HLP BOARD M R 2017 R S P B M JUNE 28, 2017 · 27 Distribution-related 77,644 NCP Demand 41,146 11,713 15,347 9,135 36,195 11 77,353 291 77,644 28 Customer-related 4,492 # of Cust

HEBER LIGHT AND POWER

HLP BOARD MATERIALS

RE:

2017 RATE STUDY

PREPARED FOR BOARD MEETING

OF

JUNE 28, 2017

EXHIBIT A

REVENUE REQUIREMENTS ANALYSIS

EXHIBIT A

Rev. Req.

Unadjusted for Distribution Customer Total

Ln. Rev. Req. [1] Adjustments Allocation Demand Energy Total Related Related Rev. Req.

(a) (b) (c) (d) (e) (f) (g) (h) (i)

Power Production

1 Hydro Maintenance 40,800 - 40,800 40,800 - 40,800 - - 40,800

2 Gas Generation - Fuel Costs 767,471 - 767,471 - 767,471 767,471 - - 767,471

3 Generation Expense [2] 282,000 400,000 682,000 522,000 - 522,000 - 160,000 682,000

4 Total Power Production 1,090,271 400,000 1,490,271 562,800 767,471 1,330,271 - 160,000 1,490,271

Purchased Power Costs

5 Power Purchases 7,226,779 - 7,226,779 - 7,226,779 7,226,779 - - 7,226,779

6 Jordanell Partner Energy 1,103,809 (1,103,809) - - - - - - -

7 Energy Rebates 116,000 - 116,000 - 116,000 116,000 - - 116,000

8 Total Purchased Power Costs 8,446,587 (1,103,809) 7,342,779 - 7,342,779 7,342,779 - - 7,342,779

Distribution Expense - Operations

9 Operations Expense 197,000 - 197,000 - - - 197,000 - 197,000

10 Materials - Operations 18,000 - 18,000 - - - 18,000 - 18,000

11 Safety Materials 47,500 - 47,500 - - - 47,500 - 47,500

12 Meter Expenses 3,000 - 3,000 - - - - 3,000 3,000

13 Total Distribution Expense - Ops. 265,500 - 265,500 - - - 262,500 3,000 265,500

Distribution Expense - Maintenance

14 Maintenance of Structures 899,500 - 899,500 - - - 899,500 - 899,500

15 Maintenance of Station Equipment 501,200 - 501,200 - - - 501,200 - 501,200

16 Metering Maintenance 5,000 - 5,000 - - - - 5,000 5,000

17 Total Distribtion Expense - Maint. 1,405,700 - 1,405,700 - - - 1,400,700 5,000 1,405,700

Customer Accounts Expense

18 Bad Debts Expense 20,000 - 20,000 - - - - 20,000 20,000

Administrative & General [3]

19 Building Expenses 24,020 - 24,020 6,981 - 6,981 13,571 3,469 24,020

20 Training & Travel 156,122 - 156,122 45,371 - 45,371 88,206 22,545 156,122

21 Salaries - Administration [3] 1,541,000 (400,000) 1,141,000 331,590 - 331,590 644,644 164,765 1,141,000

22 Business Office Supplies 8,800 - 8,800 2,557 - 2,557 4,972 1,271 8,800

23 Operations Office Supplies 8,600 - 8,600 2,499 - 2,499 4,859 1,242 8,600

24 Legal Office Supplies 15,500 - 15,500 4,505 - 4,505 8,757 2,238 15,500

25 Postage / Shipping 80,000 - 80,000 23,249 - 23,249 45,199 11,552 80,000

26 Credit Card Fees 65,000 - 65,000 18,890 - 18,890 36,724 9,386 65,000

27 Outside Services 57,000 - 57,000 16,565 - 16,565 32,204 8,231 57,000

28 Employee Pensions & Benefits [3] 967,150 - 967,150 281,067 - 281,067 546,422 139,661 967,150

29 Post-employment Benefits [3] 47,500 - 47,500 13,804 - 13,804 26,837 6,859 47,500

30 Retirement [3] 578,000 - 578,000 167,975 - 167,975 326,560 83,466 578,000

31 Miscellaneous 32,000 - 32,000 9,300 - 9,300 18,079 4,621 32,000

32 Maintenance of General Plant 12,000 - 12,000 3,487 - 3,487 6,780 1,733 12,000

33 Communications 60,963 - 60,963 17,717 - 17,717 34,443 8,803 60,963

34 Trucks 245,500 - 245,500 71,346 - 71,346 138,703 35,451 245,500

35 IT Maint / Support - - - - - - - - -

36 Total A&G Expenses 3,899,155 (400,000) 3,499,155 1,016,902 - 1,016,902 1,976,959 505,293 3,499,155

37 Total Operating Expenses 15,127,213 (1,103,809) 14,023,405 1,579,702 8,110,250 9,689,952 3,640,159 693,293 14,023,405

Generation Related

Description

Heber Light and Power

Electric Utility Cost of Service Study

COST OF SERVICE

Analysis of Revenue Requirements

for the Projected Test Year 2017

($)

HL&P Electric COS_2017_Preliminary (Version 3).xlsx 1 eA XA cxÇwxÜ? \ÇvA

EXHIBIT A

Rev. Req.

Unadjusted for Distribution Customer Total

Ln. Rev. Req. [1] Adjustments Allocation Demand Energy Total Related Related Rev. Req.

(a) (b) (c) (d) (e) (f) (g) (h) (i)

Generation Related

Description



COST OF SERVICE

Analysis of Revenue Requirements

for the Projected Test Year 2017

($)

Other Revenue Requirements

38 Average Annual Debt Service [4] 1,201,690 - 1,201,690 293,582 - 293,582 893,547 14,562 1,201,691

39 Capital Adds Paid from Cash [5] 1,091,896 - 1,091,896 427,574 - 427,574 627,990 36,332 1,091,896

40 Reserve Funding [6] 135,000 - 135,000 52,864 - 52,864 77,644 4,492 135,000

41 Other Deductions [7] 20,200 - 20,200 - - - - 20,200 20,200

42 Total Other Revenue Requirements 2,448,786 - 2,448,786 774,020 - 774,020 1,599,181 75,586 2,448,787

43 Sub-total Revenue Requirements 17,575,999 (1,103,809) 16,472,191 2,353,723 8,110,250 10,463,973 5,239,340 768,879 16,472,192

Revenue Credits

44 Other Income [8] (140,000) - (140,000) - (100,000) (100,000) (40,000) - (140,000)

45 Connection Fees [9] (35,000) - (35,000) - - - - (35,000) (35,000)

46 Interest Income [10] (25,000) - (25,000) (6,108) - (6,108) (18,589) (303) (25,000)

47 Pole Attachment Revenue [11] (41,000) - (41,000) - - - (41,000) - (41,000)

48 Receivables Penalty Income [12] (42,000) - (42,000) (6,001) (20,679) (26,681) (13,359) (1,960) (42,000)

49 Write-offs Collected [12] (2,000) - (2,000) (286) (985) (1,271) (636) (93) (2,000)

50 Meter Reading Charge [13] (1,000) - (1,000) - - - (1,000) (1,000)

51 Total Revenue Credits (286,000) - (286,000) (12,395) (121,664) (134,059) (113,585) (38,357) (286,000)

52 Sub-Total Revenue Requirements 17,289,999 (1,103,809) 16,186,191 2,341,328 7,988,586 10,329,914 5,125,755 730,522 16,186,192

53 Annual Dividends (Return) 300,000 - 300,000 43,395 148,063 191,458 95,002 13,540 300,000

54 Total Revenue Requirements 17,589,999 (1,103,809) 16,486,191 2,384,723 8,136,649 10,521,372 5,220,758 744,062 16,486,192

[1] Primary source for inputs is the 2017 approved budget.

[2] Resource / Dispatch salaries and wages categorized as A&G Expense for budget purposes. Split between Generation (60%) and Customer (40%) based on approximation

of split for the 2015 Rate Study.

[3] Allocated based on functionalized salaries and wages - see worksheet "Analysis of Functionalized Salaries & Wages and Associated Overheads for Year 2017."

