannot estimate a liability for the:
. removal and disposal of certain transmission and distribution assets, and
o abandonment and decommissioning of certain hydroelectric generation and natural gas storage facilities.
On April 17,2015, the EPA published a hnal rule regarding CCRs, also termed coal combustion byproducts or coal ash in the Federal
Register and this rule became effective on October 15, 2015. Colship, of which Avista Corp. is a 15 percent owner of units 3 and 4,
produces this byproduct. The rule establishes technical requirements for CCR landfills and surface impoundments urder Subtitle D of
the Resource Conservation and Recovery Act, the nation's primary law for regulating solid waste. The Company, in conjunction with
the other Colstrip owners, is developing a multi-year compliance plan to strategically address the new CCR requirements and existing
State obligations while maintaining operational stability. During the second quarter of 20 I 5, the operator of Colstrip provided an initial
cost estimate of the expected retirement costs associated with complying with the new CCR rule and this estimate was subsequently
updated during the fourth quarter of 2015. Based on the initial assessments, Avista Corp. recorded an increase to its ARO of $12.5
million during 2015 with a corresponding increase in the cost basis of the utility plant.
The actual asset retirement costs related to the new CCR rule requirements may vary substantially from the estimates used to record the
increased obligation due to uncertainty about the compliance strategies that will be used and the preliminary nature of available data
used to estimate costs, such as the quantity of coal ash present at certain sites and the volume of fill that will be needed to cap and
cover certain impoundments. Avista Corp. will coordinate with the plant operator and continue to gather additional data in future
periods to make decisions about compliance sffategies and the timing of closure activities. As additional information becomes
available, Avista Corp. will update the ARO for these changes in estimates, which could be material. The Company expects to seek
recovery of any increased costs related to complying with the new rule through customer rates.
The following table documents the changes in the Company's asset retirement obligation during the years ended December 3l (dollars
in thousands):
2015 2014
Asset retirement obligation at beginning of year
Liabilities incurred
Liabilities settled
Accretion expense (income)
Asset retirement obligation at end of year
3,028 $
12,539
(2e)
4s9
2,859
(41)
210
15,997 $3,028
FERC FORM NO. 2/3-Q (REV 1 't2220
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
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-time employees at Avista Corp. that were
hired prior to January 1,2014. Individual benefits under this plan are based upon the employee's years ofservice, date ofhire and
average compensation as specified in the plan. Non-union employees hired on or after January 1,2014 participate in a defined
contribution 40 I (k) plan in lieu of a defined benefit pension plan. The Company's funding policy is to contribute at least the minimum
amounts that are required to be funded under the Employee Retirement Income Security Act, but not more than the maximum amounts
that are currently deductible for income tax purposes. The Company contributed $12.0 million in cash to the pension plan in 2015,
$32.0 million in2014 and $44.3 million in 2013. The Company expects to contribute $12.0 million in cash to the pension plan in
2016.
The Company also has a SERP that provides additional pension benefits to executive officers and certain key employees of the
Company. The SERP is intended to provide benefits to individuals whose benefits under the defined benefit pension plan are reduced
due to the application of Section 4 I 5 of the Internal Revenue Code of I 986 and the deferral of salary under deferred compensation
plans. The liability and expense for this plan are included as pension benefits in the tables included in this Note.
The Company expects that benefit payments under the pension plan and the SERP will total (dollars in thousands):
20 l6 201'l 201 8 2019 2020 To1al202l-2025
Expected benefit payments $ 29,182 $30,260 $31,332 $32,804 $34,430 $189,919
The expected long-term rate ofretum on plan assets is based on past performance and economic forecasts for the types ofinvestments
held by the plan. In selecting a discount rate, the Company considers yield rates for highly rated corporate bond portfolios with
maturities similar to that of the expected term of pension benefits.
The Company provides certain health care and life insurance benefits for eligible retired employees that were hired prior to January 1,
2014. The Company accrues the estimated cost of postretirement benefit obligations during the years that employees provide services.
The liability and expense of this plan are included as other postretirement benefits. Non-union employees hired on or after January I ,
2014, will have access to the retiree medical plan upon retirement; however, Avista Corp. will no longer provide a conhibution toward
their medical premium.
The Company has a Health Reimbursement Arrangement (HRA) to provide employees with tax-advantaged funds to pay for allowable
medical expenses upon retirement, The amount earned by the employee is fixed on the retirement date based on the employee's years
of service and the ending salary. The liability and expense of the HRA are included as other postretirement benefits.
The Company provides death benefits to beneficiaries of executive offlrcers who die during their term of office or after retirement.
Under the plan, an executive officer's designated beneficiary will receive a payment equal to twice the executive officer's annual base
salary at the time of death (or if death occurs after retirement, a payment equal to twice the executive officer's total annual pension
benefit). The liability and expense for this plan are included as other postretirement benefits.
The Company expects that benefit payments under other postretirement benefit plans will total (dollars in thousands):
2016 2017 201 8 20t9 2020 Total202l-2025
Expected benefit payments 7,345 $7,522 $7 ,713 $7,933 S 6,907 $36,560
The Company expects to contribute $7.3 million to other postretirement benefit plans in 2016, representing expected benefit payments
to be paid during the year excluding the Medicare Part D subsidy. The Company uses a December 31 measurement date for its pension
FERC FORM NO. 2/3-Q (REV 12-07)122.21
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2U5tA4
Notes to Financial Statements
and other postretirement benefit plans.
The following table sets forth the pension and other postretirement benefit plan disclosures as of December 3 l, 201 5 and 2014 and the
components ofnet periodic benefit costs for the years ended December 31, 2015,2014 and 2013 (dollars in thousands):
Pension Benefits
Other Post-
retirement Benefits
20t5 2014 2015 2014
Change in benefit obligation:
Benefit obligation as of beginning of year
Service cost
Interest cost
Actuarial (gain)/loss
Plan change
Transfer of accrued vacation
Cumulative adjustment to reclassif, liability
Benefits paid
Benefit obligation as ofend ofyear
Change in plan assets:
Fair value of plan assets as of beginning of year
Actual return on plan assets
Employer contributions
Benefits paid
Fair value ofplan assets as ofend ofyear
Funded status
Unrecognized net actuarial loss
Unrecognized prior service cost
Prepaid (accrued) benefit cost
Additional liability
Accrued benefit liability
Accumulated pension benefit obligation
613,503 $634,674 $138,795 $t27,989
634,674
19,791
26,117
(3s,790)
(228)
(3 I ,061 )
527,004
15,7 57
26,224
97,128
(31,439)
127,989
2,925
5,1 58
12,668
(1,000)
(l,521)
(7,424)
108,249
I,844
5,226
18,714
437
(6,481)
539,31 I
(4,305)
12,000
(29,772)
481,502
55,974
32,000
(30, I 65)
31,312 $
(444)
29,732
1,580
517,234 $539,31 I $30,868 $31,312
(96,269) $
162,961
25
(95,363) S
175,596
256
(t07,927) S
92,433
(10,1 80)
(96,677)
82,421
(10,379)
66,717
(162,986)
80,489
(l 75,8s2)
(25,674)
(82,253)
(24,635)
(72,042)
(e6,26e) $(95,363) $(107,927) $(96,677)
542,209 $55 1,615
FERC FORM NO. 2/3-Q (REV 12-07)122.22
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Report
2015t44
Notes to Financial Statements
Pension Benefits
Other Post-
retirement Benefits
201 5
Accumulated postretirement benefit obligation:
For retirees
For fully eligible employees
For other paxticipants
Included in accumulated other comprehensive loss (income) (net of tax):
20t4 2015 20t4
16$
t05,925
166
1 14,138
65,652
34,498
38,645
(6,617)
60,081
58,276
31,843
37,870
(6,747)
53,574
s
$
$
$
s
$
$
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
Weighted average assumptions as of December 3l:
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
Pension Benefits
6,527 $7,820 $123 S
105,941
(99,414)
114,304
( 106,484)
53,464
(53,34 I )
46,827
(46,759)
68
Pension Benefits
Other Post-
retirement Benefits
201 5 2014 2015
4.57%
4.21%
5.30%
4.87Y.
4.21%
s.t0%
6.60%
4.87%
4.57%
4.16%
6.36%
7.00%
5.00%
2022
7.00%
5.00%
2023
4.16%
5.02%
6.40%
7.00%
s.00%
2021
7.00Yo
s.00%
2022
Other Postretirement Benefi ts
20t4 201 5 20t4
Components of net periodic benefit
FERC FORM NO, 2/3-O (REV 1 122.23
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
cost:
Service cost
Interest cost
Expected return on plan assets
Amortization of prior service cost
Net loss recognition
Net periodic benefit cost
Equity securities
Debt securities
Real estate
Absolute return
19,791 $
26,117
(28,299)
2
9,451
75,757 $
26,224
(32, I 3 1)
22
4,731
2,925 $
5,1 58
(r,991)
(1,199)
5,095
1,844
5,226
(1,903)
(l,t l6)
4,289
27,062 $14,603 $9,988 S 8,340
Plan Assets
The Finance Committee of the Company's Board of Directors approves investment policies, objectives and strategies that seek an
appropriate return for the pension plan and other postretirement benefit plans and reviews and approves changes to the investment and
tunding policies.
The Company has conffacted with investment consultants who are responsible for managing/monitoring the individual investment
managers. The investment managers' performance and related individual fund performance is periodically reviewed by an internal
benefits committee and by the Finance Committee to monitor compliance with investment policy objectives and strategies.
Pension plan assets are invested in mutual funds, trusts and partnerships that hold marketable debt and equity securities, real estate,
absolute return and commodity funds. In seeking to obtain the desired return to fund the pension plan, the invesfment consultant
recommends allocation percentages by asset classes. These recommendations are reviewed by the internal benefits committee, which
then recommends their adoption by the Finance Committee. The Finance Committee has established target investment allocation
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:
20ts 2014
27%
58%
6%
9o/o
27%
58%
6%
9%
The fair 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, the investment manager estimates fair
value based upon other inputs (including valuations of securities that are comparable in coupon, rating, maturity and industry).
Investments in common/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 the valuation date. The Company's investments in common/collective trusts have redemption limitations that permit
quarterly redemptions following notice requirements of 45 to 60 days. The fair values of the closely held investments and partnership
interests are 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. Most of the Company's investments in closely held investments
and partnership interests have redemption limitations that range from bi-monthly to semi-annually following redemption notice
FERC FORM NO. 2/3-Q (REV 12-07)'t22.24
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
201510.4
Notes to Financial Statements
requirements of 60 to 90 days. One investment in a partnership has a lock-up for redemption currently expiring in2022 and is subject
to extension.
The fair value of pension plan assets invested in real estate was determined by the investment manager based on three basic
approaches:
o 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 fair value of pension plan assets was determined as of December 3 I , 20 1 5 and 20 I 4.
Effective December 3 1, 2015, the Company adopted ASU No. 2015-07, "Fair Value Measurement (Topic 820): Disclosures for
Investrnents in Certain Entities That Calculate Net Asset Value per Share (or Its Equivalent)," which removed from the fair value
hierarchy, investments for which the practical expedient is used to measure fair value at net asset value (NAV). In prior years, the
Company held investments fair valued using NAV and these amounts were included as level 3 items. This ASU was adopted
retrospectively; therefore, the 2014 amounts have been reclassified to conform to the 2015 presentation. Also, since these amounts are
no longer included in the fair value hierarchy as Ievel 3 items, the level 3 reconciliations are no longer applicable and have been
excluded from this footnote.
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 3 I , 201 5 at fair value (dollars in thousands):
Level I Level 2 Level 3
Cash equivalents
Fixed income securities:
U.S. government issues
Corporate issues
International issues
Municipal issues
Mutual funds:
U.S. equity securities
International equity securities
Absolute return (1)
Plan assets measured at NAV (not subject to hierarchy disclosure)
Common/collective trusts:
Real estate
Partnership/closely held investments :
Absolute return (l)
Private equity funds (2)
86$
87,678
40,343
13,996
10,647 $
47,845
187,308
34,458
22,416
- $ 10,727
47,945
187,308
34,458
22,416
87,678
40,343
13,996
24,147
39,302
73
FERC FORM NO. 2/3-Q (REV 12-07)122.25
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tA4
Notes to Financial Statements
Real estate
Total 302,668 $-$517,234
The following table discloses by level within the fair value hierarchy (see Note l4 for a description of the fair value hierarchy) of the
pension plan's assets measured and reported as of December 31,2014 at fair value (dollars in thousands):
Level I Level2 Level 3
Cash equivalents
Fixed income securities:
U.S. government issues
Corporate issues
International issues
Municipal issues
Mutual funds:
Fixed income securities
U.S. equity securities
Intemational equiry securities
-$
19,681
104,959
19,93 5
2,762
157,415
103,203
40,838
15,334
3,138 $
7,788
-$3,138
19,681
104,959
19,935
10,550
157,423
103,203
40,838
t5,334
8
Absolute return (1)
Plan assets measured at NAV (not subject to hierarchy disclosure)
Common/collective trusts:
Real estate
Partnership/closely held investments :
Absolute return (l)
Private equity funds (2)
Real estate
Total 464,127 $10,934 S -$539,31 1
This category invests in multiple strategies to diversiff risk and reduce volatility. The strategies include: (a) event driven,
relative value, convertible, and fixed income arbitrage, (b) distressed investments, (c) long/short equity and fixed income, and
(d) market neutral strategies.
This category includes private equity funds that invest primarily in U.S. companies.
The fair value of other postretirement plan assets invested in debt and equity securities was based primarily on market prices. The fair
value ofinvestment securities traded on a national securities exchange is determined based on the last reported sales price; securities
traded in the over-the-counter market are valued at the last reported bid price. 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 equiry securities and 40 percent debt securities in both 2015 and2014.
FERC FORM NO.2/3.Q 12-071 122.26
21,303
36,114
73
6,760
(l)
(2)
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
The fair value of other postretirement plan assets was determined as of December 3 I , 20 I 5 and 2014.
The following table discloses by level within the fair value hierarchy (see Note 14 for a description of the fair value hierarchy) of other
postretirement plan assets measured and reported as of December 3 I , 20 l5 at fair value (dollars in thousands):
Level I lxvel2 kvel 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
Intemational equity securities
Total
-$
12,000
13,224
5,635
e$-$
12,000
13,224
5,635
30,8s9 $9$-$30,868
The following table discloses by level within the fair value hierarchy (see Note 14 for a description of the fair value hierarchy) of other
postretirement plan assets measured and reported as of Decemb er 31 ,2074 at fair value (dotlars in thousands):
Level I Level2 l-evel 3 Total
-s
I1,968
13,210
6,131
3$-$J
I1,968
13,210
6,13 I
31,309 $3S -$31,312
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 postetirement benefit obligation as of
December 31,2015 by $9.7 million and the service and interest cost by $0.5 million. A one-percentage-point decrease in the assumed
health care cost trend rate for each year would decrease the accumulated postretirement benefit obligation as of December 3 l, 201 5 by
$7.5 million and the service and interest cost by $0.4 million.
401(k) Pluns 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 conhibutions were as follows for the years ended December 3l (dollars in thousands):
201 5 2014
Employer 40 I (k) matching contributions 7,875 $6,741
FERC FORM NO. 2/3-Q (REV 12-07)122.27
The Company has an Executive Deferral Plan. This plan allows executive officers and other key employees the opportunity to defer
Name of Respondent
Avista Corporation
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
0411512016
Year/Period of Report
2015tQ4
Notes to Financial Statements
until the earlier of their retirement, termination, disability or death, up to 75 percent of their base salary and/or up to I00 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 3 I (dollars in thousands):
20t5 2014
Deferred compensation assets and liabilities $ 8,093 $ 8,677
NOTE 9. ACCOUNTING FORINCOME TAXES
Defened 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 carryforwards..The realization of deferred
income tax assets is dependent upon the ability to generate taxable income in future periods. The Company evaluated available
evidence supporting the realization of its deferred income tax assets and determined it is more likely than not that deferred income tax
assets will be realized.
As of December 31, 2015, the Company had $15.3 million of state tax credit carryforwards of which it is expected $2.9 million will
expire unused; the Company has reflected the net amount of $12.4 million as an asset at December 31, 2015. State tax credits expire
from 2019 to2028.
The Company and its eligible subsidiaries file consolidated federal income tax returns. The Company also files state income tax retums
in certain jurisdictions, including Idaho, Oregon and Montana. Subsidiaries are charged or credited with the tax effects of their
operations on a stand-alone basis. The Internal 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 and2014 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 had net regulatory assets related to the probable recovery of certain deferred income tax liabilities from customers
through future rates as of December 31 (dollars in thousands):
20ls 2014
Regulatory assets for deferred income taxes
Regulatory liabilities for deferred income taxes
s 101,240 $ I00,412
17,609 14,534
NOTE 10. ENERGY PURCHASE CONTRACTS
Avista Corp. has contracts for the purchase of fuel for thermal generation, natural gas for resale and various agreements for the
purchase or exchange of electric energy with other entities. The 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 31 (dollars in thousands):
20ls 2014
Utility power resources $ 511,937 $ 556,915
FERC FORM NO. 2/3-Q (REV 12-07)122.28
The following table details Avista Corp.'s future contractual commitments for power resources (including transmission contracts) and
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
Year/Period of Report
20151Q4
Notes to Financial Statements
natural gas resources (including transportation contracts) (dollars in thousands):
20t6 2017 201 8 2019 2020 Thereafter Total
Power resources
Natural gas resources
Total
$ 261,560 $
79,335
168,83 I $
64,400
t49,375 S
65,144
t45,074 $
57,105
104,688 $
45,446
838,536 $ 1,668,064
427,435 738,865
s 340,895 $ 233,231 $ 214,519 $ 202,179 $150,134 $ 1,265,971 $ 2,406,929
These energy purchase contracts were entered into as part ofAvista Corp.'s obligation to serve its retail electric and natural gas
customers' energy requirements, including contracts entered into for resourse 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 contracfual amounts related to the Company's contracts
with certain PUDs to purchase portions of the output of certain generating facilities. Although Avista Corp. has no investment in the
PUD generating facilities, the fixed contracts obligate Avista Corp. to pay certain minimum amounts whether or not the facilities are
operating. The cost of power obtained under the contracts, including payments made when a facility is not operating, is included in
utility resource costs in the Statements of Income. The contractual amounts included above consist of Avista Corp.'s share of existing
debt service cost and its proportionate share of the variable operating expenses of these projects. The minimum amounts payable under
these contracts are based in part on the proportionate share of the debt service requirements of the PUD's revenue bonds for which the
Company is indirectly responsible. The Company's total future debt service obligation associated with the revenue bonds outstanding at
December 31,2015 (principal and interest) was $72.0 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):
2016 2017 201 8 2019 Thereafter
Contractualobligations $33,694 $31,134 S 26,405 $31,117 $3l,g1l s 192,295 $ 346,456
NOTE 1I. NOTES PAYABLE
Avista Corp.
Avista Corp. has a committed line of credit with various financial institutions in the total amount of $400.0 million that expires in April
201 9. The Company has the option to request an extension for an additional one or two years beyond April 2019, provided, 1) that no
event ofdefault has occurred and is continuing prior to the requested extension and 2) the remaining term ofagreement, including the
requested extension period, does not exceed five years. The committed line of credit is secured by non-transferable first mortgage
bonds of the Company issued to the agent bank that would only become due and payable in the event, and then only to the extent, that
the Company defaults on its obligations under the committed line of credit.
The committed line of credit agreement contains customary covenants and default provisions. The credit agreement has a covenant
which does not permit the ratio of "consolidated total debt" to "consolidated total capitalization" of Avista Corp. to be greater than 65
percent at any time. As of December 3 1 , 20 I 5, 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):
2015 2014
FERC FORM NO. 2/3-Q 1 '122.29
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
Year/Period of Report
2015tQ4
Notes to Financial Statements
Balance outstanding at end ofperiod
Letters ofcredit outstanding at end ofperiod
Average interest rate at end ofperiod
Maturity
Year Description
As of December 31, 2015 and 2014,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 outstanding as of December 31 (dollars in thousands):
$ 105,000 $ 105,000
$ 44,595 $ 32,579
t.t&% 0.93%
2015 2014
Interest
Rate
20t6
2018
20r8
2019
2020
2022
2023
2028
2032
2034
2035
2037
2040
2041
2044
2045
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 Morlgage Bonds
First Moftgage Bonds (2)
First Mortgage Bonds
Total secured bonds
Secured Pollution Control Bonds held by Avista
Corporation (1)
Total long-term debt
0.84% $
5.95%
739%-7.45%
5.450
3.89%
5.13%
7.r8%-7.54%
6.37%
(t)
(l)
6.250/o
s.70%
5.55%
4.45%
4.11%
4.37%
4.23o/o
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
60,000
100,000
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
60,000
80,000
I,536,700 1,436,700
(83,700) (83,700)
$ 1,453,000 s 1,353,000
In December 2010,$66.7 million and $17.0 million of the City of Forsyh, Montana Pollution Control Revenue Refunding
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 20 1 0A and Series 20 I 0B). The new bonds were not
FERC FORM NO.2/3-Q 1 122.30
(l)
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
Year/Period of Report
2015tQ4
Notes to Financial Statements
offered to the public and were purchased by Avista Corp. due to market conditions. The Company expects that at a later date,
subject to market conditions, these bonds may be remarketed to unaffiliated investors. So long as Avista Corp. is the holder of
these bonds, the bonds will not be reflected as an asset or a liability on Avista Corp.'s Balance Sheets.
(2) In December 2015, Avista Corp. issued $100.0 million of first mortgage bonds to five institutional investors in a private
placement transaction. The first mortgage bonds bear an interest rate of 4.37 percent and mature in 2045 . 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 following table details future long-term debt maturities including advances from associated companies (see Note 13) (dollars in
thousands):
2016 2017 201 8 2019 2020 Thereafter Total
Debt maturities 90,000 $- $ 272,500 $90,000 $52,000 $ 1,000,047 $ 1,504,547
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: l) 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 certain exceptions in the case of bonds issued on the basis of retired bonds) unless the Company's "net eamings" (as defined in
the Mortgage) for any period of l2 consecutive calendar months out of the preceding I 8 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 3 I , 20 I 5, property additions and retired bonds would have allowed, and the net eamings
test would not have prohibited, the issuance of $ I . I billion in aggregate principal amount of additional first mortgage bonds at Avista
Corp.
See Note I 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
In 1997, the Company issued Floating Rate Junior Subordinated Deferrable Interest Debentures, Series B, with a principal amount of
$51 .5 million to Avista Capital II, an affiliated business trust formed by the Company. Avista Capital II issued $50.0 million of
Preferred Trust Securities with a floating distribution rate of LIBOR plus 0.875 percent, calculated and reset quarterly. The distribution
rates paid were as follows during the years ended December 3l;
2015 2014
Low distribution rate
High distribution rate
Distribution rate at the end of the year
t.t1%
1.29%
1.29%
1.10%
t.t1%
1.11%
Concurrent with the issuance of the Preferred Trust Securities, Avista Capital II issued $ I .5 million of Common Trust Securities to the
Company. These debt securities may be redeemed at the option of Avista Capital II at any time and mature on June 1 , 2037 . ln
December 2000, the Company purchased $10.0 million of these Preferred Trust Securities.
FERC FORM NO. 2/3-Q (REV 12-07)122.31
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
20151Q4
Notes to Financial Statements
The Company owns 1 00 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 levels 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.
Level 2 - Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly
observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation
methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward
prices for commodities, time value, volatility factors, and current market and contractual prices for the underlying instruments, as well
as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term
of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the
marketplace.
Level 3 - Pricing inputs include significant inputs that are generally unobservable from objective sources. These inputs may be
used with internally developed methodologies that result in management's best estimate of fair value.
Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value
measurement. The Company's assessment of the significance of a particular input to the fair value measurement requires judgment, and
may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels. The determination
of the fair values incorporates various factors that not only include the credit standing of the counterparties involved and the impact of
credit enhancements (such as cash deposits and letters of credit), but also the impact of Avista Corp.'s nonperformance risk on its
Iiabilities.
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 3l (dollars in thousands):
201420r5
Carrying
Value
Estimated
Fair Value
Carrying
Value
Estimated
Fair Value
Bonds (Level 2)
Bonds (Level 3)
Advances from associated companies (Level 3)
951,000 $
502,000
51,547
402,000
51,547
432,728
38,582
1,055,797 $
505,768
36,083
95 t ,000 $ l,l 18,972
FERC FORM NO.2/3.Q 12-071 't22.32
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
These estimates of fair value of long-term debt and long-term debt to affiliated ffusts were primarily based on available market
information, which generally consists of estimated market prices from third parry brokers for debt with similar risk and terms. The
price ranges obtained from the third party brokers consisted ofpar values of70.00 to I 19.70, where a par value of 100.00 represents
the carrying value recorded on the Balance Sheets. Level2long-term debt represents publicly issued bonds with quoted market prices;
however, due to their limited trading activity, they are classified as level 2 because brokers must generate quotes and make estimates if
there is no trading activity near a period end. Level 3 long-term debt consists ofprivate placement bonds and Advances from
associated companies, which typically have no secondary trading activity. Fair values in Level 3 are estimated based on market prices
from third party brokers using secondary market quotes for debt with similar risk and terms to generate quotes for Avista Corp. bonds.
The following table discloses by level within the fair value hierarchy the Company's assets and liabilities measured and reported on the
Balance Sheets as of December 31,2015 and2014 at fair value on a recurring basis (dollars in thousands):
Level I Level2
Counterparty
and Cash
Collateral
Level 3 Netting (l) Total
December 31, 2015
Assets:
Enerry commodity derivatives
Level 3 energy commodity derivatives:
Natural gas exchange agreements
Foreign currency derivatives
Interest rate swaps
Deferred compensation assets :
Fixed income securities
Equity securities
Total
Liabilities:
Enerry commodity derivatives
Level 3 energy commodity derivatives:
Natural gas exchange agreement
Power exchange agreement
Power option agreement
Interest rate swaps
Foreign currency derivatives
Total
7,488 $76,187 $678 $(74,634) $9,719
-$
1,727
5,761
74,637 $
2
1,548
-$(73,9s4) $
(678)
(2)
683
678
1,548
1,727
5,761
-$97,193 $
85,498
19
-$
5,717
21,961
124
(88,480) $
(678)
8,713
5,039
21,961
124
85,498
t7(2)
-$182,710 s 27,802 $(89,160) $121,352
FERC FORM NO.2/3-Q 12-07 122.33
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
Level I Level2 Level 3
Counterparty
and Cash
Collateral
Netting (l)Total
December 31,2014
Assets:
Energy commodity derivati ves
Level 3 energy commodity derivatives:
Natural gas exchange agreement
Foreign currency derivatives
Interest rate swaps
Deferred compensation assets :
Fixed income securities
Equity securities
Total
Liabilities:
Energy commodity derivatives
Level 3 energy commodity derivatives:
Natural gas exchange agreement
Power exchange agreement
Power option agreement
Foreign currency derivatives
Interest rate swaps
Total
7,867 $97,696 $1,349 $(e7,060) $9,852
-$
1,793
6,074
96,729 S -$
1,349
(95,204) $
(1,349)
(l)
(s06)
1,525
460
1,793
6,074
I
966
-$127,094 $
2t
77,568
-$
1,384
23,299
424
(l10,714) $
(1,349)
(1)
(29,386)
16,380
35
23,299
424
20
48,182
-s 204,683 $25,107 S (141,450) $88,340
( I ) The Company is permitted to net derivative assets and derivative liabilities with the same counterpaffy 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 market quotes, adjusted
for periods in between quotable periods. Natural gas derivative valuations are estimated using New York Mercantile Exchange
CNYMEX) pricing for similar instruments, adjusted for basin differences, using market quotes. Where observable inputs are available
for substantially the full term of the contract, the derivative asset or liability is included in Level 2.
FERC FORM NO. 2/3.Q (REV 1 122.34
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQl A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
To establish fair values for interest rate swaps, the Company uses forward market curves for interest rates for the term of the swaps and
discounts the cash flows back to present value using an appropriate discount rate. The discount rate is calculated by third party brokers
according to the terms of the swap agreements and evaluated by the Company for reasonableness, with consideration given to the
potential non-performance risk by the Company. Future cash flows of the interest rate swaps are equal to the fixed interest rate in the
swap compared to the floating market interest rate multiplied by the notional amount for each period.
To establish fair value for foreign currency derivatives, the Company uses forward market curves for Canadian dollars against the US
dollar and multiplies the difference between the locked-in price and the market price by the notional amount of the derivative. Forward
foreign currency market curyes are provided by third party brokers. The Company's credit spread is factored into the locked-in price of
the foreign exchange contracts.
Deferred compensation assets and liabilities represent funds held by the Company in a Rabbi Trust for an executive deferral plan.
