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Strategic Customer Meeting Gillette, WY June 26, 2013


Adjusted Capital Cost Recovery revenues Corrected direct assignment values and depreciation Updated payroll expense Reallocated payroll expense associated with revised maintenance plan • Allocated Idle Service revenues by class • Updated service charges

• • • •


Estimated Actual Costs

Existing

Proposed

% Increase

Connect Fee

$180.00

$15.00

$30.00

100%

Connect Fee After Hours

$230.00

$100.00

$150.00

50%

Meter Test (2/12 months)

$180.00

$25.00

$50.00

100%

Service Call - office hours

$275.00

$75.00

$150.00

100%

Service Call - after hours

$375.00

$250.00

$300.00

20%

Reconnection Fee (DNP) - office hours

$180.00

$50.00

$75.00

50%

Reconnection Fee (DNP) - after hours

$230.00

$100.00

$150.00

50%

Charge Description


Operating Revenues Base Revenue COPA Deferred Revenue Other Total Operating Expenses Purchased Power Transmission O&M Distribution-Ops Distribution-Maint. Cons Acctg Cust Service Admin & General Depreciation Tax Total Return

Test Year 12/31/12 (a) 160,698,575 $ 28,206,376 (700,000) 1,814,643 190,019,594 $

Adjustments (b) (15,792,650) $ 3,470,109 700,000 65,475 (11,557,066) $

Adjusted Test Year (c) 144,905,925 $ 31,676,486 0 1,880,118 178,462,528 $

Rate Change (d) 38,650,784 $ (31,676,486) 0 24,790 6,999,088 $

Adjusted w/ Rate Change (e) 183,556,709 0 0 1,904,908 185,461,617

(4,413,927) $ (144,038) 349,208 324,847 299,842 3,446 476,755 (2,044,244) 932,000 (4,216,110) $

140,414,851 $ 1,071,098 9,286,890 3,723,160 2,842,313 84,600 6,141,661 13,588,088 1,416,376 178,569,036 $

$

$

144,828,777 $ 1,215,136 8,937,681 3,398,313 2,542,471 81,154 5,664,905 15,632,332 484,376 182,785,146 $

0$

140,414,851 1,071,098 9,286,890 3,723,160 2,842,313 84,600 6,141,661 13,588,088 1,416,376 178,569,036

$

7,234,448 $

(7,340,956) $

(106,508) $

6,999,088 $

6,892,581

(386,887) $ 0

$

(386,887) $

5,909,403 $ 108,778 224,365 6,242,546 $

0$

5,909,403 108,778 224,365 6,242,546

$

$

$

Interest & Other Deductions Interest on L-T Debt Interest-Other Other Deductions Total

$

$

6,296,290 $ 108,778 224,365 6,629,433 $

Operating Margin

$

605,015 $

(6,954,069) $

(6,349,054) $

6,999,088 $

650,034

Non-Operating Margins Interest Income $ Other Margins G&T Capital Credits Other Capital Credits Total $

2,140,098 $ 28,040 6,316,539 88,028 8,572,705 $

$

$

0$

2,140,098 $ 28,040 6,316,539 88,028 8,572,705 $

0$

2,140,098 28,040 6,316,539 88,028 8,572,705

Net Margins

9,177,720 $

(6,954,069) $

2,223,651 $

6,999,088 $

9,222,739

$


Consumers

kWh Sold

Adjusted Revenue

Proposed Revenue

Percent Change

Change

Residential Residential ToD

14,199 130

203,662,298 3,693,686

16,962,934 249,297

18,102,654 260,799

1,139,720 11,502

6.72% 4.61%

Residential Heat Rate Residential

122 14,451

2,652,547 210,008,531

179,382 17,391,614

183,598 18,547,051

4,216 1,155,438

2.35% 6.64%

Seasonal

3,360

8,200,000

1,435,043

1,481,710

46,667

3.25%

Irrigation

170

2,500,000

230,876

250,530

19,654

8.51%

General Service

5,555

142,909,871

11,098,250

12,180,376

1,082,126

9.75%

General Service - CBM

1,467

66,261,032

6,412,052

7,243,044

830,992

12.96%

848

466,600,400

31,022,388

32,333,662

1,311,274

4.23%

1,702

431,747,000

38,650,209

41,073,998

2,423,788

6.27%

13

1,121,946,000

63,309,141

63,309,141

0

0.00%

LP Trans CBM

5

80,874,000

4,410,408

4,504,513

94,104

2.13%

LP Compression CBM

2

33,754,000

2,293,950

2,293,950

0

0.00%

Black Hills

2

1,001,405

45,738

45,738

0

0.00%

0 30 30

2,109,828 911,000 3,020,828

205,050 77,690 282,740

210,439 80,122 290,561

5,389 2,432 7,821

2.63% 3.13% 2.77%

2,568,823,067 176,582,411

183,554,274

6,971,864

3.95%

Other Revenue

1,880,118

1,904,908

24,790

1.32%

Total Revenue

178,462,528

185,459,182

6,996,654

3.92%

Large Power Large Power CBM

Large Power Trans

Security Lighting Street Lighting Lighting

Total Energy Sales

28,249


• Large Power CBM Rate • Eliminate the minimum contract demand • Adjust the demand charges to recover the revenue previously in the contract demand charge • Increase the customer charge to $200 • Maintain the proposed class revenue requirement • PRECorp is currently reviewing the proposal and the impact on all members of the class


• Large Power Rate • Increase the demand charges in the rate • $3/kW for the first 50, or $5.65 • $2.36/kW for excess, or $7.70 • Increase the secondary customer charge to $150 • Reduce the energy charges • Maintain the proposed class revenue requirement • PRECorp is currently reviewing the proposal and the impact on all members of the class


 6/26  7/16  7/22-7/24  07/31  8/20  8/30  3/10/2014

Strategic Customer Meeting Board Meeting – Review Current Draft Customer Meetings in Sundance, Gillette, Sheridan Strategic Customer Meeting Board Meeting – Board Approval of COSS & Rate Increase Application Final to WY PSC New Rates Effective Date

June 2013 Coss update