20161201Quarterly Report.pdf

,.,
December I, 2016
VL4 OVERNIGHT DELIVERY
Jean D. Jewell
Commission Secretary
Idaho Public Utilities Commission
472 W. Washington
Boise, ID 83 702
RECE IVED
20 G Ot C -I AH 11 : 0 I
; '--.2,LI C
C JHtAISS ION
1407 W. North Temple, Suite 310
Salt Lake City, Utah 84111
Re: Rocky Mountain Power's Quarterly Energy Cost Adjustment Mechanism Report
Ms. Jewell:
Please find enclosed for review three (3) copies of Rocky Mountain Power's (RMP) 2016 third
quarter (December 2015 through September 2016) Energy Cost Adjustment Mechanism
(ECAM) report and a confidential CD containing the ECAM work papers. The Idaho Public
Utilities Commission authorized implementation of an ECAM in Order No. 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.
Very truly yours,
r/~ Jeffrey K. Larsen
Vice President, Regulation
Enclosures
cc: Randy Lobb
Mike Louis
Randy Budge
Jim Smith
Katie Iverson
Eric Olsen
"
Idaho
Energy Cost Adjustment Mechanism (ECAM)
Exhibit 1
Idaho ECAM Deferral
AcbJal NPC: December 2015 through DecflTlber 2016
line
No. Dec2015 CY2016
ID Base NPC Embedded in Rates($) PAC-E-15-09 • 86,901,906 S 94.801,644
Amual Idaho Base Load @ meter (MWi; PAC-E-15-09 3 328058 3483.480
NPC Rate Embedded in Base Rates ($/MWh) Line 1 /Line2 • 26.11 S 27.21
NPC Oec-15 Jan-16 Feb-16 Mar-16 Aer-16 Ma;r:-16 Jun-16 Jul-1& Aug-1& see-te
4 NPC Rate Embedded in Base Rates ($/MV\lh) Line 3 • 26.11 $ 27.21 $ 27.21 $ 27.21 $ 27.21 $ 27.21 $ 27.21 $ 27.21 $ 27.21 $ 27.21
5 ID Actual Sales@ Meter (MW,; 230182 274886 240338 236 695 220 158 272 080 392199 437402 3n315 291587
6 ID NPC Collected in Rates($) Line 4xLine!: • 6,010.483 $ 7.480.930 $ 6.540,720 $ 6,441.560 $ 5,991,532 $ 7.404.567 $ 10,673,547 $ 11,903,741 $ 10,270.113 $ 7,935.426
7 Total Company Adjusted Actual NPC Exd. Integration Adj.($ Adjusted Actual NPC • 124.952.631 $ 127 .266,973 $ 112.962,667 $ 111,624,599 $ 101.968,591 S 107.913.172 $ 138,649.739 S 141,319,682 S 141.489,017 S 132.663,306
8 Intra-Hour Wnd Integration Cost ($/MW,: • 2.35 S 2.38 S 2.38 S 2.38 S 2.38 S 2.38 S 2.38 S 2.38 S 2.38 S 2.36
9 Third Party Wnd Sold to Wlolesale (M\,••.+a: 130,212 107,042 125,408 121,872 88,057 84,622 66,100 96.221 66.115 59,719
10 ThirdPartyWndAdjustment(S; Une8xline£ I 305,998 $ 254,567 S 296,246 $ 289,836 S 209,417 $ 201,248 $ 204,762 S 228,833 $ 157,236 $ 142,024
11 Total Company Adjusted Actual NPC (S: Line7 -Line 10 • 124,646,633 $ 127.012,.(()6 S 112,664.621 S 111,334,763 $ 101,759.174 S 107,711,923 S 138,644,9n s 141,090,849 $ 141,331.781 S 132.521.282
12 Total Company Load O lnput(MWl; 5.259747 5 234 063 4 585.201 4 556.366 4 233165 4 490640 5146196 5 566066 54n 438 4 563475