These funds consist of actively traded equity and bond funds with quoted prices in active markets. The balance disclosed in the table
above excludes cash and cash equivalents of $0.6 million as of December 31, 2015 and $0.8 million as of December 31,2014.
Level 3 Foir Value
Under the power exchange agreement the Company purchases power at a price that is based on the on the average operating and
maintenance (O&M) charges from three surrogate nuclear power plants around the country. To estimate the fair value of this
agreement the Company estimates the difference between the purchase price based on the future O&M charges and forward prices for
energy.
The Company compares the Level 2 brokered quotes and forward price curves described above to an internally developed forward
price which is based on the average O&M charges from the three surrogate nuclear power plants for the current year. Because the
nuclear power plant O&M charges are only known for one 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 hansactions
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 year 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 intemally derived price based on a combination of generation plant heat rate factors, natural gas market pricing, delivery and
other O&M charges), 2) estimated delivery volumes, and 3) volatility rates for periods beyond January 201 8. 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 sfrike price and
volatility assumptions used in the calculation.
For the natural gas commodity exchange agreement, the Company uses the same Level 2 brokered quotes described above; however,
the Company also estimates the purchase and sales volumes (within contractual limits) as well as the timing of those transactions.
Changing the timing of volume estimates changes the timing of purchases and sales, impacting which brokered quote is used. Because
the brokered quotes can vary significantly from period to period, the unobservable estimates of the timing and volume of transactions
can have a significant impact on the calculated fair value. The Company currently estimates volumes and timing of transactions based
on a most likely scenario using historical data. Historically, the timing and volume of transactions have not been highly correlated with
market prices and market volatility.
FERC FORM NO.2/3-Q 12-07)122.35
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2016
Year/Period of Report
201stQ4
Notes to Financial Statements
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 3 l, 2015 (dollars in thousands):
Fair Value
(Net) at
December 31,
2015
Valuation
Technique Unobservable Input Range
Power exchange agreement (21,961) Surrogatefacility
' pricing
O&M charges
Escalation factor
Transaction volumes
$33.s2-$43.65/tv1wh (l )
3% - 2016 to 2019
233,054 - 397,030 MWhs
Power option agreement (124)Black-Scholes-
Merton
Strike price
Delivery volumes
Volatility rates
$35.4344Wh -2016
$48.78A4Wh -2019
157,517 -285,979 MWhs
0.20 (2)
Natural gas exchange
agreement
(5,039) Internally derived
weighted average
cost of gas
Forward purchase
prices
$1.67 - $2.84/mmBTU
Forward sales prices $1.88 - $3.68/mmBTU
Purchase volumes I 15,000 - 310,000 mmBTUs
Sales volumes 30,000 - 310,000 mmBTUs
( I ) The average O&M charges for the delivery year beginning in November 201 5 were $39 .27 per MWh. For ratemaking purposes the
average O&M charges to be included for recovery in retail rates vary slightty between regulatory jurisdictions. The average O&M
charges for the delivery year beginning in 201 5 are $43.52 for Washington and $39 .27 for Idaho.
(2) The estimated volatility rate of 0.20 is compared to actual quoted volatility rates of 0.37 for 2016 to 0.24 in January 2018.
Avista Corp.'s risk management department and accounting department are responsible for developing the valuation methods
described above and both groups report to the Chief Financial Ofhcer. The valuation methods, significant inputs and resulting fair
values described above are reviewed on at least a quarterly basis by the risk management departrnent and the accounting department to
ensure they provide a reasonable estimate of fair value each reporting period.
The following table presents activity for energy commodity derivative assets (liabilities) measured at fair value using significant
unobservable inputs (Level 3) for the years ended December 31 (dollars in thousands):
Natural Gas
Exchange
Agreement
Power Power
Exchange Option
Agreement Agreement Total
FERC FORM NO.2/3.Q 12-07 122.36
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4t1512016
Year/Period of Report
2015tQ4
Notes to Financial Statements
Year ended December 31, 2015:
Balance as of January 1,2015 $ (35) $ (23,299) S (424) $ (23,758)
Total gains or losses (realized./unrealized):
Included in regulatory assets/liabilities (l) (6,008) (6,198) 300 (l 1,906)
Settlements 1,004 7,536 8,540
Ending balance as of December 3 I , 20 I 5 (2)$ (s,039) $ (21,961) $ (124) $ (27,124)
Year ended December 31,2014:
Balance as ofJanuary 1,2014 $ (1,219) $ (14,441) $ (775) $ (16,435)
Total gains or losses (realized/unrealized):
Included in regulatory assets/liabilities (1) 3,873 (10,002) 35I (5,778)
Setrlements (2,689) 1,144 (1,545)
Ending balance as of December 31,2014 (2)$ (3s) $ (23,299) $ (424) S (23,7s8)
( I ) All gains and losses are included in other regulatory assets and liabilities. There were no gains and losses included in either net
income or other comprehensive income during any of the periods presented in the table above.
(2) There were no purchases, issuances or transfers from other categories ofany derivatives instruments during the periods presented
in the table above.
NOTE T5. COMMON STOCK
The Company had a Direct Stock Purchase and Dividend Reinvesfrnent PIan under which the Company's shareholders could
automatically reinvest their dividends and make optional cash payments for the purchase of the Company's common stock at current
market value. This plan was terminated by the Company in 2014.
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),
. ceftain covenants applicable to the Company's outstanding long-term debt and committed line of credit agreements,
o the hydroelectric licensing requirements of section l0(d) of the FPA (see Note l), and.
. certain requirements under the Public Utility Commission of Oregon (OPUC) approval of the AERC acquisition. As
of July I , 20 I 5 (one year following the acquisition date), 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 sufficiently capitalized and insured.
The Company declared the following dividends for the year ended December 3l:
2015 2014
Dividends paid per common share $ 1.32 $ 1.27
FERC FORM NO. 2/3-O {REV 12-07 122.37
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
o4115t2016
Year/Period of Report
2U5tA4
Notes to Financial Statements
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, 2015 was limited to approximately $385.3 million.
Under the requirements of the OPUC approval of the AERC acquisition as outlined above, the amount available for dividends at
December 3 I , 201 5 was limited to approximately $23 1 .0 million.
The Company has l0 million authorized shares of preferred stock. The Company did not have any preferred stock outstanding as of
December 3 l, 201 5 and 2014.
Stock Repurchase Programs
During 2014, Avista Corp.'s Board of Directors approved a program to repurchase up to 4 million shares of the Company's
outstanding cornmon stock (2014 program). Repurchases of common stock under this program began on July 7, 2014 and the program
expired on December 31,2014. Repurchases were made in the open market or in privately negotiated transactions. Under the 2014
program the Company repurchased 2,529,615 shares at a total 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 20 I 4.
Avista Corp. initiated a second stock repurchase program on January 2,2015 that expired on March 31, 2015 for the repurchase of up
to 800,000 shares of the Company's outstanding common stock (frst quarter 2015 program). The number of shares repurchased
through the first quarter 201 5 program was in addition to the number of shares repurchased under t}te 2014 program, which expired on
December 31,2014. Under the first quarler 2015 program, the Company repurchased 89,400 shares at a total cost of $2.9 million and
an average cost of$32.66 per share. All repurchased shares under the 2014 program and the frst quarter 2015 program reverted to the
status ofauthorized but unissued shares.
NOTE 16. COMMITMENTS AND CONTINGENCTES
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 Iitigation 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.
C al ifo r n ia Refund Pro c ee ding
Recently, APX, a market maker in these proceedings in whose markets Avista Energy participated in the summer of 2000, has asserted
that Avista Energy and its other customer/participants may be responsible for a share of the disgorgement penalty APX may be found
to owe to the California parties. The penalty arises as a result of the FERC finding that APX committed violations in the Califomia
market in the summer of 2000. APX is making these assertions despite Avista Energy having been dismissed in FERC Opinion No.
536 from the on-going administrative proceeding at the FERC regarding potential wrongdoing in the Califomia markets in the summer
of 2000. APX has identified Avista Energy's share of APX's exposure to be as much as $16.0 million even though no wrongdoing
allegations are specifically attributable to Avista Energy. Avista Enerry believes its settlement insulates it from any such liability and
that as a dismissed party it.cannot be drawn back into the litigation. Avista Energy intends to vigorously dispute APX's assertions of
indirect liability, but cannot at this time predict the eventual outcome.
FERC FORM NO. 2/3.Q (REV 12.07)122.38
Name of Respondent
Avista Corooration
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015t44
Notes to Financial Statements
Pacific No rtlrw est Refund Proceeding
In July 2001, the FERC 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 flurding that the equities do not justify 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
3,2011, the FERC issued an Order on Remand. On April 5, 2013, 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 1, 2000 through and
including June 20, 2001 . The Order on Remand established an evidentiary, trial-type hearing before an ALJ, and reopened the record
to permit 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 demonstate that such activity directly affected
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 Pacihc 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 201 3.
On July 11,2012 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 has approved the settlements and they are
final. The remaining direct claimant against Avista Corp. and Avista Energy in this proceeding is the City of Seattle, Washington
(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 identifr 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 of substantive provisions of the FPA 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 FPA. On May 22,2015, the FERC issued its Order on
Initial Decision in which it upheld the ALJ's Initial Decision denying all of Seattle's claims against Avista Corp. and Avista Energy.
Seattle filed a Request for Rehearing of the FERC's Order on Initial Decision which was denied on December 31, 2015. Seattle
appealed the FERC's decision to the Ninth Circuit. The Company does not expect that this matter will have a material adverse effect
on its financial condition, results of operations or cash flows.
Sierrs CIub and Montana Environmental Information Center Complaint Against the Owners of Colstrip
On March 6,2013, the Sierra 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
Talen (formerly PPL Montana), Puget Sound Energy, Portland General Elechic Company, NorthWestern Energy and PacifiCorp. The
Complaint alleges certain violations of the Clean Air Act, including the New Source Review, Title V and opacity requirements.
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 1, 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.
On August 27,2014, the Plaintiffs filed a Second Amended Complaint. The Second Amended Complaint withdraws from the
FERC FORM NO.2/3-Q 1 122.39
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Report
2015tQ4
Notes to Financial Statements
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 Plaintiffs have since indicated that they do not
intend to pursue two of the seven projects, leaving a total of five projects remaining. A number of motions for summary judgment were
filed by both the Plaintiffs and the defendants. The Court issued its rulings on these motions and, as a result, only two projects remain
for trial. The Plaintiffs have filed objections to the order.
The case has been bifurcated into separate liability and remedy trials. The Court has set the liability trial date for May 3 I , 2016. No
date has been set for the remedy trial.
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 predict the outcome or determine whether it would have a material impact on the
Company.
Cobinel Gorge Total Dissolved Gas Abstemenl Plsn
Dissolved atmospheric gas levels (referred to as "TDG") in the Clark Fork River exceed state of Idaho and federal water quality
numeric standards downstream of 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. Under the terms of a gas supersaturation
mitigation plan, Avista is reducing TDG by constructing spill crest modifications on spill gates at the dam, and the Company expects to
continue spill crest modifications over the next several years, in ongoing consultation with key stakeholders. Avista Corp. cannot at
this time predict the outcome or estimate a range of costs associated with this contingency; however, 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 snd Noxon Ropids
In 1999, the United States Fish and Wildlife Service (USFWS) Iisted bull trout as threatened under the Endangered Species Act. In
2010, the USFWS issued a revised designation of critical habitat for bull trout, which includes the lower Clark Fork River. The
USFWS issued a final recovery plan in October 2015.
The Clark Fork Settlement 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 hout enhancement efforts. Fishway designs for Cabinet Gorge have been completed, and the
Company is developing construction cost estimates currently. The Company believes its ongoing efforts through the Clark Fork
Settlement Agreement continue to effectively address issues related to bull trout. Avista Corp. cannot at this time predict the outcome
or estimate a range of costs associated with this contingency; however, 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.
Co I lective B ar g ain in g A g r eemenls
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 expires in March 2016. In October 2015, a new collective bargaining agreement concerning
wages over the three-year period 20 l6 through 20 I 8 was approved by the local IBEW in Washington and Idaho. The new collective
bargaining agreement will be effective in March 2016.
A three-year agreement in Oregon, which covers approximately 50 employees, expires in March 2017.
FERC FORM NO. 2/3-Q (REV 1 122.40
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Report
2U5tA4
Notes to Financial Statements
There is a risk that if collective bargaining agreements expire and new agreements are not reached in each of our jurisdictions,
employees could strike. Given the magnitude of employees that are covered by collective bargaining agreements, this could result in
disruptions of our operations. However, the Company believes that the possibility of this occurring is remote.
Customer Information and lilork Management Systems Project Cosl Recovery
Over the past four years, Avista Corp. has invested significant capital into Project Compass. Project Compass was completed and went
into service during the frst quarter of 2015. As part of the Washington electric and natural gas general rate cases filed in February
2015 and the Oregon natural gas general rate case filed in May 2015, Avista Corp. requested the full recovery of the Washington and
Oregon share of the costs associated with this project.
On July 27 ,2075, the UTC Staff in the Company's electric and natural gas general rate cases filed responsive testimony. Included in
their testimony was a recommendation to disallow $12.7 million (Washington's share) of Project Compass costs primarily related to the
delay in the completion of the project. In a UTC order received in January 2016, the UTC approved the full recovery of Washington's
share of Project Compass costs with no disallowances.
In October 20 I 5, the OPUC staff filed testimony in the Company's natural gas general rate case which included a recommendation to
disallow $ I .2 million (Oregon's share) of Project Compass costs, similar to the initial recommendation in Washington. In an OPUC
order received in February 2016, the OPUC approved the full recovery of Oregon's portion of Project Compass costs, with no
disallowances.
Other Contingencies
In the normal course of business, the Company has various other legal claims and contingent mafiers 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 maffers 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, plants and wildlife that have either already
been added to the endangered species list, listed as "threatened" or petitioned for listing. Thus far, measures adopted and implemented
have had minimal impact on the Company. However, the Company will continue to seek recovery, through the ratemaking process, of
all operating and capitalized costs related to these issues.
Under the federal licenses for its hydroelectric projects, the Company is obligated to protect its property rights, including water rights.
In addition, the company holds additional non-hydro water rights. The state of Montana is examining the status of all water right claims
within state boundaries through a general adjudication, Claims within the Clark Fork River basin could adversely affect the energy
production of the Company's Cabinet Gorge and Noxon Rapids hydroelectric facilities. The state of Idaho has initiated adjudication in
northern Idaho, which will ultimately include the lower Clark Fork River, the Spokane River and the Coeur d'Alene basin. The
Company is and will continue to be a participant in these and any other relevant adjudication processes. The complexity of such
adjudications makes each unlikely to be concluded in the foreseeable future. As such, it is not possible for the Company to estimate the
FERC FORM NO. 2/3.Q (REV 12-07 122.41
Name of Respondent
Avista Corooration
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
Year/Period of Report
2015tQ4
Notes to Financial Statements
impact of any outcome at this time. The Company will continue to seek recovery, through the ratemaking process, of all operating and
capitalized costs related to this issue.
NOTE I7. 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 incurred by Avista
Corp. and the costs included in base retail rates. This difference in net power supply costs primarily results from changes in:
. short-term wholesale market prices and sales and purchase volumes,
. the level and availability of hydroelectric generation,
. the level and availability of thermal generation (including changes in fuel prices), and
r 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 $18.0 million as of December 31,2015 compared to a liability of $14.2 million as of
December 31, 2014, and these deferred power cost balances represent amounts due to customers.
Avista Corp. has a PCA mechanism in Idaho that allows it to modiff 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 $0.2 million as of December 31, 2015 compared to a regulatory asset of $8.3 million as of December 31,2014.
Natural Gas Cost Deferrols and Recovery Mecltunisms
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. Total net deferred natural gas costs to be refunded to customers were a liability of $ I 7.9 million
as of December 31,2015 compared to a liability of $3.9 million as of December 31,2014.
Decoupling and Earnings Sharing Mechanisms
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 included in a general rate case, which could be
caused by changes in weather, energy conservation or the economy. Generally, the Company's 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.
llashington Decoupling and Earnings Sharing
In Washington, the UTC approved the Company's decoupling mechanisms for electric and natural gas for a five-year period that
commenced January l, 2015. 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
FERC FORM NO.2/3.Q 12-07 122.42
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t20',t6
Year/Period of Report
2015tQ4
Notes to Financial Statements
rebate rate adjustments.
The decoupling mechanisms each include an after-the-fact earnings test. At the end ofeach calendar year, separate electric and natural
gas earnings calculations will be made for the prior calendar year. These earnings tests will reflect actual decoupled revenues,
normalized power supply costs and other normalizing adjustnents.
As of December 31, 2015, the Company had a total net decoupling surcharge (asset) of $10.9 million for WashinSon elechic and
natural gas customers and a liability (rebate to customers) for earnings sharing of $3.4 million for Washington electric customers.
Idaho Fixed Cost Adjustment (FCA) and Earnings Sharing Mechanisms
In ldaho, the IPUC approved the implementation of FCAs for electric and natural gas (similar in operation and effect to the
Washington decoupling mechanisms) for an initial term of three years, cornmencing on January 1,2016.
For the period 2013 through 2015, the Company had an after-the-fact eamings test, such that if Avista Corp., on a consolidated basis
for electric and natural gas operations in Idaho, eamed more than a 9.8 percent ROE, the Company was required to share with
customers 50 percent of any earnings above the 9.8 percent. There was no provision for a surcharge to customers if the Company's
ROE was less than 9.8 percent. This after-the-fact earnings test was discontinued as part of the settlement of the Company's 2015 Idaho
electric and natural gas general rates cases. As of December 3 I , 201 5 and December 31,2014, the Company had total cumulative
earnings sharing liabilities (rebates to customers) of $8.8 million and $10.1 million, respectively for electric and natural gas customers.
NOTE 18. SUPPLEMENTAL CASH FLOW INFORMATTON
?ol 5 )o14
Cash paid for interest
Cash paid (received) for income taxes
$72,405 $69,693
$(10,506) S4l,l54
FERC FORM NO.2/3.Q 12-071 122.43
This Page Intentionally Left Blank
t\ail te ot Kesp(Jlluent
Avista Corporation
tnrs Kepon rs:(1) [An Orisinal(2) l-lA Resubmission
uale or Kepon(Mo, Da, Yr)
o4t1512016
rea[renoq or r\.epqrr
End of 2015/Q4
Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization and Depletion
Line
No.
Item
(a)
Total Company
For the Current
QuarterfYear
1 UTILIry PLANT
2 ln Service
J Plant in Service (Classified)4,912,498,999
4 Property Under Capital Leases 6,729,064
5 Plant Purchased or Sold
b Completed Construction not Classified
7 Experimental Plant Unclassified
8 TOTAL Utility Plant (Total of lines 3 thru 7)4,919,228,063
I Leased to Others
10 Held for Future Use 3,966,915
11 Construction Work in Progress 1 90,1 08,665
12 Acquisition Adjustments
13 TOTAL Utility Plant (Total of lines 8 thru 12)5,1 13,303,643
14 Accumulated Provisions for Depreciation, Amortization, & Depletion 1,680,907,938
15 Net Utility Plant (Total of lines 13 and 14)3,432,395,705
'16 DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17 ln Service:
18 Depreciation 1,626,086,020
IY 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 54,821 ,918
22 TOTAL ln Service (Total of lines 18 thru 21)1,680,907,938
23 Leased to Others
24 Depreciation
25 Amortization and Depletion
to 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)
al Amortization of Plant Acquisition Adjustment
33 TOTAL Accum. Provisions (Should agree with line 14 above)(Total of lines 22, 26, 30, 31, and 32)1.680,907,938
FERC FORM NO.2 (12-96)Page 200
Name of Respondent
Avista Corporation
This Reoort ls:(1) ffiRn Originat(2) I-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
YeailPenoo oI Kepon
End of 2015/Q4
Summary of Utility Plant and Accumulated Provisions for Depreciation, Amortization and Depletion (continued)
Line
No.
Electric
(c)
Gas
(d)
Other (specify)
(e)
Common
(f)
3.525.164.547 962,527,501 424,806,951
4 286,715 858,864 5,583,485
5
6
7
8 3,s2s,45',t,262 963,386,365 430,390,436
o
10 3,776,330 190,585
11 152,073,992 13,516,794 24,517,879
12
13 3,681,301,584 977,093,744 454,908,315
14 1,264,628,194 317,998,694 98,281,050
15 2,416,673,390 659,095,050 356,627,265
18 1,247,691 ,281 316,058,415 62,336,324
21 16,936,912 1,940,280 35,944,726
22 'l ,264,628,1 93 317,998,695 98,281,050
24
25
26
28
29
30
32
33 1,264,628,193 317,998,695 98,281,050
FERC FORM NO.2 (12-96)Page 20'l
r\ame or Kesponoenl
Avista Corporation
lhts KeDon ls:(1) filnn originat(2) nA Resubmission
uate oI Kepofi(Mo, Da, Yr)
041't5t2016
Year/Period of Report
End of 2015/Q4
Gas Plant in Service (Accounts 101,102,103, and 106)
"l . Report below the original cost of gas plant in service according to the prescribed accounts.
2. ln addition to Account 1 01 , 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 accounts.
5. Classify Account 106 according to prescribed accounts, on an
estimated basis if necessary, and include the entries in column (c).Also to be included in column (c) are enhies 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 supplemental statement showing the account distributions of these tentative classifications in columns (c) and (d),
Line
No.
Account
(a)
Balance at
Beginning of Year
/h'l
Additions
/c)
1 INTANGIBLE PLANT
2 301 Orqanization
3 302 Franchises and Consents
4 303 MiscellaneouslntanqiblePlant 4,070,621 1,342,257
5 TOTAL lntangible Plant (Enter Total of lines 2 thru 4)4.070,621 1,342,257
6 PRODUCTION PLANT
7 Natural Gas Production and Gatherinq Plant
8 325.1 Producinq Lands
o 325.2 Producing Leaseholds
10 325.3 Gas Riohts
11 325.4 Rights-of-Way
12 325.5 Other Land and Land Riohts
13 326 Gas Well Structures
14 327 Field Comoressor Station Structures
15 328 Field Measuring and Regulating Station Equipmenl
16 329 Other Structures
17 330 Producino Gas Wells-Well Construction
18 331 Producing Gas Wells-Well Equipmenl
19 332 Field Lines
20 333 Field Compressor Station Equipment
21 334 Field Measuring and Regulating Station Equipment
22 335 Drillinq and Cleaninq 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 Riqhts
30 341 Structures and lmprovements
3'l 342 Extraction and Refininq Equioment
32 343 Pipe Lines
33 344 Extracted Products Storaqe Equioment
FERC FORM NO.2 (12-96)Page 204
Name of Respondent
Avista Corporation
This Reoort ls:(1) ffiRn originat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
Gas Plant in Service (Accounts '101,102,103, and 105) (continued)
ncluding the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of
\ccount t01 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 1 02, include in column (e) the
rmounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or
:redits 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
;ubaccount 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,
lnd date of transaction. lf proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give date of
;uch filinq.
Line
No.
Retirements
(d)
Adjustments
(e)
Transfers
/fl
Balance at
End of Year
(o)
2
3
4 942,550 4,470,328
(942,550 4.470,328
8
9
10
11
12
't3
14
15
to
17
'18
19
20
21
22
23
24
t7
tb
27
29
30
31
32
33
FERC FORM NO. 2 (12-96)Page 205
Name oI Kesponoent
Avista Corporation
tnrs Keoon ts:(1) fiRn originat(2) l-lA Resubmission
uale oI Kepon(Mo, Da, Yr)
04t15t2016
Yeazrenoo or Kepon
End of 20'15/Q4
Gas Plant in Service (Accounts 101,'102, 103, and 106) (continued)
Line
No.
Account
(a)
Balance at
Beginning of Year
/h\
Additions
1c\
34 345 CompressorEquipment
35 346 Gas Measurinq and Reoulatino Eouioment
Jb 347 Other Equipment
7.7 348 Asset Retirement Costs for Products Extraction Plant
38 TOTAL Products Ertraction 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 STOMGE AND PROCESSING PLANT
43 Underground Storage Plant
44 350.1 Land 407,111
45 350.2 Rights-of-Way 59,812
46 351 Structures and lmprovements 1,682,690 223,772
47 352 Wells 13,681 ,024 223.773
48 352.1 Storage Leaseholds and Riqhts 254,354
49 352.2 Reservoirs 1,667,492
50 352.3 Non-recoverable Natural Gas 5,810,31 1
51 353 Lines 't,106,781
52 354 Compressor Station Equipment 14,656,647 223,772
53 355 Other Equipment 458,1 85 223.773
54 356 Purification Equipment 403,712
55 357 Other Equipment 1,774,986 223.772
56 358 Asset Retirement Costs for Underqround Storaqe Plant
57 TOTAL Underground Storage Plant (Enter Total of lines 44 thru 41,963,'105 1 ,1 18,862
58 Other Storage Plant
59 360 Land and Land Riohts
60 361 Structures and lmprovements
61 362 Gas Holders
62 363 PurificationEquipment
bJ 363.1 Liquefaction Equipment
64 363.2 Vaporizing Equipment
65 363.3 Compressor Equipment
66 363.4 Measuring and Regulating Equipment
67 363.5 Other Equipment
68 363.6 Asset Retirement Costs for Other Storage Plant
69 TOTAL Other Storage Plant (Enter Total of lines 58 thru 68)
70 Base Load Liquefied Natural Gas Terminaling and Processing Plant
71 364.1 Land and Land Riohts
72 364.2 Structures and lmprovements
73 364.3 LNG Processinq Terminal Equioment
74 364.4 LNG Transportation Equipment
7(364.5 Measurinq and Reoulatino Eouioment
76 364.6 Compressor Station Equipmenl
77 364.7 Communications Eouioment
78 364.8 Other Equipment
79 364.9 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 206
Name of Respondent
Avista Corporation
This Reoort ls:(1) lXlAn Original(2) I-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
YearlPeriod of Report
End of 2015/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
36
37
38
39
40 7,628
41 7,628
44 407,111
45 59,812
46 2,268 2,268 't,906,462
47 13,904,797
48 254,354
49 1,667,492
50 5,8'r 0,31 1
51 1 , 106,781
E1 3,71 1)14,876,708
53 1,443 683,401
54 403,712
55 1.998.758
56
57 2,268 43,079.699
59
60
61
62
63
64
65
66
67
68
69
71
72
73
74
75
76
77
78
79
80
FERC FORM NO.2 (12-96)Page 207
Name oI Kesponoenl
Avista Corporation
I nts Kepon ,s:(1) [Rn Original(2) I--lA Resubmissibn
uale or f(epon(Mo, Da, Yr)
04t15t2016
Yeailt,enoo oI Kepon
End of 2015/Q4
Gas Plant in Service (Accounts 101 ll02, 103, and 1 06) (continued)
Line
No.