[4] Based on an analysis of average debt service for years 2017-2021. See worksheet; "Analysis of Average Debt Service for the Period 2017 - 2021."

[5] Based on an analysis of capital additions for years 2017-2021. See worksheet "Analysis of Capital Additions Paid from Cash for the Period 2017 - 2021."

[6] Allocated based on functionalized Capital Additions Paid from Cash (line 40).

[7] Other Deductions related to community relations - assigned to Customer Related.

[8] $100k related to UAMPS True-up assigned to Generation Related - Energy. The remaining $40k assigned to Distribution-Related.

[9] Assigned to Customer-Related.

[10] Allocated to functions based on allocated Debt Service (line 38).

[11] Assigned to Distribution-Related function.

[12] Allocated to functions based on Sub-total Revenue Requirements (line 43).

[13] Assigned to Customer-Related.function.


EXHIBIT B

REVENUE REQUIREMENTS ALLOCATION

EXHIBIT B

Projected Sub-

Test Year Allocation Yard Total Street Total

Ln. Ref. Rev. Req. Basis Residential Small Medium Large Total Lights System Lights System

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)

Allocation Factors

1 No. of Customers Sch. D 0.878838 0.099751 0.011951 0.001467 0.113169 0.007567 0.999575 0.000425 1.000000

2 kWh Sales Sch. C 0.526415 0.121793 0.199259 0.143593 0.464645 0.000328 0.991388 0.008612 1.000000

3 NCP Demand Sch. E 0.529939 0.150860 0.197665 0.117648 0.466173 0.000143 0.996255 0.003745 1.000000

4 CP Demand Sch. F 0.601348 0.103976 0.170109 0.122586 0.396671 0.000071 0.998090 0.001910 1.000000

Allocation of Revenue Requirements

Generation

5 Energy-related Sch. B 767,471 kWh Sales 404,008 93,473 152,925 110,204 356,602 252 760,861 6,610 767,471

6 Demand-related Sch. B 562,800 CP Demand 338,439 58,518 95,737 68,992 223,246 40 561,725 1,075 562,800

7 Customer-related Sch. B 160,000 # of Cust. 140,614 15,960 1,912 235 18,107 1,211 159,932 68 160,000

8 Sub-total Generation CALC 1,490,271 883,061 167,951 250,575 179,430 597,955 1,502 1,482,519 7,752 1,490,271


9 Energy-related Sch. B 7,342,779 kWh Sales 3,865,347 894,302 1,463,114 1,054,373 3,411,789 2,406 7,279,542 63,237 7,342,779

Distribution

10 Demand-related Sch. B 1,663,200 NCP Demand 881,395 250,911 328,756 195,672 775,339 237 1,656,971 6,229 1,663,200

11 Customer-related Sch. B 28,000 # of Cust. 24,607 2,793 335 41 3,169 212 27,988 12 28,000

12 Sub-total Distribution CALC 1,691,200 906,002 253,704 329,090 195,713 778,507 449 1,684,959 6,241 1,691,200

Administrative & General

13 Generation-related Sch. B 1,016,902 CP Demand 611,513 105,733 172,984 124,658 403,375 73 1,014,961 1,942 1,016,902

14 Distribution-related Sch. B 1,976,959 NCP Demand 1,047,668 298,244 390,775 232,585 921,605 282 1,969,555 7,404 1,976,959

15 Customer-related Sch. B 505,293 # of Cust 444,071 50,403 6,039 741 57,184 3,824 505,078 215 505,293

16 Sub-total Administrative & General CALC 3,499,155 2,103,252 454,381 569,797 357,985 1,382,164 4,178 3,489,594 9,561 3,499,155

17 Total Operating Expenses CALC 14,023,405 7,757,662 1,770,337 2,612,577 1,787,502 6,170,415 8,536 13,936,613 86,791 14,023,405

Other Requirements

Annual Debt Service

18 Generation-related Sch. B 293,582 CP Demand 176,545 30,525 49,941 35,989 116,455 21 293,021 561 293,582

19 Distribution-related Sch. B 893,547 NCP Demand 473,526 134,801 176,623 105,124 416,547 127 890,200 3,347 893,547

20 Customer-related Sch. B 14,562 # of Cust 12,798 1,453 174 21 1,648 110 14,556 6 14,562

21 Total Debt Service CALC 1,201,691 662,868 166,779 226,737 141,135 534,651 259 1,197,778 3,913 1,201,691

Capital Adds Paid from Cash

22 Generation-related Sch. B 427,574 CP Demand 257,121 44,457 72,734 52,415 169,606 31 426,758 816 427,574

23 Distribution-related Sch. B 627,990 NCP Demand 332,797 94,739 124,131 73,882 292,752 90 625,638 2,352 627,990

24 Customer-related Sch. B 36,332 # of Cust 31,930 3,624 434 53 4,112 275 36,317 15 36,332

25 Total Capital Additions CALC 1,091,896 621,847 142,820 197,300 126,350 466,470 395 1,088,712 3,184 1,091,896

($)

Description

General Service



COST OF SERVICE


for the Projected Test Year FY 2017


EXHIBIT B

Projected Sub-



(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)

($)

Description

General Service



COST OF SERVICE



Other Requirements (cont.)

Reserve Funding

26 Generation-related 52,864 CP Demand 31,790 5,497 8,993 6,480 20,970 4 52,764 101 52,864

27 Distribution-related 77,644 NCP Demand 41,146 11,713 15,347 9,135 36,195 11 77,353 291 77,644

28 Customer-related 4,492 # of Cust 3,948 448 54 7 508 34 4,490 2 4,492

29 Total Reserve Funding 135,000 76,884 17,658 24,394 15,622 57,673 49 134,606 394 135,000

Other Deductions

30 Customer-related 20,200 # of Cust 12,147 2,100 3,436 2,476 8,013 1 20,161 39 20,200

31 Total Other Requirements CALC 2,448,787 1,373,747 329,357 451,867 285,582 1,066,807 704 2,441,257 7,530 2,448,787

32 Sub-total Revenue Requirements CALC 16,472,192 9,131,409 2,099,694 3,064,444 2,073,085 7,237,222 9,240 16,377,871 94,321 16,472,192

Revenue Credits

33 Genation - Demand Sch. B (12,395) CP Demand (7,454) (1,289) (2,108) (1,519) (4,917) (1) (12,371) (24) (12,395)

34 Generation - Energy Sch. B (121,664) kWh Sales (64,046) (14,818) (24,243) (17,470) (56,531) (40) (120,616) (1,048) (121,664)

35 Distribution-related Sch. B (113,585) NCP Demand (60,193) (17,135) (22,452) (13,363) (52,950) (16) (113,159) (425) (113,585)

36 Customer-related Sch. B (38,357) # of Cust (33,709) (3,826) (458) (56) (4,341) (290) (38,340) (16) (38,357)

37 Total Revenue Credits CALC (286,000) (165,402) (37,068) (49,261) (32,409) (118,738) (347) (284,487) (1,513) (286,000)

38 Sub-total Net Revenue Requirements CALC 16,186,192 8,966,008 2,062,626 3,015,182 2,040,676 7,118,484 8,892 16,093,384 92,808 16,186,192

39 Annual Dividends (Return) Sch. B 300,000 Sub-total R.R. 166,179 38,229 55,884 37,823 131,936 165 298,280 1,720 300,000

40 Total Net Revenue Requirements CALC 16,486,192 9,132,186 2,100,855 3,071,067 2,078,498 7,250,420 9,057 16,391,664 94,528 16,486,192

Demand Related Rev. Requirements

41 Operating Expenses CALC 5,219,862 2,879,015 713,406 988,252 621,908 2,323,565 632 5,203,212 16,650 5,219,862

42 Other Requirements CALC 2,373,201 1,312,925 321,732 447,769 283,025 1,052,526 283 2,365,733 7,467 2,373,201

43 Revenue Credits CALC (125,979) (67,647) (18,424) (24,560) (14,882) (57,867) (17) (125,530) (449) (125,979)

44 Sub-Total Demand Related CALC 7,467,083 4,124,293 1,016,714 1,411,460 890,050 3,318,224 898 7,443,415 23,669 7,467,083

