public service company of colorado transmission formula ... pdfs/sec.2a(i...35 schedule 2- reactive...

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Public Service Company of ColoradoTransmission Formula Rate Template

Twelve Months Ended December 31, 2013

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Public Service Company of Colorado Table 1

Transmission Formula Rate Template Table of Contents


Table No. Schedule/Workpaper Description

Table 2 Rates Summary of Rates

Table 3 ATRR Est. Annual Transmission Revenue Requirements- Estimated

Table 4 ATRR Act Annual Transmission Revenue Requirements- Actual

Table 5 WP_A-1 True-up of Estimated Rates

Table 6 WP_A-2 Prior Period Corrections

Table 7 WP_B-1 Gross Plant, Accumulated Depreciation & Amortization, and Depreciation Expense

Table 8 WP_B-2 Accumulated Deferred Income Taxes (Credits)

Table 9 WP_B-3 Accumulated Deferred Income Taxes (Debits)

Table 10 WP_B-4 Acquisition Adjustment

Table 11 WP_B-5 Prepayments & Materials and Supplies

Table 12 WP_B-6 Regulatory Liabilities- FERC Account 254

Table 13 WP_B-7 Construction Work in Progress

Table 14 WP_B-Inputs Est. Rate Base Data Inputs- Estimated

Table 15 WP_B-Inputs Act. Rate Base Data Inputs- Actual

Table 16 WP_C-1 Transmission O&M

Table 17 WP_C-2 Administrative and General Expenses

Table 18 WP_C-3 Post-Employment Benefits Other than Pensions (FAS 106)

Table 19 WP_C-4 Regulatory Commission Expense Detail (FERC Account 928)

Table 20 WP_D-1 Taxes Other Than Income Tax

Table 21 WP_E-1 Revenue Credits

Table 22 WP_F-1 Account 456.1- Revenues from Transmission of Electricity of Others

Table 23 WP_G-1 Capital Structure Details

Table 24 WP_H-1 Depreciation and Amortization Rates

Table 25 WP_I-1 Transmission System Peak Demand Summary

Table 26 Schedule 1 Scheduling System Control and Dispatch Service

Table 27 Schedule 2 Reactive Supply and Voltage Control From Generation Source Services

Table 28 Schedule 3 Regulation and Frequency Response Service

Table 29 Schedule 5 Operating Reserve - Spinning Reserve Service

Table 30 Schedule 6 Operating Reserve - Supplemental Reserve Service

Table 31 WP_FCR Fixed Charge Rate Worksheet ("FCR")

Table 32 WP_Cost per Unit Cost Per Unit

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Transmission Formula Rate Template Rates


Summary of Rates

Line No. Description Reference

Transmission

Amount

1 Revenue Requirement ATRR Est. Line 128 215,056,093$

2

3 Prior Year True Up Adjustment Prior Years True-up Formula

4 Interest on Prior Year True Up Adjustment Prior Years True-up Formula

5 Prior Period Correction True up Adjustment WP_A-2 Line 52 -

6 Interest on Prior Period Correction True Up Adjustment WP_A-2 Line 53 -

7

8 Estimated Revenue Requirement with True Up Sum Lines 1 through 6 215,056,093$

9

10 Divisor

11 Transmission Network Load WP_I-1 Line 15, colum (g) 6,046,996

12

13 Rates

14 Annual Cost ($/kW-Yr) Line 8 / Line 11 35.564$ /kW-year

15 Network & Point-to-Point Rate ($/kW-Mo) Line 14 / 12 2.964$ /kW-month

16

17 Weekly P-To-P Rate Line 14 / 52 0.684$ /kW-week

18 Daily P-To-P Rate (Capped at weekly rate) Line 17 / 6 0.114$ /kW-day

19 On Peak Hourly P-To-P Rate (Capped at weekly & daily rate) (Line 18 / 16) X 1,000 7.125$ /MWh

20 Off Peak Hourly P-To-P Rate ((Line 17 / 7) / 24) X 1,000 4.070$ /MWh

21

22 FERC Annual Charge (Note 1) 0.0640$ /MWh

23

24

25

26

27 Schedule 1- Scheduling, System Control and Dispatch

28 Monthly Point-to-Point Delivery Schedule 1 Line 22 0.0440$ /kW-month

29 Weekly Point-to-Point Delivery Schedule 1 Line 23 0.0100$ /kW-week

30 Daily Point-to-Point Delivery Schedule 1 Line 24 0.0010$ /kW-day

31 Hourly Point-to-Point Delivery Schedule 1 Line 25 0.0600$ /MWh

32 Network Integration Delivery Schedule 1 Line 22 0.0440$ /kW-month

33 Ancillary Service Delivery Schedule 1 Line 22 0.0440$ /kW-month

34

35 Schedule 2- Reactive Supply and Voltage Control From Generation Sources Service







42

43 Schedule 3- Regulation and Frequency Response Service







50

51 Schedule 5- Operating Reserve- Spinning Reserve Service







58

59 Schedule 6 - Operating Reserve - Supplemental Reserve Service







Ancillary Service Rates (2)

Note 2. Ancillary Service Schedules 2, 3, 5, 6 will be based on actual data from the latest FERC Form 1. These schedules will be updated

annually with the Annual Update but will not be subject to the True-up provision. Ancillary Service Schedule 1 will be updated annually, will

be based on forecast data and will be subject to the True-up provision.

Note 1. The FERC's annual charge per MWh is established by the Commission annually, and is assessed to the Transmission Owner, and

is passed through to the Transmission Customers.

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Transmission Formula Rate Template ATRR Est.


Annual Transmission Revenue Requirements- Estimated

Line No. RATE BASE & RETURN CALCULATION Reference/Notes Total Transmission

(1) (2) (3) (5)

1 GROSS PLANT IN SERVICE (Note A)

2 Production WP_B-1 Col. (c), Line 2 4,513,587,506 NA 0.00% -

3 Transmission WP_B-1 Col. (d), Line 3 1,679,946,184 DA 100.00% 1,679,946,184

4 Distribution WP_B-1 Col. (d), Line 4 3,875,112,601 NA 0.00% -

5 General Plant WP_B-1 Col. (d), Line 5 142,166,199 W/S 9.88% 14,051,707

6 Intangible Plant WP_B-1 Col. (d), Line 6 40,096,438 W/S 9.88% 3,963,132

7 Common Intangible WP_B-1 Col. (d), Line 7 203,362,316 CE 7.28% 14,803,208

8 Common General WP_B-1 Col. (d), Line 8 387,362,855 CE 7.28% 28,197,028

9 TOTAL GROSS PLANT Sum Lines 2 through 8 10,841,634,098 1,740,961,259

10

11

12 ACCUMULATED DEPRECIATION (Note A)

13 Production WP_B-1 Col. (d), Line 12 1,495,824,175 NA 0.00% - 14 Transmission WP_B-1 Col. (d), Line 13 361,985,593 DA 100.00% 361,985,593 15 Distribution WP_B-1 Col. (d), Line 14 1,139,332,988 NA 0.00% - 16 General Plant WP_B-1 Col. (d), Line 15 56,896,574 W/S 9.88% 5,623,657 17 Intangible Plant WP_B-1 Col. (d), Line 16 27,604,325 W/S 9.88% 2,728,411 18 Common Intangible WP_B-1 Col. (d), Line 17 153,776,506 CE 7.28% 11,193,743 19 Common General WP_B-1 Col. (d), Line 18 192,573,313 CE 7.28% 14,017,852 20 TOTAL ACCUMULATED DEPRECIATION Sum Lines 13 through 19 3,427,993,473 395,549,257

21

22 NET ACQUISITION ADJUSTMENT (Note B)

23 Production WP_B-4 Col.(i) Line 15 196,791,460 NA 0.00% -

24 Transmission Serving Production WP_B-4 Col.(j) Line 15 9,637,582 NA 0.00% -

25 Transmission Serving Transmission WP_B-4 Col.(k) Line 15 5,062,976 DA 100.00% 5,062,976

26 TOTAL NET ACQUISITION ADJUSTMENT Sum Lines 23 through 25 211,492,018 5,062,976

27

28 NET PLANT IN SERVICE (Note A)

29 Production Line 2 minus 13 plus 23 plus 24 3,224,192,373 -

30 Transmission Line 3 minus 14 plus 25 1,323,023,567 1,323,023,567

31 Distribution Line 4 minus 15 2,735,779,613 -

32 General Plant Line 5 minus 16 85,269,625 8,428,050

33 Intangible Plant Line 6 minus 17 12,492,113 1,234,720

34 Common Intangible Line 7 minus 18 49,585,810 3,609,465

35 Common General Line 8 minus 19 194,789,542 14,179,176

36 TOTAL NET PLANT IN SERVICE Sum Lines 29 through 35 7,625,132,644 1,350,474,978

37 Line 36, Col (5) divided by Col (3) NP= 17.71%

38

39 OTHER RATE BASE ITEMS (Note C)

40 Account No. 281 WP_B-2 Col (c) & (e), Line 3 (70,554,152) DA 0.00% -

41 Account No. 282 WP_B-2 Col (c) & (e), Line 30 (1,780,904,988) DA (351,989,211)

42 Account No. 283 WP_B-2 Col (c) & (e), Line 81 (167,770,098) DA (5,781,711)

43 Account No. 190 WP_B-3 Col (c) & (e), Line 74 409,502,424 DA 44,022,120

44 Regulatory Liabilities- FERC Account No. 254 (Note C) WP_B-6 Col (e), Line 14 (2,435,759) W/S 9.88% (240,750)

45 Account No. 255 267.8.h - DA 100.00% -

46 Account No. 107 (CWIP) (Note E) WP_B-7 Col (a), Line 16 - DA 100.00% -

47 Net Pre-Funded AFUDC on CWIP included (Note E) WP_B-7 Col (d), Line 16 - DA 100.00% -

48 Unamortized Balance of Abandoned Incentive Plant (Note E) WP_B-Inputs Est. Line 142 - DA 100.00% -

49 Unamortized Balance of Extraordinary Property Loss (Note E) WP_B-Inputs Est. Line 142 - DA 100.00% -

50 TOTAL OTHER RATE BASE ITEMS Sum Lines 40 through 49 (1,612,162,573) (313,989,552)

51

52 LAND HELD FOR FUTURE USE (Note F) WP_B-Inputs Est. Line 142 - TP 96.74% -

53

54 WORKING CAPITAL

55 Cash Working Capital (Note G) - -

56 Materials & Supplies - Transmission WP_B-5 Line 48 215,900 TP 96.74% 208,857

57 Materials & Supplies - Other WP_B-5 Line 50 (1,421,355) NP 17.71% (251,734)

58 Prepayments (Account 165) Plant Related WP_B-5 Line 8 7,635,404 NP 17.71% 1,352,294

59 Prepayments (Account 165) Labor Related WP_B-5 Line 16 3,382,012 W/S 9.88% 334,278

60 Prepayments (Account 165) Transmission Related WP_B-5 Line 21 885,598 TP 96.74% 856,710

61 Prepayments (Account 165) Other Not Allocated WP_B-5 Line 35 16,172,614 NA 0.00% -

62 TOTAL WORKING CAPITAL Sum Lines 55 through 61 26,870,173 2,500,405

63

64 RATE BASE Line 36 plus 50 plus 52 plus 62 6,039,840,243 1,038,985,831

65

66 Rate of Return Line 156, Col (5) 7.87% 7.87%

6768 RETURN (Rate Base * Rate of Return) Line 64 times Line 66 475,335,427 81,768,185

Allocator

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EXPENSE, TAXES & REVENUE Total

Line No. REQUIREMENTS CALCULATION Reference/Notes Total Transmission

(1) (2) (3) (5)

69 OPERATION & MAINTENANCE EXPENSE

70 Transmission WP_C-1 Line 31 72,813,563

71 Less Total Account 561 WP_C-1 Lines 2 through 9 (5,346,588)

72 Add Back Account 561.4 WP_C-1 Line 5 -

73 Add Back Account 561.5 WP_C-1 Line 6 583,681




77 Less Total Account 565 (Note H) WP_C-1 Line 13 (35,547,515)

78 Add Back Account 565.25- System Integration Costs WP_C-1 Line 34 -

79 Transmission Subtotal Sum Lines 69 through 78 34,054,269 TP 96.74% 32,943,418 80

81 Administrative and General (Note I) WP_C-2 Line 15 152,424,859

82 Less: Acc. 924, Property Insurance WP_C-2 Line 5 (5,983,194)

83 Balance of A & G Sum Lines 81 through 82 146,441,665 W/S 9.88% 14,474,294 84 Plus: Account 924, Property Insurance Line 82 5,983,194 NP 17.71% 1,059,674

85 Account 928 - Transmission Specific WP_C-4 Line 6 2,271,048 DA 100.00% 2,271,048

86 A & G Subtotal Sum Lines 81 through 85 154,695,907 17,805,016

87

88 TOTAL O & M EXPENSE Line 79 plus Line 86 188,750,175 50,748,434

89

90

91 DEPRECIATION AND AMORTIZATION EXPENSE

92 Transmission WP_B-1 Line 24 27,508,195 DA 100.00% 27,508,195 93 Plus: Pre-Funded AFUDC Amortization (Note E) WP_B-7 Col (f), Line 18 - DA 100.00% - 94 Plus: Recovery of Abandoned Incentive Plant (Note E) WP_B-Inputs Est. Line 142 - DA 100.00% - 95 Plus: Recovery of Extraordinary Property Loss (Note E) WP_B-Inputs Est. Line 142 - DA 100.00% - 96 General WP_B-1 Line 26 9,560,406 W/S 9.88% 944,951 97 Intangible WP_B-1 Line 27 3,864,628 W/S 9.88% 381,980 98 Common Intangible WP_B-1 Line 28 17,271,504 CE 7.28% 1,257,232 99 Common General WP_B-1 Line 29 27,210,054 CE 7.28% 1,980,682 100 Acquisition Adjustment Amortization (Note F) WP_B-4 Line 15 96,504 DA 100.00% 96,504

101 TOTAL DEPRECIATION AND AMORTIZATION Sum Lines 92 through 100 85,511,292 32,169,544

102

103 TAXES OTHER THAN INCOME (Note J)

104 Labor Related WP_D-1 Line 5 13,133,045 W/S 9.88% 1,298,070

105 Plant Related WP_D-1 Line 9 96,882,658 NP 17.71% 17,158,732

106 Miscellaneous WP_D-1 Line 11 - NA 0.00% -

107 TOTAL OTHER TAXES Sum Lines 104 through 106 110,015,703 18,456,802

108

109 INCOME TAXES (Note K)

110 T=1 - {[(1 - SIT) * (1 - FIT)] / (1 - SIT * FIT * p)} = 38.01%

111 CIT=(T/1-T) * (1-(WCLTD/R)) = 45.50%

112 where WCLTD=(line 153) and R= (line 156)

113 and FIT, SIT & p are as given in Note K.