Account
(a)
Balance at
Beginning of Year
/h\
Additions
(c)
81 TOTAL Nat'l Gas Storage and Processing Plant (Total of lines 57,4'1,963,105 1,118,862
82 TRANSMISSION PLAN
83 365.1 Land and Land Riqhts
84 365.2 Rishts-of-Way
85 366 Structures and lmprovements
86 367 Mains
87 368 Compressor Station Equipment
88 369 Measuring and Regulating Station Equipment
89 370 CommunicationEquipment
90 371 Other Equipment
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 855,3't7 31 ,457
95 375 Structures and lmprovements 1 ,'1 35,565 197,827
96 376 Mains 425,897,6'13 37,847,636
97 377 Compressor Station Equipment
98 378 Measuring and Regulating Station Equipment-General 1 0, '1 99,1 't 8 423,507
99 379 Measuring and Regulating Station Equipment-City Gate 7,880,758 1,651,797
00 380 Services 255,486,916 22,316,711
01 381 Meters 104,152,189 7.882,260
02 382 Meterlnstallations
03 383 House Regulators
04 384 House Regulator lnstallations
05 385 lndustrial Measuring and Regulating Station Equipment 4.688.395 244,495
06 386 Other Property on Customers' Premises
07 387 Other Equipment 539
08 388 Asset Retirement Costs for Distribution Plant
09 TOTAL Distribution Plant (Enter Total of lines 94 thru 108)81 0,296,410 70,595,690
10 GENERAL PLANT
11 389 Land and Land Riqhts 1,327,029
12 390 Structures and lmprovements 5,761 ,699 86,765
'13 391 Office Furniture and Eouioment 624,640 20,269
14 392 TransportationEquipment 12,253,089 2,652,361
15 393 Stores Eouioment 141,498
t16 394 Tools, Shop, and Garage Equipment 5,955,544 367,787
117 395 LaboratoryEquipment 530,584 8,434
118 396 Power Operated Equipment 4,316,053 384,934
119 397 CommunicationEquipment 3,478,666
t20 398 MiscellaneousEquipment 2,367
121 Subtotal (Enter Total of lines 111 thru 120)34,391 ,1 69 3,520,550
122 399 Other Tangible Property
123 399. 1 Asset Retirement Costs for General Plant
t24 TOTAL General Plant (Enter Total of lines 121, 122 and 123)34,391,169 3,s20,550
125 TOTAL (Accounts 101 and 106)890,728,933 76,577,359
26 Gas Plant Purchased (See lnstruction 8)
127 (Less) Gas Plant Sold (See lnstruction 8)
t28 Experimental Gas Plant Unclassified
129 TOTAL Gas Plant ln Service (Enter Total of lines '125 thru 128)890,728,933 76,577,3s9
FERC FORM NO. 2 (12-96)Page
Name of Respondent
Avista Corporation
This Reoori ls:(1) finn Orisinat(2) l-lA Resubmission
Date of Report
(Mo, Da, Yr)
o4t15t2016
Year/Period of Reporl
End of 2Q15lQtl
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)
81 2,268 43.079.699
83
84
85
86
87
88
89
90
91
92
94 886,774
95 3,710 1,329.682
95 1,390,887 3,087 462,357,449
97
98 38,780 131,898 10,715,743
99 43,527 ( 131,898)( 3,087)9,354,043
00 456,588 277,347,039
01 166,372 111,868,077
02
03
04
05 4,932,890
06
07 539
08
09 2.099,864 878,792,236
11 1,320 1,325,709
12 5,848,464
13 10,577 634,332
14 687,878 14,217,573
15 't41,498
lo 58,314 2 6,265,019
17 107,604 431,414
18 ( 261)4,700,726
19 9,552 258 3,469,372
20 2.367
21 875.245 37,036.474
22
23
24 875.245 37.036,474
25 3.919,927 963,386,365
26
27
28
29 3,919,927 963,386,365
FERC FORM NO. 2 (12-96)Page 209
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn Orisinat(2) I-lA Resubmission
Date of Report(Mo, Da, Y0
04t15t2016
YeailPenoo ol Hepor
End of 2015/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 lo be Used
in Utility Service
(c)
Balance at
End of Year
(d)
1 Gas Distribution Mains and Services 03to1t2007 159,823
2 located in Coeurd'Alene, ldaho
3 Gas Distribution Mains and Services 07t01t2011 30,762
4 located in Coeur d'Alene, ldaho
5
6
7
8
I
10
11
12
13
14
15
't6
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
15 Total I 190,585
FERC FORM NO.2 (12-96)Page 2'l'4
Name of Respondent
Avista Corporation
This Reoort ls:(1) lx_.lAn Original(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t't512016
Year/Period of Repor
End of 2015/Q4
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.
Lrne
No.
Description of Project
(a)
Construction Work in
Progress-Gas
(Account 107)
(b)
Estimated Additional
Cost of Project
(c)
1 East Medford Reinforcement 4,797,215
2 Gas Revenue Blanket 1,513,280
3 Dollar Rd Service Center Addition and Remodel 1,210,047
4 Spokane St Bridge Gas Main 1 ,030,1 01
5 Minor Projects under $1,000,000 4,966,1 5 1 97,500,000
6
7
I Notes:
9 Estimated additional cost amounts represent a five year
10 budget total.
1'l
12
13
14
15
to
17
18
19
20
21
22
23
24
25
26
27
28
29
30
3'l
32
33
34
35
36
37
38
39
40
41
42
43
44
45 Total 13,516,794 97,500,000
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Report is:
(1) X An Originale\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
20151Q4
General Descriotion of Construction Overhead Procedure
1 . For each construction overhead explain: (a) the nature and extent of work, etc., the overhead charges are intended to cover, (b) the general
procedure for determining the amount capitalized, (c) the method of distribution to construction jobs, (d) whether different rates are applied to
different types of construction, (e) basis of differentiation in rates for different types of construction, and (0 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.
Construction costs with a direct relationship to new construction and capital replacement activities that cannot be clearly
identified with specific projects are charged to overhead pools. The established pools are:. Construction Overhead North Gas. Construction Overhead South Gas
Pool costs are allocated monthly to gas construction projects on a percent rate applied to direct project costs, excluding
AFUDC. Each pool's rate is calculated separately and applied only to the related gas construction projects for allocation.
Allowance for funds used during construction is calculated system wide using a rate that is equivalent to the allowed rate of
return approved in the latest rate order from the company's primary state commission (Washington State). For 2015,
Avista used a rate of 7.32%, which is the allowed Rate of Return contained in the Washington Utilities Transportation
Commission Final Order 05 date August 18,2014 for consolidated Dockets UE-140188 and UG-140189.
FERC FORM NO.2 1 218.1
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn Originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2016
YeailPenoo oI Kepon
End of 2015/Q4
General Description of Construction Overhead Procedure (continued)
COMPUTATTON OF ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION RATES
1 . For line (5), column (d) below, enter the rate granted in the last rate proceeding. lf not available, use the average rate earned during the preceding 3 years.
2. ldentify, in a footnote, the specific entity used as the source for the capital struclure figures.
3, lndicate, in a footnote, if the reported rate of retum is one that has been approved in a rate case, black-box settlement rate, or an actual 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 Debt S
(2) Short-Tenn lnterest s
(3) Long-Term Debt D d
(4) Prefened Stock P p
(5) Common Equity c c
(6) Totat Capitalization
(7) Average Construciion Work ln Progress Balance W
2. Gross Rate for Borrowed Funds s(SM/) + d[(D/(D+P+C)) (1-(SA /))]
3. Rate for Other Funds t1-(S^^/)l [p(P/(D+P+C)) + o(C(D+P+C))]
4. Weighted Average Rate Actually Used for the Year:
a. Rate for Borrowed Funds -
b. Rate for Other Funds -
2.58
4.74
FERC FORM NO.2 (REV 12-O7l Page 218a
Name of Respondent
Avista Corporation
This Report ls:(1) [An Original(2) l-lA Resubmission
Date of Report I Year/Period of Repor(Mo, Da, Yr) |o4l1slzo16 | eno of 2o15lQ4
Accumulated Provision for Depreciation of Gas Utility Plant (Account 108)
1. Explain in a footnote any important adjustments during year.
2. Explain in a footnote any difference between the amount for book cost of plant retired, line 10, column (c), and that reported for gas
plant in service, page 204-209, column (d), excluding retirements of nondepreciable property.
3. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when
such plant is removed from service. 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 classifications.
4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
5. AtlinesTandl4,addrowsasnecessarytoreportall data. Additional rowsshouldbenumberedinsequence,e.g.,T.0l ,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)
1 Balance Beginning of Year 296,850,488 296,8s0,48[
3 (403) Depreciation Expense 21,139,34C 21,1 39,34(
4 (403.1) Depreciation Expense for Assel Retirement Costs
((413) Expense of Gas Plant Leased to Others
b Transportation Expenses - Clearing 1,833,71C 1,833,71(
7 Other Clearing Acmunts
8 Other Clearing (Specify) (footnole details):( 808,214)( 808,214,
9
10 TOTAL Deprec. Prov. for Year (Total of lines 3 hru 8)22,164,838 22,164,83t
12 Book Cost of Plant Retired ( 2,979,2081 r,., ( , 2r97t,r6g,
13 Cost of Removal ( 215,4901 ( 215,490,
14 Salvage (Credit)12\,(12'
15 TOTAL Net Chrgs for Plant Ret. (Total of lines 12 thru 14)( 3,194,686)( 3,194,686:
16 Other Debit or Credit liems (Describe) (footnote details):122,224 | ..:122,224',
17
18 Book Cost of Asset Retirement Costs
19 Balance End of Year (Total of lines '1,'10,'15,16 and '18)315,698,414 3't5,698,4'14
Section B, BALANCES AT END OF YEAR ACCORDING TO
FUNCTIONAL CLASSIFICATIONS
21 Productions-Manufactured Gas
22 Production and Gathering-Natural Gas
23 Products Exkaction-Natural Gas
24 Underground Gas Storage 't4,482,360 14.482.36C
25 Other Storage Plant
26 Base Load LNG Terminaling and Processing Plant
27 Transmission
28 Distribution 286,927,35:286,927,353
29 General 14,288,701 14,288,701
30 TOTAL (Total of lines 21 thru 29)315,698,414 315,698,414
FERC FORM NO.2 (12-96)Page 219
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
0411512016
Year/Period of Report
20151Q4
FOOTNOTE DATA
@
Adjustment to beginning balance $448,214
FERC FORM NO.2 552.1
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) lX_lAn Original(2) I-lA Resubmission
Date of Report(Mo, Da, Yr)
o411512016
Year/Period of Report
End of 20i5lQzl
Gas Stored (Accounts :t17 .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), (f), (S), and (h) (such as to correct cumulative inaccuracies
of gas measurements), explain in a footnote the reason for the adjustments, the Dth and dollar amount of adjustment, and account charged or credited.
2. Report in column (e) all encroachments during the year upon the volumes designated as base gas, column (b), and system balancing gas, column (c),
and gas property recordable in the plant accounts.
3. State in a footnote the basis of segregation of inventory between current and noncurrent portions. Also, state in a footnote the method used to report
storage (i.e., fixed asset method or inventory method).
_tnE
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
(D
1 lalance at Eeginning of 6,992,07(28,731,49t 35,723,51/
2 ias Delivered to Storage 29,241,181 29,241,1Ei
3 ias Withdrawn from 45,'198,19,45,198,19
4 )ther Debits and Credits
5 lalance at End ol Year 6,992,07(12,774,48'19.766.56
5 )th 1.253,06(5,413,71 6,606,77(
7 \mount Per Dth 5.5801 2.35S'2.964!
FERC FORM NO. 2 (REV 04-04)Page
Name of Respondent
Avista Corporation
This ReDort ls:(1) fiRn origlnat(2\ [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t't5t2016
Year/Period of Report
End of 2015/Q4
lnvestments (Account 123, 124, and 1 36)
1. Report below investrnents in Accounts 123, lnvestrnents in Associated Companies, '124, Other lnvestments, and 136, Temporary Cash lnveslments.
2. Provide a subheading for each account and lisl thereunder the information called for:
Temporary Cash lnvestments, also may be grouped by classes.
(b) lnvestment Advances-Report separately for each person or company the amounts of loans or investment advances that are propedy includable in Account 1 23. lnclude advances
subjecttocurentrepaymentinAccountl45and146. Withrespecttoeachadvance,showwhethertheadvanceisanoteoropenaccount.
Line
No.
Description of lnveslmenl
(a)(b)
Book Cost at Beginning of Year
(lf book cost is different from
cost to respondent, give cost to
respondent in a footnote and
explain difference)
(c)
Purchases or
Additions
During the Year
(d)
1 lnvestrnent in Spokane Energy ( l 23000)500,000
2 lnvestment in Avista Capital ll (123010)11,547,000
2 Other lnvestrnent - WZN Loans Sandpoint (124350)61 ,177
4 Other lnvestment - Coli Cash Value (124600)17,877,754
5 Other lnvestment - Coli Bonowings (124610)( 17,877,754)
6 Other lnvestment - WZN Loans Oregon (124680)31 ,125
7 Other lnvestment - WNP3 Exchange Power (124900)79,626,000
I Other lnvestment - AMT WNP3 Exchange (124930)( 68,192,916)
I Temp Cash lnvestments (136000)15,508,864
10 Energy Commodity Contract (1 24020)
11
12
13
14
15
16
17
18
19
20
21
22
23
24
t5
t6
27
28
29
30
31
32
33
34
35
36
37
38
39
40
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) lIlAn Original(2\ l-lA Resubmission
Date of Report
(Mo, Da, Yr)
o4t1512016
Year/Period of Report
End of 2015/Q4
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 slate the name of pledges and purpose of the pledge.
number.
5. Report in mlumn (h) interest and dividend revenues from investments 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 difference between cost of the investment (or the other amount at which
canied in the books of account if different from cost) and the selling price thereof, not including any dividend or interest adjustment includible in column (h).
Line
No.
Sales or Other
Dispositions
During Year
(e)
PrincipalAmount 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 difierence)
(s)
Revenues for
Year
(h)
Gain or Loss from
lnvestment
Disposed of
(i)
1 500,000
2 11,547,000
?1,822 59,355
4 ( 1,839,750)19,717,504
(1,839,750 ( 19,717,504)
o 7,584 23.541
7 79,626,000
a 2,450,031 ( 70,642,947\
I 15,304,632 204,232
10 ( 14,694,374)14.694.374
11
12
13
14
15
16
17
18
19
?0
21
22
23
24
25
26
27
28
29
30
31
32
34
35
36
5t
38
39
40
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
o4115t2016
Year/Period of Report
End of 2015/Q4
lnvestments in Subsidiary Companies (Account 123.1)
1, Report below investments in Account 123.1, lnvestments in Subsidiary Companies.
2. Provide a subheading for each company and list thereunder the information called for below. Sub-total by company and give a total in columns (e), (0, (g) and (h).
(a) lnvestment 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. Reportseparatelytheequityinundistributedsubsidiaryeamingssinceacquisilion. Thetotal incolumn(e) shouldequal theamountenteredforAccount4lS.l.
Line
No.
Description of lnvestment
(a)
Date
Acquired
(b)
Date of
Maturity
(c)
Amount of
lnvestment al
Beginning of Year
(d)
1 lnvestment in Avista Capital 01t0'U1997 206,138,971
2 Avista Capital - Equity in Eamings ( 148,878,702)
2 lnvestment in AERC 07101t2014 89,816,380
4 AERC- Equity in Eamings 1,179,202
5
b
7
8
o
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
Jb
5t
38
39
40 TOTAL Cost of Account 123.1 $TOTAL 148,255,851
FERC FORM NO. 2 (12-96)Page 224
Name of Respondenl
Avista Corporation
This ReDort ls:(1) fiRn original(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2016
Year/Period of Report
End of 2015/Q4
nvestments in Subsidiary Companies (Account 123.1) (continued)
4. Designateinafootnote,anysecurities,notes,oraccounlsthatwerepledged,andstatethenameofpledgeeandpurposeofthepledge.
docket number.
6. Report in mlumn (f) interest and dividend revenues from investments, 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 (or the other amount at which
carried in the books of account if different from cost), and the selling price thereof, not including interest adjustments includible in mlumn (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 Investmenl
at End of Year
(s)
Gain or Loss from
lnvestment
Disposed of
(h)
1 206,138,971
2 4,856,990 ( 144,021,712)
3 89,816,380
4 6,307,795 '1,905,356 5,581,641
5
b
7
I
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
tt
28
29
30
31
32
,l,t
34
35
36
37
38
39
40 11,164,785 1,905,356 157,5"t5,280
FERC FORM NO.2 (12-95)Page 225
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This ReDort ls:(1) fiRn Original(2) I-lA Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Prepayments (Acct'165), Extraordinary Property Losses (Acct 182.1), Unrecovered Plant and Regulatory Study Costs (Acct 182.2)
PREPAYMENTS (ACCOUNT 1 65)
1. Report below the particulars (details) on each prepayment.
Line
No.
Nature of Paymenl
(a)
Balance at End
ofYear
(in dollars)
(b)
I Prepaid lnsurance 1,728,569
2 Prepaid Rents 10,740
3 Prepaid Taxes
4 Prepaid lnterest
R Miscellaneous Preoavments 8,841,625
6 TOTAL 10,580,934
FERC FORM NO.2 (12-96)Page 230a
Name of Respondenl
Avista Corporation
Thls Reoort ls:(1) fiRn originat(2\ l--lA Resubmission
Date of Report(Mo, Da, Yr)
o411512016
YeariPeriod of Repor
End of 2015/Q4
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 Account 182.3 or amounts less than $250,000, whichever is less) may be grouped by classes.
4. Report separately any'Defened 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, cou( decision).
Line
No.
Description and Purpose of
Other Regulatory Assets
(a)
Balance al
Beginning
Current
Quarterffear
(b)
Debits
(c)
Written off During
Ouarter/Year
Account
Charged
(d)
Written off
During Period
Amount Recovered
(e)
Wriften off
During Period
Amount Deemed
[Jnrecoverable
(0
Balance at End ol
Cunent
Quarterffear
G)
1 Reg Asset Post Rel Liab 235,758,10i 283 749,255 235,008,84{
2 Regulatory Asset FAS109 Utility Plant M,773,12,283 2,668,88(42jU.241
3 Regulatory Asset Lancaster Generation 1,246,66',t07 1.246,66i
4 Regulatory Asset FAS109 DSIT Non Plant 48,022,78 3,804,81 51,827,59:
5 Regulatory Asset FAS109 DFIT State Tax Cr 4,238.61 413,50r 4,652,121
6 Regulatory Asset FAS'109 WNP3 3,441,37,283 737,482 2.703,891
7 Regulatory AssetSpokane River Relicense 464,89i 107 78,736 386,11
8 Regulatory Asset-Spokane River PM&E 429,26,t57 t5,5tt 355,95(
o Regulatory AsselLake CDA Fund 9,01 5.461 +07 211 ,065 8,804,40,
10 Regulatory AssetLake CDA IPA Fund 2,000,00r 2.000.00(
11 Reg Asset-Decoupling Surcharge 468,89 468,89
12 Regulatory AsselDecoupling Surcharge 5,46(18(5,64(
13 Regulatory AssetLake CDA Def Costs 1,277,42:.r07 32,719 1,2M,70i
't4 Def CS2 & Colstdp 5,804,311 107 981,015 4,823,29{
15 Reardan Wind Generation 170,52 107 170,529
16 lD Wind Gen AFUDC 46.17 107 46,1 71
17 Regulatory Asset Wartsila Units 1 53,151 +07 1 53,1 56
18 MTM ST Regulatory Asset 29.640,37 244 1 2,380,197 17,260,17
19 MTM LT Regulatory Asset 24,483,17:7,936,54r 32,419,721
20 Regulatory Asset FAS 1 43 Asset Retirement
Obligation 2,301,25 574,641 2,875,89t
21 Reg AssetAN- CDA Lake Settlement 34,51 6,1 7l 107 884,08(33,632,09(
22 Reg Asset WA- CDA Lake Settlement 900.03 107 '152,118 747,911
23 Regulatory Asset Workers Comp 2,194,U:,r07 146,51 1 2.U7.831
24 Regulatory Asset lD PCA Deferral 1 932,88 932,88;
25 Regulatory Asset lD PCA Defenal 2 6,2'1 '1,801 i57 6,21 1,802
26 Regulatory Asset lD PCA Defenal 3 2,078,99 i57 2.078,991
27 Spokane River TDG 871,18,107 290,395 s80,78(
28 Settled lnterest Rate Swap Asset 33,964,531 6,821,97 40,786,51i
2S DSM Asset 4,603.411 3,167,511 107 4,603,41t 3,167,51 (
30 Unsettled lnterest Rate Swap Asset 77,062,51 6,91 0,26r 83,972,77i
31 Other Reg Assets 103,53i 117,67,221,21i
32
33
34
35
36
37
38
39
t0 Total 576,217,55i 30,680,01 33,896,502 573,031,07(
FERC FORM NO.2/3Q (REV 12-07)Page 232
Name of Respondent
Avista Corporation
This Reoort ls:(1) ffiAn Original(2) l-lA Resubmission
uate ot Hepon(Mo, Da, Yr)
o4t15t2016
Year/Period of Repor
End of !o'!$Qz[
Miscellaneous Deferred Debits (Account 186)
1. Report below the details called for concerning miscellaneous deferred debits.
2. For any defened debit being amortized, show period of amortization in column (a).
3. Minor items (less than $250,000) may be grouped by classes.
Line
No.
Description of Miscellaneous
Defened Debits
(a)
Balance at
Beginning
of Year
(b)
Debits
(c)
Credits
Account
Charged
(d)
Credits
Amounl
(e)
Balance at
End of Year
(D
1
2 Colstrip Common Fac.1 .'1 '10.99!406 1,1 10,999
3 Regulatory Asset-Mt Lease Pymt 631,1 97 540 360,684 270,513
4 Regulatory Asset-Mt Lease Pymt 1,353,216 540 676,632 676,584
5 Colstrip Common Fac.2,355,642 2,355,642
b Prepaid Airplane Lease LT 24,52t 417,438 931 441,966
7 Misc DD- Airplane Lease 21,69i 493,708 515,400
8 Plant Alloc of Clearing Jrl 3,530,342 1,642,293 1,888,049
I Misc Posting Suspense 43,1 37 72,159 VAR 1 1 5,295
10 Renewable Energy-Cert Fees 67,688 557 45,938 21,750
11 Nez Perce Settlemenl 150,325 557 5,212 145,1 13
12 Reg Asset lD-Lake CDA 178,106 506 30,975 147,131
13 Credit Union Labor & Expense 36,474 26,504 62,978
14 Misc Work Orders <$50,000 ( 109,222\23,1 30 VAR (86,092)
15 Subsidiary Billings 433,608 38,043 VAR 471,651
16 Misc Defened Debits (WA)16,568 16,568
17 Regulatory Assets Consv 1,878,235 276,346 2,154,581
18 Reg Asset-Decoupling deferred '13,305,979 13,305,979
't9 Optional Wind Power ( 21s,0561 8,821 909 (206,235)
20 Gas Telemetry equip 6,503 1,68(4,823
2'l Misc deferred debits/Res Acct 225,361 225,361
22 Mutual Aid Response PGE 81,208 81,20t
23 Deferred Project Compass (lD)3,346,902 3,346,902
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39 Miscellaneous Work in Progress
{0 Total 11,803,983 18,025,597 3,069,98:26,759,597
FERC FORM NO. 2 (12-95)Page 233
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn Originat(2\ I-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Accumulated Deferred lncome Taxes (Account 190)
1 . Report the informalion called for below mnceming the respondenfs accounting for deferred income taxes.
2. At Other (Specify), include defenals relating to other income and deductions.
3. Provide in a footnote a summary of the type and amount of deferred income taxes reported in the beginning-of-year and end-of-year balances for deferred income
taxes that the respondent estimates could be included in the development of jurisdictional recouse rates.
Line
No.
Account Subdivisions
(a)
Balance at
Beginning
of Year
(b)
Changes During
Year
Amounts Debited
to Account 4'10.1
(c)
Changes During
Year
Amounb Credited
to Account 41 1.1
(d)
2 Electric 8,884,982 ( 1,688,218)
3 Gas 1,147 ,644 397,117
4 Other (Define) (foohote details)113,228,848 ( I 1,483,s44)
5 Total (Total of lines 2 thru 4)123,261,474 ( 12,774,6451
o Other (Specify) (footnote details)
7 TOTAL Account 190 (Total of lines 5 thru 6)123,261,474 ( 12,774,645)
o Federal lncome Tax 123,261,474 ( 12,774,64s)
10 State lnmme Tax
11 Local lncome Tax
FERC FORM NO. 2 (REV 12-07)Page
Name of Respondent
Avista Corporation
This Report ls:(1) E]Rn Originat(2\ I-lA Resubmission
Date of Reporl(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
Accumulated Deferred lncome Taxes (Account 190) (continued)
Lrne
No.
Changes During
Year
Amounts Debited
to Account 410.2
(e)
Changes During
Year
Amounts Credited
to Account 41 1.2
(0
Adjustrnents
Debits
Account No.
(s)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
0
Adjustments
Credits
Amount
0)
Balance at
End of Year
(k)
2 10,573,200
3 750,527
4 124,712,392
5 136,036,1 19
6
7 136,036,1 19
I 136,036,1 1 9
10
11
FERC FORM NO. 2 (REV 12-071 235
Name of Respondent
Avista Corporation
This Report ls:(1) [nn Original(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Capital Stock (Accounts 201 and 204)
xefened stock.
2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.
3. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued.
Line
No.
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 Par Value 200,000,000
2 Restriced shares
4 TOTAL Common 200.000,000
(
b
7 Account 204 - Prefened Stock lssued 10,000,000
8
I Total Prefened 10,000,000
'10
11
12
IJ
14
15
16
tt
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
a1
34
2R
36
37
38
39
40
FERC FORM NO.2 (12-96)Page 250
Name of Respondent
Avista Corporation
This Reoort ls:(1) []An originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
YeailPenoo oI Kepon
End of 2015/Q4
Capital Stock (Accounts 201 and 204)
4. The identilication of each class of prefened stock should show the dividend rate and whether the dividends are cumulative or noncumulative.
5. State in a footnote if any capital stock thal has been nominally issued is nominally outstanding at end of year.
purpose of pledge.
Line
No.
Outstanding per Bal. Sheel
(total amt outstanding
without reduction for amts
held by respondent)
Shares
(e)
Outstanding per Bal.
Sheet
Amounl
(0
Held by
Respondent
As Reacquired
Stock (Acct 21 7)
Shares
(s)
Held by
Respondent
As Reacquired
Slock (Acct 21 7)
Cost
(h)
Held by
Respondent
ln Sinking and
Other Funds
Shares
(i)
Held by
Respondent
ln Sinking and
Other Funds
Amount
(i)
1
2 62,312,651 984,603,843
3
4 62,312,651 984,603,843
5
6
7
I
I
10
lt
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
?8
29
30
31
32
JJ
34
35
36
37
38
39
40
FERC FORM NO. 2 (12-96)Page 251
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) l--lA Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2016
Year/Period of Repor
End of 2015/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
wlth the balance sheet, page 1 12. Explain changes made in any account during the year and give the accounting entries effecting
such change.
(a) Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation.
(b) Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave
rise to amounts reported under this caption including identification with the class and series of stock to which related.
(c) Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits,
and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which
related.
(d) Miscellaneous Paid-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 ( 9,506,476)
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
JJ
34
35
36
37
38
39
40 Total ( 9,506,476)
FERC FORM NO.2 (12-95)Page 253
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn original(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 20'!ilQul
DrscouNT oN cAP|TAL 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.
luring the year and specify the account charged.
Line
No.
Class and Series of Stock
(a)
Balance at
End ofYear
(b)
2
J
4
5
6
7
8
10
1'1
12
13
14
TOTAL
CAP|TAL STOCK EXPENSE (ACCOUNT 214)
1 . Report the balance al end of year of capital stock expenses for each class and series of capital stock. Use as many rows as necessary to report all data. Number the rows in
sequence starting from the last row number used for Discount on Capital Stock above.
of capital stock expense and specify the account charged.
Line
No.
Class and Series of Stock
(a)
Balance at
End of Year
(b)
to Common Stock- no par f ,i.i1:]1;i:i1:ffi 2el3g2l 3l
17
18
19
20
21
22
23
?4
25
26
27
28
TOTAL ( 2s,238,213)
FERC FORM NO. 2 (12-s6)Page 254
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
20151Q4
FOOTNOTE DATA
'ScheAule Page:254
Beginning Balance S
(25,O79,1.231
lssuance of Common Stock S
55,902
Repurchase and Retirement of Common Stock S
31,833
Tax Benefit-Options Excercised S
(51,358)
Excess Tax Benefits on stock compensation S 1,831,678
Stock Compensation Accrual
Ending Balance
(6,027,1,45\
129,238,2L31
During 2015, the Company executed a stock repurchase program. Through LzlltlL5, the Company repurchased
89,400 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 (12-96)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)
o4t15t2016
Year/Period of Report
2U5tA4
Securities lssued or Assumed and Securities Refunded or Retired During the Year
1. Furnish a supplemental statement briefly describing security financing and refinancing transactions during the year and the accounting for
the securities, discounts, premiums, expenses, and related gains or losses. 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
forth the facts of the accounting clearly with regard to redemption premiums, unamortized discounts, expenses, and gain or losses relating to
securities retired or refunded, including the accounting forsuch amounts carried in the respondent's accounts atthe 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 consummaled.
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.
ln Decembet 2015, Avista Corp. issued $100.0 million of first mortgage bonds to three institutional
investors in a private placement transaction. The first mortgage bonds bear an interest rate of 4.37
percent and mature in 2045. 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-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. 15305, entered October 6,
2015;
Order of the Public Service Commission of the State of Montana, Default Order No. 4535
ln 2015, we issued $1.6 million of common stock under the employee stock ownership and long term
incentive plans. During 2015, the Company executed a stock repurchase program. Through
12131/15, the Company repurchased 89,400 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 (1 255.1
Name of Respondent
Avista Corporation
This Reoort ls:(1) lIlAn Original(2) I-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
YeailPenoo oI Kepon
End of 2015/Q4
Long-Term Debt (Accounts 22 222,223, and 2241
224, Other Long-Term Debt.
2. For bonds assumed by the respondent, include in column (a) the name ofthe issuing company as well as a description ofthe bonds.
3. ForAdvances from Associated Companies, reportseparately advances on notes and advances on open accounts. Designate demand notes as such. lnclude in column (a) names
of associated companies from which advances were received.
4. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certiflcales were issued.
Line
No.
Class and Series of Obligation and
Name of Stock Exchange
(a)
Nominal Date
of lssue
(b)
Date of
Maturity
(c)
Outstanding
(Total amount
oubtanding without
reduction for amts
held by respondent)
(d)
1 FMBS. SERIES A - 7,53% DUE 05/05/2023 05/06/ 1 993 05tos12023 5,500,000
2 FMBS. SERIES A -7,54%DUE5IO5I2O23 05/07/1 993 05t05t2023 1,000,000
3 FMBS - SERTES A - 7.39% DUE 5111t2018 05/1 1/1993 05111t2018 7,000,000
4 FMBS - SERIES A - 7.45% DUE 611112018 06/09/1 993 06t11t2018 1 5,500,000
5 FMBS. SERIES A - 7.18% DUE 811112023 o8t12/1993 08t11t2023 7,000,000
b ADVANCE:ASSOCIATED;AVISTA CAPITAL II (ToPRS)06/03/1 997 06t01t2037 51,547,000
7 FMBS.6.37% SERIES C 06/1 9/1 998 06t19t2028 25,000,000
I FMBS .5.45% SERIES 11t1812004 12t0112019 90,000,000
I
10 FMBS .6.25% SERIES 111',1712005 12t0112035 150,000,000
11 FMBS - 5.70% SERIES 12t15t2006 07t01t2037 150,000,000
tt FMBS - 5,95% SERIES 04t0212008 06t01t2018 250.000.000
13 FMBS - 5.125% SERIES 0912212009 04t01t2022 250,000,000
14 COI-SIRIP2010A'PCRBsDUE 2032, ,',., i,'i:r' .,r,'.,.' , .,,,:,.,., I ' ,12t15t2010 10to1t2032 66,700,000
15 COLSTRIP2010BPCRBsDUE2034 ' ''' r' '1 r: ''i:r' ' - r 1',:r'i'r ''::;,r';;i-!l 12t',t5t2010 03t01t2034 1 7,000,000
16 FMBS - 3.89% SERIES 12t20t2010 2t20t2020 52,000,000
17 FMBS - 5.55% SERIES 12t20t2010 2t20t2040 3s,000,000
18 4.45% SERTES DUE 12-14 -2041 12t1412011 2t14t2041 8s.000,000
19 4.23% SERTES DUE 11-29-2047 11t30t2012 1t29t2047 80,000,000
20 FMBS. O.84% SERIES ogt14t2013 08t1412016 90,000,000
21 FMBS- 4.11% SERIES 12t18t2014 121O112044 60,000,000
22 FMBS.4j3I%SEglEg:;1:r';,,,:i:,.iqir::.,.,1i.'1,''i11;r';1:1,,.. r:::l;iti:ri.rir::. :12t16t2015 12t01t2045 100,000,000
23
24
25
26
27
28
29
30
31
32
JJ
34
?E
36
37
38
39
40 TOTAL 1,588,247,000
FERC FORM NO. 2 (12-96)Page 256
Name of Respondent
Avista Corporation
This Reoort ls:(1) lI_lAn Original(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Long-Term Debt (Accounts 221,222,223, and 2241
5. ln a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respecl lo long-term advances, show for each company: (a)
principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates.
6. lf the respondent has pledged any of its long{erm debt securities, give particulars (details) in a footnote, including name
of the pledgee and purpose of the pledge.
7. lf 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.
difference between the total of column (f) and the total Accounl42T , lnterest on Long-Term Debt and Account 430, lnterest on Debt to Associated Companies.
9. Give details conceming any long{erm debt authorized by a regulatory commission but not yet issued.
Line
No.
lnterest for
Year
Rate
(in o/o)
(e)
lnterest for
Year
Amount
(f)
Held by
Respondent
Reacquired Bonds
(Acd222)
(s)
Held by
Respondent
Sinking and
Other Funds
(h)
Redemption Price
per $1 00 at
End of Year
(D
1 7.530 414,'150
2 7.540 75,400
7.390 517,300
4 7.4s0 1,154,7 50
5 7.1 80 502,600
6 1.289 473,352
7 6.370 1.592,500
o 5.450 4,905,000
I
10 6,250 9,375,000
11 5.700 8,550,000
12 5.950 14,875,000
13 s.125 '12,812,500
14 r,0.300 162,236 66,700,000
15 0,300 41,349 17,000,000
IO 3.890 2,022.800
17 5.550 1,942,500
18 4.450 3,782,500
19 4.230 3,384,000
20 0.840 756,000
21 4.110 2,466,000
22 4.370 194,222
23
24
25
26
28
29
30
31
32
JJ
34
35
36
37
38
39
40 69,999,159 83,700,000
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Report
20151Q4
FOOTNOTE DATA
256 Line No.: 14 Column: e
interest rate at 12131
: 256 Line No.: 15 Column: e
interest rate al12131
t9chedule Page: 256 Line No.: 6 Column: e
interest rate al12131
Upon issuance Avista Capital fI issued $1.5 million of Common Trust Securities to theCompany. InSecurities.
owed to third
December 2000, t.he Company purchased $1-0.0 mifl-ion of these Preferred Trust
The interesE for Ehe year disclosed in column (i) reffects the net amount
: 256 Line No.: 6 Column: a
rties.
Upon J-ssuance
Company. fnSecurities.
owed to third
December 2000, the Company
The int.erest for the year
Avista Capit.al II issued $l-.5 million of Common Trust Securities to tpurchased $10.0 million of these Preferred Trustdisclosed in column (i) refl-ects the net amountrties.
The Company reacquired this debt in 2010. These bonds have not been retired or canceled; the Company plans, based oni,ffilP,#"5# :
The Company reacquired this debt in2010. These bonds have not been retired or canceled; the Company plans, based on
liquidity needs and market conditions, to remarket these bonds at a future date.
,
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. 15305, entered October 6, 2015;
Order of the Public Service Commission of the State of Montana, Default Order No. 4535
FERC FORM NO.2 (r2-96)P 552,1
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This ReDort ls:(1) fiRn originat(2) l-lA Resubmission
Date of Report
(Mo, Da, Yr)
04t't512016
Year/Period of Report
End of 20'15/Q4
Unamortized Debt Expense, Premium and Discount on Long-Term Debt (Accounts 18'1,225,2261
1 . Report under separate subheadings for Unamortized Debt Expense, Unamortized Premium on Long-Term Debt and Unamortized Discount on Long-Term Debt, details of expense,
premium or discount applicable to each class and series of long{erm debt.
2. Show premium amounb by enclosing the figures in parentheses.
3. ln column (b) show the principal amount of bonds or other long{erm debt originally issued.
4. ln column (c) show the expense, premium or discount with respect to the amounl of bonds or other long-term debt originally issued.
Line
No.
Designailon of
Long-Term Debt
(a)
Principal Amount
oi Debt lssued
(b)
Total Expense
Premium or
Discount
(c)
Amortization
Period
Date From
(d)
Amortization
Period
Date To
(e)
1 FMBS - SERIES A .7.53% DUE 05/05/2023 5,500,00(42,712 05/06/1993 05t05t2023
2 FMBS - SERIES A .7 ,54O/O DUE 5IO5I2O23 1,000,00(7,766 05/07/1993 0510512023
3 FMBS - SERIES A - 7,39O/O DUE 51 1 1 12018 7,000,00(s4,364 0s/1 1/1993 0st11t2018
4 FMBS - SERIES A .7.45% DUE 611112018 15,500,00c 170,597 06/09/1993 06/1 1/201 8
5 FMBS . SERIES A - 7.18% DUE 811112023 7,000,00(54,364 08/1211993 0811112023
6 ADVANCE ASSOCIATED-AVISTA CAPITAL ll (ToPRS)s1,547,00(1,296,086 06/03/1 197 06t01t2037
7 FMBS - 6.370lO SERIES C 25,000,00(1s8,304 06/19/1998 06t1912028
8 FMBS.5.45% SERIES 90,000,00(1,432,081 11t18t2004 12tUnyq
I FMBS - 6.25% SERIES 1 50,000,00(2,1 80,435 11t17t2005 12101t2035
10 FMBS.5.7O% SERIES '150,000,00(4,924,304 1415n006 07t01t2037
11 FMBS.5.95% SERIES 250,000,00(3,081,419 0410212008 06/01/201 8
12 FMBS - 5.125% SERIES 250,000,00(2,859,788 091222009 04t012022
'13 FMBS - 3.89% SERIES s2,000,00(385,129 a2012010 1212012020
14 FMBS - 5.55% SERIES 35,000,00(258,834 2t2012010 12t2012040
15 Sho(-Term Credit Facility 3,959,449 2t14t2011 02t10nu7
16 4.45"/0 SERTES DUE 12-14-2041 8s,000,00(692,833 2i1412011 12!14t2041
17 4.23% SERTES OUE 11-29-2047 80,000,00(730,833 t30t2012 11t29t2047
18 0.84% Series Due 08-14-2016 90,000,00(5'15,369 08t14t2013 08t14t2016
19 4.11% Seires Due 12-1-2044 60,000,00(428,782 12t18t2014 12t01t2044
20 4.37% Series Due '12-1-2045 100,000,00(12t1612015 1AUD04s
21 Rathrum 2005 71,646 09/30/2005 12t01t2035
22 Debt Strategies 56,760 08/01/2035 08/01/2005
23 WKSI Shelf Registration Statement 16,064 03i01/201 3 03/01 /201 I
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 Respondent
Avista Corporation
This Reoort ls:(1) fiRn Originat(2\ l-lA Resubmission
Date of Report(Mo, Da, Yr)
o411512016
Year/Period of Report
End of 2015/Q4
Unamortized Debt Expense, Premium and Discount on Long-Term Debt (Accounts 181,225,2261
the date of the Commission's authorization of treatment other than as specitied by the Uniform System oi Accounts.
6. ldentity separately undisposed amounts applicable lo issues which were redeemed in prior years.
Debt-Credit.
Line
No.
Balance al
Beginning
of Year
0
Debits During
Year
(s)
Credits During
Year
(h)
Balance at
End of Year
(i)
I 1 1,983 1,424 1 0,559
2 2,179 259 1,920
3 7,429 2,175 5,254
4 23,884 6,824 1 7,060
(15,705 1,812 '13,893
o 315,333 14,015 301,318
7 7',t,236 5,277 65,959
I 437,377 93,536 343,84'l
9 1,523,947 72,569 1,451,378
10 3,636,631 161,032 3,475,599
11 1,035,559 303,090 732,469
12 1,668,777 227,561 1,441,216
13 231,715 38,619 1 93,096
14 224,330 8,628 215,702
15 2,309,836 s33,039 1,776,797
16 623,806 23,104 600,702
17 687,501 20,886 666,615
18 290,594 174,357 116,237
19 381,512 47,270 14,003 414,779
20 564,'t65 564,165
21 49,739 2,368 47,371
22 592 29 563
23 9,876 3,671 6,205
24
25
26
27
28
29
30
JI
32
33
34
35
36
37
38
39
40
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
Year/Period of Report
2015tQ4
FOOTNOTE DATA
Expenses may change as more invoices related to this issuance become known
FERC FORM NO.2 (12 552.1
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn Original(2\ l-lA Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
YeailHenoo or Kepor
End of 2015/Q4
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 amount of bonds ot 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 debited 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
(0
1 Misc Debt Repurchases I 05/1 0/1 993 ( 4,6e5,395 ( 871,755"(692,787)
2 ADVANCE ASSOCIATED.AVISTA CAPITAL II
(ToPRS)12t18t2000 10,000,00(1,769,12!1,094,01 1 1,045.207
3 Misc 2002 Repurchase 2t31t2002 10,000,00(2,228,15i 672,851 620,760
4 Misc 2003 Repurchase 2t31t2003 25,330,00(315,271 106,861 99,861
5 Misc 2004 Repurchase 2t31t2004 36,590,00(( 7,244,895 ( 1,083,6321 (785,339)
6 Misc 2005 Repurchase 2t31t2005 26,000,00(( 1,700,371 ( 687,9451 ( 637,031)
7 Misc 2006 Repurchase 2131t2006 6,875,00((483,582 ( 48,6s81 ( 32,733\
8 Misc 2008 Repurchase Costs 2t3112008 43,131 24,40C 21,705
I AVA Capital Trust lll (20221 o4t0'U2009 60,000,00(2,875,817 ( 1,681 ,3471 1,4s2,072)
10 COLSTRIP 2010A PCRBs DUE 2032 12t14t2010 66,700,00(3,709,174 ( 2,776,075)2,620,408)
11 COLSTRIP 2010B PCRBs DUE 2034 12t14t2010 17,000,00(1,916,297 ( 1,s84,4631 1,501 ,969)
12 FMBS - 7.25% SERTES (2040)12t20t2010 30,000,00(5,263,822 ( 4,561,9791 4,386,518)
13 FMBS - 6.125% SERTES (2020)12t20t2010 45,000,00(6,273,664 ( 3,764,1991 3,1 36,832)
14 KETTLE FALLS P C REV BONDS DUE 14 (2047)0612812012 4,'100,000 (105,020 ( 98,7691 ( 9s,769)
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 Respondent
Avista Corporation
This Reoort ls:(1) lxlAn Orisinal(2) l--lA Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2016
Year/Period of Repor
End of 2015/Q4
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)
Amount
(b)
1 Net lncome for the Year (Page 1 16)123,227,041
2 Reconciling ltems for the Year
J
4 Taxable lncome Not Reported on Books
5 ( 293,458,641)
6
7
I TOTAL ( 293,458,641)
I Deductions Recorded on Books Not Deducted for Return
10 167,01 8,431
11
12
13 TOTAL 167,018,431
14 lncome Recorded on Books Not lncluded in Return
15 32,011,483
16
17
18 TOTAL 32,011,483
19 Deductions on Return Not Charged Against Book lncome
20 ( 50,133,967)
21
22
23
24
25
26 TOTAL ( 50,133,967)
27 Federal Tax Net lncome 34,172,612
28 Show Computation of Tax:
29 State Tax @ 2%91 9,1 49
30 Federal Tax net income less state tax 35,091,761
3'1
32 prior year true ups ( 7,241,736)
33 cabinet gorge ( 154,305)
34 Total Federal Expense 4,886,075
35
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) []An olginal(2) [-lA Resubmission
Date of Report
(Mo, Da, Yr)
04115t2016
Year/Period of Reporl
End of 2015iQ4
axes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
1 . Give details of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and
other sales taxes which have been charged to the accounts to which the taxed material was charged. lf the actual or estimated amounts of such taxes are known, show the amounts in a
footnote and designate whelher estimated or actual amounts.
2. lnclude on this page, taxes paid during the year and charged direcl to fnal accounts, (not charged to prepaid or accred taxes). Enler the amounts in both columns (d) and (e). The
balancing of this
page is not af{ected by the inclusion of these taxes.
3. lnclude in column (d) taxes charged during the year, taxes charged to operations and otheraccounts through (a) accrals credited to taxes accrued, (b) amounts 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 ol 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
Iaxes Accrued
(b)
Balance at
Beg. of Year
Prepaid Taxes
(c)
1 FEDEML:
2 lncome Tax 2010 1.078,764
2 lncome Tax 201 1 34.876)
4 lncome Tax 20'12 2,014,544
5 lncome Tax 2013 ( 3,666,9671
6 lncome Tax 2014 ( 34,331,525)
7 lnmme Tax (Cunent)
a Prior Retained Eaminqs (2012)( 2,124,050"
9 Prior Retained Eamings (2013)483,257"
10 Prior Retained Earninqs (2014)470,244\
11 Cunent Relained EAminqs
12 Total Federal ( 38,017,611
13
14 STATE OF WASHINGTON
15 Property Tax (2014)14,264,301
16 Property Tax (2015)
17 Excise Tax (2010)22,495',,
18 Excise Tax (2014)2,768,507
19 Excise Tax (2015)
20 Natural Gas Use Tax 1,409
21 Municipal Occupation Tax 2,953,568
22 Community Solar
23 Sales & Use Tax (2013)1
24 Sales & Use Tax (2014)72.250
25 Sales & Use Tax (20'15)
26 Total Washinqton 20,037,541
27
28 STATE OF IDAHO:
29 lncome Tax (201 3)41,220
30 lncome Tax (2014)1 13,280
31 lncome Tax (2015)
32 Property Tax (20'13)719)
33 Property Tax (2014)3,397,575
34 Prope0 Tax (2015)
35 Sales & Use Tax (2014)5,6'17
36 Sales & Use Tax (2015)
37 KWH Tax (2012)1
38 KWH Tax (2014)27,143
20 KWH Tax (2015)
FERC FORM NO. 2 (REV 12-07)Page 262a
Name of Respondent
Avista Corporation
This Report ls:(1) ffinn Originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/O4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(contanued)
5. lf any tax (exclude Federal and Stale income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (a).
6. Enter all adjustments of the accrued and prepaid tax accounts in mlumn (f) and explain each adjustment in a footnote. Designale debit adjustments by parentheses.
authority.
number of the appropriate balance sheet plant account or subaccount.
9. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
1 0. ltems under $250,000 may be grouped.
11. Report in column (q) the applicable effective state income tax rate.
Line
No.
Taxes Charged
During Year
(d)
Taxes Paid
During Year
(e)
Adjustments
(0
Balance at
End ofYear
Taxes Accrued
(Account 236)
(s)
Balance at
End of Year
Prepaid Taxes
(lncluded in Acct 165)
(h)
1
2 1,078,764)
34,876
4 264,697 2,279,241)
5 '123,858 4,349,313 806,204
b 4,319,636)( 37,000,000)2j66,027 51 4,866
7 11,039,712 24,1 30,403 5,786,505)( 18,877,196)
6 2,124,050
v ( 483,257\
10 470,244
11 ( 1,920,588)( 1,920,s88)
12 5,188,043 ( 12,869,597)'19,9s9,971)
13
14
15 ( 150,566)14,117,079 (3,344)
to 1 5,566,000 6,438 15,s59,562
22,495
18 81.26'l 2,849,769 (1)
19 26,045,762 23,339,258 2,706,504
20 3,7'10 3,823 759)537
21 23,837,695 23,888,611 2,902,651
22 ( 105,669)( 105,669)
23 1)
24 71,906 344
25 '1,085,002 957,174 127,828
26 66,385,689 65,234,058 75s)21,188,412
27
28
29 41,220
30 ( 255,4821 ( 142,202\
31 497,695 555,000 57,305)
32 719
33 3,345,172 52,403
34 7,127,878 3,569,906 3,557,972
35 I 5,617
Jb 150,773 1 37,990 12,784
37 1)
38 5,049)22,094
39 393,696 369,501 24,195
FERC FORM NO.2 (REV 12-071 Page 263a
Name of Respondent
Avista Corporation
This ReDort ls:(1) lIlAn Original(2\ l--lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
1 . Give details of the combined prepaid and accrued tax accounts and show lhe total taxes charged to operations and other accounts during the year. Do not include gasoline and
other sales taxes which have been charged to the accounts to which the taxed material was chaEed. lf the actual or estimated amounts of such taxes are known, show the amounts in a
footnote and designate whether estimated or aclual amounts.
2. lnclude on this page, taxes paid during the year and charged direct to final accounb, (not charged to prepaid or accred taxes). Enter the amounts in both columns (d) and (e). The
balancing of this
page is not affected by the inclusion of these taxes.
3. lnclude in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accrals credited to taxes accrued, (b) amounts 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 accounls.
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.
DISTRIBUTION OF TMES CHARGED (Show utility department where applicable and account charged.)
Line
No.
Electric
(Account 408.1,
409.1 )
(D
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)
(l)
I
2
I
4 264,697
5 123,858
b 32 ( 4121044)
7 '13,555,299 4.221.438\318,627
o
I
10
11 1,920,588)
12 13,555,33'l ( 4,221,438\( 5,334,450)
'13
14
15 1 36,375)( 45,8721 31,682
to 1 2,373,000 3,1 57,000 36,000
17 22,495
18 ( 49,041)1,745)14,727
't9 20,166,813 s,79s,040 83,909
20 3,710
21 18,1 14,786 5,556,559
22
23 1
24
25
26 50,472,892 14,460,982 188,813
27
28
29
30 (204,386)51,096)
31 1,013,154 96,506
32 1 718
33
34 5,717,716 1,396,809 1 3,353
35
36 8)
37
38 5,049)
39 413,181
FERC FORM NO. 2 (REV 12-071 Page 262b
Name of Respondent
Avista Corporation
This Report ls:(1) [An Original(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t20't6
Year/Period of Report
End of 2015/Q4
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 adjustments of the accrued and prepaid tax accounts in column (f) and explain each adjustment in a footnote. Designate debit adjustrnents by parentfreses.
authority.
number of the appropriate balance sheet plant account or subaccount.
9. For any tax apportioned to more than one utllity department or account, state in a footnote lhe basis (necessity) of apportioning such tax.
10. ltems under $250,000 may be grouped.
1 1. Report in column (q) the applicable effective state income tax rate.
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)
Adjustment to Ret.
Eamings
(Account 439)
(o)
Other
(p)
State/Local
lncome Tax
Rate
(q)
1
2
3
4
5
6 1 98,624)
7 1,387,224
I
I
10
11
12 1,188,600
13
14
15
to
il
18 117,320
19
20
21 't66,349
22 105,669)
23
24
25 '1,085,002
26 1,263,002
27
28
29
30
31 61 1.965)
32
33
34
35 1
36 150,781
37
38
39 ( 19,485)
FERC FORM NO.2 (REV 12-071 Page 263b
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn originat(2) [-lA Resubmission
Date of Report
(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
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. of Year
Taxes Accrued
(b)
Balance at
Beg. of Year
Prepaid Taxes
(c)
1 Franchise Tax (2013)3,1281
2 Franchise Tax (20'14)1,650,689
3 Franchise Tax (2015)
4 Total ldaho 5,231,678
5
6 STATE OF MONTANA
7 lncome Tax (2011 & Prior)22,865
8 lncome Tax (2014)( .423,731
I lnmme Tax (2015)
10 Property Tax (2014)4,226,439
11 Property Tax (2015)
12 Colstrio Generatin Tax
13 KWH Tax (2014)263,479
14 KWH Tax (2015)
15 Consumer Council Tax
16 Public Commission Tax 19
17 Total Montana 4,089,080
18
19 STATE OF OREGON
20 lncome Tax (2012)99,999
21 lncome Tax (2014)655,1851
22 lncome Tax (20'15)
23 Prooertv Tax (201 3)( 2,086,1081
24 Prooerty Tax (2014)86,5481
t5 Property Tax (2015)
26 BETC Credit (20't0)( 17,483)
27 BETC Credit (2011)( 29,e62)
28 BETC Credit (2012)( 57,789)
29 Glendate Reoulatory Cr. 2009 ( 34,911)
30 Franchise Tax (2014)776,328
31 Franchise Fee (2015)
32 Total Oreoon ( 2,091,659)
33
34 STATE OF CALIFORNIA
35 lncome Tax (201 1)800)
36 lnmme Tax (2014)1,600)
37 Total Califomia (2,400)
38
39 MISCELLANEOUS STATES:
FERC FORM NO.2 (REV 12-07)Page 262a.'l
Name 01 Kespondent
Avista Corporation
lhrs Keoon ls:(1) fiAn originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2016
Year/Period of Report
End of 2015/Q4
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
During Year
(e)
Adlustmenb
(f)
Balance at
End ofYear
Taxes Accrued
(Account 236)
(s)
Balance at
End of Year
Prepaid Taxes
(lncluded in Acct 165)
(h)
( 3,128)
2 1,650,689
I 4,61 1,505 3,084,524 1,526,981
4 12,521,736 12,737,365 (1)5,016,048
(
b
7 22,865)
8 348,781 74.9s0)
I 1 08.607)305,000 ( 413,607)
10 4,217,182 9,257
11 8,484,422 4.250.729 4,233,693
12 3,965 3,965
13 263,479
14 1,1 38,846 898,734 240,112
15 7\61 23
16 95 54 60
17 9,844,712 9,939,204 3,994,588
18
19
20 ( 300,000)200,000)1
21 555,185 ( 100,000)
22 ( 378,037)( 378,037)
23 2,086,108
24 86,548
t3 2,722,850 5,445,699 2,722,849)
26 ( 17,483)
27 29,962)
28 ( 57,789)
29 34,9'l 1)
30 776,332 4
31 3,552,644 2,632,302 2l 920,340
32 8,325,298 8,6s4,333 ?( 2,420,691)
33
34
35 800
36 1,600
37 2,400
38
39
FERC FORM NO, 2 (REV 12-07)Page 263a.1
Name of Respondent
Avista Corporation
This Rer(1) 12!(2) T
rort ls:
An Original
A Resubmission
Date of Report(Mo, Da, Y0
04t15t2016
YeaillJenoo ol Kepon
End of 2015/Q4
Taxes Accrued, Prepaid and Charged During Year, Distribution of Taxes Charged (Show utility dept where applicable and acct charged)
(continued)
DISTRIBUTION OF TMES CHARGED (Show utility department where applicable and account charged.)
Line
No.
Electric
(Account 408.1,
409.1)
0
Gas
(Account 408.1,
409.1 )
fi)
Other Utility Dept.
(Account 408.1,
40e.1)
(k)
Other lncome and
Deductions
(Account 408.2,
409.2)
(|)
2 (720)(402\
3 3,476,436 1,118,268
4 10,410,333 2,560,085 14,063
5
6
7 ( 22,865)
8 348,781
o 125,077
10
11 8,484,422
12 3,965
13
14 1,138,846
'15 89
16 81
17 10,078,396
18
19
20 300,000)
21 138,796 416,389
22 780 2,342
23 910,347 1,175,761
24 '162,053 75,50s)
25 1,358,914 1,363,936
26
27
28
29
30 997
31 3,535,778
32 2,570,890 6,1 19,698
33
34
35 800
36 1,600
37 2,400
38
39
FERC FORM NO.2 (REV 12-O7l Page 262b.1
Name of Respondent
Avista Corporation
This Report ls:(1) [en Original(2) TIA Resubmission
uate oI Kepon(Mo, Da, Yr)
0411512016
Year/Period of Report
End of 2015/Q4
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)
Adjustment to Ret.
Eamings
(Account 439)
(o)
Other
(p)
State/Local
lncome Tax
Rate
(q)
1
2 1,',t22
2 16,802
4 ( 462,744\
5
6
7
8
I 233,684)
10
11
12
1a
14
15 141
16 l4
17 233,684)
18
19
20
21
22 ( 381,159)
24
25
26
27
28
29
30 997)
31 16,866
32 365,290)
33
34
35
Jb
?7
38
39
FERC FORM NO.2 (REV 12-07l'Page 263b.1
Name of Respondent
Avista Corporation
This Reoort ls:(1) [xJAn Original(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
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 at
Beg. ofYear
Prepaid Taxes
(c)
1 lncome Tax (2013)1
2 lncome Tax (2014)28,632
lncome Tax (2015)
4 Total Misc States 28,633
(
COUNTY & MUNICIPAL
7 WA Renewable Enerqy 561
I Vehicle Excise Tax 2015
o Misc.2
10 Total County (559)
tt
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 ( 10,72s,297)
FERC FORM NO, 2 (REV 12-07)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) []An orisinat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
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
During Year
(e)
Adjustrnents
0
Balance at
End of Year
Taxes Accrued
(Account 236)
(s)
Balance at
End ofYear
Prepaid Taxes
(lncluded in Acct 165)
(h)
1 1
2 28,532
3 646,729)646,729)
4 ( 646,729)( 618,096)
E
6
7 294,364)( 294,364)561 )
8 '13,850 ( 13,850)
I 65,975 65,800 759 939
10 ( 228,389)( 214,714)759 (13,472)
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
35
37
38
39 TOTAL 101,392,760 83,480,649 2 7,186,818
FERC FORM NO.2 (REV 12-O7l Page 253a.2
Name ot Hespondent
Avista Corporation
This Reoort ls:(1) fiAn originat(2) I-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
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.
Electric
(Account 408.'1,
409.1 )
(D
Gas
(Account 408.1
40e.1 )
(i)
Other Utility Dept.
(Account 408.'1,
409.1)
(k)
Other Income and
Deduclions
(Account 408.2,
409.2)
(D
1
2
3 176
4 176
5
6
7
8
I ( s41)
10 541 )
11
12
13
14
15
16
17
18
19
2A
21
22
23
24
25
26
27
28
29
30
3'l
32
33
34
35
Jb
7.7
38
39
TOTAL 87,087,842 18,921,727 5,131,939)
FERC FORM NO.2 (REV 12-07)Page 262b.2
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn Orisinat(2) J-lA Resubmission
Date of Reporl(Mo, Da, Yr)
04l't512016
Year/Period of Report
End of 2015/Q4
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)
Adjustment to Ret.