45 Add: Annual Dividends CALC 138,397 76,441 18,844 26,160 16,496 61,501 17 137,959 439 138,397

46 Total Demand Related CALC 7,605,481 4,200,734 1,035,558 1,437,621 906,547 3,379,725 914 7,581,373 24,107 7,605,481

Energy Related Rev. Requirements

47 Operating Expenses CALC 8,110,250 4,269,355 987,774 1,616,039 1,164,577 3,768,391 2,658 8,040,403 69,846 8,110,250

48 Revenue Credits CALC (121,664) (64,046) (14,818) (24,243) (17,470) (56,531) (40) (120,616) (1,048) (121,664)

49 Sub-Total Energy Related CALC 7,988,586 4,205,309 972,957 1,591,797 1,147,107 3,711,860 2,618 7,919,787 68,799 7,988,586

50 Add: Annual Dividends CALC 148,063 77,943 18,033 29,503 21,261 68,797 49 146,788 1,275 148,063

51 Total Energy Related CALC 8,136,649 4,283,252 990,990 1,621,300 1,168,368 3,780,657 2,666 8,066,575 70,074 8,136,649

52 Sub-total Demand and Energy CALC 15,742,129 8,483,985 2,026,547 3,058,921 2,074,914 7,160,382 3,581 15,647,949 94,181 15,742,129


EXHIBIT B

Projected Sub-



(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)

($)

Description

General Service



COST OF SERVICE



Customer Related Rev. Requirements

53 Operating Expenses CALC 693,293 609,292 69,157 8,285 1,017 78,459 5,246 692,998 295 693,293

54 Other Requirements CALC 75,586 60,823 7,625 4,098 2,558 14,281 421 75,524 62 75,586

55 Revnue Credits CALC (38,357) (33,709) (3,826) (458) (56) (4,341) (290) (38,340) (16) (38,357)

56 Sub-Total Customer Related CALC 730,522 636,406 72,956 11,925 3,519 88,399 5,377 730,182 341 730,522

57 Add: Annual Dividends CALC 13,540 11,795 1,352 221 65 1,638 100 13,533 6 13,540

58 Total Customer Related CALC 744,062 648,201 74,308 12,146 3,584 90,038 5,476 743,715 347 744,062

59 Total Revenue Requirements CALC 16,486,192 9,132,186 2,100,855 3,071,067 2,078,498 7,250,420 9,057 16,391,664 94,528 16,486,192


EXHIBIT C

COST OF SERVICE SUMMARY

EXHIBIT C

Yard Sub-Total Street Total

Ln. Ref. Residential Small Medium Large Total Lights System Lights System

(a) (b) (c) (d) (e) (f) (g) (h) (i)

Revenues from Existing Rates

1 Base Sch. G $ 1,575,186 112,623 25,637 5,571 143,830 6,408 1,725,425 - 1,725,425

2 Energy Sch. G $ 7,740,735 1,240,732 1,810,426 1,158,498 4,209,656 - 11,950,390 - 11,950,390

3 Demand Sch. G $ - 848,996 1,128,134 900,791 2,877,922 - 2,877,922 - 2,877,922

4 Total Revenue from Existing Rates CALC $ 9,315,921 2,202,352 2,964,196 2,064,860 7,231,408 6,408 16,553,737 - 16,553,737

Total Allocated Revenue Requirements

5 Demand Sch. A $ 4,200,734 1,035,558 1,437,621 906,547 3,379,725 914 7,581,373 24,107 7,605,481

6 Energy Sch. A $ 4,283,252 990,990 1,621,300 1,168,368 3,780,657 2,666 8,066,575 70,074 8,136,649

7 Customer Sch. A $ 648,201 74,308 12,146 3,584 90,038 5,476 743,715 347 744,062

8 Total Allocated Revenue Requirements CALC $ 9,132,186 2,100,855 3,071,067 2,078,498 7,250,420 9,057 16,391,664 94,528 16,486,192

9 Reallocation of Donated S.L. Accounts CALC $ 52,664 12,115 17,710 11,986 41,812 52 94,528 (94,528) -

10 Restated Allocation of Rev. Requirements CALC $ 9,184,850 2,112,970 3,088,777 2,090,485 7,292,232 9,109 16,486,192 - 16,486,192

11 Revenue Excess (Deficiency) CALC $ 131,071 89,381 (124,581) (25,625) (60,824) (2,701) 67,545 - 67,545

12 Ratio of Revenue to Allocated Revenue Req. CALC # 1.01 1.04 0.97 0.99 1.00 - 1.00

13 Unadjusted Required Increase (Decrease) CALC % -1.41% -4.06% 4.20% 1.24% 0.84% 42.16% -0.41% 0.00% -0.41%

14 Across Board Required Rate Increase CALC % -0.41% -0.41% -0.41% -0.41% -0.41% -0.41% -0.41% -0.41% -0.41%

15 Across the Board Revenue Increase (Decrease) CALC $ (38,012) (8,986) (12,095) (8,425) (29,507) (26) (67,545) - (67,545)

Restated Revenue Requirements

16 Total CALC $ 9,277,909 2,193,365 2,952,101 2,056,435 7,201,901 6,382 16,486,192 - 16,486,192

17 Demand CALC $ 4,267,765 1,081,158 1,381,931 896,924 3,360,013 644 7,628,422 - 7,628,422

18 Energy CALC $ 4,351,599 1,034,627 1,558,495 1,155,965 3,749,087 1,879 8,102,565 - 8,102,565

19 Customer CALC $ 658,544 77,580 11,676 3,546 92,801 3,859 755,204 - 755,204

20 Total CALC $ 9,277,909 2,193,365 2,952,101 2,056,435 7,201,901 6,382 16,486,192 - 16,486,192

21 Projected kWh Sales / Usage Sch. C kWh 92,327,569 21,361,264 34,947,902 25,184,733 81,493,899 57,477 173,878,945 1,510,472 175,389,417

22 Less: Donated SL Accounts CALC kWh - - - - - - (1,510,472) (1,510,472)

23 Adjusted kWh Sales CALC kWh 92,327,569 21,361,264 34,947,902 25,184,733 81,493,899 57,477 173,878,945 - 173,878,945

24 Average Cost Per kWh Under Current Rates CALC $/kWh 0.10090 0.10310 0.08482 0.08199 0.08874 0.11149 0.09520 - 0.09520

25 Average Cost Per kWh Under ATB Increase CALC $/kWh 0.10049 0.10268 0.08447 0.08165 0.08837 0.11103 0.09481 - 0.09481

Rate Increase (Decrease)

26 Per Unit CALC $/kWh (0.00041) (0.00042) (0.00035) (0.00033) (0.00036) (0.00045) (0.00039) - (0.00039)

27 Percent CALC % -0.4% -0.4% -0.4% -0.4% -0.4% -0.4% -0.4% 0.0% -0.4%

Description

General Service

Heber Light & Power


SUMMARY

Revenue Excess/Deficiency Under Present and Proposed Rates


($)


EXHIBIT C

Yard Sub-Total Street Total

Ln. Ref. Residential Small Medium Large Total Lights System Lights System

(a) (b) (c) (d) (e) (f) (g) (h) (i)

Description

General Service

Heber Light & Power


SUMMARY

Revenue Excess/Deficiency Under Present and Proposed Rates


($)

Rev. Requirement Breakdown (%)