114 1 / (1 - T) = (from ln 110) 1.6132

115 Amortized Investment Tax Credit (enter negative) Company Records (2,604,617)

116

117 Income Tax Calculation Line 68 times Line 111 216,277,619 37,204,524

118 ITC adjustment Line 114 times Line 115 (4,201,768) NP 17.71% (744,168)

119 TOTAL INCOME TAXES Sum Lines 117 through 118 212,075,851 36,460,356

120

121

122 REVENUE CREDITS (Note L)

123 Account No. 454 (Rent from Transmission Facilities) WP_E-1 Line 4 2,184,020 DA 100% 2,184,020

124 Account No. 421.1 (Gain From Disposition of Utility Plant) WP_E-1 Line 9 2,435,759 WS 9.88% 240,750

125 Account No. 456.1 (Revenue from Trans. of Elect. of Others) WP_F-1 Line 37 Col. (b) + (c) 2,122,457 DA 100% 2,122,457

126 Total Revenue Credits 6,742,236 4,547,227 127

128 REVENUE REQUIREMENT 1,064,946,212 215,056,093

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Allocator

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Total

Line No. SUPPORTING CALCULATIONS Reference/Notes Total Transmission

(1) (2) (3) (5)

129 TRANSMISSION PLANT INCLUDED IN THE ATRR (Note M)

130 Transmission plant WP_B-1 Col. (a), Line 3 1,736,774,457

131 Transmission related Acquisition Adjustment WP_B-4 Col. (c), Line 15 5,308,257

132 Total Transmission Plant Sum Lines 129 through 130 1,742,082,714

133 Eliminate Generator Step-up facilities WP_B-Inputs Est. Line 117 (56,828,273)

134 Transmission plant included in OATT Trans Rate Sum Lines 131 through 132 1,685,254,441

135 Percent of Transmission Plant in the ATRR Line 134 divided by Line 132 TP= 96.74%

136

137 WAGES & SALARY ALLOCATOR (W/S)

138 Production Company Records 76,505,404 NA 0.00% -

139 Transmission WP_C-1 Line 31 15,454,690 TP 96.74% 14,950,558

140 Regional Market Company Records 418,204 NA 0.00% -

141 Distribution Company Records 43,157,192 NA 0.00% -

142 Other Company Records 15,730,124 NA 0.00% -

143 Total Sum Lines 138 through 142 151,265,615 14,950,558

144

145 W/S Allocator Line 143, Col. (5) divided by Col. (3) W/S= 9.88%

146

147 Common to Electric Transmission Allocator Common Plant to Electric (Common Plant Study) 73.65%

148 W/S Allocator, Line 145 9.88%

149 Line 147 times Line 148 CE= 7.28%

150

151

152 RETURN (Note N) $ % Cost Weighted

153 Long Term Debt WP_G-1 Col (n), Line 4 3,531,423,077 43.03% 4.71% 0.0203

154 Preferred Stock WP_G-1 Col (n), Line 6 - 0.00% 0.00% 0.0000

155 Common Stock WP_G-1 Col (n), Line 12 4,674,705,633 56.97% 10.25% 0.0584

156 Total Sum Lines 153 through 155 8,206,128,710 ROR= 0.0787

157

158

159 PREPAYMENTS ALLOCATION FACTOR TO ELECTRIC 2011 FERC Form 1

160

161 Total Electric Plant in Service 207, Ln.100, Col. (g) 9,844,527,463

162 Common PIS Allocated to Electric 356 463,629,997

163 Electric Plant Held for Future Use 214, Ln. 47, Col. (d) 32,130,829

164 Electric Construction Work in Progress 216, Ln. 43, Col. (b) 208,935,617

165 Common CWIP Allocated to Electric 356 14,248,979

166 Total Electric Plant Sum Lines 161 through 165 10,563,472,885

167 Total Utility Plant 110, Ln. 4, Col. (c) 13,225,785,539

168

169 Electric Plant to Total Plant Allocation Factor Line 166 divided by Line 167 79.870%

Allocator

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General Notes: a) References to data from FERC Form 1 are indicated as: page#.line#.col.#

Notes:

A Gross Plant, Accumulated Depreciation Reserves will be the average of thirteen monthly balances.

B Pending approval of the unopposed settlement in Docket No. ER11-2853, transmission serving transmission related amounts associated with the Calpine Acquisition are included.

Future Acquisition Adjustment amounts will not be included in the formula except as directed by the Commission pursuant to a Section 205 filing.

The Net Acquisition Adjustment will be the average of thirteen monthly balances.

C Reflects the BOY/EOY average of the transmission related portion of balances in Accounts 281, 282, 283, 190, and 255 as adjusted by any amounts in contra accounts

identified as regulatory assets or liabilities related to FASB 106, 109, 133,158 or FASB Interpretation No. 48. Balance of Account 255 is reduced by prior flow throughs and

completely excluded if the utility chose to utilize amortization of tax credits against taxable income as discussed in Note k.

D The Regulatory Liability associated with the sale of the Technical Service Building (TSB) will be included in Rate Base. Future Regulatory Liabilities will not be included in the

formula except as directed by the Commission pursuant to a Section 205 filing.

E Includes any incentive Construction Work in Progress (CWIP), any related Pre-funded Allowance for Funds Used During Construction (AFUDC), any unamortized balances

related to the recovery of abandoned incentive plant costs, any extraordinary property losses and any related depreciation and amortization expense amounts.

Formula amounts for all of the foregoing items will remain at $0 until approved by FERC pursuant to a Section 205 filing under a separate docket.

F Includes only transmission related or functionally booked as transmission land held for future use.

G Cash Working Capital will be set at and remain $0 until such time as PSCo files and receives FERC approval.

H Account 565 Transmission by Others is included only to the extent used to integrate the PSCo Transmission system.

I Post-Employment Benefits Other than Pensions (FAS 106) shall remain as a stated, fixed amount and shall not be changed except as directed by the Commission

following a filing seeking such change pursuant to section 205 or 206 of the FPA. The adjustment is shown on WP_C-3 PBOP.

Regulatory Commission expenses (FERC Account 928) will be directly assigned or allocated to Transmission.

General Advertising Expenses (FERC Account 930.1) will be excluded.

EPRI Fees and EEI Dues recorded in FERC Account 930.2 will be excluded.

J Includes only FICA, unemployment, property, and other assessments charged in the current year.

Taxes related to income are excluded. Franchise taxes are not included in transmission revenue requirement in the Rate Formula Template,

K The currently effective income tax rate, where FIT is the Federal income tax rate; SIT is the State income tax rate, and p =

"the percentage of federal income tax deductible for state income taxes".

PSCo has elected to utilize amortization of tax credits against taxable income, rather than book tax credits to Account No. 255 and reduce

rate base, must reduce its income tax expense by the amount of the Amortized Investment Tax Credit (Form 1, 266.8.f) less adjustments

multiplied by (1/1-T) (page 3, line 30).

Inputs Required: FIT = 35.00%

SIT= 4.63% (State Income Tax Rate or Composite SIT)

p = 0.00% (percent of FIT deductible for state purposes)

L Includes income related to transmission facilities, such as pole attachments, rentals and special use for the Transmission facilities included herein.

FERC 421.1 Gain on the Disposition of Utility Property will be assigned or allocated to the transmission function based on the specific property sold.

Revenue from coincident peak loads included in the DIVISOR are also not included as revenue credits unless this revenue is offset by a corresponding expense

M Removes the dollars of plant booked to transmission plant that is excluded from the Tariff because it does not meet the Tariff's definition of Transmission

Facilities, or is booked to transmission (e.g. step-up transformers) that is included in the development of OATT ancillary service rates,

or is otherwise not eligible to be recovered under this Tariff.

N Return on Equity will be set at 10.25%. Thereafter, any change will require a filing with the Commission pursuant to Section 205 or 206 filing.

If and when the Company issues preferred stock, footnote will indicate the authorizing regulatory agency, the docket/case number, and the date of the authorizing order.

If a change in an income tax rate is known sufficiently in advance to be reflected in the estimated rates that will become effective January 1 for the upcoming formula rate year, PSCo

will reflect the new tax rate(s) in the estimated rate calculations for the months in which the new tax rate will be in effect for the formula rate year. Otherwise, such tax change will be

captured and reflected in the annual formula true-up by weighting the tax rates in effect during the year by the number of days each such tax rate was in effect.

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Transmission Formula Rate Template ATRR Act


Annual Transmission Revenue Requirements- Actual

Line No. RATE BASE & RETURN CALCULATION Reference/Notes Total Transmission

(1) (2) (3) (5)

1 GROSS PLANT IN SERVICE (Note A)

2 Production WP_B-1 Col. (c), Line 2 - NA 0.00% - 3 Transmission WP_B-1 Col. (c), Line 3 - DA 100% - 4 Distribution WP_B-1 Col. (c), Line 4 - NA 0.00% - 5 General Plant WP_B-1 Col. (c), Line 5 - W/S 0.00% - 6 Intangible Plant WP_B-1 Col. (c), Line 6 - W/S 0.00% - 7 Common Intangible WP_B-1 Col. (c), Line 7 - CE 0.00% - 8 Common General WP_B-1 Col. (c), Line 8 - CE 0.00% - 9 TOTAL GROSS PLANT Sum Lines 2 through 8 - -

10

11

12 ACCUMULATED DEPRECIATION (Note A)

13 Production WP_B-1 Col. (c), Line 12 - NA 0.00% - 14 Transmission WP_B-1 Col. (c), Line 13 - DA 100% - 15 Distribution WP_B-1 Col. (c), Line 14 - NA 0.00% - 16 General Plant WP_B-1 Col. (c), Line 15 - W/S 0.00% - 17 Intangible Plant WP_B-1 Col. (c), Line 16 - W/S 0.00% - 18 Common Intangible WP_B-1 Col. (c), Line 17 - CE 0.00% - 19 Common General WP_B-1 Col. (c), Line 18 - CE 0.00% - 20 TOTAL ACCUMULATED DEPRECIATION Sum Lines 13 through 19 - -

21

22 NET ACQUISITION ADJUSTMENT (Note B)

23 Production WP_B-4 Col.(i) Line 15 - NA 0.00% -

24 Transmission Serving Production WP_B-4 Col.(j) Line 15 - NA 0.00% -

25 Transmission Serving Transmission WP_B-4 Col.(k) Line 15 - DA 100.00% -

26 TOTAL NET ACQUISITION ADJUSTMENT Sum Lines 23 through 25 - -

27

28 NET PLANT IN SERVICE (Note A)

29 Production Line 2 minus 13 plus 23 plus 24 - -

30 Transmission Line 3 minus 14 plus 25 - -

31 Distribution Line 4 minus 15 - -

32 General Plant Line 5 minus 16 - -

33 Intangible Plant Line 6 minus 17 - -

34 Common Intangible Line 7 minus 18 - -

35 Common General Line 8 minus 19 - -

36 TOTAL NET PLANT IN SERVICE Sum Lines 29 through 35 - -

37 Line 36, Col (5) divided by Col (3) NP= 0.00%

38

39 OTHER RATE BASE ITEMS (Note C)

40 Account No. 281 WP_B-2 Col (c) & (e), Line 3 - DA 0.00% -

41 Account No. 282 WP_B-2 Col (c) & (e), Line 30 - DA -



44 Regulatory Liabilities- FERC Account No. 254 (Note C) WP_B-6 Line 14 - W/S 0.00% -

45 Account No. 255 267.8.h - DA 100.00% -

46 Account No. 107 (CWIP) (Note E) WP_B-7 Col (a), Line 16 - DA 100.00% -

47 Net Pre-Funded AFUDC on CWIP included (Note E) WP_B-7 Col (d), Line 16 - DA 100.00% -

48 Unamortized Balance of Abandoned Incentive Plant (Note E) WP_B-Inputs Act. Line 142 - DA 100.00% -

49 Unamortized Balance of Extraordinary Property Loss (Note E) WP_B-Inputs Act. Line 142 - DA 100.00% -

50 TOTAL OTHER RATE BASE ITEMS Sum Lines 40 through 49 - -

51

52 LAND HELD FOR FUTURE USE (Note F) WP_B-Inputs Act. Line 142 - TP 0.00% -

53

54 WORKING CAPITAL

55 Cash Working Capital (Note G) - -

56 Materials & Supplies - Transmission WP_B-5 Line 48 - TP 0.00% -

57 Materials & Supplies - Other WP_B-5 Line 50 - NP 0.00% -

58 Prepayments (Account 165) Plant Related WP_B-5 Line 8 - NP 0.00% -

59 Prepayments (Account 165) Labor Related WP_B-5 Line 16 - W/S 0.00% -

60 Prepayments (Account 165) Transmission Related WP_B-5 Line 21 - TP 0.00% -

61 Prepayments (Account 165) Other Not Allocated WP_B-5 Line 35 - NA 0.00% -

62 TOTAL WORKING CAPITAL Sum Lines 55 through 61 - -

63

64 RATE BASE Line 36 plus 50 plus 52 plus 62 - -

65

66 Rate of Return Line 156 0.00% 0.00%

6768 RETURN (Rate Base * Rate of Return) Line 64 times Line 66 - -

Allocator

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EXPENSE, TAXES & REVENUE Total

Line No. REQUIREMENTS CALCULATION Reference/Notes Total Transmission

(1) (2) (3) (5)