Eamings
(Account 439)
(o)
Other
(p)
State/Local
lncome Tax
Rate
(q)
1
2
3 646,90s)
4 (646,905)
E
6
7 294,364)
8
I 66,516
10 227.8481
11
12
13
14
15
16
17
18
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
TOTAL 51s,'131
FERC FORM NO.2 (REV 12-O7l Page 263b.2
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn originat(2) nA Resubmission
Date of Report(Mo, Da, Yr)
04115t2016
YearlPeriod of Repor
End of 2015/Q4
Miscel laneous Cu rrent and Accrued Liabil ities (Account 242)
't . 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.
Llne
No.
Item
(a)
Balance at
End of Year
(b)
1 MARGIN CALL DEPOSITS 470,000
2 FOREST USE PERMITS 3,196,',122
3 MIRABEAU ACCRUED RENT 643
4
5 FERC ADMIN FEE ACC 666,664
6 FERC ELEC ADMIN CHG 135,000
7 MT LEASE PAYMENTS 4.697,415
8 PAYROLL EQLZTN 18.822.859
I LOW INCOME ENERGY ASSIST 2,560,045
10 AVISTA GMNTS ENG SUSTAIN WSU 1 16,612
11 MOBIUS 100,000
12 WORKERS COMP LIABILITY 2,047,832
13 ACCOUNTS PAYABLE EXPENSE ACCRUAL SC 4,190,040
14 CURRENT PORTION. BENEFIT LIAB 7,463,567
15 CLEARING ACCOUNT 512,042
16 PREPAYMENTS 158,208
17 CUSTOMER ACCOUNTS 9,670,215
18 CURRENT PORTION OF PENSION 2,769,853
19
20
21
22
23
24
25
26
27
28
29
30
3l
32
33
34
35
36
37
38
39
40
41
42
43
44
45 Total 57,577 ,'.117
FERC FORM NO.2 (12-96)Page 268
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiAn originat(2) l-lA Resubmission
Date of ReDort
(Mo, Da, Yi)
04t15t2016
YearlPeriod of Repor
End of 2015/Q4
Other Deferred Credits (Account 253)
1
2
3
Report below the details called for concerning other deferred credits.
For any defened credit being amortized, show the period of amortization,
Minor items (less than $250,000) may be grouped by classes.
Line
No.Description of Other
Defened Credits
(a)
Balance at
Beginning
ofYear
(b)
Debit
Contra
Account
(c)
Debit
Amount
(d)
Credits
(e)
Balance at
End of Year
(0
1 Defer Gas Exchange (253028)1,124,990 1 1,125,000
2 Rathdrum Refund (2531 20)171,932 33,82i 138,1 10
3 NE Tank Spill (253130)26,528 23,298 3,230
4 Bills Pole Rentals (253140)31 '1,640 127,231 184,401
5 cR-cs2 GE LTSA (253150)1,164.668 1,164,66t
6 Credit Resource Actg 225,361 225,361
7 DOC EECE Grant 177,282 1 59,364 17,918
8 Defer Comp Retired Execs (253900)10,329 10,32!
9 Defer Comp Active Execs (253910)8.676,886 583,10€8,093,780
10 Executive lncent Plan (253920)140,000 140,000
11 Unbilled Revenue (253990)674,258 174,47(848,734
12 WA Energy Recovery Mechanism 4,224,011 7 ,311,17i '1.l,535,183
13 Misc Defened Credits 3,677,'156 903,71t 2,773,438
1A REC Deferral
15 Kettle Falls Diesel Leak 664,699 428,564 236,1 35
16 Energy Commodity (253020)14,694,374 14,694,374
17
'18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45 Total 21,269,740 3,6s9,469 22,180,032 39,790,303
FERC FORM NO.2 (12-96)Page
Name of Respondent
Avista Corporation
This Report ls:(1) EInn original(2) [-lA Resubmission
uale ot Kepon(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of &15/Qul
Accumulated Deferred Income Taxes-Other Property (Account 282)
1. Report the information called for below mnceming the respondents accounting for defened income taxes relating to property not subject to accelerated amorlization.
2. At Other (Specify), include defenals relating to other income and deductions,
Line
No.
Accounl SuMivisions
(a)
Balance at
Beginning
of Year
(b)
Amounts
Debited to
Account 410.1
(c)
Amounts
Credited to
Account 4,l1.1
(d)
2 Electric 389,834,1 32 53,938,541
3 Gas '141,409,318 ( s,797,368)
4 Other (Define) (footnote details)51,477,902 16,007,841
5 Total (Enter Total of lines 2 thru 4)582,721,352 64,149,014
6 Other (Specify) (footnote details)
7 TOTAL Account 282 (Enter Total of lines 5 thr 582,721,352 64,149,0'14
q Federal lnmme Tax 568,018,213 62,428,794
10 State lncome Tax 14,703,139 1,720,220
'11 Local lnmme Tax
FERC FORM NO.2 (REV 12-071 Page 274
Name ot F(espondent
Avista Corporation
This Report ls:(1) E]An originat(2) l-lA Resubmission
uate ot Kepon(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of !Ql!Qz[
Accumulated Deferred lncome Taxes-Other Property (Account 282) (continued)
3. Provide in a footnote a summary of the type and amount of defened income taxes reported in the beginning-otyear and endof-year balances for defened income taxes that the
respondent estimates could be included in the development of jurisdictional recourse rates,
Line
No.
Changes during
Year
Amounts Debited
to Account 4 10.2
(e)
Changes during
Year
Amounts Credited
to Account 41 1.2
(0
Adjustrnents
Debits
Acct. No.
G)
Adjustments
Debits
Amount
(h)
Adjustments
Credits
Account No.
(D
Adjustmenb
Credits
Amount
(i)
Balance at
End of Year
(k)
2 443,772,673
2 135,611,950
4 67,485,743
5 646,870,366
b
7 646,870,366
o 630,447,007
10 1 6,423,359
11
FERC FORM NO. 2 (REV 12-07)Page 275
Name of Respondent
Avista Corporation
This ReDort ls:(1) finn originat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
Accumulated Deferred lncome Taxes-Other (Account 283)
1. Report the information called for below concerning the respondents accounting for defened income taxes relating to amounts recorded in Account 283.
2. At Other (Specify), include defenals relating to other income and deductions.
Line
No.Account Subdivisions
(a)
Balance at
Beginning
ofYear
(b)
Changes During Year
Amounts
Debited to
Account 410.1
(c)
Changes During Year
Amounts
Credited to
Account 41 1.1
(d)
2 Electric 17,343,593 ( 869,714)
3 Gas 708,828)( 2,628,563)
4 Other (Define) (footnote details)208,219,022 7,992,949
5 Total (Total of lines 2 thru 4)224,853/87 4,494,672
6 Other (Specify) (footnote details)
7 TOTAL Account 283 (Total of lines 5 thru 224,853,787 4,494,672
I Federal lnmme Tax 224,853,787 4,494,672
10 State lnmme Tax
11 Local lncome Tax
FERC FORM NO. 2/3Q (REV 12.07)Page 276
Name of Respondent
Avista Corporation
This ReDort ls:(1) []Rn orisinat(2) l-lA Resubmission
uate ot Kepon(Mo, Da, Yr)
0/.t15t2016
YearPenoo oI h(epon
End of 20'15/Q4
Accumulated Deferred lncome Taxes-Other (Account 283) (continued)
3. Provide in a footnote a summary of the type and amount of defened inmme taxes reported in the beginningof-year and end{tyear balances for defened income taxes that the
respondent estimates could be included in the development of jurisdictional recourse rates.
Line
No.
Changes during
Year
Amounts Debited
to Account 4'10.2
(e)
Changes during
Year
Amounts Credited
to Account 41 1.2
(0
Adjustments
Debits
Acc,t. No.
(s)
Adjustments
Debits
Amount
(h)
Adjustmenb
Credits
Account No.
0
Adjustrnents
Credits
Amounl
0)
Balance at
End ofYear
(k)
2 ( 106,469)16,367,410
3 50,645 ( 3,286,746)
4 ( 5,173,655)3,691,659 214,729,975
5 ( s,173,6s5)3,635,835 227,810,639
6
7 ( s,173,6s5)3,635,835 227.8'10.639
9 ( 5,173,65s)3,635,835 227,810,639
10
11
FERC FORM NO. 2/3Q (REV 12-07)Page
This Page Intentionally Left Blank
r\ar ile ()r r(esponoenl
Avista Corporation
tnrs Kepoft ts:(1) $Rn original(2) I-lA Resubmission
uatE ur ntrPUIt
(Mo, Da, Yr)
04t15t2016
r garlTEilgq ur nsPur
End of 2015/Q4
Other Regulatory Liabil ities (Account 254)
1. I
inclu
2.t
3. I
4.1
comr
leport below the details called for concerning other regulatory liabilities which are created through the ratemaking actions of regulatory agencies (and not
jable in other amounts),
:or regulatory liabilities being amortized, show period of amortization In column (a).
vlinor 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 ilem, the regulatory citation where the respondent was directed to refund the regulatory liability (e.9. Commission Order, state
nission order, court decision).
Line
No.Description and Purpose of
Other Regulatory Liabilities
(a)
Balance al
Beginning of
Cunent
QuarterlYear
(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
(f)
Balance at
End of Cunenl
Ouarterffear
(s)
1 daho lnvestment Tax Credit (254005)10,462.03 825.971 1 1.288.009
2 )reqon BETC Credit (254010)831,1 3 zffi,7?1.099,872
3 Noxon ITC {254025\3.241.23 190 52,63i 3,188,s99
4 3ommunity Solar ITC (254035)190.41t 190,418
5 Settled lnt Rate Swaps (254090)16,423,55 428 2.1 52,00r 14,271,547
6 Jnsettled lnt Rate Swaps (254'100)460.31 176 437.521 22,ffi7
7 :AS 109 lnvest Credit (254180)63,90 190 1 6.181 47.712
I \ez Perce /254220\638.34 557 22,001 616,340
9 ldaho Earninqs Test (254229)4 ?75 41 407 3,51 5.35(i60,068
10 3PA Parallel Capacitv (254331)808,13 407 808,13{
11 3PA Res Exchanqe Q54345\1 65q 45 40't 1,230,83:428,624
12 )ther Requlatory Liabilities 1,841.65(1,841.650
13 /UA ERM 9.962.09 9,962,091 6,457,271 6,457,271
14 ID PCA 754,958 754,958
15 loseburo /Medford 8,72 8,729
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45 Total 18,831,35r 18,196,87:0 '10,339,001 40,976,481
FERC FORM NO. 2/3Q (REV 12-07)Page 278
Name of Respondent
Avista Corporation
This
(1)
(2)
pport ls:
IJAn Original
lA Resubmission
Date of Report(Mo, Da, Y0
o4t1512016
Year/Period of Report
End of 2015/Q4
Gas Operating Revenues
1 . Report below nafural gas operating revenues for each prescribed account total. The amounts must be consistent with the detailed data on succeeding pages.
2. Revenues in columns (b) and (c) include transition costs from upstream pipelines.
3. Other Revenues in columns (f) and (g) include reservation charges received by the pipeline plus usage charges, less revenues reflected in columns (b) through (e). lnclude in
columns (f) and (g) revenues for Accounts 480495.
Line
No.
Titie of Account
(a)
Revenues for
Transition
Costs and
Takeor-Pay
Amount for
Cunent Year
(b)
Revenues for
Transition
Costs and
Takeor-Pay
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)
1 480 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 Transfea
7 487 Forfeited Discounts
8 488 Miscellaneous Service Revenues
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 ofOthens
13 490 Sales of Prod. Ext. from Natural Gas
14 491 Revenues from Natural Gas Proc. by Others
15 492 lncidental Gasoline and Oil Sales
16 493 Rentfrom Gas Property
17 494 lnterdepartmental Rents
18 495 OtherGas Revenues
19 Subtotal:
20 496 (Less) Provision for Rate Refunds
21 TOTAL:
FERC FORM NO.2 (REV',l2-071 Page 300
Name of Respondent
Avista Corporation
This
(1)
(2\
i.eoort ls:
I_lAn Original
lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Gas Operating Revenues
4. lf increases or decreases from previous year are not derived kom previously reported ligures, explain any Inconsistencies in a footnote.
5. OnPagel0S,includeinformationonmajorchangesduringtheyear,newservice,andimportantrateincreasesordecreases.
6. Report the revenue from transportation services that are bundled with storage services as transportation service revenue.
Line
No.
Other
Revenues
Amount for
Cunenl Year
(0
Other
Revenues
Amount for
Previous Year
G)
Total
Operating
Revenues
Amount for
Current Year
(h)
Total
0perjating
Revenues
Amount for
Previous Year
0
Dekatherm of
Natural Gas
Amount for
Cunent Year
0)
Dekatherm ol
Natural Gas
Amount for
Previous Year
(k)
1 93,825,1 26 203,373,340 193,825,1 26 203,373,340 17,661,330 19,017,094
I I 03,32s,365 1 10,129,1 54 1 03,325,365 1 10,1 29,1 54 11,767 ,22s 12,742,856
2
4 208,1 28,979 230,997,1 69 208,1 28,978 230,997,1 69 83,1 31,135 56,068,962
5 281,994 337,273 281,994 337,273 33,451 41,051
b
7
8 80,331 '188,455 80,331 188,455
o
10
11
7,988,080 7,735,097 7,988,080 7,735,097 16,723,353 16,231,147
12
13
14
15
16 3.211 3j32 3,211 3,132
17
18 10,770,s92 5,329,746 10,770,593 5,329,746
'19 524,403,678 558,093,366 524,403,678 558,093,366
20 221,098 221,098
21 524,403,678 557,872,268 524,403,678 557,872,268
FERC FORM NO.2 (REV 12-07)Page 301
Name ol Kespondenl
Avista Corporation
This ReDort Is:(1) finn originat(2\ l_lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Repor
End of 2015/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.
Ltne
No.
Description of Transaction
(a)
Amount
(in dollars)
(b)
1 Commissions on Sale or Distribulion of Gas of Others
2 Compensation for Minor or lncidental Services Provided for Others
3 Profit or Loss on Sale of Material and Supplies not Ordinarily Purchased for Resale
4 Sales of Stream, Water, or Electricig, including Sales or Transfers to Other Departments
5 Miscellaneous Royalties
6 Revenues from Dehydration and Other Processing of Gas of Others except as provided for in the lnstructions to Account 495
7 Revenues for Right and/or Benefits Received from Others which are Realized Through Research, Development, and Demonstration Ventures
I Gains on Settlements of lmbalance Receivables and Payables
9 Revenues from Penalties eamed Pursuant to Tarifl Provisions, including Penalties Associated with Cashout Settlements
10 Revenues from Shipper Supplied Gas
1'l Other revenues (Specify):
12 Misc Bills 264.257
13 Defened Exchange Revenue 4,500,000
14 Decoupling Defened Revenue 6,004,224
15 DSM Lost Margin (Oregon)2,111
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 10,770,592
FERC FORM NO. 2 (12-96)Page
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn Orisinal(2\ [-lA Resubmission
Date of Report(Mo, Da, Yr)
o4115t2016
Year/Period of Report
End of 2015/Q4
Gas Operation and Maintenance Expenses
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
,|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
6 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
11 754 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 Ootal of lines 7 thru 17)0 0
19 Maintenance
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 (12-95)Page 317
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
0411512016
YearPenoo ol Kepon
End of 2015/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 Gas Shrinkage 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
4'.!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 Equipment 0 0
54 789 Maintenance of Compressor Equipment 0 0
55 790 Maintenance of Gas Measuring and Regulating Equipment 0 0
56 79'l 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
FERC FORM NO. 2 (12-96)Page 318
Name of Respondent
Avista Corporation
Thas ReDort ls:(1) finn original(2\ l_lA Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
59 C. Exploration and Development
60 Operation
61 795 Delay Rentals 0 0
62 796 Nonproductive 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
b9 800.1 Natural Gas Well Head Purchases, lntracompany Transfers 0 0
70 801 Natural Gas Fleld 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 319,282,550 416,037J20
74 804. 1 Liquefied Natural Gas Purchases 0 0
75 805 Other Gas Purchases 0 0
76 (Less) 805.1 Purchases Gas CostAdjustments ( 13,720,762)8,065.460
77 TOTAL Purchased Gas (Total of lines 68 thru 76)333,003,312 407,971,660
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 (12-96)Page 319
Name of Respondent
Avista Corporation
This Reoort ls:(1) []nn ortsinat(2) f-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2016
Year/Period of Report
End of 2fl5llQzl
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
86 808.1 Gas Withdrawn from Storage-Debit 45,1 98,1 94 23,222,085
87 (Less) 808.2 Gas Delivered to Storage-Credit 29,241 ,184 38,924,873
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
92 811 Gas Used for Products Extraction-Credit 446,368 1,602,046
93 812 Gas Used for Other Utility Operations-Credit 0 0
94 TOTAL Gas Used in Utility Operations-Credit (Iotal of lines 91 thru 93)446,368 1,602,046
95 813 Other Gas Supply Expenses 't,750,521 't,634,458
96 TOTAL Other Gas Supply Exp. (Total of lines 77,78,85,86 thru 89,94,95)350,264,475 392,301,284
97 TOTAL Production Expenses Clotal of lines 3, 30, 58, 65, and 96)350,264,475 392,301,284
98 2. NATURAL GAS STOMGE, TERMINALING AND PROCESSING EXPENSES
99 A. Underground Storage Expenses
100 Operation
101 814 Operation Supervision and Engineering 13,588 9,776
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
t06 819 Compressor Station Fuel and Power 0 0
107 820 Measuring and Regulating Station Expenses 0 0
108 821 Purification Expenses 0 0
t09 822 Exploration and Development 0 0
110 823 Gas Losses 0 0
111 824 Other Expenses 677,721 723,454
12 825 Storage Well Royalties 0 0
'13 826 Rents 0 0
114 TOTAL Operation (Total of lines of 101 thru 113)691,309 733,230
FERC FORM NO. 2 (12-96)Page 320
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn originat(2\ [-lA Resubmission
Date of Reporl
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
115 Maintenance
116 830 Maintenance Supervision and Engineering 0 0
117 831 Maintenance of Structures and lmprovements 0 0
1't8 832 Maintenance of Reservoirs and Wells 0 0
'1 19 833 Maintenance of Lines 0 0
120 834 Maintenance of Compressor Station Equipment 0 0
121 835 Maintenance of Measuring and Regulating Station Equipmenl 0 0
122 836 Maintenance of Purificatlon Equipment 0 0
123 837 Malntenance of Other Equipment 648,898 661,095
124 TOTAL Maintenance Ootal of lines 1 16 thru 123)648,898 661,095
125 TOTAL Underground Storage Expenses (Total of lines 1 14 and 124)1,340,207 1,394,325
126 B. Other Storage Expenses
127 Operation
128 840 Operation Supervision and Engineering 0 0
29 841 Operation Labor and Expenses 0 0
130 842 Rents 0 0
131 842.1 Fuel 0 0
32 842.2 Power 0 0
133 842.3 Gas Losses 0 0
134 TOTAL Operation (Total of lines 1 28 thru 133)0 0
135 Maintenance
'136 843.1 Maintenance Supervision and Engineering 0 0
137 843.2 Maintenance of Structures 0 0
138 843.3 Maintenance of Gas Holders 0 0
''t39 843.4 Maintenance of Purification Equipment 0 0
140 843.5 Maintenance of Liquefaction Equipment 0 0
't41 843.6 Maintenance of Vaporizing Equipment 0 0
142 843.7 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
145 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
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiAn Orisinal(2\ [-lA Resubmission
Date of Report I Year/Period of Report(Mo, Da, Yr) Io4t1st2o16 | eno ot 2otslQ4
Gas Operation and Maintenance Expenses(continued)
_tne
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
47 C. Liquefied Natural Gas Terminaling and Processing Expenses
48 Operation
149 844.1 Operation Supervision and Engineering 0 0
150 844.2 LNG Processing Terminal Labor and Expenses 0 0
151 844.3 Liquefaction Processing Labor and Expenses 0 0
52 844.4 Liquefaction Transportation Labor and Expenses 0 0
153 844.5 Measuring and Regulating Labor and Expenses 0 0
154 844.6 Compressor Station Labor and Expenses 0 0
t55 844.7 Communication System Expenses 0 0
156 844.8 System Control and Load Dispatching 0 0
157 845.1 Fuel 0 0
158 845.2 Power 0 0
159 845.3 Rents 0 0
160 845.4 Demurrage Charges 0 0
161 (less) 845.5 Wharfage Receipts-Credit 0 0
162 845.6 Processing Liquefied or Vaporized Gas by Others 0 0
163 846.1 Gas Losses 0 0
164 846.2 Other Expenses 0 0
165 TOTAL Operation (Total of lines '149 thru 164)0 0
166 Maintenance
167 847.1 Maintenance Supervision and Engineering 0 0
168 847.2 Maintenance of Structures and lmprovements 0 0
169 847.3 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
172 847.6 Maintenance of Compressor Station Equipmenl 0 0
173 847.7 Maintenance of Communication Equipment 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
177 TOTAL Natural Gas Storage (Total of lines 125, 146, and 176)1,340,207 1,394,325
FERC FORM NO. 2 (12-96)Page 322
Name ot Hespondenl
Avista Corporation
This Reoort ls:(1) []nn originat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
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
180 850 Operation Supervision and Engineering 0 0
181 851 System Control and Load Dispatching 0 0
182 852 Communication System Expenses 0 0
183 853 Compressor Station Labor and Expenses 0 0
184 854 Gas for Compressor Station Fuel 0 0
185 855 Other Fuel and Power for Compressor Stations 0 0
186 856 Mains Expenses 0 0
187 857 Measuring and Regulating Station Expenses 0 0
188 858 Transmission and Compression of Gas by Others 0 0
189 859 Other Expenses 0 0
190 860 Rents 0 0
191 TOTAL Operation (Total of lines 180 thru 190)0 0
192 Maintenance
193 861 Maintenance Supervision and Engineering 0 0
194 862 Maintenance of Structures and lmprovements 0 0
"t95 863 Maintenance of Mains 0 0
196 864 Maintenance of Compressor Station Equipment 0 0
197 865 Maintenance of Measuring and Regulating Station Equipment 0 0
198 866 Maintenance of Communication Equipment 0 0
199 867 Maintenance of Other Equipmenl 0 0
200 TOTAL Maintenance (Total of lines 193 thru 1 99)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 2.335.426 2,231,329
205 871 Distribution Load Dispatching 0 0
206 872 Compressor Station Labor and Expenses 0 0
zo7 873 Compressor Station Fuel and Power 0 0
FERC FORM NO. 2 (12-96)Page 323
Name of Respondent
Avista Corporation
lnrs Heoon ls:(1) finn original(2) [-lA Resubmission
uale oI Kepon(Mo, Da, Yr)
04t1s12016
Year/Period of Report
End of 2015/Q4
Gas Operation and Maintenance Expenses(continued)
Line
No.
Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
208 874 Mains and Services Expenses 5,809,786 5,050,253
209 875 Measuring and Regulating Station Expenses-General 192,859 227,487
210 876 Measuring and Regulating Station Expenses-lndustrial 8,087 6,093
211 877 Measuring and Regulating Station Expenses-City Gas Check Station 131 ,087 168,066
112 878 Meter and House Regulator Expenses 1,069,806 821,734
213 879 Customer lnstallations Expenses 3,226,050 2,770,677
214 880 Other Expenses 3,026,742 2,956,344
215 881 Rents 57,176 50,086
216 TOTAL Operation (Total of lines 204 thru 215)15,857,019 14,282,069
217 Maintenance
218 885 Maintenance Supervision and Engineering 179.467 202,495
219 886 Maintenance of Structures and lmprovements 0 0
220 887 Maintenance of Mains 2,552,162 3,689,559
221 888 Maintenance of Compressor Station Equipment 0 0
222 889 Maintenance of Measuring and Regulating Station Equipment-General 531 ,220 408,967
223 890 Maintenance of Meas. and Reg. Station Equipment-lndustrial 240,023 306,081
224 891 Maintenance of Meas. and Reg. Station Equip-City Gate Check Station 118,017 86,733
225 892 Maintenance of Services 2,688,703 2,624,504
226 893 Maintenance of Meters and House Regulators 2,739,937 2,473,195
227 894 Maintenance of Other Equipment 349,692 359,692
228 TOTAL Maintenance (Total of lines 218 thru 227)9,399,221 10,'t51 ,226
229 TOTAL Distribution Expenses (Total of lines 216 and 228)25,256,240 24,433,295
230 5, CUSTOMER ACCOUNTS EXPENSES
231 Operation
232 901 Supervision 310,965 288,098
233 902 Meter Reading Expenses 2,232,796 2,032,328
234 903 Customer Records and Collection Expenses 7,748,363 7,431,401
FERC FORM NO.2 (12-96)Page 324
Name of Respondent
Avista Corporation
This Reoort ls:(1) SRn Originat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04115t2016
Year/Period of Report
End of 2015/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 2,708,708 2,448.316
236 905 Miscellaneous Customer Accounts Expenses 234,815 175,445
237 TOTAL Customer Accounts Expenses (Total of lines 232 thru 236)13,235,647 12,375,588
238 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
239 Operation
240 907 Supervision 0 0
241 908 Customer Assistance Expenses 7,622,111 7,161,608
242 909 lnformational and lnstructional Expenses 886,365 920,1 94
243 910 Miscellaneous Customer Service and lnformational Expenses 95,402 158,451
244 TOTAL Customer Service and lnformation Expenses (Total of lines 240 thru 243)8,603,878 8,240,253
245 7. SALES EXPENSES
246 Operation
247 911 Supervision 0 0
248 912 Demonstrating and Selling Expenses 0 0
249 913 Advertising Expenses 0 0
250 916 Miscellaneous Sales Expenses 0 0
251 TOTAL Sales Expenses (Total of lines 247 thru 250)0 0
252 8. ADMINISTRATIVE AND GENERAL EXPENSES
253 Operation
254 920 Administrative and General Salaries 12,117j28 9,505,163
255 921 Office Supplies and Expenses 1,634,570 1,766,3'.12
256 (Less) 922 Administrative Expenses Transferred-Credit '18,378 20,731
257 923 Outside Services Employed 3,629,636 4,655,459
258 924 Property lnsurance 467.995 485,783
259 925 lnjuries and Damages 1,353,757 't,641,068
260 926 Employee Pensions and Benefits 671 ,836 719,807
261 927 Franchise Requirements 0 0
262 928 Regulatory Commission Expenses 2,481 ,480 2,081,530
263 (Less) 929 Duplicate Charges-Credit 0 0
264 930. 1 General Advertising Expenses 878 73
265 930.2Miscellaneous General Expenses 1,662,443 1,485,418
266 931 Rents 353,710 302,200
267 TOTAL Operation Clotal of lines 254 thru 266)24,355,055 22,622,O82
268 Maintenance
269 932 Maintenance of General Plant 3,826,155 3.600.782
270 TOTAL Administrative and General Expenses (Total of lines 267 and 269)28,181,210 26,222,864
271 TOTAL Gas O&M Expenses (Iotal of lines 97,177,201 ,229,237,244,25'l , and 270)426,881,657 464,967,609
FERC FORM NO. 2 (12-95)Page 325
Name of Respondent
Avista Corporation
This Reoort ls:(1) []nn orisinat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Gas Used in Utility Operations
1. Report below details of credits during the year to Accounts Sl0, Sl l, and S l2,
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 mlumn (c) the Dth of gas
used, omifting 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
Amount of
Credit
(in dollars)
(d)
Natural Gas
Amount of
Credit
(in dollars)
(d)
810 Gas Used for Compressor Station Fuel - Credit 804 2,175,486
2 81 1 Gas Used for Products Extraction - Credil 811 2,894,933 446,368
3 Gas Shrinkage and Other Usage in Respondent's
Ovn Processino
4 Gas Shrinkage, etc. for Respondents Gas
Processed by Others
5 812 Gas Used for Other Utility Operations - Credit
(Repo( separately lor each principal use. Group
minor uses.)
6
7
I
o
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25 Total s,070,419 446,368
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)
o4t1512016
Year/Period of Report
2015tQ4
FOOTNOTE DATA
tSchedule Page: 331 Line No.:1 Column: d 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 of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2\ [-lA Resubmission
Date of Report(Mo, Da, Yr)
o4115t2016
YeailPenod oI Kepon
End of zEllllQ!!