28 Demand CALC % 46.0% 49.3% 46.8% 43.6% 46.6% 10.1% 46.3% 25.5% 46.1%

29 Energy CALC % 46.9% 47.2% 52.8% 56.2% 52.1% 29.4% 49.2% 74.1% 49.4%

30 Customer CALC % 7.1% 3.5% 0.4% 0.2% 1.2% 60.5% 4.5% 0.4% 4.5%

31 Total CALC % 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0%

32 Purchased Power as Percent of Total R.R. CALC % 42.33% 42.57% 47.64% 50.73% 47.06% 26.57% 44.41% 66.90% 44.54%

Per-unit Annual Revenue Requirements

33 Demand CALC $/kW-Mo. 14.58 12.97 12.65 13.80 13.05 8.18 13.86 - 13.81

34 Energy CALC $/kWh 0.0471 0.0484 0.0446 0.0459 0.0460 0.0327 0.0466 - 0.0466

35 Customer CALC $/Cust.&Lt. 5.28 5.51 6.92 17.12 5.81 3.61 5.35 - 5.35

36 Total CALC $/kWh 0.1005 0.1027 0.0845 0.0817 0.0884 0.1110 0.0948 - 0.0948


EXHIBIT D-1

ESTIMATED REVENUES

UNDER CURRENT RATES

EXHIBIT D-1

Large Total

First All First All First All General General Yard Total

Ln. Ref. 1000 kWh Additional Total 1000 kWh Additional Total 10000 kWh Additional Total Service Service Lights System

(a) (b) (c) (d) (e) (f) (d) (e) (f) (g) (j) (k) (l)

Proposed Increase in Base Rates 0.00%

Residential

1 Base Charge CALC 12.70

2 Energy Charge CALC 0.0798 0.1002

Small General Service (=<30 kW)


4 Demand Charge CALC 8.90

5 Energy Charge 0.0780 0.0460

Medium General Service (>30 and <=250 kW)




Large General Service (>250 kW)

9 Base Charge 26.90


11 Energy Charge 0.0460

Street Lights (Charge per Light)

12 All CALC 6.00

Number of Accounts

13 January SCH D 10,217 1,159 141 17 1,317 89 11,624

14 February SCH D 10,239 1,162 141 17 1,320 89 11,647

15 March SCH D 10,260 1,164 141 17 1,322 89 11,671

16 April SCH D 10,282 1,167 141 17 1,325 89 11,695

17 May SCH D 10,303 1,169 141 17 1,327 89 11,719

18 June SCH D 10,325 1,172 141 17 1,330 89 11,743

19 July SCH D 10,346 1,174 141 17 1,332 89 11,768

20 August SCH D 10,368 1,177 141 17 1,335 89 11,792

21 September SCH D 10,390 1,179 141 17 1,337 89 11,816

22 October SCH D 10,412 1,182 141 17 1,340 89 11,840

23 November SCH D 10,433 1,184 141 17 1,342 89 11,865

24 December SCH D 10,455 1,187 141 17 1,345 89 11,889

25 Average CALC 10,336 1,173 141 17 1,331 89 11,756

26 Percent of Rate Class CALC 100.00% 0.00% 0.00% 100.00% 100.00% 100.00% 100.00%

Projected kWh Sales (kWh)

27 January CALC 7,314,067 3,100,643 10,414,710 731,815 1,586,805 2,318,619 1,171,856 1,743,755 2,915,612 2,006,675 7,240,906 17,655,616

28 February CALC 7,145,592 2,449,677 9,595,269 732,944 1,637,765 2,370,709 1,179,871 1,817,889 2,997,760 1,981,474 7,349,943 16,945,212

29 March CALC 5,916,241 1,205,846 7,122,087 688,130 1,226,721 1,914,852 1,133,993 1,460,760 2,594,753 1,946,131 6,455,736 13,577,823

30 April CALC 5,767,925 964,616 6,732,541 678,771 1,207,951 1,886,723 1,107,881 1,585,692 2,693,573 1,908,105 6,488,401 13,220,941

31 May CALC 5,253,314 606,254 5,859,568 645,458 853,911 1,499,369 1,149,769 1,602,386 2,752,155 1,970,434 6,221,958 12,081,526

32 June CALC 5,469,538 1,083,681 6,553,219 641,564 834,540 1,476,104 1,196,208 1,792,865 2,989,073 2,096,141 6,561,318 13,114,537

33 July CALC 6,066,215 2,036,693 8,102,907 655,918 999,834 1,655,752 1,203,386 1,735,687 2,939,072 2,230,526 6,825,350 14,928,258

34 August CALC 7,154,178 1,990,713 9,144,891 672,663 1,064,223 1,736,886 1,226,279 1,903,891 3,130,170 2,435,643 7,302,699 16,447,590

35 September CALC 6,022,631 1,168,690 7,191,321 667,900 934,911 1,602,812 1,184,652 1,735,913 2,920,564 2,230,660 6,754,036 13,945,357

36 October CALC 5,592,772 664,086 6,256,858 639,689 873,195 1,512,884 1,148,621 1,668,271 2,816,891 1,989,792 6,319,567 12,576,425

37 November CALC 5,358,439 1,064,869 6,423,308 637,438 942,399 1,579,836 1,168,923 1,785,525 2,954,448 2,153,210 6,687,494 13,110,802

38 December CALC 6,982,608 1,948,283 8,930,891 673,783 1,132,935 1,806,718 1,213,424 2,030,405 3,243,829 2,235,943 7,286,490 16,217,381

39 Total CALC 74,043,520 18,284,049 92,327,569 8,066,073 13,295,191 21,361,264 14,084,863 20,863,039 34,947,902 25,184,733 81,493,899 173,821,468

Percent of Rate Class CALC 80.20% 19.80% 100.00% 37.76% 62.24% 100.00% 40.30% 59.70% 100.00% 100.00% 100.00%

Description

Heber Light & Power


ESTIMATED REVENUES UNDER PROPOSED RATES - CURRENT DESIGN

For the Projected Test Year 2017

Residential Small General Service Medium General Service


EXHIBIT D-1

Large Total



(a) (b) (c) (d) (e) (f) (d) (e) (f) (g) (j) (k) (l)

Description

Heber Light & Power





Projected Demands (kW)

40 January INPUT 4,727.5 5,687.4 3,284.9 13,699.8 13,699.8

41 February INPUT 8,500.9 8,090.6 4,363.4 20,954.9 20,954.9

42 March INPUT 8,941.5 8,210.3 4,774.5 21,926.3 21,926.3

43 April INPUT 8,746.4 8,448.0 4,640.8 21,835.2 21,835.2

44 May INPUT 8,356.4 10,700.9 6,410.3 25,467.6 25,467.6

45 June INPUT 8,117.3 10,311.1 6,456.7 24,885.0 24,885.0

46 July INPUT 8,292.3 10,272.7 6,549.3 25,114.4 25,114.4

47 August INPUT 8,413.7 10,443.0 6,455.8 25,312.5 25,312.5

48 September INPUT 8,622.5 10,471.8 6,590.6 25,685.0 25,685.0

49 October INPUT 7,836.5 10,036.8 6,288.3 24,161.5 24,161.5

50 November INPUT 7,351.3 10,082.4 5,684.2 23,117.8 23,117.8

51 December INPUT 7,486.6 10,058.4 5,226.6 22,771.5 22,771.5

52 Total CALC 95,392.8 - - 112,813.4 66,725.3 274,931.5 274,931.5

Estimated Revenue ($)

