20210903PAC to PIIC Attach 89-1 ID RMP ECAM Q2.pdf

August 30, 2021 VIA ELECTRONIC DELIVERY

Jan Noriyuki Idaho Public Utilities Commission 11331 W. Chinden Blvd. Building 8 Suite 201A
Boise, ID 83714
Re: Rocky Mountain Power’s Quarterly Energy Cost Adjustment Mechanism (ECAM) Report Q2 2021 (January 2021 through June 2021)

Ms. Noriyuki:
Please find enclosed for review Rocky Mountain Power’s (RMP) Q2 2021 (January 2021 through June 2021) energy cost adjustment mechanism (ECAM) report and a confidential zip folder containing the ECAM work papers. The Idaho Public Utilities Commission (IPUC)
authorized implementation of an ECAM in Order 30904 to track and defer the difference between base net power costs (NPC), established in a general rate case (GRC), and actual NPC incurred by RMP to serve its Idaho customers.
This report contains confidential information and is being provided to those that have executed the confidentiality agreement to receive this quarterly ECAM report.
Informal inquiries may be directed to Ted Weston, Idaho Regulatory Manager at (801) 220-
2963. Sincerely,

Joelle Steward Vice President, Regulation Enclosures

cc: Terri Carlock Mike Louis (C) Randy Budge (C) Brian Collings (C)
Maurice Brubaker (C)
Eric Olsen (C) Jim Smith

Idaho
Energy Cost Adjustment Mechanism (ECAM)
Q2 2021
(January 1, 2021 through June 30, 2021)
Summary
Summary Table of Deferred ECAM Balance
NPC Differential for Deferral 5,695,327$
EITF 04-6 Adjustment 37,221
LCAR (604,125)
Total Deferral Before Sharing 5,128,423
Sharing Band 90%
Customer Responsibility 4,615,580
Lake Side 2 Resource Adder 2,967,792
Production Tax Credits (2,564,949)
RTM Adjustment 7,988,145
REC Deferral (119,827)
Interest on Deferral 86,119
Annual Deferral (Jan - Dec 2021) 12,972,862
Unamortized Previous Balance 18,899,721
Depreciation Regulatory Asset -
Total ECAM Rider Revenues (11,617,428)
Total Company Recover 20,255,155$
-