Other Gas Supply Expenses (Account 81 3)
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)
1 Gas Resource Manaoement
2 Labor 791,056
2 Labor Loadinq 667,312
4 Other Expenses (Professional Services, Travel, Transportation, Oflice Supplies, Traininq)143.124
5
6 Regulatory Affairs
7 Labor 7,939
8 Labor Loading 6,781
9 Other Expenses (Travel, Transportation, Gas Technology lnstitute Payments)134,309
10
11
12
13
14
15
16
17
'18
19
20
21
22
23
24
25 Total 1,750.521
FERC FORM NO. 2 (12-96)Page 334
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) nA Resubmission
uate oI h{epon(Mo, Da, Yr)
0411512016
Year/Period of Report
End of 20'15/Q4
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 ilems. 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.341,750
2 Experimental and general research expenses.
a. Gas Research lnstitute (GRl)
b. Other
3 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 142.773
4 Community Relations 36,686
5 Director Expenses 399,068
b Education and information 9,602
7 Ratinq aqencv fees 68,856
8 Aircraft Operation Fees 77,157
9 Misc general expenses > 5k 296,932
10 Misc general expenses < 5k 289,619
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25 Total 1,662,443
FERC FORM NO. 2 (12-96)Page 335
Name of Respondent
Avista Corporation
lhrs Keoon ls:(1) fiAn originat(2) [-lA Resubmission
Date of Report I YearlPeriod of Report(Mo, Da, Yr) |o4t1st2o16 | eno of 2o15tQ4
Depreciation, Depletion and Amortization of Gas Plant (Accts 403,4O4.'l, 404.2,404.3,405) (Except Amortization of
Acouisition Adiustments)
;ubaccount or functional classifications other than those pre-prinled in column (a). lndicate in a footnote the manner in which column (b) balances are
Section A. Summary of Depreciation, Depletion, and Amortization Charges
Line
No.Functional Classification
(a)
Depreciation
Expense
(Account 403)
(b)
Amortization
Expense for
Asset
Retirement
Costs
(Account
403.1) (c)
Amoriization and
Depletion of
Producing Natural
Gas Land and Land
Righb
(Acmunt 404.1)
(d)
Amortization of
Underground Storage
Land and Land
Rrghts
(Acmunt 404.2)
(e)
lntangible plant 227
2 Production plant, manufactured gas
3 Production and gathering plant, natural gas
4 Products extraction plant
5 Underground gas storage plant 740,s49
6 Other storage plant
7 Base load LNG terminaling and processing plant
8 Transmission plant
o Distribution plant 1 9,667,1 83
10 General plant 731,608
11 Common plantgas 5,454,239 7,737
12 TOTAL 26,593,579 7,964
FERC FORM NO. 2 (12-96)Page 336
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn originat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2016
Year/Period of Report
End of 2015/Q4
Depreciation, Depletion and Amortization of Gas Plant (Accts 403,404.1,404.2,404.3,405) (Except Amortization of
Acquisition Adiustments) (continued)
depreciation charges, show in a footnole any reyisions 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-term
Gas Plant
(Account 404.3)
(f)
Amortization of
Other Gas Plant
(Account 405)
(s)
Total
(b to g)
(h)
Funclional Classification
(a)
1 447,074 447,301 lntangible plant
2 Production plant, manufactured gas
J Production and gathering plant, natural gas
4 Products extraction plant
5 740,549 Underground gas storage planl
b Other storage plant
7 Base load LNG terminaling and processing planl
o Transmission plant
q 19,667,183 D'stribution plant
10 42,98€774,594 General planl
11 4,525,983 9,987,959 Common plant{as
12 5,016,041 3't ,617,s86 TOTAL
FERC FORM NO.2 (12-95)Page 337
Name ol Kesponc,ent
Avista Corporation
This Reoort ls:(1) []Rn orisinal(2) J-lA Resubmission
Date of Report I Year/Period of Report(Mo, Da, Yr) |o4l1st2o16 | Eno ot 2o15tQ4
Depreciation, Depletion and Amortization of Gas Plant (Accts 403,404.1,404.2,404.3,405) (Except Amortization of
Acquisition Adjustments) (continued)
4. Add rows as necessary to completely report all data. Number the additional rows in sequence as 2.0'1, 2.02, 3.01, 3.02, etc.
Section B. Factors Used in Estimating Depreciation Gharges
Line
No.Functional Classifi cation
{a}
Plant Bases
(in thousands)
/bl
Applied Depreciation
orAmortization Rates
(percent)
lcl
1 Produclion and Gatherinq Planl
2 Offshore (footnote details)
3 Onshore (footnote details)
4 Underground Gas Storage Plant (foolnote details)
5 Transmission Plant
6 Offshore (footnote details)
7 Onshore (footnote details)
8 General Plant (footnote details)
9
10
11
12
13
14
15
FERC FORM NO.2 (12-96)Page 338
Name of Respondent
Avista Corporation
This Reoort ls:(1) []Rn orisinal(2) [-lA Resubmission
uate oI Hepon(Mo, Da, Yr)
o4t15t2016
YearlPeriod of Report
End of 2015/Q4
Particulars Concerning Certain lncome Deductions and lnterest Charges Accounts
Report the in{ormation specified below, in the order given, for the respective income deduction and interest charges accounls.
period of amoilzation.
may be grouped by classes within the above accounts.
(c) lnterest on Debt to Associated Companies (Account 430)-For each associated mmpany thal incuned interesl on debt during the year, indicate the amount and interest rate
which interest was incuned during the year,
(d) Other lnterest Expense (Accounl 431 ) - Report details including the amount and interest rate for other interest charges incuned during tlre year.
Line
No.
Item
(a)
Amount
(b)
1 Acct, 425.00 - MISCELLANEOUS AMORTIZATIONS
2 Items Under 9250,000
Total - 425.00
4 Acct. 426.10 - DONATIONS
5 Rosaurers Supermarket lnc- Storm Gift Cards to customers 460,950
6 Items Under $250,000 2,747,071
7 Total 426.1 0 3,208,021
8 Acct. 426.20 - LIFE INSURANCE
o Oflicers Life 162,742
10 SERP 2,796,424
11 Items Under $250,000 120,828
12 Total 426.20 3,079,994
13 Acct. 426.30 - PENALTIES
14 Items Under $250,000 70,316
15 Total 426.30 70,316
16 Acct,426,40. EXPENDITURES FOR CERTAIN CIVIC, POLITICAL, AND RELATED ACTIVITIES
17 Items Under $250,000 1,625,650
18 Total 426.40 1,625,650
19 Acct.426.50 - OTHER DEDUCTIONS
20 Executive Defened Compensation 146,861
21 Hanna & Associates lnc 285,872
22 Items Under $250,000 953,767
23 Total 426.50 1,386,s00
24 Acct. 43O,OO - INTEREST ON DEBT TO ASSOC. COMPANIES
25 Avista Capital ll (long-term debt) (variable rate ranged from '1.1 1 to 1,29 perc)473,352
26 Avista Capital, lnc.131,922
27 Total 430.00 605.274
28 Acct. 431.00 - OTHER INTEREST EXPENSE
29 lnterest on elecldc defenals 562,497
30 lnterest on natural qas defenals 339,979
31 lnteresl on committed line of credit 1,297,048
32 Other 436,703
33 Total 431.00 2,636,227
34
35
FERC FORM NO.2 (12-96)Page 340
Name of Respondent
Avista Corporation
This Reoort Is:(1) fiRn Originat(2) nA Resubmission
uale oI Hepon(Mo, Da, Yr)
o411512016
Year/Period of Report
End of 2015/Q4
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 othemise incurred by the utility.
Line
No.
Description
(Furnish name of regulatory commission
or body, the docket number, and a
description of the case.)
(a)
Assessed by
Regulatory
Commission
(b)
Expenses
of
Utility
(c)
Total
Expenses
to Date
(d)
Deferred in
Account 182.3
at Beginning
of Year
(e)
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 Project
2,210.963 86,315
5
6 Washington Utilities and Transportation Commission
7 lncludes annual fee and various other electric dockets
1,025,044 1,182,202
I
I lncludes annual fee and various other natural gas
dockets 328,989 302,117
10
11 ldaho Public Utilities Commission
12 lncludes annual fee and various other electric dockets
61 9,966 259,840
13
14 lncludes annual fee and various other natural gas
dockets 177,604 88,'152
15
16 Public Utility Commission of Oregon
17 lncludes annual fee and various other dockets
598,978 684,324
18
19 Not directly assigned electric
754.166
20 Not directly assigned natural gas
301,3'17
21
22
23
24
25 Total 4,961,544 3,658,433
FERC FORM NO. 2 (12-96)Page 350
Name of Respondent
Avista Corporation
This Reoort Is:(1) []Rn orisinat(2) l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t1512016
Year/Period of Report
End of 2015/Q4
Regulatory Commission Expenses (Account 928)
3. Show in column (k) any expenses incurred in prior years that are being amortized. List in column (a) the period of amortization.
4. ldentity separately all annual charge adjustments (ACA).
5. List in column (f), (g), and (h) expenses incuned during year which were charges cunently to income, planl, or other accounts.
6. Minor items (less than $250,000) may be grouped.
Line
No.
Expenses
lncuned
During Year
Charged
Cunently To
Department
(0
Expenses
lncurred
During Year
Charged
Cunently To
Account No.
(s)
Expenses
lncuned
During Year
Charged
Cunently To
Amount
(h)
Expenses
lncurred
During Year
Deferred to
Account
182.3
fi)
Amortized
During Year
Contra
Account
(i)
Amorlized
During Year
Amount
(k)
Defened in
Account 182.3
End ofYear
fl)
1
2
3
4
Electric 928 2,297,278
(
6
7
Electric 928 2,207,246
I
I
Gas 928 631 ,1 06
10
11
12
Electric 928 879,806
13
14
Gas 928 265,756
15
'16
17
Gas 928 1,283,302
18
19 tElectric 928 754,166
20
Gas 928 301,317
21
22
23
24
25 8,619,977
FERC FORM NO.2 (12-95)Page 35'l
Name of Respondent
Avista Corporation
This Reoort ls:(1) filAn orisinat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Repor
End of 2015/Q4
Employee Pensions and Benefits (Account 926)
1. Report below the items contained in Account 926, Employee Pensions and Benefits
Line
No.
Expense
(a)
Amounl
(b)
1 Pensions - defined benefit plans 671,836
2 Pensions - other
3 Poslretirement benefits other than pensions (PBOP)
4 Pos! employment benefit plans
5 )ther (Specifo)
6
7
I
I
10
11
12
13
't4
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 67't,836
FERC FORM NO.2 (NEW 12-O7l Page 352
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Reoort ls:(1) lxlAn Original(2\ l-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Distribution of Salaries and Wages
the particular opem0ng function(s) relating to the expenses.
reporting detail of other accounts, enter as many rows as necessary numbered sequentially starting with 75.01, 75.02, elc.
Line
No.
Classillcation
(a)
Direct Payroll
Distribution
(b)
Payroll Billed
by Affiliated
Companies
(c)
Allocation of
Payroll Charged
for Clearing
Accounts
(d)
Total
(e)
3 Production 10,679,26t 10,679,266
4 Transmission 2,940,35:2.940.353(Distribution 8,288,33S 8,288,33!
o Customer Accounts 7,465,204 7.465,204
7 Customer Service and lnhrmational 739,691 739,691
8 Sales
o Administrative and General 1 7,886,460 '17.886.46(
10 TOTAL Operation (Total of lines 3 thru 9)47,999,313 47,999.31:
12 Production 3,327,489 3,327,485
13 Transmission 1,267,086 1,267,086
14 Distribution 5,715,670 5,715.67C
15 Administrative and General '15,660,18(1 5,660,1 8C
16 TOTAL Maintenance (Total of lines 12 thru 15)10,310,245 15,660,18(25,970,425
'18 Production (Total of lines 3 and 12)14,006,755 't4,006,755
tv Transmission (Total of lines 4 and 13)4,207,439 4,207,439
20 Distribution (Total of lines 5 and 14)14,004,009 't4,004,009
21 Customer Accounts (line 6)7,465,204 7,465,204
22 Customer Service and lnformational {line 7)739,69'l 739,691
23 Sales (line 8)
24 Administrative and General (Total of lines 9 and 15)17,886,46C 15,660,1 8(33,546,640
25 TOTAL Operation and Maintenance (Total of lines '18 hru 24)58,309,558 15,660,18(73,969,738
28 Production - Manufactured Gas
29 Production - Natural Gas(lncludino Exoloration and Develoomenl)
30 Other Gas Suooly 798,99r 798,995
31 Storage, LNG Terminalinq and Processinq 6,49t 6,496
32 Transmission
33 Distribution 5,089,'10;5,089,107
34 Customer Acmunts 2,912,24(2,912,246
35 Cuslomer Service and lnformational 334,84(334,840
36 Sales
37 Administrative and General 6,8s6,32'6.856.322
38 TOTAL Operation (Total of lines 28 thru 37)1s,998,00(15,998,006
40 Production - Manufac{ured Gas
41 Production - Natural Gas(lncluding Exploration and Development)
42 Other Gas Supply
43 Storage, LNG Terminaling and Processing
44 Transmission 1,142,631 1,142,631
45 Distribution 3,333,26i 3,333,267
FERC FORM NO. 2 (REV|SED)Page
Name of Respondent
Avista Corporation
This ReDort ls:(1) [IlAn Original(2) I-lA Resubmission
Date of Reporl
(Mo, Da, Yr)
o4t15t2016
Year/Period of Report
End of 2015/Q4
Distribution of Salaries and Wages (continued)
Line
No.
Classification
(a)
Direct Payroll
Distribution
(b)
Payroll Billed
by Afiiliated
Companies
(c)
Allocation of
Payroll Charged
for Clearing
Accounts
(d)
Total
(e)
46 Administrative and General 5,526,66:s,526,66i
47 TOTAL Maintenance (Total of lines 40 thru 46)4,47s,898 5,526,66:10,002,56(
50 Productjon - Manufactured Gas (Tohl of lines 28 and 40)
51 Production - Natural Gas (lncluding Expl. and Dev,Xll.29 and 41)
52 Other Gas Supply (Total of lines 30 and 42)798,995 798,99a
53 Storage, LNG Terminalinq and Processing (Total of ll. 3'l and 43)6,496 6,49(
54 Transmission (Total of lines 32 and 44)1,142,631 1j42,631
55 Distribution (Total of lines 33 and 45)8,422,374 8,422,374
56 Customer Accounts (Total of line 34)2,912,246 2,912,24t
57 Customer Service and lnformational (Total of line 35)334,840 334,84(
58 Sales (Total of line 36)
59 Administrative and General (Total of lines 37 and 46)6,856,322 5,526,66:12,382,984
60 Total Operation and Maintenance (Total of lines 50 thru 59)20,473,904 5,526,66:26,000,56r
62 Operation and Maintenance
63 TOTAL ALL Utility Dept. (Total of lines 25, 60, and 62)78,783,462 21,186,84i 99,970,304
bb Electric Plant 41,185,936 15,544,341 56.730,27t
67 Gas Plant 8,341,s83 4,768,95(1 3,1 10,53!
68 Other
69 TOTAL Construction (Total of lines 66 thru 68)49,527,519 20,313,29{69,840,817
71 Electric Plant 1,974,884 520,97"2,495,85€
72 Gas Plani 1'17,086 30,88;147,973
73 Other
74 TOTAL Plant Removal (Total of lines 71 thru 73)2,091,970 5s1,85(2,643,82S
75 Other Accounts (Specity) (footnote details)4s,518,991 42,0s2,019 3,466,972
76 TOTAL Other Accounts 45,518,991 ( 42,052,019 3,466,972
77 TOTAL SALARIES AND WAGES 175.921,942 20 175,921p22
FERC FORM NO. 2 (REV|SED)Page 355
Name of Respondent
Avista Corporation
This Reoort Is:(1) fiRn originat(2) l--lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Charges for Outside Professional and Other Gonsultative Services
except those which should be reported in Account 426.4 Expenditures for Certain Civic, Political and Related Activities.
(a) Name of person or organization rendering services.
(b) Total charges for the year.
2. Sum under a description 'Other', all of the aforementioned services amounting to $250,000 or less.
3. Total under a description "Total', the total of all of the aioremenlioned services.
according to the instructions for that schedule.
Line
No.
Description
(a)
Amount
(in dollars)
(b)
1 ABB ENT SOFTWARE INC 293,054
2 AWEC SYSTEMS INTEGRATOR 432,852
3 BAKER CONSTRUCTION & DEVELOPMENT 3,217,838
4 BLAKC & VEATCH CORP 647,901
5 CIRRUS DESIGN 405,1't5
6 COEUR D ALENE TRIBE 825,508
7 DAVIS WRIGHT TREMAINE LLP 393,607
6 ERNST & YOUNG 6,644,948
9 H2E INC 319,876
'10 HANNA & ASSOCIATES 312,920
11 HAWORTH 571,467
12 HDR ENGINEERING 683,579
13 HELVETICM 253,574
14 HICKY BROTHERS RESEARCH 33'1,483
15 HP ENTERPRISE SERVICES 'r,039,597
16 IBM CORPORATION 4,735,761
17 IFACTOR CONSULTING 327790
18 INTERVOICE 442,815
19 LANDAU ASSOCIATES 488,076
20 MAX J KUNEY COMPANY 427,883
21 MCKINSTRY ESSENTION LLC 4,770,671
22 NEAL STRUCTURAL REPAIR 350,285
23 NORTHWEST POWER POOL 354,703
24 OPOWER INC 257,662
25 PAINE HAMBLEN LLP 449,985
26 POWER CIry ELECTRIC 434,032
27 PRO BUILDING SYSTEM 481,901
28 SAPERE CONSULTING 912,616
29 SENTURUS INC 322,861
30 STEELHEAD MECHANICAL 324,074
31 STRATA 429,899
32 URS ENERGY CONSTRUCTION 2,450,856
33 UTILITIES INTERNATIONAL 270,128
34 WESTERN ELECTRICITY 944,249
35 OTHER 19,257,681
FERC FORM NO.2 (REVISED)Page 357
Name of Respondent
Avista Corporation
This Reoort ls:(1) fiRn Original(2) l_lA Resubmission
Date of Report(Mo, Da, Yr)
o4t15t2016
YeailPenoo oI Kepon
End of 2015/Q4
Transactions with Associated (Affil iated) Com panies
1 . Reporl below the information called for conceming all goods or services received from or provided to associated (affiliated) companies amounting to more than $250,000.
2. Sum under a description 'Othef, all of the aforementioned goods and services amounting to $250,000 or less.
3. Total under a description 'Total', the total of all of the aforementioned goods and services.
4. Where amounts billed lo or received from the associated (afiiliated) company are based on an allocation process, explain in a footnoie the bas's of the allocation.
Line
No.
Description of the Good or Service
(a)
Name of Associated/Afflliated Company
(b)
Account(s)
Charged or
Credited
(c)
Amount
Charged or
Credited
(d)
2 Other Steam Plant Souare 931000 149,3M
?Other Spokane Energy 456000 14,230
4
5
6
7
8
I
10
11
12
13
14
't5
16
17
18
19
21 Corporate Support Salix '146000 737,375
22 Corporate Suooorl Avista Development 146000 292,333
23 Other Avista Capital 146000 75,1'15
24 Other AELP, lnc 146000 137,732
25 Other Avista Enerov 146000 879
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
FERC FORM NO.2 (NEW 12-O7l Page 358
Name of Respondent
Avista Corporation
This ReDort ls:(1) fiAn originat(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
o4t1512016
Year/Period of Report
End of 2015/Q4
Gas Storage Projects
1 . Report injections and withdrawals of gas for all storage projects used by respondent.
Line
No.
Item
(a)
Gas
Belonging to
Respondent
(Dth)
(b)
Gas
Belonging to
Othen
(Dth)
(c)
Total
Amount
(Dth)
(d)
2 January 106,680 106,680
3 February 115,972 115,972
4 March 643,498 643,498
5 April 1,054,1 23 1,054,123
b May 3,026,992 3,026,992
7 June 1,235,126 1,235,126
I July 1,467,109 1,467,109
I Augusl 2,259,399 2,259,399
10 September '1,507,656 1,507,656
11 October 253,308 253,308
12 November 15,614 15,614
13 December 357,764 357,764
14 TOTAL (Total of lines 2 thru 13)12,043,241 12,043,241
'16 January 3,083,016 s,083,016
17 February 2,208,427 2,208,427
18 March 1,459,725 1,459,725
'19 April 667,428 667,428
20 May 72,619 72,619
21 June 1,950,700 1.950,700
22 July 803,1 53 803,153
23 August 7,301 7,301
24 September 164,506 164,s06
25 October 107,138 '107,138
26 November 1,s69,433 1,569,433
27 December 1p28213 1,928,213
28 TOTAL (Total of lines 16 thru 27)14,021,659 14,021,659
FERC FORM NO. 2 (12-96)Page 512_
Name of Respondent
Avista Corporation
This Reoort ls:(1) finn Original(2) [-lA Resubmission
Date of Report(Mo, Da, Y0
04t15t2016
Year/Period of Report
End of 2015/Q4
Gas Storage Projects
1. On line 4, enter the total storage capacity certificated by FERC.
2. Report total amount in Dth or other unit, as applicable on lines 2, 3, 4, 7. lf quantity is converted from Mcf lo Dlh, provide conversion factor in a footnote.
Line
No.
Item
(a)
Total Amounl
(b)
STORAGE OPERATIONS
1 Top or Workinq Gas End of Year 8,528,000
2 Cushion Gas (lncluding Native Gas)7,730,668
3 Total Gas in Reservoir (Total of line 1 and 2)16,258,668
4 Certificated Storaoe Caoacitv 16,2s8,668
Number of lnjection - Withdrawal Wells 54
6 Number of Observation Wells 48
7 Maximum Days' Withdrawal from Storage
8 Date of Maximum Days'Wihdrawal 1 1/30/201 5
0 LNG Terminal Comoanies lin Dth)
'10 Number of Tanks
l1 Caoacitv of Tanks
12 LNG Volume
13 Received at "Ship Rail'
14 Transferred to Tank
15 Withdrawn from Tanks
16 'Boil Off VaDorization Loss
FERC FORM NO. 2 (12-96)Page 513_
Name of Respondent
Avista Corporation
This Report is:
(1) X An OriginalQ\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
2015tQ4
FOOTNOTE DATA
Mcf converted to Dth using a factor of 1.04
FERC FORM NO.2 552.1
This Page Intentionally Left Blank
Name of Respondent
Avista Corporatlon
This Reoort ls:(1) fien originat(2) l-lA Resubmission
uate o1 f(epon(Mo, Da, Y0
04t1512016
Year/Period of Report
End of 2015/Q4
Auxiliary Peaking Facilities
installations, gas liquefaction plants, oil gas sets, etc.
2. For column (c), for underground storage projects, report the deliver capacity on Febrar 1 of the heating season overlapping the year-end for which lhis report is submitted.
For other facilities, report the raled maximum daily delivery capacities.
separate plant as contemplated by general instruction 12 ofthe Uniform System ofAccounts.
Line
No.
Location of
Facility
(a)
Type of
Facility
(b)
Maximum Daily
Delivery Capacity
of Facility
Dth
(c)
Cost ol
Facility
(in dollan)
(d'l
Was Facility
Operated on Day
of Highest
Transmission Peak
Deliverv?
1
2 Chehalis, Washington Underground Natural Gas 346,667 37,061,388 Yes
2 Storage Field
4 Washington & ldaho Supply
5
6 Chehalis, Washington Underground Natural Gas 52,000 6,018,313 Yes
7 Storage Field
8 Oregon Supply
I
10 Chehalis, Washington Underground Natural Gas 2,623 No
11 Storbge Field
12 Oregon Supply
13
14 Rock Springs, Wyoming Underground Natural Gas 186,125 Yes
15 Storage Field
16 Washington & ldaho Supply
17
18 Rock Springs, Wyoming Underground Natural Gas 63,875 i rri,i,:$ltiii:ir.(iili ..::,ii'l.il)Yes
19 Storage Field
20 Oregon Supply
21
22
23
24
25
26
27
28
29
30
FERC FORM NO. 2 (12-96)Page 5't I
Name of Respondent
Avista Corporation
This Report is:
(1) X An Original(2\ A Resubmission
Date of Report
(Mo, Da, Yr)
04t15t2016
Year/Period of Report
20151Q4
FOOTNOTE DATA
WneNo.:to cotumn:a
Respondent is a particrpant in the facil pacity.
Respondent is a participant in the facilities, not an owner and is charged a fee for demand deliverability and capacity.
not an owner and is a fee for demand
FERC FORM NO.2 552.1
Name of Respondent
Avista Corporation
This Report ls:(1) [An Original(2) [-lA Resubmission
Date of Report(Mo, Da, Yr)
04t15t2016
Year/Period of Report
End of 2015/Q4
Gas Account - Natural Gas
1. The purpse of this schedule is to account for the quantity ol natural gas received and delivered by the respondent.
2. Natural gas means eilher natural gas unmixed or any mixture of natural and manufactured gas.
3. Enter in column (c) the year to date Dth as reported in the schedules indicated for the items of receipts and deliveries.
4. Enter in column (d) the respective quarte/s Dth as reporled in the schedules indicated for the ilems of receipts and delivenes.
5. lndicate in a foolnote the quantities of bundled sales and transportation gas and specify the line on which such quantities are listed.
6, lf the respondent opelales two or more systems which are not interconnected, submit separate pages for this purpose.
were nol transporled through any interstate portion of the reporting pipeline.
L lndicate in a footnote the specific gas purchase expense account(s) and related to which the aggregate volumes reporled on line No. 3 relate.
reporling y€ar, and (3) contract slorage quantilies.
footnotes.
Line
No.
Item
(a)
Ref. Page No. of
(FERC Form Nos.
2t2-A)
(b)
Total Amount
of Dth
Year to Date
(c)
Cunent Three
Months
Ended Amount of Dth
Quarterly Only
01 Name of System:
2 GAS RECEIVED
3 Gas Purchases (Accounts 800-805)112,733,321 26,490,639
4 Gas of Others Received for Gathering (Account 489.1)303
5 Gas of Othea Received for Transmission (Account 489.2)305
6 Gas of OtheE Received for Distribution (Account 489.3)301 '16,467,89;4,535,635
7 Gas of OtheE Received ior Contracl Storage (Account 489.4)307
8 Gas of Others Received for Production/Extraction/Processinq (Account 490 and 491 )
a Exchanged Gas Received from Othem (Account 806)328
10 Gas Received as lmbalances (Account 806)328 69,42i ( 11,5721
11 Receipb of Respondents Gas Transported by Others (Account 858)332
12 Other Gas Withdrawn from Storaoe (Exolain'l '1.965,88i 2,956,092
13 Gas Received from Shippen as Compressor Station Fuel
14 Gas Received from Shippers as Lost and Unaccounted for
'ts Other Receipts (Specify) (footnote details)
16 Total Receipts (Total of lines 3 thru 1 5)131.236,52:33,970,794
17 GAS DELIVERED
18 Gas Sales (Accounts 480484)112,593,14(28,945,296
19 Deliveries of Gas Gathered for Others (Account 489.1)303
20 Deliveries of Gas Transporled for Others (Account 489.2)305
tt Deliveries of Gas Distributed for Others (Account 489.3)301 16,467,89i 4,535,635
22 Deliveries of Contracl Storage Gas (Account 489.4)307
23 Gas of Othen Delivered for Production/Extraction/Processing (Account 490 and 491)
24 Exchanoe Gas Delivered to Othen (Acmunt 806)328
25 Gas Delivered as lmbalances (Account 806)328
26 Deliveries ol Gas to Others for Transportation (Account 858)332
27 Other Gas Delivered to Storage (Explain)
28 Gas Used for Compressor Station Fuel s09 2,175,48t 489,863
29 Other Deliveries and Gas Used for Other Operations
30 Total Deliveries (Total of lines 18 thru 29)131 .236.52:33,970,794
3'1 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)131,236,52:33,970,794
FERC FORM NO. 2 (REV 01-11)Page
AVU.G
[{[CEIVED
2016 J1FR 39 AH t0: 0B
ll.i4ll-! ^l'r',! r^ii...,' : ;:,'i/;)l-:r-,
l.tT !LITrL- l) (. i*iti ISSI0N
Avista CorP.
2015
IDAHO
State Natural Gas Annual RePort
(rc 61-40s)
This Page fntentionally Left Blank
Name of Respondent
Avista Corporation
This Report is:
lx I nn originat
I n Resubmission
Date of Reporl
mm/dd/yyyy
4t15t2016
Year / Period of Reporl
End of 2015 I Q4
STATEMENT OF UTILITY OPERA NNG INCOME.IDAHO
lnstructions
1 . For each account below, report the amount attributable to the state of ldaho based on ldaho jurisdictional Results of Operations.