Base Charge

53 January CALC 129,760 9,275 2,136 464 11,876 534 142,170

54 February CALC 130,032 9,295 2,136 464 11,896 534 142,462

55 March CALC 130,304 9,315 2,136 464 11,915 534 142,754

56 April CALC 130,577 9,335 2,136 464 11,935 534 143,047

57 May CALC 130,851 9,355 2,136 464 11,955 534 143,340

58 June CALC 131,125 9,375 2,136 464 11,976 534 143,634

59 July CALC 131,399 9,395 2,136 464 11,996 534 143,929

60 August CALC 131,675 9,415 2,136 464 12,016 534 144,225

61 September CALC 131,950 9,435 2,136 464 12,036 534 144,520

62 October CALC 132,227 9,456 2,136 464 12,056 534 144,817

63 November CALC 132,504 9,476 2,136 464 12,077 534 145,114

64 December CALC 132,781 9,496 2,136 464 12,097 534 145,412

65 Total CALC 1,575,186 112,623 25,637 5,571 143,830 6,408 1,725,425

66 Average Base Charge ($/Cust.) CALC

Demand Charge

67 January CALC 42,074 56,874 44,346 143,294 143,294

68 February CALC 75,658 80,906 58,906 215,470 215,470

69 March CALC 79,580 82,103 64,455 226,138 226,138

70 April CALC 77,843 84,480 62,651 224,974 224,974

71 May CALC 74,372 107,009 86,538 267,919 267,919

72 June CALC 72,244 103,111 87,165 262,520 262,520

73 July CALC 73,802 102,727 88,416 264,945 264,945

74 August CALC 74,882 104,430 87,153 266,466 266,466

75 September CALC 76,740 104,718 88,974 270,432 270,432

76 October CALC 69,745 100,368 84,892 255,004 255,004

77 November CALC 65,426 100,824 76,737 242,987 242,987

78 December CALC 66,630 100,584 70,559 237,773 237,773

79 Total CALC 848,996 1,128,134 900,791 2,877,922 2,877,922

80 Average Demand Charge ($/kW) CALC 8.90 10.00 13.50 10.47 43.13


EXHIBIT D-1

Large Total



(a) (b) (c) (d) (e) (f) (d) (e) (f) (g) (j) (k) (l)

Description

Heber Light & Power





Energy Charge

81 January CALC 583,663 310,684 894,347 57,082 72,993 130,075 70,780 80,213 150,993 92,307 373,374 1,267,721

82 February CALC 570,218 245,458 815,676 57,170 75,337 132,507 71,264 83,623 154,887 91,148 378,542 1,194,218

83 March CALC 472,116 120,826 592,942 53,674 56,429 110,103 68,493 67,195 135,688 89,522 335,314 928,255

84 April CALC 460,280 96,655 556,935 52,944 55,566 108,510 66,916 72,942 139,858 87,773 336,141 893,075

85 May CALC 419,214 60,747 479,961 50,346 39,280 89,626 69,446 73,710 143,156 90,640 323,421 803,382

86 June CALC 436,469 108,585 545,054 50,042 38,389 88,431 72,251 82,472 154,723 96,422 339,576 884,630

87 July CALC 484,084 204,077 688,161 51,162 45,992 97,154 72,684 79,842 152,526 102,604 352,284 1,040,445

88 August CALC 570,903 199,469 770,373 52,468 48,954 101,422 74,067 87,579 161,646 112,040 375,108 1,145,481

89 September CALC 480,606 117,103 597,709 52,096 43,006 95,102 71,553 79,852 151,405 102,610 349,117 946,826

90 October CALC 446,303 66,541 512,845 49,896 40,167 90,063 69,377 76,740 146,117 91,530 327,710 840,555

91 November CALC 427,603 106,700 534,303 49,720 43,350 93,070 70,603 82,134 152,737 99,048 344,855 879,159

92 December CALC 557,212 195,218 752,430 52,555 52,115 104,670 73,291 93,399 166,689 102,853 374,213 1,126,643

93 Total CALC 5,908,673 1,832,062 7,740,735 629,154 611,579 1,240,732 850,726 959,700 1,810,426 1,158,498 4,209,656 11,950,390

94 Average Energy Charge ($/kWh) CALC 0.0798 0.1002 0.0838 0.0780 0.0460 0.0581 0.0604 0.0460 0.0518 0.0460 0.0517 0.0688

95 Total Revenues (Base Rate) CALC 9,315,921 629,154 611,579 2,202,352 850,726 959,700 2,964,196 2,064,860 7,231,408 6,408 16,553,737

96 Total Restated Revenue Requirement 9,277,909 2,193,365 2,952,101 2,056,435 7,201,901 6,382 16,486,192

97 Difference 38,012 8,986 12,095 8,425 29,507 26 67,545


EXHIBIT D-2 ESTIMATED REVENUES

UNDER ALTERNATIVE RATE DESIGN FOR SMALL GENERAL SERVICE

EXHIBIT D-2

Large Total

First All First All First All First All General General Yard Total

Ln. Ref. 1000 kWh Additional Total 1000 kWh Additional Total 1000 kWh Additional Total 10000 kWh Additional Total Service Service Lights System

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) (n) (o) (p)

Proposed Increase in Base Rates 0.00%

Residential


2 Energy Charge CALC 0.0798 0.1002

Small General Service (< 4 kW)


4 Demand Charge CALC -


Small General Service (>= 4 kW)




Medium General Service (>= 4 kW and <=250 kW)




Large General Service (>250 kW)

12 Base Charge 26.90


14 Energy Charge 0.0460

Street Lights (Charge per Light)

15 All CALC 6.00

Number of Accounts 233 926

16 January SCH D 10,217 233 928 141 17 1,319 89 11,626

17 February SCH D 10,239 234 930 141 17 1,322 89 11,649

18 March SCH D 10,260 234 932 141 17 1,324 89 11,673

19 April SCH D 10,282 235 934 141 17 1,326 89 11,697

20 May SCH D 10,303 235 936 141 17 1,329 89 11,721

21 June SCH D 10,325 236 938 141 17 1,331 89 11,745

22 July SCH D 10,346 236 940 141 17 1,334 89 11,769

23 August SCH D 10,368 237 942 141 17 1,336 89 11,793

24 September SCH D 10,390 237 944 141 17 1,339 89 11,818

25 October SCH D 10,412 238 945 141 17 1,341 89 11,842

26 November SCH D 10,433 238 947 141 17 1,344 89 11,866

27 December SCH D 10,455 239 949 141 17 1,346 89 11,890

28 Average CALC 10,336 236 939 141 17 1,333 89 11,757

29 Percent of Rate Class CALC 100.00% 100.00% 100.00% 100.00% 100.00% 100.00% 100.00%

Description

Heber Light & Power


ESTIMATED REVENUES UNDER PROPOSED RATES - ALTERNATIVE RATE DESIGN FOR SMALL GENERAL SERVICE


Residential Small General Service - Non Demand Medium General Service Small General Service - Demand


EXHIBIT D-2

Large Total




Description

Heber Light & Power





Projected kWh Sales (kWh)

30 January CALC 7,314,067 3,100,643 10,414,710 114,845 88,691 203,536 616,969 1,498,114 2,115,084 1,171,856 1,743,755 2,915,612 2,006,675 7,240,906 17,655,616

31 February CALC 7,145,592 2,449,677 9,595,269 105,668 47,476 153,143 627,276 1,590,290 2,217,565 1,179,871 1,817,889 2,997,760 1,981,474 7,349,943 16,945,212

32 March CALC 5,916,241 1,205,846 7,122,087 89,559 31,604 121,163 598,571 1,195,117 1,793,689 1,133,993 1,460,760 2,594,753 1,946,131 6,455,736 13,577,823

33 April CALC 5,767,925 964,616 6,732,541 96,307 39,271 135,578 582,464 1,168,681 1,751,145 1,107,881 1,585,692 2,693,573 1,908,105 6,488,401 13,220,941

34 May CALC 5,253,314 606,254 5,859,568 89,982 27,091 117,074 555,475 826,820 1,382,295 1,149,769 1,602,386 2,752,155 1,970,434 6,221,958 12,081,526

35 June CALC 5,469,538 1,083,681 6,553,219 86,776 29,168 115,944 554,788 805,372 1,360,160 1,196,208 1,792,865 2,989,073 2,096,141 6,561,318 13,114,537

36 July CALC 6,066,215 2,036,693 8,102,907 102,783 52,819 155,602 553,136 947,015 1,500,150 1,203,386 1,735,687 2,939,072 2,230,526 6,825,350 14,928,258

37 August CALC 7,154,178 1,990,713 9,144,891 103,813 67,212 171,025 568,851 997,011 1,565,861 1,226,279 1,903,891 3,130,170 2,435,643 7,302,699 16,447,590

38 September CALC 6,022,631 1,168,690 7,191,321 98,592 46,535 145,127 569,308 888,377 1,457,685 1,184,652 1,735,913 2,920,564 2,230,660 6,754,036 13,945,357