Idaho
Energy Cost Adjustment Mechanism (ECAM)
Q2 2021
(January 1, 2021 through June 30, 2021)
Exhibit 1
Idaho Energy Cost Adjustment Mechanism DeferraJanuary 1, 2021 - December 31, 2021
LinNo.CY 20161 ID Base NPC Embedded in Rates ($PAC-E-16-12 91,646,727$ 2 nnual Idaho Base Load @ meter (MWh PAC-E-16-12 3,407,488
3 NPC Rate Embedded in Base Rates ($/MWh) Line 1 / Line 26.90$
Jan-21 Feb-21 Mar-21 Apr-21 May-21 Jun-21 Jul-21 Aug-21 Sep-21 Oct-21 Nov-21 Dec-21 Total
4 NPC Rate Embedded in Base Rates ($/MWh) Line 26.90$ 26.90$ 26.90$ 26.90$ 26.90$ 26.90$
5 ID Actual Sales @ Meter (MWh 278,026 235,534 251,284 244,147 303,130 460,976 6 ID NPC Collected in Rates ($Line 4 x Line 7,477,703$ 6,334,860$ 6,758,445$ 6,566,493$ 8,152,881$ 12,398,262$ 47,688,644$
7 Total Company Adjusted Actual NPC Excl. Integration Adj. (djusted Actual NP 121,498,117$ 116,743,943$ 122,899,381$ 118,734,784$ 122,753,053$ 198,731,308$ 801,360,584$
8 Intra-Hour Wind Integration Cost ($/MWh 0.19$ 0.19$ 0.19$ 0.19$ 0.19$ 0.19$
9 Third Party Wind Sold to Wholesale (MWh Note (1) 109,395 150,362 90,204 97,798 85,473 85,224 10 Third Party Wind Adjustment ($Line 8 x Line 20,814$ 28,608$ 17,162$ 18,607$ 16,262$ 16,215$ 117,669$
11 Total Company Adjusted Actual NPC ($Line 7 - Line 1 121,477,303$ 116,715,334$ 122,882,218$ 118,716,176$ 122,736,791$ 198,715,093$ 801,242,916$ 12 Total Company Load @ Input (MWh 5,157,135 4,726,803 4,695,850 4,164,164 4,393,449 4,728,054 27,865,454 13 ctual NPC ($/MWh Line 11 / Line 1 23.56$ 24.69$ 26.17$ 28.51$ 27.94$ 42.03$ 28.75$
14 ID Actual Load @ Input (MWh 292,158 276,164 232,036 233,126 353,046 406,911
15 ctual ID NP Line 13 x Line 1 6,881,836$ 6,819,105$ 6,071,976$ 6,646,197$ 9,862,814$ 17,102,043$ 53,383,971$
16 NPC Differentia Line 15 - Line (595,867)$ 484,245$ (686,469)$ 79,705$ 1,709,933$ 4,703,781$ 5,695,327$
EITF 04-6 Adjustmen17 Idaho Allocated EITF 04-6 Deferral Adjustment ($31,536$ 15,319$ 11,635$ (1,209)$ 12,702$ (32,762)$ 37,221$
LCA18ctual Idaho Jurisdictional ECPC minus NPC (Assume Actual = PAC-E-16-12 1,536,179$ 1,536,179$ 1,536,179$ 1,536,179$ 1,536,179$ 1,536,179$ 9,217,071$
19 LCAR Rate @ Meter ($/MWh PAC-E-16-12 5.54$ 5.54$ 5.54$ 5.54$ 5.54$ 5.54$ 20 ID Actual Sales @ Meter (MWh Line 278,026 235,534 251,284 244,147 303,130 460,976 21 LCAR Revenue Collected through Base Rates ($Line 19 x Line 2 1,539,989$ 1,304,627$ 1,391,862$ 1,352,331$ 1,679,038$ 2,553,349$ 9,821,197$
22 LCAR Adjustmen Line 18 - Line 21 (3,810)$ 231,551$ 144,316$ 183,848$ (142,859)$ (1,017,171)$ (604,125)$
ECAM Deferral23 Total ECAM Deferral (NPC Deferral, EITF 04-6 Adjustment, LCA Sum of Lines: 16, 17, 2 (568,142) 731,115 (530,518) 262,343 1,579,775 3,653,849 5,128,423 24 Total ECAM Deferral after 90% Sharing Line 23 x 90 (511,328)$ 658,004$ (477,466)$ 236,109$ 1,421,798$ 3,288,464$ 4,615,580$
Lakeside 2 Resource Adde25 Lake Side 2 Generation (MWh djusted Actual NP 252,754 216,480 199,985 215,285 284,657 322,192 26 Resource Adder Rate ($/MWh PAC-E-13-04 1.99$ 1.99$ 1.99$ 1.99$ 1.99$ 1.99$ 27 Total Lake Side 2 Resource Adder ($Line 25 x Line 2 502,980$ 430,795$ 397,970$ 428,417$ 566,467$ 641,162$ 2,967,792$
Production Tax Credits (PTCs
28 ID Allocated PTCs in Rates ($/MWh PAC-E-16-12 (1.99)$ (1.99)$ (1.99)$ (1.99)$ (1.99)$ (1.99)$ 29 ID Actual Sales @ Meter (MWh Line 278,026 235,534 251,284 244,147 303,130 460,976 30 ID PTCs in Rates ($Line 28 x Line 2 (554,321)$ (469,602)$ (501,002)$ (486,773)$ (604,372)$ (919,081)$ 31 ID Allocated Actual PTCs ($(1,080,048) (1,228,401) (1,051,173) (1,064,584) (947,922) (727,972) 32 ID PTCs Deferral ($Line 31 - Line 3 (525,728)$ (758,799)$ (550,170)$ (577,811)$ (343,551)$ 191,109$ (2,564,949)$
RTM Adjustmen33 ID RTM Adjustment ($1,234,245$ 1,385,662$ 1,248,897$ 1,306,192$ 1,152,519$ 1,660,630$ 7,988,145$
Renewable Energy Credits (REC) Revenu34 ID REC Revenue in Rates ($/MWh PAC-E-16-12 (0.09)$ (0.09)$ (0.09)$ (0.09)$ (0.09)$ (0.09)$ 35 ID Actual Sales @ Meter (MWh Line 278,026 235,534 251,284 244,147 303,130 460,976
36 ID REC Revenue in Rates ($Line 34 x Line 3 (24,951)$ (21,137)$ (22,551)$ (21,910)$ (27,204)$ (41,369)$
37 ID Allocated Actual REC Revenue ($(87,489) (72) (11,534) (154,109) (12,215) (13,529) 38 REC Revenue Adjustment ($Line 37 - Line 3 (62,538)$ 21,065$ 11,017$ (132,199)$ 14,988$ 27,840$ (119,827)$
39 Total Deferral Sum of Lines 24, 27, 32,33, 3 637,632$ 1,736,728$ 630,247$ 1,260,708$ 2,812,222$ 5,809,206$ 12,886,743$
40 Interest Rat Order No. 34866 1.00% 1.00% 1.00% 1.00% 1.00% 1.00%
ECAM Balancing Account ($41 Beginning Balanc 19,050,233$ 16,837,465$ 17,391,877$ 16,430,988$ 16,004,678$ 16,993,093$
42 ECAM Deferral After Sharin Line 2 (511,328) 658,004 (477,466) 236,109 1,421,798 3,288,464
43 Lake Side 2 Resource Adde Line 2 502,980 430,795 397,970 428,417 566,467 641,162 44 PTCs Deferral Line 3 (525,728) (758,799) (550,170) (577,811) (343,551) 191,109 45 RTM Adjustmen Line 3 1,234,245 1,385,662 1,248,897 1,306,192 1,152,519 1,660,630 46 REC Revenue Adjustmen Line 3 (62,538) 21,065 11,017 (132,199) 14,988 27,840 47 Less: Monthly ECAM Rider Revenues allocated to ECA (2,865,347) (1,196,572) (1,605,223) (1,700,527) (1,837,550) (2,412,208)
48 Interes 14,947 14,256 14,087 13,509 13,743 15,576
49 ECAM Deferral Balance ($)16,837,465$ 17,391,877$ 16,430,988$ 16,004,678$ 16,993,093$ 20,405,667$ -$ -$ -$ -$ -$ -$ 20,405,667$
Depreciation Regulatory Asset Balancing Account ($
50 Beginning Balance PAC-E-13-02 (150,512)$ (150,512)$ (150,512)$ (150,512)$ (150,512)$ (150,512)$
51 Monthly Deferral
52 Less: Monthly ECAM Rider Revenues allocated to DepreciatioRegulatory Asset
53 Depreciation Regulatory Asset Ending Balance ($(150,512)$ (150,512)$ (150,512)$ (150,512)$ (150,512)$ (150,512)$ -$ -$ -$ -$ -$ -$ (150,512)$
54 Total ECAM Deferral Balance Sum of Lines 49, 5 16,686,954$ 17,241,366$ 16,280,477$ 15,854,166$ 16,842,581$ 20,255,155$ -$ -$ -$ -$ -$ -$ 20,255,155$
Note:(1) Recovery of non-owned wind integration costs pending future rate cases.