69 OPERATION & MAINTENANCE EXPENSE

70 Transmission WP_C-1 Line 31 -

71 Less Total Account 561 WP_C-1 Lines 2 through 9 -






77 Less Total Account 565 (Note H) WP_C-1 Line 13 -

78 Add Back Account 565.25- System Integration Costs WP_C-1 Line 34 -

79 Transmission Subtotal Sum Lines 69 through 78 - TP 0.00% - 80

81 Administrative and General (Note I) WP_C-2 Line 15 -

82 Less: Acc. 924, Property Insurance WP_C-2 Line 5 -

83 Balance of A & G Sum Lines 81 through 82 - W/S 0.00% - 84 Plus: Account 924, Property Insurance Line 82 - NP 0.00% -

85 Account 928 - Transmission Specific WP_C-4 Line 5 - DA 100.00% -

86 A & G Subtotal Sum Lines 81 through 85 - -

87

88 TOTAL O & M EXPENSE Line 79 plus Line 86 - -

89

90

91 DEPRECIATION AND AMORTIZATION EXPENSE

92 Transmission WP_B-1 Line 24 - DA 100.00% - 93 Plus: Pre-Funded AFUDC Amortization (Note E) WP_B-7 Col (f), Line 16 - DA 100.00% - 94 Plus: Recovery of Abandoned Incentive Plant (Note E) WP_B-Inputs Act. Line 142 - DA 100.00% - 95 Plus: Recovery of Extraordinary Property Loss (Note E) WP_B-Inputs Act. Line 142 - DA 100.00% - 96 General WP_B-1 Line 26 - W/S 0.00% - 97 Intangible WP_B-1 Line 27 - W/S 0.00% - 98 Common Intangible WP_B-1 Line 28 - CE 0.00% - 99 Common General WP_B-1 Line 29 - CE 0.00% - 100 Acquisition Adjustment Amortization (Note F) WP_B-4 Line 15 - DA 100.00% -

101 TOTAL DEPRECIATION AND AMORTIZATION Sum Lines 92 through 100 - -

102

103 TAXES OTHER THAN INCOME (Note J)

104 Labor Related WP_D-1 Line 5 - W/S 0.00% -

105 Plant Related WP_D-1 Line 9 - NP 0.00% -

106 Miscellaneous WP_D-1 Line 11 - NA 0.00% -

107 TOTAL OTHER TAXES Sum Lines 104 through 106 - -

108

109 INCOME TAXES (Note K)

110 T=1 - {[(1 - SIT) * (1 - FIT)] / (1 - SIT * FIT * p)} = 0.00%

111 CIT=(T/1-T) * (1-(WCLTD/R)) = 0.00%

112 where WCLTD=(line 153) and R= (line 156)

113 and FIT, SIT & p are as given in Note K.

114 1 / (1 - T) = (from ln 110) -

115 Amortized Investment Tax Credit (enter negative) FF1 266.8.f

116

117 Income Tax Calculation Line 68 times Line 111 - -

118 ITC adjustment Line 114 times Line 115 - NP 0.00% -

119 TOTAL INCOME TAXES Sum Lines 117 through 118 - -

120

121

122 REVENUE CREDITS (Note L)

123 Account No. 454 (Rent from Transmission Facilities) WP_E-1 Line 4 - DA 100% -

124 Account No. 421.1 (Gain From Disposition of Utility Plant) WP_E-1 Line 9 - WS 0.00% -

125 Account No. 456.1 (Revenue from Trans. of Elect. of Others) WP_F-1 Line 37 Col. (b) + (c) - DA 100% -

126 Total Revenue Credits - - 127

128 REVENUE REQUIREMENT - -

(4)

Allocator

of 51




Total

Line No. SUPPORTING CALCULATIONS Reference/Notes Total Transmission

(1) (2) (3) (5)

129 TRANSMISSION PLANT INCLUDED IN THE ATRR (Note M)

130 Transmission plant WP_B-1 Col (a), Line 3 -

131 Transmission related Acquisition Adjustment WP_B-4 Col. (c), Line 15 -

132 Total Transmission Plant Sum Lines 129 through 130 -

133 Eliminate Generator Step-up facilities WP_B-Inputs Act. Line 117 -

134 Transmission plant included in OATT Trans Rate Sum Lines 131 through 132 -

135 Percent of Transmission Plant in the ATRR Line 134 divided by Line 132 TP= 0.00%

136

137 WAGES & SALARY ALLOCATOR (W/S)

138 Production FF1. 354.20.b NA 0.00% -

139 Transmission WP_C-1 Line 31 - TP 0.00% -

140 Regional Market FF1. 354.22.b NA 0.00% -

141 Distribution FF1. 354.23.b NA 0.00% -

142 Other FF1. 354.24.b NA 0.00% -

143 Total Sum Lines 138 through 142 - -

144

145 W/S Allocator Line 143, Col. (5) divided by Col. (3) W/S= 0.00%

146

147 Common to Electric Transmission Allocator FF1.356

148 W/S Allocator, Line 145 9.88%

149 Line 147 times Line 148 CE= 0.00%

150

151

152 RETURN (Note N) $ % Cost Weighted

153 Long Term Debt WP_G-1 Line 4 - 0.00% 0.00% 0.0000

154 Preferred Stock WP_G-1 Line 6 - 0.00% 0.00% 0.0000

155 Common Stock WP_G-1 Line 12 - 0.00% 10.25% 0.0000

156 Total Sum Lines 153 through 155 - ROR= 0.0000

157

158

159 PREPAYMENTS ALLOCATION FACTOR TO ELECTRIC 2012 FERC Form 1

160

161 Total Electric Plant in Service 207, Ln.100, Col. (g)

162 Common PIS Allocated to Electric 356

163 Electric Plant Held for Future Use 214, Ln. 47, Col. (d)

164 Electric Construction Work in Progress 216, Ln. 43, Col. (b)

165 Common CWIP Allocated to Electric 356

166 Total Electric Plant Sum Lines 161 through 165 -

167 Total Utility Plant 110, Ln. 4, Col. (c), plus Ln. 16, Col. (c)

168

169 Electric Plant to Total Plant Allocation Factor Line 166 divided by Line 167 0.00%

Allocator

(4)

of 51




General Notes: a) References to data from FERC Form 1 are indicated as: page#.line#.col.#

Notes:

A Gross Plant, Accumulated Depreciation Reserves will be the average of thirteen monthly balances.

B Pending approval of the unopposed settlement in Docket No. ER11-2853, transmission serving transmission related amounts associated with the Calpine Acquisition are included.

Future Acquisition Adjustment amounts will not be included in the formula except as directed by the Commission pursuant to a Section 205 filing.

The Net Acquisition Adjustment will be the average of thirteen monthly balances.

C Reflects the BOY/EOY average of the transmission related portion of balances in Accounts 281, 282, 283, 190, and 255 as adjusted by any amounts in contra accounts

identified as regulatory assets or liabilities related to FASB 106, 109, 133,158 or FASB Interpretation No. 48. Balance of Account 255 is reduced by prior flow throughs and

completely excluded if the utility chose to utilize amortization of tax credits against taxable income as discussed in Note k.

D The Regulatory Liability associated with the sale of the Technical Service Building (TSB) will be included in Rate Base. Future Regulatory Liabilities will not be included in the

formula except as directed by the Commission pursuant to a Section 205 filing.

E Includes any incentive Construction Work in Progress (CWIP), any related Pre-funded Allowance for Funds Used During Construction (AFUDC), any unamortized balances

related to the recovery of abandoned incentive plant costs, any extraordinary property losses and any related depreciation and amortization expense amounts.

Formula amounts for all of the foregoing items will remain at $0 until approved by FERC pursuant to a Section 205 filing under a separate docket.

F Includes only transmission related or functionally booked as transmission land held for future use.

G Cash Working Capital will be set at and remain $0 until such time as PSCo files and receives FERC approval.

H Account 565 Transmission by Others is included only to the extent used to integrate the PSCo Transmission system.

I Post-Employment Benefits Other than Pensions (FAS 106) shall remain as a stated, fixed amount and shall not be changed except as directed by the Commission

following a filing seeking such change pursuant to section 205 or 206 of the FPA. The adjustment is shown on WP_C-3 PBOP.

Regulatory Commission expenses (FERC Account 928) will be directly assigned or allocated to Transmission.

General Advertising Expenses (FERC Account 930.1) will be excluded.

EPRI Fees and EEI Dues recorded in FERC Account 930.2 will be excluded.

J Includes only FICA, unemployment, property, and other assessments charged in the current year.

Taxes related to income are excluded. Franchise taxes are not included in transmission revenue requirement in the Rate Formula Template,

K The currently effective income tax rate, where FIT is the Federal income tax rate; SIT is the State income tax rate, and p =

"the percentage of federal income tax deductible for state income taxes".

PSCo has elected to utilize amortization of tax credits against taxable income, rather than book tax credits to Account No. 255 and reduce

rate base, must reduce its income tax expense by the amount of the Amortized Investment Tax Credit (Form 1, 266.8.f) less adjustments

multiplied by (1/1-T) (page 3, line 30).

Inputs Required: FIT =

SIT= (State Income Tax Rate or Composite SIT)

p = (percent of FIT deductible for state purposes)

L Includes income related to transmission facilities, such as pole attachments, rentals and special use for the Transmission facilities included herein.

FERC 421.1 Gain on the Disposition of Utility Property will be assigned or allocated to the transmission function based on the specific property sold.

Revenue from coincident peak loads included in the DIVISOR are also not included as revenue credits unless this revenue is offset by a corresponding expense

M Removes the dollars of plant booked to transmission plant that is excluded from the Tariff because it does not meet the Tariff's definition of Transmission

Facilities, or is booked to transmission (e.g. step-up transformers) that is included in the development of OATT ancillary service rates,

or is otherwise not eligible to be recovered under this Tariff.

N Return on Equity will be set at 10.25%. Thereafter, any change will require a filing with the Commission pursuant to Section 205 or 206 filing.

If and when the Company issues preferred stock, footnote will indicate the authorizing regulatory agency, the docket/case number, and the date of the authorizing order.

If a change in an income tax rate is known sufficiently in advance to be reflected in the estimated rates that will become effective January 1 for the upcoming formula rate year, PSCo

will reflect the new tax rate(s) in the estimated rate calculations for the months in which the new tax rate will be in effect for the formula rate year. Otherwise, such tax change will be

captured and reflected in the annual formula true-up by weighting the tax rates in effect during the year by the number of days each such tax rate was in effect.

of 51


Transmission Formula Rate Template WP_A-1


True-up of Estimated Rates

Line No.

I. Revenue Requirement True-up:

1 Estimated Revenue Requirement for the Prior Rate Year - (ATRR. Est. line 128) 215,056,093$

2 Actual Revenue Requirement for the Prior Rate Year - (ATRR Act. Line 128) -$

3 Revenue Requirement Adjustment (Over Recovery is a Credit, Under Recovery is a Debit) (ln 2 - ln 1) ($215,056,093)

4 II. Volume True-up:

5 Projected Divisor Load for the Prior Rate Year, WP_I-1 Est. Col (g), Line 15 6,046,996 kw

6 Actual Divisor Load for the Prior Rate Year, WP_I-1 Act. Col (d), Line 15 0 kw

7 Volume Adjustment (line 5 - line 6) 6,046,996 kw

8 Estimated Rate per kw-yr for the Prior Rate Year (line 1 / line 5) $35.564

9 Actual Rate per kw-yr for the Prior Rate Year (line 2 / line 6) $0.0000

10 Volume Revenue Adjustment (Over Recovery is a Credit, Under Recovery is a Debit) (line 7 x line 8) $215,056,093

11 Net True-up Adjustment (Over Recovery is a Credit, Under Recovery is a Debit) (line 3 + line 10) ($0)

12 III. Interest Calculation:

13

14

15 FERC Monthly

16 Quarterly Interest

17 Months Interest Rates Rate

18 January - Yr 2012 0.00% 0.0000

19 February 0.00% 0.0000

20 March 0.00% 0.0000

21 April 0.00% 0.0000

22 May 0.00% 0.0000

23 June 0.00% 0.0000

24 July 0.00% 0.0000

25 August 0.00% 0.0000

26 September 0.00% 0.0000

27 October 0.00% 0.0000

28 November 0.00% 0.0000

29 December 0.00% 0.0000

30 January - Yr 2013 0.00% 0.0000

31 February 0.00% 0.0000

32 March 0.00% 0.0000

33 April 0.00% 0.0000

34 May 0.00% 0.0000

35 June 0.00% 0.0000

36 July 0.00% 0.0000

37 August 0.00% 0.000038 September 0.00% 0.0000

39 Average Monthly Interest Rate 0.0000

40 Over/Under Recovery Amount (ln 11 amount) ($0)41 Average Monthly Interest Rate (ln 39) 0.0000

42 Monthly Interest Recovery Amount (ln 40 x ln 41) $0

43 Number of Months for Interest Recovery Amount 24

44 Interest Recovery Amount (ln 43 times ln 42) $0

45 Prior Year True-up Adjustment (ln 11) ($0) (Input to Annual Update)46 Interest on Prior Year True-up Adjustment (ln 44) $0 (Input to Annual Update)

Note:

The interest is calculated using the interest rate posted on the FERC website.

See link to website below.

http://www.ferc.gov/legal/acct-matts/interest-rates.asp#skipnavsub

of 51


Transmission Formula Rate Template WP_A-2


Prior Period Corrections

Line

No.