39 October CALC 5,592,772 664,086 6,256,858 92,209 33,842 126,051 547,481 839,353 1,386,834 1,148,621 1,668,271 2,816,891 1,989,792 6,319,567 12,576,425

40 November CALC 5,358,439 1,064,869 6,423,308 102,949 51,837 154,787 534,488 890,561 1,425,050 1,168,923 1,785,525 2,954,448 2,153,210 6,687,494 13,110,802

41 December CALC 6,982,608 1,948,283 8,930,891 121,804 106,941 228,746 551,979 1,025,994 1,577,973 1,213,424 2,030,405 3,243,829 2,235,943 7,286,490 16,217,381

42 Total CALC 74,043,520 18,284,049 92,327,569 1,205,287 622,487 1,827,775 6,860,786 12,672,704 19,533,489 14,084,863 20,863,039 34,947,902 25,184,733 81,493,899 173,821,468

Percent of Rate Class CALC 80.20% 19.80% 100.00% 65.94% 34.06% 100.00% 35.12% 64.88% 100.00% 40.30% 59.70% 100.00% 100.00% 100.00%

Projected Demands (kW)

43 January INPUT 4,309.6 5,687.4 3284.9 13,281.9 13,281.9

44 February INPUT 7,805.0 8,090.6 4363.4 20,259.0 20,259.0

45 March INPUT 8,313.4 8,210.3 4774.5 21,298.2 21,298.2

46 April INPUT 8,153.3 8,448.0 4640.8 21,242.1 21,242.1

47 May INPUT 7,675.3 10,700.9 6410.3 24,786.5 24,786.5

48 June INPUT 7,358.2 10,311.1 6456.7 24,126.0 24,126.0

49 July INPUT 7,285.4 10,272.7 6549.3 24,107.5 24,107.5

50 August INPUT 7,353.0 10,443.0 6455.8 24,251.8 24,251.8

51 September INPUT 7,575.7 10,471.8 6590.6 24,638.2 24,638.2

52 October INPUT 7,180.0 10,036.8 6288.3 23,505.0 23,505.0

53 November INPUT 6,943.2 10,082.4 5684.2 22,709.8 22,709.8

54 December INPUT 7,035.1 10,058.4 5226.6 22,320.1 22,320.1

55 Total CALC 86,987.3 112,813.4 66,725.3 266,526.0 266,526.0

Estimated Revenue ($)

Base Charge

56 January CALC 129,760 2,965 7,423 2,136 464 12,989 534 143,284

57 February CALC 130,032 2,971 7,439 2,136 464 13,011 534 143,577

58 March CALC 130,304 2,978 7,454 2,136 464 13,033 534 143,871

59 April CALC 130,577 2,984 7,470 2,136 464 13,054 534 144,166

60 May CALC 130,851 2,990 7,485 2,136 464 13,076 534 144,461

61 June CALC 131,125 2,996 7,501 2,136 464 13,098 534 144,757

62 July CALC 131,399 3,003 7,517 2,136 464 13,120 534 145,053

63 August CALC 131,675 3,009 7,532 2,136 464 13,142 534 145,350

64 September CALC 131,950 3,015 7,548 2,136 464 13,164 534 145,648

65 October CALC 132,227 3,021 7,564 2,136 464 13,186 534 145,946

66 November CALC 132,504 3,028 7,580 2,136 464 13,208 534 146,245

67 December CALC 132,781 3,034 7,595 2,136 464 13,230 534 146,545

68 Total CALC 1,575,186 35,994 90,109 25,637 5,571 157,310 6,408 1,738,905

69 Average Base Charge ($/Cust.) CALC


EXHIBIT D-2

Large Total




Description

Heber Light & Power





Demand Charge

70 January CALC 38,356 56,874 44,346 139,576 139,576

71 February CALC 69,464 80,906 58,906 209,276 209,276

72 March CALC 73,989 82,103 64,455 220,548 220,548

73 April CALC 72,564 84,480 62,651 219,695 219,695

74 May CALC 68,311 107,009 86,538 261,858 261,858

75 June CALC 65,488 103,111 87,165 255,764 255,764

76 July CALC 64,840 102,727 88,416 255,983 255,983

77 August CALC 65,442 104,430 87,153 257,025 257,025

78 September CALC 67,424 104,718 88,974 261,116 261,116

79 October CALC 63,902 100,368 84,892 249,161 249,161

80 November CALC 61,795 100,824 76,737 239,355 239,355

81 December CALC 62,613 100,584 70,559 233,755 233,755

82 Total CALC 774,187 1,128,134 900,791 2,803,112 2,803,112

83 Average Demand Charge ($/kW) CALC 8.90 10.00 13.50 10.52 42.01

Energy Charge

84 January CALC 583,663 310,684 894,347 8,958 4,080 13,038 48,124 68,913 117,037 70,780 80,213 150,993 92,307 373,374 1,267,721

85 February CALC 570,218 245,458 815,676 8,242 2,184 10,426 48,928 73,153 122,081 71,264 83,623 154,887 91,148 378,542 1,194,218

86 March CALC 472,116 120,826 592,942 6,986 1,454 8,439 46,689 54,975 101,664 68,493 67,195 135,688 89,522 335,314 928,255

87 April CALC 460,280 96,655 556,935 7,512 1,806 9,318 45,432 53,759 99,192 66,916 72,942 139,858 87,773 336,141 893,075

88 May CALC 419,214 60,747 479,961 7,019 1,246 8,265 43,327 38,034 81,361 69,446 73,710 143,156 90,640 323,421 803,382

89 June CALC 436,469 108,585 545,054 6,769 1,342 8,110 43,273 37,047 80,321 72,251 82,472 154,723 96,422 339,576 884,630

90 July CALC 484,084 204,077 688,161 8,017 2,430 10,447 43,145 43,563 86,707 72,684 79,842 152,526 102,604 352,284 1,040,445

91 August CALC 570,903 199,469 770,373 8,097 3,092 11,189 44,370 45,863 90,233 74,067 87,579 161,646 112,040 375,108 1,145,481

92 September CALC 480,606 117,103 597,709 7,690 2,141 9,831 44,406 40,865 85,271 71,553 79,852 151,405 102,610 349,117 946,826

93 October CALC 446,303 66,541 512,845 7,192 1,557 8,749 42,704 38,610 81,314 69,377 76,740 146,117 91,530 327,710 840,555

94 November CALC 427,603 106,700 534,303 8,030 2,385 10,415 41,690 40,966 82,656 70,603 82,134 152,737 99,048 344,855 879,159

95 December CALC 557,212 195,218 752,430 9,501 4,919 14,420 43,054 47,196 90,250 73,291 93,399 166,689 102,853 374,213 1,126,643

96 Total CALC 5,908,673 1,832,062 7,740,735 94,012 28,634 122,647 535,141 582,944 1,118,086 850,726 959,700 1,810,426 1,158,498 4,209,656 11,950,390

97 Average Energy Charge ($/kWh) CALC 0.0798 0.1002 0.0838 0.0780 0.0460 0.0671 0.0780 0.0460 0.0572 0.0604 0.0460 0.0518 0.0460 0.0517 0.0688

98 Total Revenues (Base Rate) CALC 9,315,921 94,012 28,634 158,641 535,141 582,944 1,982,382 850,726 959,700 2,964,196 2,064,860 7,170,078 6,408 16,492,407

99 Total Restated Revenue Requirement 9,277,909 304,925 1,888,440 2,952,101 2,056,435 7,201,901 6,382 16,486,192

100 Difference 38,012 (146,285) 93,942 12,095 8,425 (31,823) 26 6,216


EXHIBIT E

ESTIMATED IMPACT OF THE

CURRENT NET METERING POLICY

AND PROPOSED RESIDENTIAL SURCHARGE

EXHIBIT E

After

Line Net Total Before After Net Before After Net Before

No. Metering [1] Production Consumption Generation Net Net Metering Difference Metering [1] Net Metering Difference Metering [1] Net Metering Difference

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m)