13 Actual NPC ($/MW,) Line 11 /Une 12 • 23.70 S 24.27 $ 24.57 $ 24.43 $ 24,04 $ 23.99 $ 26.94 $ 25.35 $ 25.80 $ 29.04
14 ID Actual Load @ lnpu 257 936 291 364 255 515 246,428 238 594 307 756 472 566 475020 387189 275322
15 Actual ID NPC Line 13 x Line 1-4 • 6,112,624 $ 7,070,388 $ 6,278,349 $ 6.021,464 S 5,735.455 $ 7,381,803 $ 12,731,519 $ 12.041,001 $ 9,990.448 $ 7,995,220
16 NPC Differential line 6-Line 15 • 102,141 $ (410,542) S (282,370) $ (420,096) $ (256,077) $ (22,764) S 2,057,972 $ 137,261 S (279,665) $ 59,794
EITF 0-4-6 Adjustment
17 Idaho Allocated EITF 04~ Deferal Adjustment($ I 6,a.45 S 45,788 $ 6,049 S (127-166) S (70,751) S (10,095) $ 4,747$ 150,655 $ 80,093 $ 3,210
LCAR
18 Actual Idaho JlXisdictional ECPC minus NPC (Assume Actual= Base • 1,682,789 $ 1,648,000 $ 1,648,000 S 1,648.000 $ 1,648,000 S 1,648.000 S 1,648,000 $ 1,648,000 S 1,648,000 $ 1,648,000
19 LCAR Rate PAC-E-11-121 PAC-E-15-09 • 6.07 $ 5.68 $ 5.68 $ 5.68 S 5.68 $ 5.68 $ 5.68 $ 5.68 S 5.68 S 5.68
20 ID Actual Sales @ Meter (MWl; Line 5 230182 274.886 240.338 236.695 220.158 272080 392199 437.402 Jn.375 291 587
21 LCAR Revenue CoHected lhrough Base Rates($ Line 19x Line2C • 1,396,661 $ 1,560,552 $ 1,364,420 $ 1,343,735 $ 1,249,858 $ 1,544,622 $ 2,226,545 S 2,483,168 $ 2,142,387 $ 1,655,362
22 LCAR Ad.P,Jstrnent Line 18 -line 21 I 28&,128 S 87,448 S 283,580 S 304,265 $ 398,143 S 103,378 $ (578,545) $ (835,168) $ (4M,387) $ (7,362)
ECAM Deferral
23 Total ECAM Deferral (NPC Deferral, EITF 041-06 Adjustment, LCAR Sum of Lines: 16, 17. 22 • 395,114 $ 12n,307! s 27,259 $ (242 997! $ 71,315 S 20,518 $ 1 484,174 $ j547,252) $ j693,959! $ 55643
24 Total ECAM Deferral after so•t. Sharing Line 23x 90% $ 3551602 $ 124915761 s 241533 S j2181697lS 641183 S 181467 s 113351756 s 149215271 s 162415631 S 501079
Lakeside 2 Resource Adder
25 Lake Side 2 Generation (MV\Jh) Adjusted Actual NPC 215,576 258.573 241.936 182,202 286.482 314.387 306,671 309.636 259,550 220,476
26 Resource Adder Rate (SfMW'I) PAC-E-13-04 • 1.99 $ 1.99 $ 1.99 $ 1.99 S 1.99 $ 1.99 $ 1.99 $ 1.99 $ 1.99 $ 1.99
27 Total Lake Side 2 Resource Adder($) Line 25 x Line 2E • 421,996 S 514,510 S 461,453 $ 362,582 S 570,099 S &25,630 S 810,275 $ 811,578 S 516,505 S 438,747
ProducUon Tax Credits (PTCs)
28 ID ANocated PTCs in Rates ($/MWi: PAC-E-15-09 • (1.99) $ (1.99) $ (1.99) S (1.99) S (1.99) $ (1.99) $ (1.99) $ (1.99) S (1.99)
29 ID Actual Sales @ Meter (MWl; Line 5 274,886 240.338 236.695 220,158 272,080 392.199 437,402 3n.375 291.587
30 ID PTCs in Rates (SJ Line 28xLine2!: $ (548,061) $ {479,180) $ (471,915) $ (438,946) S (542,466) $ (781,955) $ (872.081) $ (752,399) S (581.358)