1 Explanation of Prior Period Correction:

2

3

4 Rate Year Prior Period Correction Applicable to (input year)

5 Effective True-up Year for Rate Year Prior Period Correction (line 4 year + 2 years) 0

6 Year Prior Period Correction Settled/Agreed (input)

7 Rate Year Prior Period Correction will be Included in ATRR (line 6 year + 1 year) 0

8 Number of Months Prior Period Correction Subject to Interest ((ln 7 year - ln 4 year) * 12) 0

9 I. Revenue Requirement True-up:

10 Revenue Requirement for Prior Period Correction True-up Year without Prior Period Correction (input)

11 Revised Revenue Requirement for True-up Year with Prior Period Correction (input)

12 Revenue Requirement True-up Adjustment (Over Recovery is a Credit, Under Recovery is a Debit) (ln 11 - ln 10) $0

13 II. Volume True-up:

14 Divisor for Prior Period Correction True-up Year without Prior Period Correction (input) kw

15 Divisor for True-up Year with Prior Period Correction (input) kw

16 Volume Adjustment (line 14 - line 15) 0 kw

17 Actual Rate (line 10 / line 14) $0.0000

18 Revised Rate (line 11 / line 15) $0.0000

19 Volume Revenue Adjustment (Over Recovery is a Credit, Under Recovery is a Debit) (line 16 x line 17) $0

20 Net Prior Period Correction True-up Adjustment (Over Recovery is a Credit, Under Recovery is a Debit) (line 12 + line 19) $0

21 III. Interest Calculation:

22 FERC Number Monthly

23 Quarterly of Days Interest

24 Month/Year Interest Rates in Month Rate

25 0.0000

26 0.0000

27 0.0000

28 0.0000

29 0.0000

30 0.0000

31 0.0000

32 0.0000

33 0.0000

34 0.0000

35 0.0000

36 0.0000

37 0.0000

38 0.0000

39 0.0000

40 0.0000

41 0.0000

42 0.0000

43 0.0000

44 0.0000

45 0.0000

46 Average Monthly Interest Rate 0.0000

47 Over/Under Recovery Amount (ln 20 amount) $0

48 Average Monthly Interest Rate (ln 46) 0.0000

49 Monthly Interest Recovery Amount (ln 47 x ln 48) $0

50 Number of Months for Interest Recovery Amount (from line 8) 0

51 Interest Recovery Amount (ln 50 times ln 49) $0

52 Prior Period Correction Adjustment (ln 20) $0 (Input to Annual Update)

53 Interest on Prior Period Correction Adjustment (ln 51) $0 (Input to Annual Update)

Note:




of 51


Transmission Formula Rate Template WP_B-1


Gross Plant, Accumulated Depreciation & Amortization, and Depreciation Expense

Estimated

Per Books GSU Reclass Adjustments Adjusted Balance

Line No. Functional Class Reference 13 Month Avg 13 Month Avg (1) 13 Month Avg (2) 13 Month Avg

(a) (b) (c) (d)

1 Plant in Service:

2 Production Plant WP_B-Inputs Est. Line 17 4,455,794,646 57,792,860 - 4,513,587,506

3 Transmission WP_B-Inputs Est. Line 17 1,736,774,457 (56,828,273) - 1,679,946,184

4 Distribution (3) WP_B-Inputs Est. Line 17 3,877,758,119 (451,362) (2,194,157) 3,875,112,601

5 General (3) WP_B-Inputs Est. Line 17 169,007,701 (513,226) (26,328,277) 142,166,199

6 Intangible (3) (4) WP_B-Inputs Est. Line 17 64,394,446 (24,298,008) 40,096,438

7 Common Intangible (4) (5) WP_B-Inputs Est. Line 17 289,703,079 (86,340,763) 203,362,316

8 Common General (3) WP_B-Inputs Est. Line 17 388,361,590 (998,735) 387,362,855

9 Total Plant In Service with Adjustments Sum Lines 2 through 8 10,981,794,038 0 (140,159,940) 10,841,634,098

10

11 Accumulated Depreciation & Amortization:

12 Production Plant WP_B-Inputs Est. Line 40 1,475,929,252 19,894,922 - 1,495,824,175

13 Transmission WP_B-Inputs Est. Line 40 381,532,121 (19,546,528) - 361,985,593

14 Distribution (3) WP_B-Inputs Est. Line 40 1,140,140,441 (128,926) (678,528) 1,139,332,988





19 Total Accumulated Depreciation & Amortization

with Adjustments Sum Lines 12 through 18 3,522,121,732 (0) (94,128,259) 3,427,993,473

20

21 Per Books GSU Reclass Adjustments Adjusted Balance

22 Depreciation and Amortization Expense: 12 Month Total 12 Month Total (1) 12 Month Total (2) 12 Month Total

23 Production Plant WP_B-Inputs Est. Line 45 127,707,850 925,087 - 128,632,937

24 Transmission WP_B-Inputs Est. Line 45 28,401,496 (893,301) - 27,508,195

25 Distribution (3) WP_B-Inputs Est. Line 45 85,405,473 (8,413) (161,145) 85,235,915





30 Total Depreciation and Amortization Expense Sum Lines 23 through 29 313,724,781 (0) (14,441,142) 299,283,640

Notes:

1. Generator Step Up's (GSU) are eliminated from Transmission, Distribution, and General Plant and reassigned to Production Plant

2. Adjustments are shown on WP_B-Inputs Est. Lines 66, 85, 91

3. Smart Grid City (retail) is eliminated

4. Retail related Franchises and Consents are eliminated from FERC 302

5. Retail Related CRS (Customer Resources System) and OMS (Outage Management System) are eliminated from Common Plant FERC 303

of 51




Gross Plant, Accumulated Depreciation & Amortization, and Depreciation Expense

Actual

Per Books GSU Reclass Adjustments Adjusted Balance

Line No. Functional Class Reference 13 Month Avg 13 Month Avg (1) 13 Month Avg (2) 13 Month Avg

(a) (b) (c) (d)

1 Plant in Service:

2 Production Plant WP_B-Inputs Act. Line 17 - - - -

3 Transmission WP_B-Inputs Act. Line 17 - - - -

4 Distribution (3) WP_B-Inputs Act. Line 17 - - - -

5 General (3) WP_B-Inputs Act. Line 17 - - - -

6 Intangible (3) (4) WP_B-Inputs Act. Line 17 - - -

7 Common Intangible (4) (5) WP_B-Inputs Act. Line 17 - - -

8 Common General (3) WP_B-Inputs Act. Line 17 - - -

9 Total Plant In Service with Adjustments Sum Lines 2 through 8 - - - -

10

11 Accumulated Depreciation & Amortization:








19 Total Accumulated Depreciation & Amortization

with Adjustments Sum Lines 12 through 18 - - - -

20

21 Per Books GSU Reclass Adjustments Adjusted Balance

22 Depreciation and Amortization Expense: 12 Month Total 12 Month Total (1) 12 Month Total (2) 12 Month Total








30 Total Depreciation and Amortization Expense Sum Lines 23 through 29 - - - -

Notes:

1. GSU's are eliminated from Transmission, Distribution, and General Plant and reassigned to Production Plant

2. Adjustments are shown on WP_B-Inputs Est. Lines 108, 127, 133

3. Smart Grid City (retail) is eliminated

4. Retail related Franchises and Consents are eliminated from FERC 302

5. Retail Related CRS (Customer Resources System) and OMS (Outage Management System) are eliminated from Common Plant FERC 303

of 51




Accumulated Deferred Income Taxes (Credits)

Estimated

Adjusted

Line No. Account Number 12/31/2012 12/31/2013

Average

Balance Adjustments (1)

Average

Balance

(a) (b) (c) (d) (e)

1 Account 281 - Accelerated amortization property

2 Pollution Control Facilities - Production (67,103,832) (74,004,471) (70,554,152) 70,554,152 -

3 Total Acct. 281 (Form 1 pg. 272-273, Line 17, Col. b & k) (67,103,832) (74,004,471) (70,554,152) 70,554,152 -

4

5 Account 282 - Other Property

6 Plant Related- Direct Assigned to Transmission

7 Electric Distribution (837,909,930) (853,545,065) (845,727,497) 845,727,497 -

8 Electric Distribution-Prod (137,573) (137,844) (137,708) 137,708 -

9 Electric Transmission (327,079,143) (362,336,770) (344,707,956) - (344,707,956)

10 Electric Transmission-Prod (7,142,116) (8,011,084) (7,576,600) 7,576,600 -

11 Hydro Production (23,123,920) (24,737,704) (23,930,812) 23,930,812 -

12 Other Production (143,111,929) (167,069,507) (155,090,718) 155,090,718 -

13 Electric General-Prod (44,775) (35,936) (40,356) 40,356 -

14 Pre-Funded (Retail) 9,712,541 9,623,869 9,668,205 (9,668,205) -

15 Steam Production (325,777,406) (340,710,858) (333,244,132) 333,244,132 -

16 Total (1,654,614,251) (1,746,960,899) (1,700,787,575) 1,356,079,619 (344,707,956)

17

18 Plant Related- Allocated to Transmission

19 Common General (2) (48,989,948) (44,410,401) (46,700,174) 179,615 (46,520,559)

20 Common Intangible (494,247) (322,460) (408,353) (408,353)

21 Electric General (2) (31,654,275) (30,756,345) (31,205,310) 6,270,713 (24,934,597)

22 Electric Intangible (1,805,508) (1,801,642) (1,803,575) (1,803,575)

23 Total (82,943,978) (77,290,847) (80,117,413) 6,450,328 (73,667,084)

24 Labor Allocation Factors, ATRR Est. Line 145 9.88%

25 Total Plant Related Allocated to Transmission (7,281,255)

26

27 FAS 109 - - - - -

28 Sub-total FAS 109 - - - - - 29

30 Total Acct. 282 (Form 1, pg. 274-275, ln 2 + Ln 6, col b & k) (1,737,558,229) (1,824,251,746) (1,780,904,988) 1,362,529,947 (351,989,211)

31

32 Account 283 - Other

33 Plant Related- Direct Assigned to Production

34 Electric Production (937) (910) (923) 923 -

35 Regulatory Asset- Calpine Acquisition Costs (377,896) (330,259) (354,077) 354,077 -

36 Total (378,832) (331,168) (355,000) 355,000 -

37

38 Direct Assigned to Transmission

39 Regulatory Asset - MPB Tree Clearing (3,497,851) (2,496,617) (2,997,234) - (2,997,234)

40 Total (3,497,851) (2,496,617) (2,997,234) - (2,997,234)

41


43 Common General (290,752) (217,231) (253,992) - (253,992)

44 Common Intangible (2) (20,367,766) (15,701,696) (18,034,731) 2,714,662 (15,320,068)

45 Electric General (1,047,108) (929,600) (988,354) - (988,354)

46 Electric Intangible (2) (5,218,556) (3,658,757) (4,438,656) 1,651,641 (2,787,016)

47 Total (26,924,181) (20,507,284) (23,715,732) 4,366,303 (19,349,429)


49 Total Plant Related Allocated to Transmission (1,912,498)

50

51 Labor Related

52 Regulatory Asset- Leasehold Improvements (729,096) (364,548) (546,822) - (546,822)

53 Pension Expense (3) (98,005,729) (98,439,832) (98,222,781) 98,222,781 -

54 Sub-total labor Related (98,734,826) (98,804,380) (98,769,603) 98,222,781 (546,822)


56 Total Plant Related Allocated to Transmission (54,048)

57

58 Related to All Plant

59 State Tax Deduction Cash vs Accrual (29,861) (29,861) (29,861) - (29,861)

60 Rent Exp - Brokerage Fee (1,012,727) (931,165) (971,946) - (971,946)

61 Book Unamortized Cost of Reacquired Debt (3,907,535) (3,325,362) (3,616,448) - (3,616,448)

62 Sub-total Production Related (4,950,122) (4,286,387) (4,618,255) - (4,618,255)

63 Net Plant Allocation Factor, ATRR Est. Line 36 17.71%

64 Total Related to All Plant (817,932)

65

66 Retail Related

67 Regulatory Asset - ICT (1,396,129) (698,064) (1,047,097) 1,047,097 -

68 Regulatory Asset- Propety Tax (5,821,608) (17,602,040) (11,711,824) 11,711,824 -

69 Regulatory Asset- Transmission Costs (298,221) (298,221) (298,221) 298,221 -

70 Regulatory Reserve- Environmental (23,554) (23,554) (23,554) 23,554 -

71 Deferred Costs (1,972,701) 540,552 (716,075) 716,075 -

72 Demand Side Management (21,008,766) (17,099,266) (19,054,016) 19,054,016 -

73 Sub-total Retail Related (30,520,979) (35,180,593) (32,850,786) 32,850,786 -

74

75 Other Non-Transmission Related

76 Prepaid Water- Aurora (474,874) (949,748) (712,311) 712,311 -

77 Rate Case Expense (881,366) (881,366) (881,366) 881,366 -

78 Mark to Market Adjust (2,959,773) (2,779,851) (2,869,812) 2,869,812 -

79 Sub-total Other Related (4,316,012) (4,610,964) (4,463,488) 4,463,488 - 80

81 Total Acct. 283 (Form 1, pg. 276-277, line 9, col b & k) (169,322,804) (166,217,393) (167,770,098) 140,258,358 (5,781,711)

Note:

Note: 2. Adjustment to ADIT associated with plant adjustments, see WP_B-Inputs.

Note: 3. ADIT associated with Pension expense has been eliminated because the prepaid pension asset is not included in rate base.

Balance at

1. Deferred Taxes associated with implementing Statements of Financial Accounting Standards Board 109, distribution, production, retail, and non-utility

plant related are eliminated.

of 51




Accumulated Deferred Income Taxes (Credits)

Actuals

Adjusted

Line No. Account Number

Average

Balance Adjustments (1)

Average

Balance

(a) (b) (c) (d) (e)

1 Account 281 - Accelerated amortization property

2 - -

3 Total Acct. 281 (Form 1 pg. 272-273, Line 17, Col. b & k) - - - - -

4

5 Account 282 - Other Property


7 - -

8 - -

9 - -

10 - -

11 - -

12 - -

13 - -

14 - -

15 - -

16 Total - - - - -

17


19 - -

20 - -

21 - -

22 - -

23 Total - - - - -

24 Labor Allocation Factors, ATRR Act. Line 145 0.00%

25 Total Plant Related Allocated to Transmission -

26

27 - -

28 Sub-total FAS 109 - - - - - 29

30 Total Acct. 282 (Form 1, pg. 274-275, ln 2 + Ln 6, col b & k) - - - - -

31

32 Account 283 - Other

33 Plant Related- Direct Assigned to Production

34 - -

35 - -

36 Total - - - - -

37


39 - -

40 - -

41 - -

42 - -

43 Total - - - - -



46

47 Labor Related

48 - -

49 - -

50 Sub-total labor Related - - - - -



53


55 - -

56 - -

57 Sub-total Production Related - - - - -

58 Net Plant Allocation Factor, ATRR Act. Line 36 0.00%

59 Total Related to All Plant -

60

61 Retail Related

62 - -

63 - -

64 - -

65 - -

66 Sub-total Retail Related - - - - -

67

68 Other Non-Production Related

69 - -

70 - -

71 - -

72 - -

73 Sub-total Other Related - - - - - 74

75 Total Acct. 283 (Form 1, pg. 276-277, line 9, col b & k) - - - - -

Note:

Note: 2. Adjustment to ADIT associated with plant adjustments, see WP_B-Inputs.

Note: 3. ADIT associated with Pension expense has been eliminated because the prepaid pension asset is not included in rate base.