2. Provide any necessary important notes regarding this statement of utility operating income in a footnole in the available space at the bottom of this page
Line
No.Account
(a)
Refer to
Form 2
Page
(b)
TOTAL SYSTEM - IDAHO
Current Year
(c)
Prior Year
(d)
1 UTILITY OPERATING INCOME
2 SDeratino Revenues (400)30G.301 438.862.993 444.237.507
3 SDeratino Exoenses ' 'l| r,':. )::/.:.1'
4 CDeration ExDenses (401)317-325 281.095.939 284.419.705
5 Maintenance Expenses (402)317-325 19.716.011 2'1 .375,618
6 Depreciation Exoense (403)336-338 39,168,371 37.201.407
7 Depreciation Expense for Asset Retirement Costs (403.1 336-338
8 Amortization & Depletion of Utility Plant (404-405)336-338 5,806,994 4.088,551
I Amortization of Utilitv Plant Acouisition Adiustmenl (405)336-338 67,304 67,304
10 Amort. of Propertv Losses, Unrecov Plant and Regulatory Study Costs (407)
11 Amortization of Conversion ExDenses {407)
12 Reoulatorv Debits (407.3)1.905.433)(326_764\
13 :Less) Requlatorv Credits (407.4)(6.951 .798)u.626.407\
14 Taxes Other Than lncome Taxes (408.1)262-263 17.489.467 16.323.848
15 lncome Taxes - Federal (409.1)262-263 2.975.069 (7.575.919)
16 - Other (409.1 26?-263
17 Provision for Deferred Income Taxes (410.1 234-235 18.662,907 30.799.737
18 lless) Provision for Deferred lncome Taxes-Ct. (411.1 234-235
19 lnvestment Tax Credit Adiustment - Net (41 1.4)77.379)(81.674)
20 lLess) Gains from Disposition of Utility Plant (4'1 1.6)
21 Losses from DisDosition Of Utilitv Plant (41 1.7)
22 :Less) Gains from Disoosition of Allowances (4'11.8)
23 Losses from Disposition of Allowances (41 1.9)
24 Acmetion Exoense (41 1.10)
25 IOTAL Utility Operatino Expenses (Total of line 4 throuqh 24)376.O47.452 381.665,406
26 Net Utility Operatinq lncome (Total line 2 less 25)62.815,541 62.572,101
IDAHO STATE NATURAL GAS ANNUAL REPORT (lC 61405)G.lD.1 14-1 1 5
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Report
mm/dd/yyyy
4115t2016
Year / Period of Reporl
End of 2015 I Q4
STATEMENT OF UTILITY OPERATING INCOME.IDAHO
lnstructions
or in a separate schedule.
3. Explain in a footnote if the previous year's figures are different ftom those reported in prior reports.
ELECTRIC UTILIW GAS UTILITY OTHER UTILITY Line
No.Cunent Year
(e)
Prior Year
(D
Cunent Year
(s)
Prior Year
(h)
Cunent Year
(i)
Prior Year
U)
331.496.092 33/.155.729 107.366.901 110.081.778 2
195.429.218 199.552.136 85.666.721 84.867.s69 4
16.712.494 17.974.692 3.003,517 3.400.726 5
33.285.897 31.796.445 5.882.474 5.404.962 b
7
4.756.U4 3.309.953 1_050.6s0 778.5S8 8
67,3(N 67,304 I
't0
11
(875.8231 @26,7U (1.029.6101 't2
(6.279.2561 (4,626,407'/672.542',13
'14.785.50'l 13.694.260 2.703.866 2.629.588 14
3.447.734 (5.09't.709)G72.66!Q.484.2101 15
16
15.094.760 24.289.658 3,568.'147 6.510.079 17
,8
(67.2031 (69.0021 t10.1761 t12.672\19
20
21
22
23
24
276.357.O70 280.570.766 99.690.382 101.094.640 25
55.139.022 53.584.963 7.676.519 8.987.138 26
IDAHO STATE NATURAL GAS ANNUAL REPORT (tC 6t405)G_tD.1 14-1 15
Name of Respondenl
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Reporl
mm/dd/yyyy
4t15t2016
Year / Period of Report
End of 2015 I Q4
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIA TION. AMORTIZATION AND DEPLETION - IDAHO
lnstructions
1. Report below the original cost of utility plant in service necessary to furnish utility 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), (Q, and (g) report other (specify),
Line
No.Account
(a)
Total Company
End of Current Year
(b)
Electric
(c)
1 Jtility Plant
2 ln Service : ::-r r'i i: "
3 Plant in Service (Classified)1.557,691,01't 1.221.O90.448
4 rrooertv Under Caoital Leases 364,335
5 )lant Purchased or Sold
6 :ompleted Construction not Classified
7 -xperimental Plant UnclassifiedITotal fiotal lines 3 throuoh 7)1,558,055,346 1.221.090.488
I Leased to Others
10 Held for Future Use 389.592 199,007
11 Sonstruction Work in Proqress 61.694.847 52.205.223
12 Ac.o r risition Adi r rstments
'13 Total Utilitv Plant ffotal lines 8 throuoh '12)1 .620.1 39,785 1.273.494.718
14 Accumulated Provision for Deoreciation- Amortization. and Deoletion 556,066,400 454.303.486
15 Net Utilitv Plant (Line 13less line 14)1.064.073.385 819.191.232
16 Detail of Accumulated Provision for Depreciation, Amortization, and Depletion "il
17 ln Service
18 fepreciation 542.275.158 450.465.351
19 qmortization and Deoletion of Producino Natural Gas Lands / Land Riohts
20 Amortization of Underoround Storaoe Lands / Land Riohts
21 Amortization of Other Utilitv Plant 13.791.242 3,838,1 35
22 Total (Total lines 18 throuoh 21) F 556.066.400 454,303,486
23 Leased to Others tl+-' : -.11,4a r . i: -r:'itr: :i:;:,: :: aJi-l|
24 Jeoreciation
25 qmortrzation ancl Depletion
26 Total Leased to Others
27 -leld for Future Use i
28 )epreciation
29 qmortization
30 Total Held for Future Use
31 {bandonment of Leases (Natural Gas)
32 Amortization of Plant Acquisition Adiustmenl
33 Total Accumulated Provision (Total lines 22. 26. 30. 31. 32\556.066.400 454.303.486
IDAHO STATE NATURAL GAS ANNUAL REPORT (tC 61405)G_1D.200-201
Name of Respondent
Avista Corporation
This Report is:
Ix-l nn originat
E A Resubmission
Date of Report
mm/dd/Ww
4115t2016
Year / Period of Report
End of 2015 I Q4
SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION . IDAHO
lnstructions
and in column (h) common function.
3. In order to accurately reflect utility plant in service necessary to furnish 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 (Specify)
(e)
Other (Specify)
(0
Other (Specify)
(s)
Common
(h)
Line
No.
tr.it: :ta i 1,,:tt't:::': : :::.1.1,.!.t,i.1r,.!:r4:L;;:r: :,i l:i t:;;:;i)i:itt!tii1.:ii,i:. i1:: i;::.lj;:i:,t; lti:rJt t;t:::,lAl 1
Y.:ii.X)t'1, :, :ia !:::i :: : :.. : :, t.;t:V1:: t',. | :t.ai::4.f|:,r!i' I :'' : :'2
209,434,371 127.166.152 3
272,701 91.634 4
5
6
7
209.707.O72 127.257.786 8
I
190,585 10
2.195.331 7.294.293 11
12
212.092.988 134.552.O79 13
70,943,555 30.819.3s9 14
141 ,149.433 103.732.720 15
1,1rr ) , i ili:i;:itid ir;:, tii:l ),..ii,t:;:i^r#}.qii )!.t:t:! !|)::i:! i:', ':;:l)':11::.: i ri,,: !;lj;lr iri;, r,i,l 16
iri-fj;t:r:i;.:,:,::nl:,. iii.: ::. .: lll.::;-31.*,i lfff {17
70.639.365 21.170.442 18
'19
20
304,1 90 9.648.917 21
70,943.555 30,819,359 22
:ll:i;: .:i:r i!!,tr ] 'r,!::i+JE€ryi 1ta-#a1u:li.$5.: rs.r.Y--,tg+,:r', ;r i *:"---) ,:.ri,. :,:.,.. .''-,:,- i :-, . . ' .1' ., - l; ?ij,a:=+i iiti .'::l.,t:::1:;,:t !i::',:: i 23
24
25
26
]'l !,,.,,.: " ,.:,,^:?r4i:: t:ii:':1iJi iliri*: ;I:,1;l;:t{r-l.i:**:r r,i*,:q::?1 t. .{jat'il*.i1,.,+::i:::,8;l;::i:.giii +:-a ::.-, * -_. :, -:r l- --'l . - -27
28
29
30
31
32
70.943.555 30.819.3s9 33
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.tD.200-201
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Report
mm/dd/yyyy
4t1st2016
Year / Period of Report
End of 2015 I 04
GAS PLANT lN SERVICE - IDAHO (Account 101,102,103 and 106)
tnstr
't.
2.
3.
4.
5.
6.
Jctions
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.
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.
lnclude in column (c) or (d), as appropriate, corrections of additions and retirements for the curent or preceding year.
For revisions to the amount of initial asset retirement costs capitalized, include by primary plant account increases in column (c), additions, and
reductions in column (e), adjustments.
Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect ofsuch amounts.
Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included
in column (c) are entries for reversals of tenlative 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) distributions of
Line
No.Account
(a)
Balance
Beginning of Year
(b)
Additions
(c)
1 NTANGIBLE PLANT .dIi:.1.:. r.^..r1:! "'iL .'.- ::: ;l .. * '.;',. ".:;r , ': ",, .
2 30l Oroanization
3 3O2 Franchises and Consents
4 303 MiscellaneouslntanqiblePlant 672_42s 648.185
5 TOTAL lntanoible Plant (Total of lines 2. 3. and 4)672,425 648.185
6 PRODUCTION PLANT li:,?:rl i ilrli.lrLi,&UinEi#Hffi t
7 Natural Gas Production and Gatherino Plant i k&1;,iiEl,:rjri I lli i{i,iiii[i# 4ri "$i ],i i i i :i:rl:- tt:i;j
I 325.1 Producinq Lands
I 325.2 Producino Leaseholds
10 325.3 Gas Riohts
11 325.4 Riohts-of-Wav
12 325.5 Other Land and Land Riohts
13 326 Gas Well Structures
14 327 Field Comoressor Station Structures
15 328 Field Measurino and Reoulatino Station Eouioment
16 329 Other Structures
17 330 Producino Gas Wells-Well Construction
18 331 Producino Gas Wells-Well Eouioment
19 332 Field Lines
20 333 Field Comoressor Station EquiDment
21 334 Field Measurinq and Reoulatinq Station Equioment
22 335 Drillino and Cleanino Eouioment
23 336 PurificationEouioment
24 337 Other Eouiomenl
25 338 Unsuccessful Exoloration and Develooment Costs
26 339 Asset Retirement Costs for Nalural Gas Production and Gatherino Plant
27 TOTAL Natural Gas Production and Gatherino Plant (Total of lines 8 throuoh 26)
28 Products Extraction Plant {.{;r";iiti16€S$gi
29 340 Land and Land Riohts
30 341 Slructures and lmorovements
31 342 Extraction and Refinino EduiDment
32 343 Pioe Lines
33 344 Exlracted Products Storaqe Equipment
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 51405)G.1D.204-20s
Name of Respondenl
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Report
mm/dd/yyyy
4l'1st2016
Year / Period of Report
End of 2015 I Q4
cAS PLANT lN SERVICE - IDAHO (Account 101,1O2,'t03 and '1061
lnstructions
these tentative classifications in columns (c) and (d), including the reversals of the prior year's tentative account distributions of these amounls. Careful
observance of these instructions and the texts of Accounts 1 01 and 1 06 will avoid serious omissions of the reported amount of respondent's plant
aclually in service at end of year.
7. Show in column (0 reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account
classifications arising from distribution of amounts initially recorded in Account '102; include in column (e) the amounts with respect to accumulated
provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary
account classifi cations.
8. For Account 399, state the nature and use of plant included in this account, and, if substantial in amount, submit a supplementary statement showing
subaccount classification of such plant conforming to the requirement of these pages.
9. ForeachaccountcomprisingthereportedbalanceandchangesinAccountl02,statethepropertypurchasedorsold,nameof vendororpurchase,and
dateoftransaction. lfproposedjoumal entrieshavebeenfiledasrequiredbytheUniformSystemofAccounts,givealsothedateofsuchfiling.
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance
End of Year
(q)
Line
No.
:i,ii li: :,il :. t','i i :l :,t lt ;.$.aj,: L:: :t ia :i&:1
2
3
255.702 33,629 1,098,537 4
255.702 33,629 1,098,537 5
6
- . :..:.. ; :. " .:t-"i.: o .;': ,'; r:r*:li{',*.:i:+:4;,,i:a : l;7
I
I
10
11
12
13
'14
15
16
17
18
't9
20
21
22
23
24
25
26
27
::".'.. 4 ..1 ,:r.:r',]-. r,..;r-."'{j.llsr?;28
29
30
31
32
33
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.tD.204-205
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Reporl
mm/dd/yyyy
4115t2016
Year/ Period of Report
End of 2015 I Q4
GAS PLANT lN SERVICE - ]DAHO (Account 1O1.'1O2.103 and 1061 (Continuedl
Line
No.Account
(a)
Balance
Beginning of Year
(b)
Additions
(c)
34 345 ComoressorEquiomenl
35 346 Gas Measurinq and Reoulatino Eouiomenl
35 347 Other Eouinmeni
37 348 Asset Retirement Costs for Products Extraction Plant
38 I-OTAL Products Extraction Plant ffotal of lines 29 throuqh 37)
39 TOTAL Natural Gas Production Plant (Total lines 27 and 38)
40 \Ianufactured Gas Production Plant (Submit Suoolementarv Schedule)
41 TOTAL Production Plant flotal lines 39 and 40)
42 IATUML GAS STORAGE AND PROCESSING PLANT
43 Jnderoround Storaoe Plant
44 350.1 Land 118,679
45 350.2 Riohts-of-Wav 17.442
46 351 Structures and lmorovements 476,681
47 352 Wells 3.720.089
48 352.'l Storaoe Leaseholds and Riohls 74.170
49 352.2 Reservoirs 59.291
50 352.3 Non-recoverable Nalural Gas 1.562.E86
5'l 353 Lines 304.569
52 354 Comoressor Station EduiDmeni 3.429.359
53 355 Other Eouioment 125.089
54 356 PurificationEquipment 't17.723
55 357 Other Eouiomeni 507.009
56 358 Asset Retirement Costs for Underoround Storaoe Plant
57 fOTAL Underqround Storaoe Plant 10.5',t2.987
58 Other Storaoe Plant
59 360 Land and Land Riqhts
60 361 Structures and lmprovements
61 362 Gas Holders
62 363 PurificationEquipment
63 363.1 Liouefaction Eouiomenl
64 363.2 Vaporizinq Equipment
65 363.3 Compressor EquiDment
66 363.4 Measurinq and Requlatino Eouioment
67 363.5 Other Equipment
68 363.6 Asset Retirement Costs for Other Storaoe Plant
69 IOTAL Other Storaqe Plant (Total of lines 58 throuoh 68)
70 Base Load Liquefied Natural Gas Terminalinq and Processino Plant
71 364.1 Land and Land Riohts
72 364.2 Structures and lmorovements
73 344.3 LNG Processino Terminal Eouioment
74 364.4 LNG Transoorlation Eouiomenl
75 364.5 Measurino and Reoulatino EouiDment
76 364.6 Comoressor Station Eouioment
77 364.7 Communications Eouioment
78 3&4.8 Other Eouioment
79 364.9 Asset Retirement Costs for Base Load Liquefied Natural Gas
80
TOTAL Base Load Liquefied Natural Gas Terminaling and Processing Plant Ootal lines 71
throuoh 79)
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 6{405)G.tD.206-207
Name of Respondent
Avista Corporation
This Report is:
E An original
E A Resubmission
Date of Report
mm/dd/yyyy
4t15t20'.t6
Year / Period of Report
End of 2015 I Q4
cAS PLANT lN SERVICE - IDAHO (Account 101. 102.'103 and 1061 (Continued)
Retirements
(d)
Adjustments
(e)
Transfers
(f)
Balance
End ofYear
(o)
Line
No.
34
35
36
37
38
39
40
41
li!;i6:- l. i:rli , 1J.\;,t;l*:: 1r' I t:: :' i. 1 t',;:: : :,, :.',*.:.' :::',,' a'. t''tiia 42
'l :" :* *""ri 1,1,:iiil!r1:t:illrlllii:,il r',,i.:;'i;,:.; ;.:.':.::: :'it?'.43
733 1',tg.412 44
107 17.549 45
62.261 538.942 46
82.283 3.802.372 47
458 74.628 48
366 59.657 49
9.647 1.572.533 50
1.881 306.450 51
79.822 3.50S.1 81 52
60,092 18s.18'l 53
726 118.449 54
62.449 569,458 55
56
360.825 10.873.812 57
i:I ; Irr.i iiIi,. 1,;,I ;].ri,;*li it:': tiit:,ii-:f,ijti,:::ii;a)58
59
60
61
62
63
64
65
66
67
68
69
li5i,ii&i,;r;.!,liiiirliillfi tr,r:rlilit,li::ai?,;:r, : ,€;i*r',l,it' ,lf: ii; lif ij;lnri; l; l:i:??t,i 70
71
72
73
74
75
76
77
78
79
80
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.1D.206-207
Name of Respondent
Avista Corporation
This Report is:
lx-l nn original
f] a Resubmission
Date of Report
m,|ddd/ywy
4l't5t2016
Year / Period of Report
End of 2015 I Q4
GAS PLANT lN SERVICE - IDAHO lAccount 101. 102.103 and 1061 (Continued)
Line
No.Accrunt
(a)
Balance
Beginning of Year
(b)
Additions
(c)
8'l IOTAL Natural Gas Storaoe and Processino Plant ffotal of lines 57. 69 and 80)10.512.987
82 TRANSMISSION PLANT
83 365.1 Land and Land Riohts
84 365.2 Riohts-of-Wav
85 366 Structures and lmDrovements
86 147 Mainc
87 1AA Cnmnraccnr Slatian Far ent
88 369 Measurinq and Requlatinq Station Equipment
89 370 Communication Equipment
90 371 Other Equioment
9'l 372 Asset Retirement Costs for Transmission Planl
92 TOTAL Transmission Plant (Total lines 83 throuqh 91)
93 DISTRIBUTION PLANT
94 374 Land and Land Riohts 87,805
95 375 Structures and lmprovements 308,398 55.813
96 376 Mains 88,987,255 9.734.369
97 377 Compressor Station Equipment
98 378 Measurino and Reoulatino Station Eouioment-General 2.152.249 84,365
99 379 Measurino and Reoulatino Station Eouioment-Citv Gate 4.322.'.t46 31.963
100 380 Services 56.559.512 5.730.033
't01 381 Meters 22.829.2U 315,642
102 382 Meterlnstallations
'103 383 House Reoulators
104 384 House Reoulator lnstallations
10s 385 lndustrial Measurino and Reoulatino Station EouiDment 716.642 53.354
106 386 Other Prooertv on Customers' Premises
107 387 Other Eouioment
108 388 Asset Retirement Costs for Distribution Plant
109 TOTAL Distribution Plant (Total lines 94 throuoh 108)175.963.29'l 16.005.539
110 GENERAL PLANT
111 389 Land and Land Riohts
112 390 Struclures and lmorovements
113 391 Office Fumiture and Eouiomenl 126.153 5.574
114 392 TransoortalionEouioment 2.288.570 799.'t 30
115 393 Stores Eouioment
116 394 Tools. Shoo. and Garaoe Eouioment 934.839 95,903
117 395 LaboratorvEouioment 99.184 2.319
118 395 Power Ooeraled Eouiomenl 1.058.664 167.603
11S 1q7 (lnmmr rninalinn Fnr rinmenl 755.259
124 398 MiscellaneousEouioment
121 Subtotal (Total of Lines 1 'l I throuoh I 20)5.262.669 1.070.529
122 399 Other Tangible Properly
123 399.1 Asset Retirement Costs for General Plant
124 TOTAL General Plant (Total of lines 121, 122 and 123\s,262,669 1.070.529
125 IOTAL (Accounts 101 and 106)192.411.372 17.724.253
126 Gas Plant Purchased (See lnstruction 8)
127 (Less) Gas Plant Sold (See lnstruction 8)
128 -xDerimental Gas Planl Unclassified
129 IOTAL Gas Plant in Service (Total of lines '125 throuoh 128)192.411.372 't7.724.253
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61{05)G.tD.208-209
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Report
mm/dd/yyyy
4115t2016
Year / Period of Report
End of 2015 I 04
GAS PLANT lN SERVICE - IDAHO (Account 101,1O2,103 and 106) (Continuedl
Retirements
(d)
Adjustments
(e)
Transfers
(D
Balance
End of Year
(s)
Line
No.
360,825 10,873,812 81
: :)',.,1, : i:,. .:11..:1:;.:i:'. ;i,.'. ::.4 :, i: l:;ai;;:\,:t :.:: : it:'it. i;-,.:. !:nat,x!:irj: )i::.,ti.*:il1 t:: :;,., i:,il!i i : t?-1.: .1i:i:;?.):;r\',.i,|:,,i ):;,:,: | ,i:', ',,:ta;:,i:l:.1):!1,:;14:t,lttjii:;r 82
83
84
85
86
87
88
89
90
91
92
93
(2)87.803 94
1 364.212 95
22,835 9.070 98.707.859 96
97
2.236 458 2,234,836 98
2.443 4,351,667 99
34.914 62.254.631 '100
23.',\44.92s 101
102
103
104
769,996 105
106
107
108
62.428 9.527 191 .915.929 109
I flliiii i:::-i.i,it;g"it.;;). :,; 11:,., 1.:110
111
112
2.909 (7.740],121.078 1'13
241 .076 (23.5't 3)9.466 2.792.577 114
115
11.246 (60.260)959.196 116
12.187 (s,549)83.767 117
r4.458 (91.366)1.120.443 118
2,600 (1 0,926)741 733 11S
120
310.058 122.446)(81.9001 5,8't 8,794 121
122
123
3't 0.058 122.446\(81.900t 5,818,794 124
628.1 88 281,535 (8't.9001 209.707.072 125
126
127
'128
628.1 88 281 .535 (81.9001 209.707.072 129
|DAHO STATE NATURAL GAS ANNUAL REPORT (tC 61405)G.tD 208-209
This Page Intentionally Left Blank
Name of Respondent
Avista Corporation
This Report is:
E An originat
t] A Resubmission
Date of Reporl
mm/dd/yyyy
4t15t2016
Year / Period of Report
End of 2015 I Q4
GAS STORED - IDAHO (Accounts 117.1,117.2. 117.3. 164.'1.164.2. and 164.3)
lnstructions
1. lf during the year adjustments were made lo the stored gas inventory reported in columns (d), (0, (S), and (h) (such as to correct cumulative
inaccuracies of gas measurements), explain in a footnote (in the available space at the bottom of this page or in a separate schedule) the reason for
the adjustments, the Dth and dollar amount of adjustment, and account charged or credited.
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 noncunent 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)
(b)
(Accounl
117.2)
(c)
Noncunent
(Account
117.3)
(d)
(Account
117.4)
(e)
Current
(Account
164.1)
(fl
LNG
(Account
164.2)
(o)
LNG
(Account
164.3)
ft)
Total
(i)
1 Balance at beoinnino of vear 1.772.478 1'.t.1'.t2.O46 13.18r'..524
2 Gas delivered to storaoe 8,901,357 8.901.357
3 Gas withdrawn from storaoe 12762757 12.762.757
4 Other debits and credits
5 Balance at end of vear 1.772.478 7.550.646 9.323.124
6 Dth 317.648 3.1 88.483 3.506.131
7 Amount Der Dth 5.58 2.37 2.66
(1) Fuel is accounted for within injeclions 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 (lC 6{405)G.tD.220
Name of Respondent
Avista Corporation
This Report is:
E An original
E A Resubmission
Date of Reporl
mm/dd/yyyy
4115t2016
Year / Period of Report
End of 2015 / Q4
GAS OPERATING REVENUES - IDAHO
lnstrr
1.
2.
3.
rctions
Report below natural gas operating revenues attributable to the state of ldaho for each prescribed account total in accordance with jurisdictional
Results of Operations.
Revenues in columns (b) and (c) include transition costs from upstream pipelines.
Other Revenues in columns (Q and (g) include reservation charges received by the pipeline plus usage charges, less revenues reflected in columns
(b) through (e). lnclude in columns (fl and (g) revenues forAccounts 480-495.
Line
No.Accpunl
(a)
Revenues for
Transition Costs
and Take-or-Pav
Revenues for
GRI and ACA
Current Year
(b)
Previous Year
(c)
Current Year
(d)
Previous Year
(e)
1 480 Residential Sales
2 481 Commercial and lndustrial Sales
3 482 Other Sales to Public Authorities
4 483 Sales for Resale ('1)
5 484 lnterdeDartmental Sales
6 485 lntracomoanv Transfers
7 487 Forfeited Discounts
8 488 Misc€llaneous Service RevenuesI489.1 Revenues from Transportation of Gas for Others
throuoh Gatherino Facilities
10 489.2 Revenues from Transportation of Gas for Others
throuoh Transmission Facilities
11 489.3 Revenues ftom Transportation of Gas for Others
throuoh Distribution Facilities
12 489.4 Revenues from Storino Gas of Others
13 490 Sales of Products Extracled from Natural Gas
14 t91 Revenues from Natural Gas Processed bv Others
15 {92 lncidental Gasoline and Oil Sales
16 193 Rent hom Gas Prooertv
17 {94 lnlerdepartmental Rents
18 {95 Other Gas Revenues I
19 3ubtotal
20 196 (Less) Provision for Rate Refunds
21 I-OTAL
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.tD.30(}'301
Name of Respondent
Avista Corporation
This Report is:
E An originat
I a Resubmission
Date of Reporl
mm/dd/yyw
4115t2016
Year / Period of Report
Endo 20151Q4
GAS OPERATING REVENUES - IDAHO
lnstructions
4. lf increases or decreases from previous year are not derived from previously reported figures, explain any inconsistencies in a footnote in the
available space at the bottom of ihis page or attached in a separate schedule.
5. See pages 108 in the FERC Form 2, lmportant Changes During the QuarterfYear, for information on major changes during the year, new service,
and important rate increases or decreases.
6. Report the revenue from transportation services that are bundled with storage services as lransportation service revenue.
Other
Revenues
Total
Operating
Revenues
Dekatherm of
Natural Gas Line
No.
Current Year
(D
Previous Year
(o)
Cunent Year
(h)
Previous Year
(D
Current Year
0)
Previous Year
(k)
40.281.230 46.555.303 40.28't.230 46.555.303 4.200.673 4.625.851 1
21.'t56.972 24.508.666 21.156.972 24.508.666 2.740.469 2.990.189 2
3
43.924.530 37.045.393 43,924.530 37.045.393 17.692.494 9.182.1 31 4
35,335 38,760 35,335 38,760 4.410 4,629 5
6
7
5,892 10.120 5.8S2 10,120 8
9
10
435,048 472.720 435,048 472,720 4,450,678 4,078,737 11
12
13
14
15
16
17
1.527.894 I,671,914 1.527.894 1,671 ,914 18
107.366.901 1't0.302.876 107.366.901 1 10.302.876 19
Q21.O98](221.098\,20
107.366.901 110.O81.778 107.366.901 'l 10.081 .778 21
(1) Sales for Resale and Deferred Exchange dollars are allocated based on the Washington / ldaho monthly commodity allocations used in
Results of Operations.
IOAHO STATE NATURAL GAS ANNUAL REPORT OC 61405)G.1D.300-301
Name of Respondent
Avista Corporation
This Report is:
E An originat
tl A Resubmission
Date of Report
mm/dd/yyyy
4t15t2016
Year / Period of Report
End of 2015 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 of
ldaho.
2. lftheamountforpreviousyearisnotderivedfrompreviouslyreportedfigures,explaininafootnote.