31 ID Allocated Actual PTCs ($ 1621.705! j486 7751 14006411 j327 028! j502.384l j6708101 !772,2711 j792.043l j524 4011
32 ID PTCs Deferral (S) line 31 -Line 3C • j7316451 $ 1715951 s 711274 S 1111917 S 401082 $ 1111145 S 991810 $ {3916441 s 561957
Unrecovered Deer Creek Mine lnvestmen·
33 ID ADocated Deer Creek Ammortization Expenst: PAC-E-15-09 $ 51931 S 109933 $ 109933 $ 109 933 S 109933 $ 109,933 S ____ 1.1)9,933 S 109i933 __ ._ ___ 109,933 S --J.0:9..,!t33
Renewable Energy Credits (REC) Revenue
34 ID REC Revenue in Rates (SIMW-.: PAC-E-11-12 / PAC-E-15-09 • (1.96) S (0.09) $ (0.09) S (0.09) S (0.09) $ (0.09) S (0.09) S (0.09) $ (0.09) S (0.09)
35 ID Actual Sales @ Meter (MWl; Lines 230,182 274.886 240,338 236.695 220,158 272.080 392.199 437.402 3n.375 291 587
36 ID REC Revenue in Rates (S: Line 34 x Line~ • (451,407) $ (24,669) S (21,56'9) $ (21,242) $ (19,758) $ (24,-417) S (35,197) S (39,254) $ (33,867) $ (26,168)
37 1D Allocated Actual REC Revenue ($ j31996) j3717) 11530) {478) j19599) (-42300) {39) j17757) !42769) j93837)
38 REC Revenue Adjustment (Sl line 37 -Line 3E • 419411 $ 201952 S 20.039 S 20763 $ 159 $ 117 UJI s 351157 S 211498 $ ,81to21 s 1171891
39 Total Deferral Sum of lines 24, 27. 32. 33. 38 • 1,260,941 $ 322,224 $ 628,362 S 345,855 $ 856,292 S 776,228 $ 2,202,267 S 355,289 S (46,672) $ 588,047
40 lnterestRate Order Nos. 32403, 32684 1.00% 1.00% 1.00% 1.00% 100% 1.00% 1.00% 1.00% 1.00% 1.00%
All Customers Balanclng Account($
41 Beginning Balana • 21,617,372 S 22,188,946 S 21.364,095 S 20,744,178 S 20,005,342 $ 19,304,058 $ 19.091,118 S 19,583,961 $ 18,029.470 $ 16,326.583
42 ECAM Deferral After Sharins; Line24 355.602 (249,576) 24,533 (216,697) 64,183 18,467 1,335,756 (492.527) (624,563) 50,079
43 Lake Side 2 Resou~ Adder Line27 428,996 51-4,560 481.453 362,582 570,099 625,630 610,275 616,576 516.505 438,7-47
44 PTCs Deferral Line32 (73,645) (7,595) 71,274 111,917 40,082 111,145 99,810 (39,644) 56,957
45 Deer Creek Ammortization Cost Line33 56,931 109,933 109.933 109.933 109,933 109,933 109,933 109,933 109,933 109.933
46 REC Revenue Adj,ustmen1 Une36 419,411 20,952 20,039 20,763 159 (17,883) 35,157 21,496 (8,902) (67,669)
47 Less: Monthly ECAM Rider Revenue1 {707,906) (1.165,701) (1,266,345) (1,102,121) (1,574,604) (1,005,579) (1,726,230) (1,926,269) (1,671.220) (1,323.-474)
46 lnteres1 18540 18625 18065 17.431 17028 16-410 16827 16488 15005 13851
49 All Customers Deferral Balance (SI • 22188 9-46 S 21 364095 S 20 744178 S 20005342 S 19 30405& S 19091118 S 19583981 S 18029-470 S 16326,583 S 15 605 00&
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Idaho ECAM Deferral
Actual NPC: December 2015 uirough December 20111
Line
No.