Balance at

1. Deferred Taxes associated with implementing Statements of Financial Accounting Standards Board 109, distribution, production, retail, and non-utility

plant related are eliminated.

of 51




Accumulated Deferred Income Taxes (Debits)

Estimated

Adjusted

Line No. Account No. 12/31/2012 12/31/2013

Average

Balance

Adjustments

(1) Average Balance

(a) (b) (c) (d) (e)

1 Account 190- Accumulated Deferred Income Taxes

2

3 Production Related - Demand

4 - -

5 Total Production - Demand Related - - - - -

6

7 Production Related - Energy

8 Fuel Tax Credit - Inc Addback 2,579 2,579 2,579 (2,579) -

9 Trapper Mine Reclamation 598,721 598,721 598,721 (598,721) -

10 Windpower Credit - FED DIT Only 8,645,705 8,645,705 8,645,705 (8,645,705) -

11 Total Production - Energy Related 9,247,005 9,247,005 9,247,005 (9,247,005) -

12


14 Electric Distribution 172,269,820 168,022,378 170,146,099 (170,146,099) -

15 Electric Distribution-Prod 12,659 12,347 12,503 (12,503) -

16 NOL Carryforward- Distribution 20,336,774 16,098,078 18,217,426 (18,217,426) -

17 Electric Transmission 25,717,596 25,981,351 25,849,474 - 25,849,474

18 Electric Transmission-Prod 1,343,030 1,311,150 1,327,090 (1,327,090) -

19 NOL Carryforward- Transmission 14,327,878 11,341,587 12,834,733 - 12,834,733

20 Hydro Production 793,550 836,408 814,979 (814,979) -

21 Other Production 8,893,163 13,828,988 11,361,076 (11,361,076) -

22 Steam Production 63,357,583 64,877,641 64,117,612 (64,117,612) -

23 NOL Carryforward- Production 15,123,131 11,971,089 13,547,110 (13,547,110) -

24 Total Plant Related- Direct Assigned to Transmission 322,175,186 314,281,016 318,228,101 (279,543,895) 38,684,206

25


27 Common General 992,233 976,876 984,554 - 984,554

28 Common Intangible 27,732 26,414 27,073 - 27,073

29 NOL Carryforward- Common (Allocated to Electric) 2,525,906 1,999,444 2,262,675 - 2,262,675

30 Electric General 953,664 995,072 974,368 - 974,368

31 Electric Intangible 12,373 11,127 11,750 - 11,750

32 NOL Carryforward- Electric General 1,887,459 2,714,917 2,301,188 - 2,301,188

33 Total Plant Related- Allocated to Transmission 6,399,367 6,723,850 6,561,608 - 6,561,608


35 Total Plant Related Allocated to Transmission 648,549

36


38 Environmental Remediation 121,069 121,069 121,069 - 121,069

39 Inventory Reserve 311,897 311,897 311,897 - 311,897

40 Enterprise Zone Credit - State DIT Only 8,552,468 7,953,966 8,253,217 - 8,253,217

41 R & E Credit - FED DIT Only 7,194,613 7,194,613 7,194,613 - 7,194,613

42 Total Related to All Plant 16,180,048 15,581,545 15,880,796 - 15,880,796

43 Net Plant Allocation Factor, ATRR Est. Line 36 17.71%

44 Allocated Total Related to All Plant 2,812,622

45

46 Labor Related

47 Non-Qualified Pension Plan - ST 28,529 13,589 21,059 - 21,059

48 Severance Accrual 2,037 - 1,019 - 1,019

49 Vacation Accrual 3,042,460 3,042,460 3,042,460 - 3,042,460

50 Performance Share Plan 121,438 104,407 112,923 - 112,923

51 Grantor Trust / Life Insurance 51,947 51,947 51,947 - 51,947

52 Post Employment Benefits - FAS 106 3,822,298 3,117,586 3,469,942 - 3,469,942

53 Post Employment Benefits - FAS 112 2,051,763 1,719,421 1,885,592 - 1,885,592

54 Deferred Compensation Plan Reserve 293,149 389,186 341,167 - 341,167

55 Deferred Rent 8,681,678 8,212,931 8,447,305 - 8,447,305

56 Employee Incentive plans 1,505,282 1,723,253 1,614,267 - 1,614,267

57 Total Labor Related 19,600,581 18,374,779 18,987,680 - 18,987,680


59 Allocated Total Labor Related 1,876,742

60

61 Retail Related

62 Bad Debts 4,607,977 4,607,977 4,607,977 (4,607,977) -

63 REC Margin Sharing 536,729 536,729 536,729 (536,729) -

64 Solar Rewards Program 362,880 362,880 362,880 (362,880) -

65 Unbilled Revenue 26,472,255 26,757,467 26,614,861 (26,614,861) -

66 Rate Refund - Long Term 8,333,844 8,333,844 8,333,844 (8,333,844) -

67 Total Retail Related 40,313,685 40,598,897 40,456,291 (40,456,291) -

68


70 Litigation Reserve 140,942 140,942 140,942 (140,942) -

71 Total Other Related 140,942 140,942 140,942 (140,942) -

7273

74 Total Account 190 (Form 1, page 234, line 8, cols b & c) 414,056,813 404,948,034 409,502,424 44,022,120

Note:

Balance at

1. Deferred Taxes associated with implementing Statements of Financial Accounting Standards Board 109, distribution, production, retail, and non-utility plant

related are eliminated.

of 51




Accumulated Deferred Income Taxes (Debits)

Actual

Adjusted

Line No. Account No.

Average

Balance

Adjustments

(1) Average Balance

(a) (b) (c) (d) (e)

1 Account 190- Accumulated Deferred Income Taxes

2

3 Production Related - Demand

4 - -

5 Total Production - Demand Related - - - - -

6

7 Production Related - Energy

8 - -

9 - -

10 - -

11 Total Production - Energy Related - - - - -

12


14 - -

15 - -

16 - -

17 - -

18 - -

19 - -

20 - -

21 - -

22 - -

23 - -

24 - -

25 Total Plant Related- Direct Assigned to Transmission - - - - -

26


28 - -

29 - -

30 - -

31 - -

32 - -

33 - -

34 Total Plant Related- Allocated to Transmission - - - - -



37


39 - -

40 - -

41 - -

42 - -

43 - -

44 - -

45 - -

46 - -

47 Total Related to All Plant - - - - -

48 Net Plant Allocation Factor, ATRR Act. Line 36 0.00%

49 Allocated Total Related to All Plant -

50

51 Labor Related

52 - -

53 - -

54 - -

55 - -

56 - -

57 - -

58 - -

59 - -

60 - -

61 - -

62 - -

63 Total Labor Related - - - - -


65 Allocated Total Labor Related -

66

67 Retail Related

68 - -

69 - -

70 - -

71 - -

72 - -

73 - -

74 - -

75 - -

76 Total Retail Related - - - - -

77


79 - -

80 Total Other Related - - - - -

8182

83 Total Account 190 (Form 1, page 234, line 8, cols b & c) - - - -

Note:

Balance at

1. Deferred Taxes associated with implementing Statements of Financial Accounting Standards Board 109, distribution, production, retail, and non-utility plant

related are eliminated.

of 51




Acquisition Adjustment

Estimated

Line No Description Production

Transmission

Serving

Production

Transmission

Serving

Transmission Total (1) Production

Transmission

Serving

Production

Transmission

Serving


Transmission

Serving

Production

Transmission

Serving

Transmission Total Production

Transmission

Serving

Production

Transmission

Serving

Transmission Total (3)

(a) (b) (c) (d)=(a)+(b)+(c) (e) (f) (g) (h)=(e)+(f)+(g) (i)=(a)-(e) (j)=(b)-(f) (k)=(c)-(g) (l)=(i)+(j)+(k) (m) (n) (o) (p)=(m)+(n)+(o)Estimated Balance

12 December 210,144,390 10,104,476 5,308,257 225,557,123 10,726,124 375,046 197,029 11,298,199 199,418,266 9,729,430 5,111,228 214,258,924 3 January 210,144,390 10,104,476 5,308,257 225,557,123 11,163,925 390,354 205,071 11,759,350 198,980,465 9,714,122 5,103,186 213,797,773 437,801 15,308 8,042 461,151 4 February 210,144,390 10,104,476 5,308,257 225,557,123 11,601,726 405,662 213,113 12,220,501 198,542,664 9,698,814 5,095,144 213,336,622 437,801 15,308 8,042 461,151 5 March 210,144,390 10,104,476 5,308,257 225,557,123 12,039,527 420,970 221,155 12,681,652 198,104,863 9,683,506 5,087,102 212,875,471 437,801 15,308 8,042 461,151 6 April 210,144,390 10,104,476 5,308,257 225,557,123 12,477,328 436,278 229,197 13,142,803 197,667,062 9,668,198 5,079,060 212,414,320 437,801 15,308 8,042 461,151 7 May 210,144,390 10,104,476 5,308,257 225,557,123 12,915,129 451,586 237,239 13,603,954 197,229,261 9,652,890 5,071,018 211,953,169 437,801 15,308 8,042 461,151 8 June 210,144,390 10,104,476 5,308,257 225,557,123 13,352,930 466,894 245,281 14,065,105 196,791,460 9,637,582 5,062,976 211,492,018 437,801 15,308 8,042 461,151 9 July 210,144,390 10,104,476 5,308,257 225,557,123 13,790,731 482,202 253,323 14,526,256 196,353,659 9,622,274 5,054,934 211,030,867 437,801 15,308 8,042 461,151

10 August 210,144,390 10,104,476 5,308,257 225,557,123 14,228,532 497,510 261,365 14,987,407 195,915,858 9,606,966 5,046,892 210,569,716 437,801 15,308 8,042 461,151 11 September 210,144,390 10,104,476 5,308,257 225,557,123 14,666,333 512,818 269,407 15,448,558 195,478,057 9,591,658 5,038,850 210,108,565 437,801 15,308 8,042 461,151 12 October 210,144,390 10,104,476 5,308,257 225,557,123 15,104,134 528,126 277,449 15,909,709 195,040,256 9,576,350 5,030,808 209,647,414 437,801 15,308 8,042 461,151 13 November 210,144,390 10,104,476 5,308,257 225,557,123 15,541,935 543,434 285,491 16,370,860 194,602,455 9,561,042 5,022,766 209,186,263 437,801 15,308 8,042 461,151 14 December 210,144,390 10,104,476 5,308,257 225,557,123 15,979,736 558,742 293,533 16,832,011 194,164,654 9,545,734 5,014,724 208,725,112 437,801 15,308 8,042 461,151

15

13 Month Avg. (Lns 2 - 14) 210,144,390 10,104,476 5,308,257 225,557,123 13,352,930 466,894 245,281 14,065,105 196,791,460 9,637,582 5,062,976 211,492,018 5,253,612 183,696 96,504 5,533,812

Source:1. Company Records2. Company Records3. Company Records

Actual

Line No Description Production

Transmission

Serving

Production

Transmission

Serving


Transmission

Serving

Production

Transmission

Serving


Transmission

Serving

Production

Transmission

Serving

Transmission Total Production

Transmission

Serving

Production

Transmission

Serving

Transmission Total (3)

(a) (b) (c) (d)=(a)+(b)+(c) (e) (f) (g) (h)=(e)+(f)+(g) (i)=(a)-(e) (j)=(b)-(f) (k)=(c)-(g) (l)=(i)+(j)+(k) (m) (n) (o) (p)=(m)+(n)+(o)Actual Balance

12 December - - - - - - 3 January - - - - - - - 4 February - - - - - - - 5 March - - - - - - - 6 April - - - - - - - 7 May - - - - - - - 8 June - - - - - - - 9 July - - - - - - -

10 August - - - - - - - 11 September - - - - - - - 12 October - - - - - - - 13 November - - - - - - - 14 December - - - - - - -

15

13 Month Avg. (Lns 2 - 14) - - - - - - - - - - - - - -

Source:1. FERC Account 114- FERC Form 1 pg. 200 Ln. 122. FERC Account 115- FERC Form 1 pg. 200 Ln. 323. FERC Account 406- FERC Form 1 pg. 114 Ln. 9

Note: Only transmission related amounts associated with the Calpine Acquisition are included. Future Acquisition Adjustment amounts will not be included in the formula except as directed by the Commission pursuant to a Section 205 filing.

FERC 406 (Amount included in Depreciation and Amortization

Expense)

Note: Only transmission related amounts associated with the Calpine Acquisition are included. Future Acquisition Adjustment amounts will not be included in the formula except as directed by the Commission pursuant to a Section 205 filing.

FERC 114- Electric Plant Acquisition Adjustment

FERC 115- Accumulated Provision for Amortization of Electric

Plant Acquisition Adjustment Net Acquisition Adjustment (Amount included in Rate Base)

FERC 406 (Amount included in Depreciation and Amortization

Expense)

FERC 114- Electric Plant Acquisition Adjustment

FERC 115- Accumulated Provision for Amortization of Electric

Plant Acquisition Adjustment Net Acquisition Adjustment (Amount included in Rate Base)

of 51




Prepayments & Materials and Supplies

Line No. Description Reference Dec-10 Dec-11 BOY/EOY Avg Reference Dec-12 Dec-13

BOY/EOY

Avg

Prepayments (FERC Account 165) (1)

1 Plant Related:

2 Insurance Prepaid Company Records 7,493,726$ 8,860,005$ 8,176,866$ -$

3 Interest Prepaid Company Records 277,824 2,208,350 1,243,087

4 Prepaid Auto Licensing Company Records 65,881 72,700 69,291 -

5 Dark Fiber Lease Company Records 70,512 70,512 70,512 -

6 Total Plant Related 7,907,943$ 11,211,567$ 9,559,755$ -$ -$ -$ 7 Allocation Factor to Electric ATRR Est. Line 169 79.87% ATRR Act Line 169 0.00%

8 Total Plant Related Allocated to Electric 7,635,404$ -$

9

10 Labor Related:

11 Prepaid VEBA Trust Company Records (619,241)$ (556,069)$ (587,655)$ -$

12 Other Prepaid- TSB Company Records 9,594,399 - 4,797,200

13 Other Prepaid - Benefits Company Records - 49,672 24,836

14 Total Labor Related 8,975,158$ (506,397)$ 4,234,380$ -$ -$ -$ 15 Allocation Factor to Electric ATRR Est. Line 169 79.87% ATRR Act Line 169 0.00%

16 Total Labor Related Allocated to Electric 3,382,012$ -$

17

18 Transmission Related:

19 Other Prepaid-Transmission Company Records -$ 144,340$ 72,170$ -$ 20 Prepaid Transmission Exp- WECC Company Records 1,603,810 23,046 813,428 -

21 Total Transmission Related 1,603,810$ 167,386$ 885,598$ -$ -$ -$

22

23 Other Related: Non-Transmission

24 Prepaid Ins-HomeSmart Company Records 11,006$ -$ 5,503$ -$

25 Gas Imbalances Prepaid Company Records 695,944 499,001 597,472 -

26 Prepaid Taxes - Federal Company Records 34,062,463 2,956,349 18,509,406 -

27 Prepaid Taxes State - CO Company Records 178,587 - 89,294 -

28 Other Prepaid Company Records 323,902 371,176 347,539 -

29 I/T Other Prepaids Company Records - 21,292

30 Other Prepaid-EM Company Records - 374,986 187,493

31 Comanche Extended Warranty Company Records - 902,782 451,391

32 Other Prepaid-DU Company Records 121,000 - 60,500 -

33 Total Other Related 35,392,902$ 5,125,586$ 20,248,598$ -$ -$ -$ 34 Allocation Factor to Electric ATRR Est. Line 169 79.87% ATRR Act Line 169 0.00%

35 Total Other Related Allocated to Electric 16,172,614$ -$

36

37 Total Prepayments

FERC Form 1 pg. 111,

Line 57, Col. (c) & (d) 53,879,813$ 15,998,142$

FERC Form 1 pg.