Residential Data

1 Number of Customers 10,336 120 120 120 120 10,336 - 1,331 1,331 - 11,667 11,667 -

2 Total kWh 92,327,569 867,915 552,000 348,000 204,000 93,195,484 867,915 83,061,848 83,061,848 - 175,389,417 176,257,332 867,915

3 Average Annual kWh per Customer 8,933 7,233 4,600 2,900 1,700 9,017 84 62,406 62,406 - 71,338 71,422 84

4 kW Demand 24,397.4 590.0 288.0 236.6 51.4 24,626.7 229.3 21,640.7 21,640.7 - 46,038.1 46,267.4 229.3

5 Average kW 2.4 4.9 2.4 2.0 0.4 2.4 0 16.3 16.3 - 18.6 18.6 0.0

6 Average Load/Capacity Factor 43.2% 16.8% 21.9% 16.8% 45.3% 43.2% 43.2% 43.8% 43.8% - 43.5% 43.5% 0.0%

Total System Data

7 Total System Customers 11,761 11,761 - 11,761 11,761 - 11,761 11,761 -

8 Total System kWh 175,389,417 176,257,332 867,915 175,389,417 176,257,332 867,915 175,389,417 176,257,332 867,915

9 Total System Average NCP Demand (kW) 46,038.1 46,267.5 229.3 46,038.1 46,267.5 229 46,038.1 46,267.5 229

Allocation Factors

10 Customer Allocation Factor 87.88% 87.88% 0 12.12% 12.12% 0.00% 100.00% 100.00% 0.00%

11 kWh Allocation Factor 52.64% 52.87% 0.23% 47.36% 47.13% -0.23% 100.00% 100.00% 0.00%

12 NCP Demand Allocation Factor 52.94% 53.23% 0.29% 47.06% 46.77% -0.29% 100.00% 100.00% 0.00%

13 CP Demand Allocation Factor 60.13% 60.46% 0.33% 39.87% 39.54% -0.33% 100.00% 100.00% 0.00%

Total System Revenue Requirements

14 Allocated on kWh Sales 7,988,586$ 8,026,253$ 37,667$ 7,988,586$ 8,026,253$ 37,667$ 7,988,586$ 8,026,253$ 37,667$

15 Allocated on NCP Demand 5,125,756 5,125,756 - 5,125,756 5,125,756 - 5,125,756 5,125,756 -

16 Allocated on CP Demand 2,341,327 2,341,327 - 2,341,327 2,341,327 - 2,341,327 2,341,327 -

17 Allocated on Customers 730,522 730,522 - 730,522 730,522 - 730,522 730,522 -

18 Sub-total 16,186,191 16,223,858 37,667 16,186,191 16,223,858 37,667 16,186,191 16,223,858 37,667

19 Allocated on Sub-total R.R. 300,000 300,000 - 300,000 300,000 - 300,000 300,000 -

20 Total 16,486,191$ 16,523,858$ 37,667$ 16,486,191$ 16,523,858$ 37,667$ 16,486,191$ 16,523,858$ 37,667$

Allocated Revenue Requirments

21 Allocated on kWh Sales 4,205,311 4,243,855 38,544 3,783,275 3,782,398 (876) 7,988,586 8,026,253 37,667

22 Allocated on NCP Demand 2,713,524 2,728,283 14,759 2,412,232 2,397,473 (14,759) 5,125,756 5,125,756 -

23 Allocated on CP Demand 1,407,953 1,415,611 7,658 933,374 925,716 (7,658) 2,341,327 2,341,327 -

24 Allocated on Customers 642,010 642,019 8 88,512 88,503 (8) 730,522 730,522 -

25 Sub-total 8,968,799 9,029,768 60,968 7,217,392 7,194,091 (23,301) 16,186,191 16,223,858 37,667

26 Allocated on Sub-total R.R. 166,231 166,972 741 133,769 133,028 (741) 300,000 300,000 -

27 Total 9,135,030 9,196,740 61,710 7,351,161 7,327,119 (24,042) 16,486,191 16,523,858 37,667

Estimated Revenue

28 Average Residential Rate 0.09894 0.09868 0.08850 0.08821 0.09400 0.09375

29 Total Revenue 9,135,030$ 9,196,740 61,710 7,351,161 7,327,119 (24,042) 16,486,191 16,523,858 37,667

30 Revenue from Net Metering Customers 20,184$ [3] 85,648$ [4] 65,464$ - - - 20,184$ 85,648$ (65,464)

31 Net Gain (Loss) Due to Net Metering Accounts (3,754)$ (24,042)$ (27,796)$

32 Annual Net Gain (Loss) per Net Metering Customer (31) (200) (232)

33 Monthly Surcharge per Customer 2.61 16.70 19.30

Heber Light & Power

2017 Electric Rate Study

Analysis of the Dollar Impact of Residential Net Metering Customers

on Total System Costs/Revenues Estimated for 2017

Description

Net Metering Customers [2] Other Customer Classes

Residential

Total System

Net Metering Impact Analysis (Version 2).xlsx Page 1 of 2 eA XA cxÇwxÜ? \ÇvA

EXHIBIT E

Heber Light & Power


Analysis of the Dollar Impact of Residential Net Metering Customers

on Total System Costs/Revenues Estimated for 2017

[1] Based on data contained in the 2017 Cost of Service Study.

[2] Calculated using data supplied by HLP. Assumes that approximately 15 new net metering customers will be added in 2017.

[3] Line 53 (col. a) x line 2 (col. h).

[4] Line 53 (col. f) x line 2 (col. g).

Net Metering Impact Analysis (Version 2).xlsx Page 2 of 2 eA XA cxÇwxÜ? \ÇvA

EXHIBIT E-1

SUMMARY OF NET METERING POLICIES

FOR OTHER UTAH MUNICIPAL UTILITIES

EXHIBIT E-1

System

Line Customer Size kW Limits

No. Municipal Electric Utility Applicability Limits Y-N Y-N Rate Y-N Rate Special Comments

1 Heber Light & Power

Residential &

Small General

Service

R = 15 kW

SGS = 25 kW Y Y Retail Rate N N/A

Customer paid in January for any unused excess energy from prior

year.

2 Logan City Light & Power All

R = 10 kW C&I

= 500 kW N Y

Wholsale

Rate N N/A

Cumulative excess energy for prior year purchased from customer

in April.

3 St. George Energy Services Department All 250 kW N Y

Renewable

Energy Rate Y

Based on kW

size of

system

Capacity may not exceed customer's peak electric needs or

capacity of distribution circuits. Current Renewable Energy Rate =

$0.0419 per kWh. Solar Reliability Charge based on kW size (e.g., a

5kW system would currently have a monthly charge of $12.07 per

month).

4 Lehi City (Pilot Program) All 10 kW N N N/A N N/A

Excess energy in any month is credited to the customer's bill in the

following month. Any unused excess energy exisiting at the end of

12 months is zeroed out. A minimum customer service charge

applies in all months.

5 Hurricane Power Residential 6 kW N Y 4₵ per kWh N N/A

6 Santa Clara All 10 kW N Y

Renewable

Power Rate Y

Based on kW

size of

system

Renewable Power Rate based on average cost of City's power

resources - currently $0.06 per kWh. Solar Reliability Charge based

on kW size (e.g., a 5kW system would currently have a monthly

charge of $12.07 per month).

7 Spring City All 5 kW Y Y

Off-system

sales rate Y

kW System

Capacity

Surcharge Total installed capacity initially limited to 50 kW.

8 Washington City All See Comments Y Y

Wholesale

Rate N N/A

Current Wholesale Rate = $0.04 per kWh. Any unused credits

remaining on customer's bill at June 1 of each year will be zeroed

out. Monthly output of facility can be no greater than 120% of

historical consumption.

Notes: Does not reflect all Utah municipal utilities having a net metering policy.

All have a minmum monthly charge based on the customer service chartge.

Based on a review of each utility's net metering policy/ordinance.