Linc
No.Accounl
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
1 1. PRODUCTIONEXPENSES :'r.: f., .. ,.': 1. ';;1; ;,.a:::,.::ii:;lj,:::.:a.1 j:.: . "t*,tt;*;E lii,ti.,i llili:li
2 A. Manufactured Gas Production .ii#*A )itt',i:i!:': i: :i'?:t ;lrc !i,:;:.:.i'tl: itirjl?ttt:!::':#.i i, *t i1tl:ii4$i:t :.-,2?.i; :.i! l|i/r,1;:;:!i.; i ii?,4
3 Manufactured Gas Production (Submit Suoolemental Statement)
4 B. Natural Gas Production .:.:':i.:!:.,i ;, f;j};s4:'l::.1.t,ir.1| :.j ": :a ",?::rl:
5 81. Natural Gas Production and Gatherinq i; i ;:4. i; i;:r i:.t.,',:4,.:l faf/; t7J;+;i.;,r, I.:i 1., - " ..1.'. -.r - '' :.dil
6 Operation : i.:Jat.: t l :'. ? ..'a.a.-:\!.' 1*1:'ii::tiqi:i' l
7 750 ODeration SuDervision and Enqineerinq
8 751 Production Maps and RecordsI752 Gas Well Expenses
10 753 Field Lines Expenses
11 754 Fleld Compressor Station Expenses
12 755 Field Comoressor Station Fuel and Power
13 756 Field Measurino and Reoulatino Station ExDenses
14 757 PurificationExDenses
15 758 Gas Well Rovalties
't6 759 Other Exoenses
17 760 Rents
18 IOTAL ODeration (Total of lines 7 throuoh 17)
19 Vlaintenance
20 761 Maintenance Supervision and Enqineerinq
21 762 Maintenance of Structures and lmprovements
22 763 Maintenance of Producinq Gas Wells
23 764 Maintenance of Field Lines
24 765 Maintenance of Field Comoressor Station Eouioment
25 766 Maintenance of Field Measurino and Reoulatino Station EouiDment
26 767 Maintenance of Purification EouiDment
27 768 Maintenance of Drillinq and Cleaninq Equioment
28 769 Maintenance of Other Equiomenl
29 TOTAL Maintenance (Total of lines 20 throuqh 28)
30 TOTAL Natural Gas Production and Gatherinq Cl-otal of lines 18 and 29)
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61{05)G.tD.317
Name of Respondent
Avista Corporation
This Report is:
E An original
E A Resubmission
Date of Report
mm/dd/yyyy
4115t2016
Year / Period of Reporl
End of 2015 I A4
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 of
Idaho.
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)
31 82. Products Extraction '. /,; i.::tr:.., t :r: :ii:ri:Eit :.:' 1, i. tt:.
32 Jperation 1l::,),ii;ril;iQ.:€t :|ti'i:A!,:i1 tt.i"::.,;S ii t:.t )'alj4jii:*
33 770 ODeration Suoervision and Enoineerino
34 771 Operation Labor
35 772 Gas Shrinkaqe
36 773 Fuel
37 774 Power
38 775 Materials
39 776 Operation Supplies and Expenses
40 777 Gas Processed by Others
41 778 Rovalties on Products Extracted
42 779 Marketino 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 Ooeration ffotal ol line 33 throuoh 46)
48 Maintenance
49 784 Maintenance Suoervision and Enqineerinq
50 785 Maintenance of Structures and lmprovements
51 786 Maintenance of Extraction and Refininq Equipment
52 787 Maintenance of Pipe Lines
53 788 Maintenance of Elitracted Products Storage Equipment
54 789 Maintenance of Comoressor EouiDment
55 790 Maintenance of Gas Measurino and Reoulatinq Eouipment
56 791 Maintenance of Other Eouioment
57 IOTAL Maintenance (Total of lines 49 throuoh 56)
58 TOTAL Products Extraction (Total of lines 47 and 571
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61.405)G.1D.318
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Report
mm/dd/yyyy
4t15t2016
Year / Period of Report
End of 2015 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 of
ldaho.
2. lftheamountforpreviousyearisnotderivedfrompreviouslyrepo(edfigures,explaininafoolnote.
Line
No.Account
(a)
Amount for
Current Year
(b)
Amount for
Previous Year
(c)
59 C. Exploration and Develoomenl ,l :::::!E;!,:. iz:::!rt \; :r.l:tt:; i; 1.... \i' ;l:
60 Cperation ,:i;7a4i:|t:.i.t;,: :a 4,:?'r:;,,. i ":l.:i:::.:.i .,;:::}1i.i:?ia;-.f,2!",; ?
61 795 Delav Rentals
62 796 Nonoroductive Well Drillino
63 797 Abandoned Leases
64 798 Other Exoloration
65 TOTAL Exoloration and DeveloDment (Total of lines 61 throuoh 64)
66 D. Other Gas Suoolv Exoenses tii:ir;ti :1ti :t;.li\:: ;\" i ii.:t:: .:,i i;it ;: : ;:: ;.;;1;11;,::V?*tit
67 Cperation 'A!i i:.ia::,i',, :::.: tif i.t litt'l:.tli liiii::iil ::l_:::::+i iii
68 800 Natural Gas Well Head Purchases
69 800.1 Natural Gas Well Head Purchases, lntracompanv Transfers
70 801 Natural Gas Field Line Purchases
71 802 Natural Gas Gasoline Plant Outlet Purchases
72 803 Natural Gas Transmission Line Purchases
73 804 Natural Gas City Gate Purchases 70.619.764 79.162.887
74 804.1 Liquefied Natural Gas Purchases
75 805 Other Gas Purchases
76 805.1 (Less) Purchased Gas Cost Adiustments
77 TOTAL Other Gas Suoolv Exoenses (Total of lines 68 throuoh 76)70.619.764 79.162.887
78 806 Exchanoe Gas
79 Purchased Gas Expenses
80 807.1 Well Expense-Purchased Gas
81 807.2 Operation of Purchased Gas Measurino Stations
a2 807.3 Maintenance of Purchased Gas Measurinq Stations
83 807.4 Purchased Gas Calculations Expenses
84 807.5 Other Purchased Gas Expenses 3.861.400 (5.284.207\
85 TOTAL Purchased Gas Expenses Cfotal of lines 80 throuqh 84)3.861.400 (5.284.207\
|DAHO STATE NATURAL GAS ANNUAL REPORT (tC 5140s)G.|D.319
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Report
nm/dd/yyyy
4t15t2016
Year / Period of Report
End of 2015 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 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
Cunenl Year
(b)
Amount for
Previous Year
(c)
86 808.1 Gas Withdrawn from Storaoe-Debil
87 808.2 (Less) Gas Delivered to Storaoe-Credit
88 809.1 Withdrawals of Liquefied Natural Gas for Processinq-Debit
89 809.2 (Less) Deliveries of Natural Gas for Processino-Credit
90 Gas Used in Utilitv Ooeration-Credit :a::.::aA..a: ;ti ,:. .. .:"5,4?,..+.i ra41 :4/4,.. :. :i | :t1:?:a;.,.r..J.....t,.., ;:;.
91 810 Gas Used for Comoressor Station Fuel-Credit
92 811 Gas Used for Products Extraction-Credil (100.4301 (361.288)
93 812 Gas Used for Other Utilitv Ooerations-Credit
94 TOTAL Gas Used in Utilitv Ooerations-Credit flotal of lines 91 throuoh 93)(1 00.4301 (361.288)
95 813 Other Gas Suoolv Exoenses 379,006 349.436
96 TOTAL Other Gas Suoolv Exoenses ffotal of lines 77.78.85.86 throuoh 89. 94. 95)74.759.740 73,866.828
97 TOTAL Production Exoenses (Total of lines 3. 30. 58. 65. and 96)74.759.740 73.866.828
98 2. NATURAL GAS STOMGE, TERMINALING AND PROCESSING EXPENSES jtiiti+ :l'l:ir : ::r+!**x ]];i :,",iij*1,'l1**:,
99 A. Underground Storaqe Expenses it:=a.s;'iil-aj'r.,";li:,ffi {*{ii}i:;at::1!f ,l:i'::;: .l'iif :}t :i.i:":''ii'l{.rgfei
100 )peration I;,:,1{1;-1;11;1,,1,,*,t*,,tutili,i:t,li;li&d; j,I ;:: 'i: -_i-t: i'. ' ' :. l
101 814 Operation Supervision and Enqineerinq 3.987 2.851
102 815 Maps and Records
103 816 Wells Exoenses
't04 817 Lines Exoense
105 818 Compressor Station Expenses
106 819 CompressorStation Fuel and Power
07 820 Measurinq and Reoulatino Station Exoenses
o8 821 PurificationExoenses
o9 822 Exploration and Develooment
10 823 Gas Losses
1'l 824 Other Exoenses 179.655 190.602
12 825 Storaqe Well Rovalties
13 826 Rents
14 TOTAL Ooeration (Total of lines 101 throuoh 1 13)183.642 193,453
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.1D.320
Name of Respondent
Avlsta Corporation
This Report is:
lFl nn orisinat
[] n Resubmission
Date of Report
mm/dd/yyyy
4115t2016
Year / Period of Report
End of 2015 I Q4
GAS OPERATION AND IIIAINTENANCE 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 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)
115 Maintenance
116 830 Maintenance Suoervision and Enqineerinq
117 831 Maintenance of Structures and lmprovements
118 832 Malntenance of Reservoirs and Wells
119 833 Maintenance of Lines
120 834 Maintenance of Compressor Station Equipmenl
121 835 Maintenance of Measurino and Reoulatino Siation EouiDment
122 836 Maintenance of Puriftcation Eouioment
123 837 Maintenance of Other Eouioment 172.O14 174.172
't24 rOTAL Maintenance (Total of lines 1'16 throuoh 123)172.O14 174.172
125 IOTAL Undemround Storaoe ExDenses (Total of lines 'l,14 and 1241 355,656 367.625
126 B. Other Storaoe Exoenses
127 Coeration
128 840 Ooeralion Suoervision and Enoineerino
129 841 Ooeration Labor and ExDenses
130 842 Rents
't3't 842.1 Fuel
132 M22 Power
133 842-3 Gas Losses
134 IOTAL Ooeration fTotal of lines 128 throuoh 1 33)
135 l\raintenance
136 843-1 Maintenance SuDervision and Enoineerino
137 843.2 Maintenance of Structures
138 843.3 Maintenance of Gas Holders
139 843.4 Mainlenance of Purification Eouioment
140 843.5 Maintenance ot Liouefaclion touiDment
141 843.6 Mainlenance of Vaoorizino Eouiomeni
142 843.7 Mainlenance of Comoressor Eouioment
143 843.8 Maintenance of Measurino and Reoulalino Eouioment
144 843-9 Mainlenance of Other Eouioment
145 I'OTAL Maintenance fTotal of lines 136 throuoh 144)
146 IOTAL Other Storaoe Exoenses (Tolal oflines 134 and 145)
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.1D.321
Name of Respondent
Avista Corporation
This Report is:
Ix-l nn originat
E A Resubmission
Date of Report
mm/cld/yyyy
4t15t2016
Year / Period of Report
End of 2015 I A4
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 lo 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
Current Year
(b)
Amount for
Previous Year
(c)
147 C. Liouefied Natural Gas Terminalino and Processinq Expenses
148 Operation
149 844.1 Ooeration Suoervision and Enoineerino
150 844.2 LNG Processino Terminal Labor and Exoenses
151 844.3 Liouefaction Processino Labor and ExDenses
152 844.4 Liouefaction Transoortation Labor and ExDenses
153 844.5 Measurino and Reoulatino Labor and ExDenses
154 844.6 Comoressor Slaiion Labor and Exoenses
155 844.7 Communicelion Svstem Exoenses
156 844.8 System Control and Load Dispatching
157 845.1 Fuel
158 845.2 Power
159 845.3 Rents
160 845.4 Demunaqe Charoes
161 845.5 (Less) Wharfaqe Receiots-Credit
162 845.6 Processino Liouefied or Vaoorized Gas by Others
163 846.1 Gas Losses
164 846.2 Other ExDenses
165 TOTAL Ooeration ffotal of lines 149 throuqh 164)
166 Maintenance
167 847.'l Maintenance Suoervision and Enoineerino
168 847.2 Maintenance of Structures and lmorovements
169 847.3 Maintenance of LNG Processino Terminal Eouiomenl
170 847.4 Maintenance of LNG Transoortation EouiDment
171 847.5 Maintenance of Measurino and Reoulatino EouiDment
172 847.6 Maintenancc of Comoressor Station EouiDment
173 847.7 Maintenance of Communication Eouioment
174 847.8 Maintenance of Other Eouioment
175 TOTAL Maintenance (Total of lines 167 throuoh 174)
176 TOTAL Liouefied Nat Gas Terminalino and Proc Exo ffotal of lines 165 and 175)
177 TOTAL Natural Gas Storaoe (Total of lines 125. '146. and 176)355.656 367.625
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61{05)G.tD.322
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Report
mm/dd/Wyy
4t15t2016
Year / Period of Report
End of 2015 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 ol
ldaho.
2. lftheamountforpreviousyearisnotderivedfrompreviouslyreportedfigures,explaininafootnote.
Line
No.Account
(a)
Amounl for
Current Year
(b)
Amounl for
Previous Year
(c)
178 TRANSMISSION EXPENSES ' aii ;{.; t!i:.#. Z:ir. : i.:: :::. i?l::- ?f;Wi.;i|..r!{} $.r*-:1. \'' - - .:,: .. 'l
179 )peration *j,.,a.'.'" ::: ; :.'-4j*:irii:{ii:::: f . ;, :t;.:.7ilt:i,:'..1;
180 850 Ooeration Suoervision and Enoineerino
18'l 851 Svstem Control and Load Disoatchino
182 852 Communication Svstem Exoenses
183 853 Comoressor Station Labor and Exoenses
184 854 Gas for Comoressor Station Fuel
185 855 Other Fuel and Power for Compressor Stations
't 86 856 Mains Exoenses
187 857 Measurinq and Requlatinq Station Expenses
188 858 Transmission and Compression of Gas bv Others
18S 859 Other Exoenses
I90 860 Rents
191 I'OTAL Operation (Total of lines 180 throuoh 190)
192 \4ainlenance
193 861 Maintenance SuDervision and Enqineerinq
194 862 Maintenance of Structures and lmorovements
195 863 Maintenance of Mains
196 864 Maintenance of Comoressor Station Eouipmenl
197 865 Maintenance of Measurino and Reoulatino Station Eouioment
198 866 Maintenance of Communication Eouiomenl
'199 867 Maintenance of Other Eouioment
200 |OTAL Maintenance (Total of lines 193 throuqh 199)
201 TOTAL Transmission (Total of lines 191 and 200)
202 DISTRIBUTION EXPENSES
203 )peration n:;'l: -i ''-i l'.q '-'1.- : ri ...i.: :;l:' r.." ilii+|.i. "'i;- r rr"i{lir jilr, t:ii. ir!
204 870 Operation Suoervision and Enoineerino 407.611 536.928
205 87'l Distribution Load Dispatchinq
206 872 Compressor Station Labor and Exoenses
207 873 Compressor Station Fuel and Power
|DAHO STATE NATURAL GAS ANNUAL REPORT (tC 61405)G.tD.323
Name of Respondent
Avlsta Corporation
This Report is:
E An originat
tl A Resubmission
Date of Report
mm/dd/yyyy
41',!512016
Year / Period of Report
End of 2015 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 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)
208 874 Mains and Services ExDenses 929.926 980,400
209 875 Measurino and Reoulatino Station Exoenses-General 39.681 30,667
210 876 Measurino and Reoulatino Siation ExDensesJndustrial 1.205 '1.674
211 877 Measurino and Reoulatino Siation ExDenses-Citv Gas Check Station 72.254 91.226
212 878 Meter and House Reoulator ExDenses 167.592 515,652
213 879 Customerlnstallations Exoenses 845.023 641.658
214 880 Other Exoenses 555.450 736.5M
2'.t5 881 Rents 't0.516 11.997
216 I-OTAL Operation (Total of lines 2O4 throuqh 215)3.O29.258 3.546.706
217 Vlaintenance
218 885 Maintenance Supervision and Enqineering 55.617 73.3S8
219 886 Maintenanee of Structures and lmprovements
220 887 Maintenance of Mains 365.872 619.M4
221 888 Maintenance of Comoressor Station Equipment
222 889 Maintenance of Measurino and Reoulatino Station Eouioment-General 62.927 63.244
223 890 Maintenance of Measurino and Reoulatino Station Eouioment-lndustrial 93.850 1 19.073
224 891 Maintenance of Meas. and Reo. Station Equipment{itv Gate Check Station 63.901 30.706
225 892 Maintenance of Services 668.326 826-277
226 893 Maintenance of Meters and House Reoulators 721.423 713.858
227 894 Maintenance of Other EouiDment s4.610 63,840
228 I-OTAL Maintenance (Total of lines 218 throuoh 227)2.086.926 2.510.O40
229 I-OTAL Distribution Exoenses (Total of lines 216 and 228\5.1 16.184 6.056.746
230 '. CUSTOMERACCOUNTS EXPENSES
231 )peration
232 901 Suoervision 75.163 68.081
233 902 Meter Readino Exoenses 226.450 187.',t11
234 903 Customer Records and Collection Expenses 't.822.871 I 663 379
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.tD.324
Name of Respondent
Avista Corporation
This Report is:
lx-l nn orisinat
f] n Resubmission
Date of Reporl
mm/dd/yyyy
4t15t2016
Year / Period of Report
End of 2015 I Q4
GAS OPERATION AND MAINTENANCE EXPENSES. IDAHO
lnstructions
1. For each prescribed account below, report operation and mainlenance expenses as allocated by the Results ofOperations 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
Current Year
(b)
Amount for
Previous Year
(c)
235 904 Uncollectible Accounts 641 .673 578.567
236 905 Miscellaneous Customer Accounts Expenses 5s.626 41.460
237 TOTAL Customer Accounts Exoenses (Total of lines 232 throuoh 236)2.a21 .783 2.538.598
238 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES ,.:,4.=,;:' :: ;:,.,. :..,,.:g:!X$i;i,?a::.:;:,.:a :t,..::;',::'.::.,.....,': :.t;.a<,{:j l:.: i;i :1!i.,t -'i...:i:i
239 Ooeration ';ij;;,;:,;i;,;1;,1,V.;.,1ii".,ri!:::.ta::|!.t ifir6:iiir lii, rl?.;1.JiE:)::t::.n : ;:.":.1:1.1;'!:,i'::
240 907 Suoervision
241 908 Customer Assistance Exoenses 137.617 123.267
242 909 lnformational and lnstructional Exoenses 182,1 55 188,335
243 910 Miscellaneous Customer Service and lnformational Exoenses 22,600 37,444
244 TOTAL Customer Service and lnformational Exoenses ffotal of lines 240 throuoh 243)342,372 349,046
245 7- SALES EXPENSES 'i. :i. ).;ia! : i:'i:. :1.: : ; i ii I 1:1i'ltl31;:fi ,:; 1::) i:i!i1 1;):lt:i::t:i::)a:i;t:iit]ti*:i\:t;4:;4::ar:i*r}iji*L
246 Ooeration .ia*:.;.f ;::' , ).!t',:.x!.:.;:t: !.: :.:r
247 9'l 1 Suoervision
248 9t2 Demonstratinq and Sellinq Expenses
249 9"13 Advertisino Exoenses
250 916 Miscellaneous Sales Exoenses
251 TOTAL Sales Expenses (Total of lines 247 throuqh 250)
252 8. ADMINISTRATIVE AND GENERAL EXPENSES ;., ;,;r:.::;:it',.1:; I .' :'r:::,:*.li;1.;'.r:'::;::.":;i.::. | . 4 t r.. ;-). r'..-. Q.: :; ),. :rl | ., .1.:. ;
253 Operation
254 920 Administrative and General Salaries 2.344.626 1.543.470
255 921 Office Supplies and Expenses 306.482 346.677
256 922 (Less) Administrative Expenses Transferred-Credit (5.054'(6.062)
257 923 Outside Services Employed 69'1 .808 940.638
258 924 Propertv lnsurance 89.331 98,065
259 925 lniuries and Damaqes 258.446 252.164
260 926 Employee Pensions and Benefits 128.010 145.999
261 927 FranchiseRequirements
262 928 Requlatory Commission Expenses 323.403 291.244
263 929 (Less) Duplicate Charqes-Credil
264 930.1 General Advertisinq Expenses 322.322 296.832
265 930.2 Miscellaneous General Expenses
266 931 Rents 70.552 63.911
267 TOTAL Ooeration (Total of lines 254 throuoh 266)4.529.926 4.372.938
268 Vlaintenance
269 932 Maintenance of General Planl 744.577 716,514
270 TOTAL Administrative and General Exoenses (Total ol lines 267 and 269)5.274,503 5.089.452
271 IOTAL Gas O&M Expenses (Total of lines 97 , 177 ,201 , 229, 237 , 244, 251 , 270)88,670,238 88,268,295
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61405)G.tD 325
Name of Respondent
Avista Corporation
This Report is:
E An originat
f] n Resubmission
Date of Report
mm/dd/yyw
4t't5t2016
Year / Period of Report
End of 20'15 lQ4
GAS TRANSMISSION MAINS .IDAHO
lnstr
1.
2.
uctlons
Report below the requested details oftransmission mains in system operated by respondent at end of year in the state of ldaho.
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.
Line
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
1.1\
Taken Up
or Abandoned
During Year
in Feet
1el
Total Length
in Use
End of Year
in Feet
/fl
1
2
3
4
5
b
7
8
9
10
11
12
13
14
15
16
't7
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33u
35
36
37
38
39
40
NOTE:
ln accordance with the deftnitions 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 (IC 5I405)G.tD.514
Name of Respondent
Avista Corporation
This Report is:
Ixl nn originat
[] n Resubmission
Date of Report
mm/dd/yyyy
4115t2014
Year / Period of Report
End of 2015 I Q4
GAS DISTRIBUTION IIIAINS - IDAHO
lnstr
1.
2.
uctions
Report below the requested details of distribution mains in system operated by respondent at end of year in the state of ldaho.
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.
Line
No.
Kind of
Material
(a)
Diameter of
Pipe
in lnches
(b)
Total Length in Use
Beginning of Year
in Feet
1c'l
Laid During Year
in Feet
/.1\
Taken Up
or Abandoned
During Year
in Feet
Total Length
in Use
End of Year
in Feet
(n
1 Steel Wraooed Less than 2"1.763.890 4.277 1 .759.6't 3
2 Steel Wraooed 2" to 4"62't.509 106 621 .403
3 Steel Wraooed 4" to 8"411.576 53 411.629
4 Steel Wraoped 8" to 12"12.197 12.197
5 Steel WrapDed Over 12"
6
7I Plastic Less than 2"5.533.070 49.896 5.582.966
9 Plastic 2" lo 4"1.473.912 21,226 1.495.138
10 Plastic 4" to 8"618,024 5,174 623,1 98
't1 Plastic 8" to '12"
12 Plastic Over 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
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61{05)G.tD.514A
Name of Respondent
Avista Corporation
This Report is:
E Anoriginal
f] e Resubmission
Date of Report
mm/dd/yyyy
4t1st2016
Year / Period of Report
End of 2015 I Q4
SERVICE 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.
Line
No.
Type of
Material
la)
Diameter of
Pipe
in lnches
lbl
Number of
Service Pipes
Beginning of YeaI
(c)
Added
During Year
1c)
Retired
During Year
/d'l
Number of
Service Pipes
End of Year
(e)
Average
Length
in Feet
{fl
1 Steel Wraooed 1" or Less 1 1.398 35 1',| 433
2 Steel Wraooed 1" to2"193 2 19'1
3 Steel WraDDed 2" to 4"1 6
4 Steel WrapDed 4'to 8'1 1
5 Steel Wraooed Over 8"
6 Steel Wraooed Unknown 388 9 379
7
I Plastic 1 " or Less 59,143 1.165 60.308
I Plastic 1" to 2"265 2 267
10 Plastic 11 11
11 Plastic 4" to 8"2 1 3
12 Plastic Over 8"
13 Plastic Unknown 2,345 2'.15 2.',t30
14
15 Other Unknown 106 u 22
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33u
35
36
37
38
39
40
(1) lnformation not available.
IDAHO STATE NATURAL GAS ANNUAL REPORT OC 6I{05)G.rD.514B
Name of Respondent
Avista Corporatlon
This Report is:
lxl nn originat
[] n Resubmission
Date of Report
mm/dd/yyyy
411512016
Year / Period of Reporl
End of 2015 I Q4
REGULATORS-GAS.IDAHO
lnstructions
't . Report below the requested details of gas regulators in possession of the respondent at the end of the year in the state of ldaho.
Line
No.
Size
(a)
Type
(b)
Make
(c)
Capacity
(d)
ln Service
Beginning of Year
Iel
Added During
Year
/fl
Retired During
Year
1o)
ln Plant
End of Year
(hI
2 No Data available
3
4
5
6
7
8I
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
?4
35
36
37
38
39
40 Total
|DAHO STATE NATURAL GAS ANNUAL REPORT (rC 6140s)G.tD.514C
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Report
nm/ddrlyyy
4115120',16
Year / Period of Report
End of 2015 I A4
CUSTOMER METERS - GAS - IDAHO
lnstructions
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,
Line
No.
Size
(a)
Type
(b)
Make
(c)
Capacity
(d)
ln Service
Beginning of Year
(e)
Added During
Year
(fl
Retired During
Year
(ol
ln Plant
End of Year
(h)
Ail AI Ail AI 78.677 '1,974 1,244 79,407
2
3
4
5
b
7
8I
10
11
12
13
't4
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
i1) The Company's systems do not supply meter information tracking by type of meter.
IDAHO STATE NATURAL GAS ANNUAL REPORT (lC 61405)G.rD.514D
Name of Respondent
Avista Corporation
This Report is:
E An originat
E A Resubmission
Date of Report
mm/dd/yyyy
4t1512016
Year / Period of Report
End of 20'15 I Q4
GAS ACCOUNT - NATURAL GAS - IDAHO
lnstructions
'1. The purpose of this schedule is to account for the quantity of natural gas received and delivered by the respondent for service in the state of ldaho.
2. Natural gas means either natural 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 specify the line on which such quantities are listed.
5. lf the respondent operates two or more systems which are not interconnected, submit separate pages for this purpose.
6. lndicate by footnote the quantities of gas nol subject to FERC regulation which did not incur FERC regulatory costs by showing ('l ) the local distribution
volumes another jurisdictional pipeline delivered to the local distribution company portion of the reporting pipeline, (2) the quantities that the reporting
pipeline transported or sold through its local distribution facilities or intrastate facilities and which the reporting pipeline received through gathering
facilities or intrastate facilities, but not through any of the interstate portion of the 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 footnote (1) the system supply quantities of gas that are stored by the reporting pipeline during the reporting year and also reported as sales,
transportation and compression volumes by the reporting pipeline during the same reporting 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 transport in a future reporting year, and (3) contract. storage quantities.
9. Also indicate the volumes oI pipeline production field sales that are included in both the company's total sales figure and the company's total transportation
figure. Add additional information as necessary to the footnotes.
Line
No.Accounl
(a)
Refer to
Form 2
Page
(b)
Amount of Dth
Year to Date
(c)
Amount of Dth
Cunent 3 Months Ended
Quaierly Only
(d)
Name of Svstem
2 3AS RECEIVED
3 Gas Purchases (Accounts 800-805)24.549.444
4 Gas of Others Received for Gatherino (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 4.450.678
7 Gas of Others Received for Contract Storage (Account 489.4)307
8 Exchanoed Gas Received from Others (Accounl 806)328 (18_614
I Gas Received as lmbalances (Account 806)324
10 ReceiDts of ResDondent's Gas Transoorted bv Others (Account 858)332
1',\Other Gas Withdrawn from Storaoe (Exolain)600.367
12 Gas Received from Shippers as Compressor Station Fuel
13 Gas Received from Shiooers as Lost and Unaccounted For
14 Other Receiols {Soecifv) (footnote details)
15 Total Receipts (Total of lines 3 throuoh 14)29.582.275
16 GAS DELIVERED
't7 Gas Sales (Accounts 480484)24.488.948
18 Deliveries of Gas Gathered for Others {Account 489.1'l 303
19 Deliveries of Gas Transoorted for Others (489.2)305
20 Deliveries of Gas Distributed for Others (Account 489.3)301 4.450.678
21 Deliveries of Contract Storaoe Gas (Account 489.4)307
22 Exchanoe Gas Delivered to Others (Account 806)328
23 Gas Delivered as lmbalances (Account 858)328
24 Deliveries of Gas to Others for TransDortation (Account 858)332
25 Other Gas Delivered to Storaoe (Exolain) n
26 Gas Used for Compressor Station Fuel 509 642.649
27 Other Deliveries (Specify) (footnote details)
28 Total Deliveries (Total of lines 17 throuqh 27)29.582.275
29 GAS UNACCOUNTED FOR
30 Production System Losses
31 Gatherinq System Losses
32 fransmission System Losses
33 Distribution Svstem Losses
34 Storaqe System Losses
35 Other Losses (Specify) (footnote details)
36 fotal Gas Unaccounied For (Total of lines 30 throuoh 35)
37 Total Deliveries and Gas Unaccounted For (Total of lines 28 and 36)29.582.275
(1)Represents net gas withdrawals and injections.
IDAHO STATE NATURAL GAS ANNUAL REPORT (IC 61-405)G.1D.520