111, Line 57, Col. (c)

& (d) -$ -$

3839

40

41

42 Description Reference Dec-10 Dec-11 BOY/EOY Avg Reference Dec-12 Dec-13

BOY/EOY

Avg

43

44 Materials & Supplies (FERC Account 154) (1)

45

46 Materials and Supplies - Construction


Line 5, Col. (b) & (c) 26,698,711$ 16,610,953$ 21,654,832$

FERC Form 1 pg.

227, Line 5, Col. (b)

& (c) -$

47 Materials and Supplies - Production


Line 7, Col. (b) & (c) 24,692,453$ 33,337,470$ 29,014,962$

FERC Form 1 pg.

227, Line 7, Col. (b)

& (c) -$

48 Materials and Supplies - Transmission


Line 8, Col. (b) & (c) 330,399$ 101,401$ 215,900$

FERC Form 1 pg.

227, Line 8, Col. (b)

& (c) -$

49 Materials and Supplies - Distribution


Line 9, Col. (b) & (c) 530,973$ 2,671,675$ 1,601,324$

FERC Form 1 pg.

227, Line 9, Col. (b)

& (c) -$

50 Materials and Supplies - Other


Line 11, Col. (b) & (c) (1,257,079)$ (1,585,630)$ (1,421,355)$

FERC Form 1 pg.

227, Line 11, Col. (b)

& (c) -$

5152 Total Materials & Supplies (FERC Account 154) 50,995,457$ 51,135,869$ -$ -$

Note 1. Prepayments and Materials & Supplies are not budgeted, therefore a Beginning of Year - End of Year average of the most recent actuals is used.

Estimated Actual

Estimated Actual

of 51




Regulatory Liabilities- FERC Account 254

Estimated

Line No. Date Reference

Beginning

Balance Amortization

Ending

Balance

(a) (b) (c) (d) (e)

Gain on the sale of the Technical Service Building (Electric portion)

1 December Company Records (3,856,618) 202,980 (3,653,638)

2 January Company Records (3,653,638) 202,980 (3,450,658)

3 February Company Records (3,450,658) 202,980 (3,247,679)

4 March Company Records (3,247,679) 202,980 (3,044,699)

5 April Company Records (3,044,699) 202,980 (2,841,719)

6 May Company Records (2,841,719) 202,980 (2,638,739)

7 June Company Records (2,638,739) 202,980 (2,435,759)

8 July Company Records (2,435,759) 202,980 (2,232,779)

9 August Company Records (2,232,779) 202,980 (2,029,799)

10 September Company Records (2,029,799) 202,980 (1,826,819)

11 October Company Records (1,826,819) 202,980 (1,623,839)

12 November Company Records (1,623,839) 202,980 (1,420,859) 13 December Company Records (1,420,859) 202,980 (1,217,879)

14 13 Month Avg. (Lns 1 - 13) (2,638,739)$ (2,435,759)$

15 12 Month Total. (Lns 2 - 13) 2,435,759$

Actual

Line No. Date Reference

Beginning

Balance Amortization

Ending

Balance

(a) (b) (c) (d) (e)

Gain on the sale of the Technical Service Building (Electric portion)

1 December FF1, Page 278.1 - - -

2 January Company Records - - -

3 February Company Records - - -

4 March Company Records - - -

5 April Company Records - - -

6 May Company Records - - -

7 June Company Records - - -

8 July Company Records - - -

9 August Company Records - - -

10 September Company Records - - -

11 October Company Records - - -

12 November Company Records - - - 13 December FF1, Page 278.1 - - -

14 13 Month Avg. (Lns 1 - 13) -$ -$

15 12 Month Total. (Lns 2 - 13) -$

of 51




Construction Work in Progress (1)

Estimated

Line No.

Work

Order #

Approved

in FERC

Docket

Work Order

Description Months CWIP Balance (2)

Adjustment to

Gross Plant

Adjustment to

Accumulated

Reserves

Adjustment to

Net Plant

Adjustment

to ADIT

Annual

Amortization

(a) (b) (c) (d) (e) (f)

1

2 December -

3 January -

4 February -

5 March -

6 April -

7 May -

8 June -

9 July -

10 August -

11 September -

12 October -

13 November -

14 December -

15

16 13 Month Avg. (Lns 2 - 14) - - - -

17 BOY/EOY Avg. (Lns 2 and 14) -

18 12 Month Total (Sum Lns 3 - 14) -

Notes:

(1) No CWIP cost data will be included except as directed by the Commission following a filing pursuant to section 205 of the FPA.

(2) Source: Unless noted otherwise, all data from the Capital Asset Accounting Work Order tracking system.

Actual

Line No.

Work

Order #

Approved

in FERC

Docket

Work Order

Description Months CWIP Balance (2)

Adjustment to

Gross Plant

Adjustment to

Accumulated

Reserves

Adjustment to

Net Plant

Adjustment

to ADIT

Annual

Amortization

(a) (b) (c) (d) (e) (f)

1

2 December -

3 January -

4 February -

5 March -

6 April -

7 May -

8 June -

9 July -

10 August -

11 September -

12 October -

13 November -

14 December -

15

16 13 Month Avg. (Lns 2 - 14) - - - -

17 BOY/EOY Avg. (Lns 2 and 14) -

18 12 Month Total (Sum Lns 3 - 14) -

Notes:

(1) No CWIP cost data will be included except as directed by the Commission following a filing pursuant to section 205 of the FPA.

(2) Source: Unless noted otherwise, all data from the Capital Asset Accounting Work Order tracking system.

Prefunded AFUDC Adjustments (2)

Prefunded AFUDC Adjustments (2)

of 51


Transmission Formula Rate Template WP_B-Inputs Est.


Rate Base Data Inputs- Estimated

Gross Plant

Intangible Plant Steam Production

Hydraulic

Production Other Production Transmission Plant Distribution Plant General Plant Common Intangible

Common

General

1 December 63,270,434 3,096,864,918 114,123,371 1,229,259,526 1,617,720,063 3,784,043,794 163,668,360 282,740,334 377,507,354

2 January 63,530,555 3,096,864,918 114,123,371 1,229,259,526 1,717,580,581 3,791,259,327 165,017,984 283,252,098 379,538,446

3 February 63,548,853 3,096,949,173 114,123,371 1,229,259,526 1,718,165,011 3,802,283,311 165,642,580 283,537,353 380,287,013

4 March 63,615,140 3,099,941,026 114,123,371 1,234,849,653 1,727,466,970 3,826,601,039 166,381,321 285,780,343 381,064,926

5 April 63,707,975 3,102,410,901 114,123,371 1,236,781,118 1,731,868,813 3,838,964,246 166,963,228 288,603,402 382,145,883

6 May 63,818,053 3,105,560,372 114,251,338 1,239,392,504 1,740,237,395 3,872,741,650 167,548,813 289,109,253 383,415,943

7 June 63,951,537 3,106,704,486 114,255,605 1,241,790,827 1,743,299,574 3,884,530,346 168,815,984 289,672,283 388,424,009

8 July 64,121,735 3,108,388,162 114,255,605 1,243,738,771 1,744,559,460 3,900,414,627 169,841,304 290,296,710 390,096,146

9 August 65,204,751 3,111,798,700 114,255,605 1,243,739,271 1,748,856,827 3,909,804,302 170,767,197 291,446,375 391,846,927

10 September 65,372,325 3,112,763,254 114,255,605 1,251,252,566 1,749,186,265 3,931,901,646 171,531,820 292,122,945 393,762,069

11 October 65,526,488 3,114,106,638 114,460,810 1,255,332,177 1,759,374,102 3,942,879,951 172,345,333 293,131,428 395,779,830

12 November 65,665,110 3,114,516,137 121,853,100 1,258,880,809 1,773,634,927 3,955,143,949 173,149,662 296,276,291 397,623,921

13 December 65,794,839 3,005,718,562 122,020,931 1,258,981,425 1,806,117,952 3,970,287,358 175,426,534 300,171,216 407,208,202

14

13 Month Avg.

(Lns 1 - 13) 64,394,446 3,097,891,327 115,401,958 1,242,501,362 1,736,774,457 3,877,758,119 169,007,701 289,703,079 388,361,590

- - - - - - - - - 16

17 Adj Balance 64,394,446 3,097,891,327 115,401,958 1,242,501,362 1,736,774,457 3,877,758,119 169,007,701 289,703,079 388,361,590

18

19 Accumulated Depreciation and Amortization

20

21

22 Intangible Plant Steam Production

Hydraulic


Common

General

23 December 36,567,094 1,079,009,039 43,652,726 318,563,019 370,336,597 1,116,067,054 57,965,868 214,683,153 179,765,890

24 January 37,193,996 1,083,951,702 43,782,077 320,644,836 372,119,809 1,120,093,123 58,882,763 216,829,805 182,064,695

25 February 37,805,081 1,088,852,136 43,889,628 323,150,654 373,981,458 1,124,056,749 59,803,552 218,981,211 184,368,967

26 March 38,400,558 1,093,421,000 44,009,377 325,283,213 375,841,041 1,127,907,805 60,728,683 221,170,001 186,669,246

27 April 38,997,570 1,097,744,325 44,135,763 327,342,923 377,713,834 1,131,802,922 61,654,817 223,379,481 188,928,796

28 May 39,596,389 1,102,236,736 44,264,062 329,867,717 379,587,755 1,135,731,970 62,585,050 225,587,272 191,078,610

29 June 40,181,109 1,107,279,256 44,388,465 332,381,623 381,469,523 1,139,777,262 63,521,569 227,753,108 193,176,250

30 July 40,763,844 1,112,574,383 44,512,971 334,910,137 383,367,220 1,143,916,717 64,461,996 229,929,342 195,175,727

31 August 41,362,118 1,118,173,371 44,637,478 337,288,964 385,253,397 1,148,151,149 65,408,626 232,124,739 197,246,059

32 September 41,963,134 1,123,790,715 44,666,822 339,828,539 387,152,817 1,152,230,915 66,358,957 234,320,149 199,326,878

33 October 42,566,695 1,129,446,348 44,759,866 341,992,819 389,063,213 1,156,409,769 67,312,816 236,510,798 201,599,006

34 November 43,172,566 1,135,125,033 44,889,886 344,565,150 391,015,852 1,160,609,240 68,277,691 238,746,683 203,683,165

35 December 43,780,474 1,015,896,103 45,030,002 347,141,412 393,015,053 1,165,071,056 69,257,743 240,991,837 206,097,307

36

13 Month Avg.

(Lns 23 - 35) 40,180,817 1,099,038,473 44,355,317 332,535,462 381,532,121 1,140,140,441 63,555,395 227,769,814 193,013,892

37

38 - - - - - - - - - 39

40 Adj Balance 40,180,817 1,099,038,473 44,355,317 332,535,462 381,532,121 1,140,140,441 63,555,395 227,769,814 193,013,892

41

42 Depreciation Expense

43


Hydraulic


Common

General

45 Total 7,213,381 95,698,607 1,569,648 30,439,595 28,401,496 85,405,473 11,339,875 26,308,683 27,348,023

46

Less ARO (13

Month Avg) (1)15

Less ARO (13

Month Avg) (1)

of 51





47 Plant Adjustments

48

49 Gross Plant

50

51 Distribution Plant General Plant

Common

General

52 FERC 302 Smart Grid City Total Smart Grid City Smart Grid City FERC 302 CRS OMS Total

Smart Grid

City

53 December 9,303,802 14,975,206 24,279,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

54 January 9,303,802 14,975,206 24,279,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

55 February 9,304,802 14,975,206 24,280,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

56 March 9,305,802 14,975,206 24,281,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

57 April 9,306,802 14,975,206 24,282,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

58 May 9,308,802 14,975,206 24,284,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

59 June 9,321,802 14,975,206 24,297,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

60 July 9,329,802 14,975,206 24,305,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

61 August 9,335,802 14,975,206 24,311,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

62 September 9,339,802 14,975,206 24,315,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

63 October 9,341,802 14,975,206 24,317,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

64 November 9,341,802 14,975,206 24,317,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735 65 December 9,351,802 14,975,206 24,327,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

66

13 Month Avg.

(Lns 53 - 65) 9,322,802 14,975,206 24,298,008 2,194,157 26,328,277 3,751,929 70,013,763 12,575,071 86,340,763 998,735