Excess DG Energy

Sold to Utility

Additional Charge to

Recoup Fixed Costs

Heber Light & Power


Summary Comparison of Utah Municipal Utilities

Net Metering Policies and Rates

Net Metering Policy Comparison.xlsx Page 1 of 1 eA XA cxÇwxÜ? \ÇvA

EXHIBIT F

CALCULATION OF AN OPTIONAL

RENEWABLE ENERGY RATE

EXHIBIT F

Sub-

Yard Total Street Total

Ln. Residential Small Medium Large Total Lights System Lights System

(c) (d) (e) (f) (g) (h) (i) (j) (k)

General Service

Description


Calculation of the Estimated Renewable Energy Rate

based on Projected Data for Year 2017

($)

Calculation of Average System Generation Cost [1]

Generation

1 Energy-related 404,008 93,473 152,925 110,204 356,602 252 760,861 6,610 767,471

2 Demand-related 338,439 58,518 95,737 68,992 223,246 40 561,725 1,075 562,800

3 Customer-related 140,614 15,960 1,912 235 18,107 1,211 159,932 68 160,000

4 Sub-total Generation 883,061 167,951 250,575 179,430 597,955 1,502 1,482,519 7,752 1,490,271


5 Energy-related 3,865,347 894,302 1,463,114 1,054,373 3,411,789 2,406 7,279,542 63,237 7,342,779

Administrative & General

6 Generation-related 611,513 105,733 172,984 124,658 403,375 73 1,014,961 1,942 1,016,902

7 Total Operating Expenses 5,359,920 1,167,985 1,886,672 1,358,462 4,413,119 3,981 9,777,021 72,931 9,849,952

Other Requirements

Annual Debt Service

8 Generation-related 176,545 30,525 49,941 35,989 116,455 21 293,021 561 293,582

Capital Adds Paid from Cash


Reserve Funding


11 Total Other Requirements 465,456 80,479 131,667 94,884 307,031 55 772,542 1,478 774,020

12 Sub-total Revenue Requirements 5,825,376 1,248,465 2,018,340 1,453,346 4,720,151 4,037 10,549,564 74,409 10,623,973

13 A&G as a Percent of Sub-total Rev. Req. 10.50% 8.47% 8.57% 8.58% 8.55% 1.80% 9.62% 2.61% 9.57%

Revenue Credits

14 Genation - Demand (7,454) (1,289) (2,108) (1,519) (4,917) (1) (12,371) (24) (12,395)

15 Generation - Energy (64,046) (14,818) (24,243) (17,470) (56,531) (40) (120,616) (1,048) (121,664)

16 Total Revenue Credits (71,499) (16,107) (26,351) (18,990) (61,447) (41) (132,987) (1,071) (134,059)

17 Sub-total Generation Revenue Requirements 5,753,877 1,232,358 1,991,989 1,434,357 4,658,703 3,996 10,416,576 73,337 10,489,914

18 Annual Dividends (Return) 106,642 22,841 36,920 26,584 86,344 74 193,061 1,359 194,420

19 Total System Generation-related Costs 5,860,519 1,255,199 2,028,908 1,460,941 4,745,048 4,070 10,609,637 74,697 10,684,334

20 Total kWh Sales 92,327,569 21,361,264 34,947,902 25,184,733 81,493,899 57,477 173,878,945 1,510,472 175,389,417

21 $/kWh System Generation Cost at Meter 0.0635 0.0588 0.0581 0.0580 0.0582 0.0708 0.0610 0.0495 0.0609

Calculation of Renewable Energy Rate.xlsx 1 eA XA cxÇwxÜ? \ÇvA

EXHIBIT F

Sub-



(c) (d) (e) (f) (g) (h) (i) (j) (k)

General Service

Description




($)

Calculation of Renewable Energy Resources Cost

Horse Butte Wind Project

2017 Projected HLP Project Cost [2]

22 Demand Related 93,898 16,235 26,562 19,141 61,938 11 155,847 298 156,145

23 Energy Related 31,965 7,396 12,099 8,719 28,214 20 60,199 523 60,722

24 Total 125,863 23,631 38,661 27,861 90,152 31 216,046 821 216,867

Add:

25 HLP Admin & General Costs [3] 13,212 2,001 3,313 2,390 7,704 1 20,917 21 20,939

26 Revenue Credits - Demand [4] (120) (17) (28) (20) (65) (0) (185) (0) (185)

27 Revenue Credits - Energy [5] (351) (88) (145) (105) (338) (0) (690) (7) (697)

28 Sub-total Revenue Requirements 138,603 25,528 41,801 30,125 97,454 31 236,089 835 236,924

29 Add: Annual Dividends [6] 2,569 473 775 558 1,806 1 4,376 15 4,391

30 Total Revenue Requirements 141,172 26,001 42,576 30,684 99,261 32 240,465 851 241,315

31 2017 Projected Output (kWh) [7] 1,415,529 327,502 535,807 386,122 1,249,432 881 2,665,842 23,158 2,689,000

32 Average Cost at Generation Busbar 0.0997 0.0794 0.0795 0.0795 0.0794 0.0363 0.0902 0.0367 0.0897

Jordanelle Project

2017 Projected HLP Project Cost [2]

33 Demand Related - - - - - - - - -

34 Energy Related 440,214 101,850 166,630 120,080 388,560 274 829,048 7,202 836,250

35 Total 440,214 101,850 166,630 120,080 388,560 274 829,048 7,202 836,250

Add:

36 HLP Admin & General Costs [8] 46,211 8,626 14,281 10,300 33,207 5 79,423 188 79,610

37 Revenue Credits - Demand [9] (563) (105) (174) (126) (405) (0) (968) (2) (970)

38 Revenue Credits - Energy [10] (4,840) (1,209) (2,001) (1,443) (4,654) (3) (9,496) (101) (9,598)

39 Sub-total Revenue Requirements 481,022 109,161 178,736 128,811 416,708 276 898,006 7,286 905,292

40 Add: Annual Dividends [11] 8,915 2,023 3,313 2,387 7,723 5 16,644 135 16,779

41 Total Revenue Requirements 489,938 111,185 182,049 131,198 424,431 281 914,650 7,421 922,071

42 2017 Projected Output (kWh) [7] 7,896,221 1,826,900 2,988,883 2,153,898 6,969,682 4,916 14,870,818 129,182 15,000,000

43 Average Cost at Generation Busbar 0.0620 0.0609 0.0609 0.0609 0.0609 0.0572 0.0615 0.0574 0.0615

Calculation of Blended Renewable Resource Cost

44 Total Revenue Requirements 631,110 137,185 224,625 161,882 523,692 313 1,155,115 8,272 1,163,386

45 Total 2017 Projected Output 9,311,750 2,154,403 3,524,691 2,540,021 8,219,114 5,797 17,536,661 152,339 17,689,000

46 Blended Per-unit Cost at Generator Busbar 0.0678 0.0637 0.0637 0.0637 0.0637 0.0540 0.0659 0.0543 0.0658

47 Restated Per-unit Cost at Meter 0.0721 0.0677 0.0678 0.0678 0.0678 0.0575 0.0701 0.0578 0.0700

Estimated Renewable Energy Surcharge

48 Per kWh 0.0086 0.0090 0.0097 0.0098 N/A N/A N/A N/A 0.0090

49 Per 100 kWh 0.86 0.90 0.97 0.98 N/A N/A N/A N/A 0.90


EXHIBIT F

Sub-



(c) (d) (e) (f) (g) (h) (i) (j) (k)

General Service

Description




($)

[1] Based on data contained in the 2017 Cost of Service Study.

[2] Total system cost based on data provided by HLP. Allocated to rate classes using demand and energy data shown on lines 1 and 2.

[3] Line 24 x line 13.

[4] Line 22 / line 12 x line 14.



[7] Total output based on data provided by HLP. Allocated to rate classes based on kWh sales (line 20).

[8] Line 35 x line 13.


[10] Line 34 / line 12 x line 15.

[11] Line 39 / line 17 x line 18.


Documents

HLP BOARD M R 2017 R S P B M JUNE 28, 2017 · 27 Distribution-related 77,644 NCP Demand 41,146 11,713 15,347 9,135 36,195 11 77,353 291 77,644 28 Customer-related 4,492 # of Cust