NPC
ID Ba&e NPC Embedded in Rates {$)
Annual Idaho Base Load@ meter (MWi:
NPC Rate Embedded in Base Rates ($/MVv'h)
4 NPC Rate Embedded in Base Rates ($/M\l\oti)
5 10 Actual Sales@ Meter (MVv'h;
6 ID NPC Collected in Rates($)
7 Total Company Adjusted Actual NPC Exel. Integration Adj.($
Intra-Hour Wind Integration Cost ($/MW,:
Third Party Wind Sold to Wlolesale (MW(
10 Third Party Wind Adjustment($;
11 Total Company Ad;_isted Actual NPC ($:
12 Total Company load@lnput (MW,:
13 Actual NPC ($/MW,)
14 IDActualLoad@ lnpu
15 Actual ID NPC
16 NPC Differential
EITF 04-6 AdJustmen1
17 Idaho Allocated EITF 04-6 Deferral Adjus1ment ($
LCAR
16 Actual Idaho Jurisdictional ECPC minus NPC (Assume Actual= Base
19 LCAR Rate
20 10 Actual Sales@ Meter (Mvvti;
21 LCAR Revenue Collected through Base Rates($
22 LCAR AdjJstment
ECAM Deferral
23 Total ECAM Deferral (NPC Deferral. EITF 041-06 Ad)Jstment, LCAR
24 Total ECAM Deferral after 90% Sharing
Lakeside 2 Resource Adder
25 Lake Side 2 Generation (Mvvti)
26 Resource Adder Rate ($/Mv'Vh)
27 Total Lake Sida 2 Resource Adder (S)
Production Tu Credits (PTCs)
26 JD Allocated PTCs in Rates ($/MW,:
29 ID Actual Sales@ Meter (MWi:
30 ID PTCs in Rates($)
31 10 Allocated Actual PTCs ($
32 ID PTCs Deferral (S)
Unrecovared Deer Crffk Mine lnvestmen·
33 ID Allocated Deer Creek Ammortization Expenst
Renewa:ble Energy Credits (REC) Revenu,
34 10 REC Revenue in Rates {$/MW,:
35 ID Actual Sales@ Meter (MWi:
36 ID REC Revenue in Rates {S:
37 ID Allocated Actual REC Revenue($ 36 REC Revenue Adjustment (SJ
39 Total Defu ral
40 lnllllrestRate
All Customers Balancing Account (S
41 Beginning Batanc:t
42 ECAM Deferral After Shari°'
43 Lake Side 2 Resource Adder
44 PTCs Deferral
45 Deer Creek Ammortization Cost
46 REC Revenue Adjustmen1
47 Less: Monthly ECAM Rider Revenue,
48 lnlllrest
49 All Customers Deferral Balance (S)
PAC-E-15-09
PAC-E-15-09
line 1 /Line 2
Line3
Line 4x Line!:
Adjusted Actual NPC
Line8xlinel<
Une7-Une 10
Line 11 I Line 12
Line13xlineH
Line6-Line15
PAC-E-11-12 f PAC·E-15-09
Lines
Line 19x Line2C
Line 16 -Line 21
Sum of Lines: 16, 17, 22
Line 23 x 90'1o
Adjusted Actual NPC
PAC-E-13-04
Line25 x Line2t:
PAC-E-15-09
LiM5
Line 28 x Line 2£
Line 31 -Line 3C
PAC-E-15-09
PAC-E-11-121 PAC-E-15-09
Lines
Line 34 ,c Line~
Line37-Line 3€
Sum of Lines 24, 27, 32, 33. 38
Order Nos. 32403, 32684
Line24
Line27
Line32
Line33
Line36
Oct-16 Nov-111 DK-16 Total
80,652,619
1.116,057.945
2,292;166
1,236,716,409
49,11~
25.22
81,358,271
705,653
39,376
16,514.789
16,967,310
(452,520)
292 508
263,_!57
5,1115,425
370,302
1,046,323
443,524
7.288.632
20,005,342
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