67

68 Accumulated Depreciation

69


Common

General


Smart Grid

City

72 December 2,127,934 8,774,398 10,902,332 597,955 5,561,304 1,628,906 59,858,950 7,986,641 69,474,497 371,595

73 January 2,157,326 9,023,985 11,181,311 611,384 5,707,645 1,640,061 60,470,762 8,116,856 70,227,679 383,092

74 February 2,186,722 9,273,572 11,460,294 624,813 5,853,986 1,651,216 61,082,575 8,247,071 70,980,862 394,589

75 March 2,216,122 9,523,159 11,739,281 638,242 6,000,328 1,662,371 61,694,387 8,377,285 71,734,044 406,087

76 April 2,245,526 9,772,745 12,018,272 651,670 6,146,669 1,673,526 62,306,200 8,507,500 72,487,226 417,584

77 May 2,274,937 10,022,332 12,297,269 665,099 6,293,010 1,684,594 62,918,013 8,637,715 73,240,322 429,082

78 June 2,304,401 10,271,919 12,576,320 678,528 6,439,352 1,695,663 63,529,825 8,767,930 73,993,418 440,579

79 July 2,333,898 10,521,506 12,855,404 691,956 6,585,693 1,706,723 64,141,638 8,898,144 74,746,506 452,077

80 August 2,363,421 10,771,092 13,134,513 705,385 6,732,034 1,717,784 64,753,450 9,028,359 75,499,593 463,574

81 September 2,392,960 11,020,679 13,413,640 718,814 6,878,376 1,728,844 65,365,263 9,158,574 76,252,681 475,072

82 October 2,422,508 11,270,266 13,692,774 732,243 7,024,717 1,739,904 65,977,076 9,288,788 77,005,768 486,569

83 November 2,452,055 11,519,853 13,971,908 745,671 7,171,058 1,750,842 66,588,888 9,419,003 77,758,733 498,066 84 December 2,481,645 11,769,440 14,251,084 759,100 7,317,400 1,761,758 67,200,701 9,549,218 78,511,677 509,564

85

13 Month Avg.

(Lns 72 - 84) 2,304,573 10,271,919 12,576,492 678,528 6,439,352 1,695,553 63,529,825 8,767,930 73,993,308 440,579

86


88


Common

General


Smart Grid

City

91 Dec 12 Month 353,711 2,995,041 3,348,752 161,145 1,756,096 132,852 7,341,751 1,562,576 9,037,179 137,969

92

93 ADIT


Common

General


Smart Grid

City

96 December (81,169) 2,296,342 2,215,173 383,102 6,320,162 (135,702) 3,646,123 1,185,554 4,695,976 189,379 97 December (202,203) 1,290,311 1,088,108 420,518 6,221,264 (143,333) 71,518 805,164 733,349 169,851

98 BOY/EOY Avg (141,686) 1,793,327 1,651,641 401,810 6,270,713 (139,518) 1,858,821 995,359 2,714,662 179,615

99

Electric Intangible Common Intangible

Common Intangible

Common Intangible

Common IntangibleElectric Intangible

Electric Intangible

Electric Intangible

of 51





100

101 Generator Step ups

102

103 Transmission GSU Distribution GSU General GSU Transmission GSU Distribution GSU General GSU Transmission GSU Distribution GSU General GSU

104 December 56,828,273 451,362 513,226 19,099,875 124,719 207,783 5,799,086 124,914 44,858

105 January 56,828,273 451,362 513,226 19,174,318 125,420 209,730

106 February 56,828,273 451,362 513,226 19,248,760 126,121 211,678

107 March 56,828,273 451,362 513,226 19,323,202 126,822 213,626

108 April 56,828,273 451,362 513,226 19,397,644 127,523 215,573

109 May 56,828,273 451,362 513,226 19,472,086 128,225 217,521

110 June 56,828,273 451,362 513,226 19,546,528 128,926 219,469

111 July 56,828,273 451,362 513,226 19,620,971 129,627 221,417

112 August 56,828,273 451,362 513,226 19,695,413 130,328 223,364

113 September 56,828,273 451,362 513,226 19,769,855 131,029 225,312

114 October 56,828,273 451,362 513,226 19,844,297 131,730 227,260

115 November 56,828,273 451,362 513,226 19,918,739 132,431 229,207 116 December 56,828,273 451,362 513,226 19,993,176 133,132 231,155 6,699,935 125,497 36,002

117

13 Month Avg.

(Lns 104 - 116) 56,828,273 451,362 513,226 19,546,528 128,926 219,469 6,249,510 125,205 40,430

118

119

120 Transmission GSU Distribution GSU General GSU121

122 Dec 12 Month 893,301 8,413 23,373

123

124

125 Unamortized Unamortized

126 Unamort. Balance Current Year Balance Unamort. Balance Current Year Balance Land Held

127 of Abandoned Amortization End of of Extraordinary Amortization End of For Future

128 Incentive Plant (2) Expense (2) Current Year Property Loss (2) Expense (2) Current Year Use (3)

129 December - -

130 January - -

131 February - -

132 March - -

133 April - -

134 May - -

135 June - -

136 July - -

137 August - -

138 September - -

139 October - -

140 November - - 141 December - -

142

13 Month Avg.

(Lns 129 - 141) - - - - - - -

143

144

145 Note 1. ARO is not included in the budgeted amounts

146 Note 2. Abandoned Plant and Extraordinary Property Loss will remain at zero and can not be changes without a Section 205 filing.

147 Note 3. Plant Held for Future Use recovered in the formula will be limited to Transmission related land and land rights recorded in Account 105, Plant Held for Future Use.

Depreciation Expense

Gross Plant Accum Depreciation & Amort ADIT

of 51


Transmission Formula Rate Template WP_B-Inputs Act.


Rate Base Data Inputs- Actual

Gross Plant

Intangible Plant Steam Production

Hydraulic


Common

General

1 December

2 January

3 February

4 March

5 April

6 May

7 June

8 July

9 August

10 September

11 October

12 November

13 December

14

13 Month Avg.

(Lns 1 - 13) - - - - - - - - -

- - - - - - - - -

16

17 Adj Balance - - - - - - - - -

18

19 Accumulated Depreciation and Amortization

20

21


Hydraulic


Common

General

23 December

24 January

25 February

26 March

27 April

28 May

29 June

30 July

31 August

32 September

33 October

34 November

35 December

36

13 Month Avg.

(Lns 23 - 35) - - - - - - - - -

37

38 - - - - - - - - -

39

40 Adj Balance - - - - - - - - -

41


43


Hydraulic


Common

General

45 Total

46

15

Less ARO (13

Month Avg) (1)

Less ARO (13

Month Avg) (1)

of 51





47

48 Plant Adjustments

49 Gross Plant

50


Common

General


Smart Grid

City

53 December - -

54 January - -

55 February - -

56 March - -

57 April - -

58 May - -

59 June - -

60 July - -

61 August - -

62 September - -

63 October - -

64 November - -

65 December - -

66

13 Month Avg.

(Lns 53 - 65) - - - - - - - - - -

67

68 Accumulated Depreciation

69


Common

General


Smart Grid

City

72 December - -

73 January - -

74 February - -

75 March - -

76 April - -

77 May - -

78 June - -

79 July - -

80 August - -

81 September - -

82 October - -

83 November - -

84 December - -

85

13 Month Avg.

(Lns 72 - 84) - - - - - - - - - -

86


88


Common

General


Smart Grid

City

91 Dec 12 Month - -

92

93 ADIT


Common

General


Smart Grid

City

96 December - -

97 December - -

98 BOY/EOY Avg - - - - - - - - - -

99

Electric Intangible

Common Intangible

Electric Intangible

Electric Intangible

Electric Intangible

Common Intangible

Common Intangible

Common Intangible

of 51





100

101 Generator Step ups

102

103 Transmission GSU Distribution GSU General GSU Transmission GSU Distribution GSU General GSU Transmission GSU Distribution GSU General GSU

104 December

105 January

106 February

107 March

108 April

109 May

110 June

111 July

112 August

113 September

114 October

115 November

116 December

117

13 Month Avg.

(Lns 104 - 116) - - - - - - - - -

118

119

120 Transmission GSU Distribution GSU General GSU

121

122 Dec 12 Month

123

124

125 Unamortized Unamortized

126 Unamort. Balance Current Year Balance Unamort. Balance Current Year Balance Land Held

127 of Abandoned Amortization End of of Extraordinary Amortization End of For Future

128 Incentive Plant (2) Expense (2) Current Year Property Loss (2) Expense (2) Current Year Use (3)

129 December - -

130 January - -

131 February - -

132 March - -

133 April - -

134 May - -

135 June - -

136 July - -

137 August - -

138 September - -

139 October - -

140 November - -

141 December - -

142

13 Month Avg.

(Lns 129 - 141) - - - - - - -

143

144

145 Note 1. ARO is not included in the budgeted amounts

146 Note 2. Abandoned Plant and Extraordinary Property Loss will remain at zero and can not be changes without a Section 205 filing.

147 Note 3. Plant Held for Future Use recovered in the formula will be limited to Transmission related land and land rights recorded in Account 105, Plant Held for Future Use.

ADIT

Depreciation Expense

Gross Plant Accum Depreciation & Amort

of 51


Transmission Formula Rate Template WP_C-1


Transmission O&M

Line No. TRANSMISSION EXPENSES Reference Non Labor Labor Total Reference Non Labor Labor Total

OPERATION

1 560 Supervision and Engineering Company Records 2,735,856 5,409,400 8,145,256 321.83.b -

2 561.1 Load Dispatching - Reliability Company Records - 45,579 45,579 321.85.b -

3 561.2 Load Dispatching - Monitor & Operate Transmission System Company Records 1,181,639 1,164,147 2,345,786 321.86.b -

4 561.3 Load Dispatching - Transmission Service & Scheduling Company Records - 820,415 820,415 321.87.b -

5 561.4 Scheduling, System Control & Dispatch Services Company Records - - - 321.88.b -

6 561.5 Reliability, Planning and Standards Development Company Records 63,108 520,573 583,681 321.89.b -

7 561.6 Transmission Service Studies (1) Company Records (3,361) 762,792 759,431 321.90.b -

8 561.7 Generation Interconnection Studies Company Records 513,878 159,615 673,493 321.91.b -

9 561.8 Reliability, Planning & Standards Development Services Company Records 65,000 53,205 118,205 321.92.b -

10 562 Station Expenses Company Records 510,325 586,466 1,096,791 321.93.b -

11 563 Overhead Line Expenses Company Records 1,114,945 1,228,853 2,343,798 321.94.b -

12 564 Underground Lines Expense Company Records - - - 321.95.b -

13 565 Transmission of Electricity by Others Company Records 35,547,515 - 35,547,515 321.96.b -

14 566 Miscellaneous Transmission Expenses Company Records 1,900,543 1,363,674 3,264,217 321.97.b -

15 567 Rents Company Records 2,042,104 22,767 2,064,871 321.98.b -

16 Total Operation 45,671,552 12,137,485 57,809,036 - - -

17

18 MAINTENANCE

19 568 Supervision and Engineering Company Records - 60,451 60,451 321.101.b -

20 569 Structures Company Records - - - 321.102.b -

21 569.1 Computer Hardware Company Records - - - 321.103.b -

22 569.2 Computer Software Company Records - - - 321.104.b -

23 569.3 Communication Equipment Company Records - - - 321.105.b -

24 569.4 Miscellaneous Regional Transmission Plant Company Records - - - 321.106.b -

25 570 Station Equipment Company Records 1,757,671 2,656,855 4,414,525 321.107.b -

26 571 Overhead Lines (2) Company Records 9,929,650 599,899 10,529,549 321.108.b -

27 572 Underground Lines Company Records - - - 321.109.b -

28 573 Miscellaneous Transmission Plant Company Records - - - 321.110.b -

29 Total Maintenance 11,687,321 3,317,205 15,004,526 - - -

30

31 TOTAL TRANSMISSION 57,358,872 15,454,690 72,813,563 - - -

32

33

34 565.25 System Integration Costs- Holy Cross TIEA (3) Company Records - - -

Company

Records -

Note 1. Amount reflects 2 year amortization of the pre-construction costs associated with the San Luis-Calumet transmission project ($2,625,528 X .5 / 2 = $656,382)

Note 2. Amount will include a 2 year amortization of the total amount deferred related to Mountain Pine Beetle. $5,926,097 will be amortized over 2 years beginning January 1, 2013.

Actual Amounts

Note 3. The Holy Cross system integration surplus/deficit payments are difficult to project, therefore, PSCo makes no effort to budget these costs or include them in the ATRR Est. However, these

payments will be included on actuals and in the ATRR Act. calculation.

Estimated Amounts

of 51




Administrative and General Expenses

Estimated

Line

No. FERC Account Description Reference Total Adjustment Adjusted Total

1 920 Administrative and general salaries Company Records 37,835,784$ -$ 37,835,784$

2 921 Office supplies and expenses Company Records 28,827,753 - 28,827,753

3 922 Administrative expenses transferred— Credit Company Records (34,392,363) - (34,392,363)

4 923 Outside services employed Company Records 10,090,207 - 10,090,207

5 924 Property insurance Company Records 5,983,194 - 5,983,194

6 925 Injuries and damages Company Records 9,319,088 - 9,319,088

7 926 Employee pensions and benefits (1) Company Records 68,932,796 - 68,932,796

8 927 Franchise requirements Company Records - - -

9 928 Regulatory commission expenses (2) Company Records 10,187,146 (10,187,146) -

10 929 Duplicate charges—Credit Company Records (2,296,112) - (2,296,112)

11 930.1 General Advertising Expenses (3) Company Records 2,121,722 (2,121,722) -

12 930.2 Miscellaneous general expenses (4) Company Records 8,314,346 (1,020,103) 7,294,243

13 931 Rents Company Records 20,487,475 - 20,487,475

14 935 Maintenance of general plant Company Records 342,794 - 342,794

15 Subtotal 165,753,830$ (13,328,972)$ 152,424,859$

Notes:

2. Regulatory Commission expenses (FERC Account 928) will be directly assigned to Transmission and are shown on WP_C-4.

3. General Advertising Expenses (FERC Account 930.1) will be excluded.

4. EPRI Fees and EEI Dues recorded in FERC Account 930.2 will be excluded.

EPRI Fees Company Records 569,987$

EEI Dues Company Records 450,116

Total Exclusion 1,020,103$

Actuals

Line

No. FERC Account Description Reference Total Adjustment Adjusted Total

1 920 Administrative and general salaries FF1, pg. 323, Line 181 -$ -$

2 921 Office supplies and expenses FF1, pg. 323, Line 182 - -

3 922 Administrative expenses transferred— Credit FF1, pg. 323, Line 183 - -

4 923 Outside services employed FF1, pg. 323, Line 184 - -

5 924 Property insurance FF1, pg. 323, Line 185 - -

6 925 Injuries and damages FF1, pg. 323, Line 186 - -

7 926 Employee pensions and benefits (1) FF1, pg. 323, Line 187 - -

8 927 Franchise requirements FF1, pg. 323, Line 188 - -

9 928 Regulatory commission expenses (2) FF1, pg. 323, Line 189 - -

10 929 Duplicate charges—Credit FF1, pg. 323, Line 190 - -

11 930.1 General Advertising Expenses (3) FF1, pg. 323, Line 191 - -

12 930.2 Miscellaneous general expenses (4) FF1, pg. 323, Line 192 - -

13 931 Rents FF1, pg. 323, Line 193 - -

14 935 Maintenance of general plant FF1, pg. 323, Line 196 - -

15 Subtotal -$ -$ -$

Notes:

2. Regulatory Commission expenses (FERC Account 928) will be directly assigned to Transmission and are shown on WP_C-4.

3. General Advertising Expenses (FERC Account 930.1) will be excluded.

4. EPRI Fees and EEI Dues recorded in FERC Account 930.2 will be excluded.

EPRI Fees FF1, pg. 353, Line 1

EEI Dues FF1, pg. 353, Line 4

Total Exclusion -$

1. Post-Employment Benefits Other than Pensions (FAS 106) shall remain as a stated, fixed amount and shall not be changed except as directed by

the Commission following a filing seeking such change pursuant to section 205 or 206 of the FPA. The adjustment is shown on WP_C-3 PBOP.

PSCo will file annually to seek FERC approval of the updated PBOP expense.

1. Post-Employment Benefits Other than Pensions (FAS 106) shall remain as a stated, fixed amount and shall not be changed except as directed by

the Commission following a filing seeking such change pursuant to section 205 or 206 of the FPA. The adjustment is shown on WP_C-3 PBOP.

PSCo will file annually to seek FERC approval of the updated PBOP expense.

of 51




Post-Employment Benefits Other than Pensions (FAS 106)

O&M

Line No. Description Total Expense O&M $ Electric $

1 Base Year 2013

2

3 PSCo Direct Expense 5,784,000 3,741,815 2,643,239

4 XES - Allocated to PSCo 2,423,000 715,908 554,042

56 Total 8,207,000 4,457,723 3,197,281

7

8

9 Estimated Amount Included in Account 926 - (2013)

10

11 PSCo Direct Expense 5,784,000 3,741,815 2,643,239

12 XES - Allocated to PSCo 2,423,000 715,908 554,042

1314 Total 8,207,000 4,457,723 3,197,281

15

16

17 Actual Amount Included in Account 926 - (2013)

18

19 PSCo Direct Expense

20 XES - Allocated to PSCo

2122 Total - - -

2324 Adjustment

25 Estimated Amount Less Base Year Amount (Line 14 minus 6) - - -

26 Actual Amount Less Base Year Amount (Line 22 minus 6) - - -

Notes:

Once established in the true-up for the first Formula Rate Year that rates are in effect,

the amount for Post-Employment Benefits Other than Pensions shall be the amount recovered

in the formula rate until a change is accepted and permitted by FERC pursuant to a

Section 205 filing (to be made annually to update the PBOP expense) or a Section 206 filing.

Source: Employee Benefit Accounting PBOP analysis and actuarial study.

of 51




Regulatory Commission Expense Detail (FERC Account 928)

Estimated


Transmission

Specific

Non-

Transmission

Related Total

1 Western Electricity Coordinating Council Fees Company Records 2,054,048 2,054,048

2 Non-Transmission Related Company Records 7,402,146 7,402,146

3 FERC Annual Charge Company Records 513,952

4 Rate Case Expenses Amortization Company Records 217,000 217,000 5 -

6 Total 2,271,048 7,916,098 10,187,146

7

Actual


Transmission

Specific

Non-

Transmission

Related Total

1 -

2 -

3 - 4 -

5 Total - - -

6

of 51


Transmission Formula Rate Template WP_D-1


Taxes Other Than Income Tax

FERC Form 1

Line No. Description Reference Estimated Reference Actual

1 FUTA 263.4.i

2 FICA 263.5.i

3 Unemployment SESA 263.13.i4 Occupational Denver 263.22.i

5 Total taxes related to wages & salaries (1) Company Records 13,133,045$ -

6

7 Real and personal property taxes 263.20.i8 Use tax 263.12.i

9 Total taxes related to property (1) Company Records 96,882,658$ -

10

11 Miscellaneous Company Records -$

12

13 Total TOTI

Line 5 plus Line 9

plus Line 11 110,015,703$ 114.14.g -$

Note 1. The PSCo budget estimates these taxes only in total. Details as to actual taxes will be available for actuals in the

Annual True-up.

of 51


Transmission Formula Rate Template WP_E-1


Revenue Credits

Estimated

Line No. FERC Description Total Adjustments Adjusted Total

1 454- Rent From Electric Property

2 45400 Rental Income on Transmission Facilities 2,184,020$ -$ 2,184,020$ 3 45400 Rental Income on Other Facilities 3,393,640 (3,393,640) -

4 Total 454 5,577,660$ (3,393,640)$ 2,184,020$

5

6 421.1 Gain on disposition of property

7421.1

Amortization of the Gain on the Sale of TSB (Allocated to

Transmission) Ref. WP_B-6 Line 15 2,435,759$ -$ 2,435,759$ 8 421.1 Gain on disposition of property (Other Related) - - -

9 Total 421.1 2,435,759$ -$ 2,435,759$

Actual

Line No. FERC Description Total Adjustments Adjusted Total

1 454- Rent From Electric Property

2 45400 Rental Income on Transmission Facilities -$ -$ 3 45400 Rental Income on Other Facilities - -

4 Total 454- FERC Form 1 pg. 300 Ln 19 -$ -$ -$

5

6 421.1 Gain on disposition of property

7421.1

Amortization of the Gain on the Sale of TSB (Allocated to

Transmission) Ref. WP_B-6 Line 15 -$ -$ -$ 8 421.1 Gain on disposition of property (Other Related) - -

9 Total 421.1- FERC Form 1 pg. 117 Ln 40 -$ -$ -$

of 51

Public Service Company of Colorado Table 22Transmission Formula Rate Template WP_F-1Account 456.1- Revenues from Transmission of Electricity of Others

Scheduling, Reactive Network & Estimate System Supply & Regulation Network & Interco. Supplemental FERC

Point-to-Point Network Control & Voltage and Energy Spinning Spinning AssessTransmission Transmission Dispatch Control Frequency Imbalance Reserve Reserve Pass Total of

Line Facilities & Schedules 7 & 8 Schedule 9 Schedule 1 Schedule 2 Schedule 3 Schedule 4 Schedule 5 Schedule 6 Through LineNo. Type Description Meter Charge FERC 456.05 FERC 456.07 FERC 456.12 FERC 456.14 FERC 456.16 FERC 456.19 FERC 456.22 FERC 456.24 FERC 456.26 Items

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

1 Credit OATT Non-Firm PTP 1,898,057 25,079 256,260 38,824 2,218,2202 Divisor PSCoM Firm PTP 5,569,861 106,032 629,424 6,305,3173 Divisor Black Hills CE/BHP 1,503,575 1,503,57545 Divisor Public Service Company of Colorado 6,221,653 6,221,6536 Ancillary Public Service Company of Colorado 118,440 703,080 821,5207 08 Divisor MEAN - Network 887,913 887,9139 Ancillary MEAN - Network 16,903 100,339 49,441 166,68310 Divisor Tri-State - Network 2,563,138 2,563,13811 Ancillary Tri-State - Network 48,794 289,648 142,722 481,16412 Divisor IREA - Network 10,735,855 10,735,85513 Ancillary IREA - Network 204,376 1,213,209 597,799 1,394,864 358,266 3,768,51414 Divisor PSCoM - Network 3,667,287 3,667,28715 Ancillary PSCoM - Network 69,813 414,423 204,204 476,475 122,381 1,287,2961617 Divisor WAPA - GFA Firm Contract 4,047,960 4,047,96018 Divisor PACIFICORP GFA Firm Contract 964,474 964,47419 Credit Tri-State, Midway - GFA Firm Contract 224,400 224,40020 Divisor Tri-State - (0007) GFA Firm Contract 2,393,588 2,393,58821 Ancillary Tri-State - (0007) GFA Firm Contract 45,566 270,488 133,281 449,33522 02324 Ancillary PRPA - BASOT 282,752 827,050 1,929,782 495,658 3,535,24225 Ancillary Tri-State (376) BASOT 28,341 168,237 82,897 279,47526 Ancillary ARPA - BASOT 27,213 79,598 185,729 292,54027 Ancillary Black Hills CE 166,098 485,837 651,9352829 Ancillary 513,952 513,9523031323334 Total 0.00 8,971,493 31,706,269 1,139,407 4,045,109 2,641,652 0 3,986,850 976,306 513,952 53,981,0363536 Summarized by Type:

37 Credit 0.00 1,898,057 224,400 25,079 256,260 38,824 0 0 0 0 2,442,620

38 Divisor 0.00 7,073,436 31,481,869 106,032 629,424 0 0 0 0 0 39,290,76039 Ancillary 0.00 0 0 1,008,296 3,159,424 2,602,828 0 3,986,850 976,306 513,952 12,247,65640 Other 0.00 0 0 0 0 0 0 0 0 0 041 Total 0.00 8,971,493 31,706,269 1,139,407 4,045,109 2,641,652 0 3,986,850 976,306 513,952 53,981,0364243 Description of Revenue Types:44 Ancillary Ancillary services includes regulation & frequency, control & dispatch, voltage control, reactive, spinning reserve, and scheduling.45 Divisor Load associated with these revenues are included in the formula divisor.46 Credit Revenue credit because the load is not included in divisor.

of 51

Public Service Company of Colorado Table 22Transmission Formula Rate Template WP_F-1Account 456.1- Revenues from Transmission of Electricity of Others

Scheduling, Reactive Network & Actuals System Supply & Regulation Network & Interco. Supplemental FERC

Point to Point Network Control & Voltage and Energy Spinning Spinning AssessTransmission Transmission Dispatch Control Frequency Imbalance Reserve Reserve Pass Total of

Line Facilities & Schedules 7 & 8 Schedule 9 Schedule 1 Schedule 2 Schedule 3 Schedule 4 Schedule 5 Schedule 6 Through LineNo. Type Description Meter Charge FERC 456.05 FERC 456.07 FERC 456.12 FERC 456.14 FERC 456.16 FERC 456.19 FERC 456.22 FERC 456.24 FERC 456.26 Items

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

1 Credit OATT Non-Firm PTP 0.002 Divisor PSCoPM Firm PTP 0.0034 Divisor Public Service Company of Colorado 0.005 Ancillary Public Service Company of Colorado 0.006 0.007 Divisor MEAN - Network 0.008 Ancillary MEAN - Network 0.009 Divisor Tri-State - Network 0.0010 Ancillary Tri-State - Network 0.0011 Divisor IREA - Network 0.0012 Ancillary IREA - Network 0.0013 Divisor PSCoM - Network 0.0014 Ancillary PSCoM - Network 0.001516 Divisor WAPA - GFA Firm Contract 0.0017 Divisor PACIFICORP GFA Firm Contract 0.0018 Divisor Tri-State, Midway - GFA Firm Contract 0.0019 Divisor Tri-State, Weld - GFA Firm Contract 0.0020 Divisor Tri-State - (0007) GFA Firm Contract 0.0021 Ancillary Tri-State - (0007) GFA Firm Contract 0.002223 Ancillary PRPA - BASOT 0.0024 Ancillary Tri-State (376) BASOT 0.0025 Ancillary ARPA - BASOT 0.0026 Ancillary Black Hills CE 0.002728 Ancillary 0.002930313233 Total 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.003435 Summarized by Type:

36 Credit 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

37 Divisor 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0038 Ancillary 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0039 Other 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0040 Total 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.004142 Description of Revenue Types:43 Ancillary Ancillary services includes regulation & frequency, control & dispatch, voltage control, reactive, spinning reserve, and scheduling.44 Divisor Load associated with these revenues are included in the formula divisor.45 Credit Revenue credit because the load is not included in divisor.

of 51


Transmission Formula Rate Template WP_G-1


Capital Structure Details

Estimated

Form 1

Line No. Description Reference December January February March April May June July August September October November December 13 Month Avg.

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

1 Long Term Debt:

2 Acct 221 Bonds 112.18.c,d 3,454,500,000 3,454,500,000 3,454,500,000 3,204,500,000 3,204,500,000 3,204,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,531,423,077 3 Acct 224 Other Long Term Debt 112.21.c,d - - - - - - - - - - - - - -

4 Total Long Term Debt 3,454,500,000 3,454,500,000 3,454,500,000 3,204,500,000 3,204,500,000 3,204,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,704,500,000 3,531,423,077

5

6 Preferred Stock (1) 112.3.c,d 0 0 0 0 0 0 0 0 0 0 0 0 0 -

7

8 Common Equity- Per Books 112.16.c,d 4,508,462,016 4,548,267,692 4,581,493,924 4,549,044,900 4,565,095,756 4,583,232,125 4,614,698,921 4,670,705,579 4,727,172,863 4,707,385,882 4,730,812,488 4,765,109,494 4,789,968,620 4,641,650,020

9 Less Acct 204 Preferred Stock 112.3.c,d 0 0 0 0 0 0 0 0 0 0 0 0 0 -

10 Less Acct 219 Accum Other Compre. Income 112.15.c,d 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554 28,418,554

11Less Acct 216.1 Unappropriated Undistributed

Subsidiary Earnings 112.12.c,d 5,454,290 5,374,290 5,235,290 5,076,290 4,905,290 4,766,290 4,627,290 4,488,290 4,349,290 4,210,290 4,071,290 3,931,290 3,792,290 4,637,059

12 Adjusted Common Equity 4,542,334,860 4,582,060,536 4,615,147,768 4,582,539,744 4,598,419,600 4,616,416,969 4,647,744,765 4,703,612,423 4,759,940,707 4,740,014,726 4,763,302,332 4,797,459,338 4,822,179,464 4,674,705,633

13

14 Total (Line 4 plus Line 12) 7,996,834,860 8,036,560,536 8,069,647,768 7,787,039,744 7,802,919,600 7,820,916,969 8,352,244,765 8,408,112,423 8,464,440,707 8,444,514,726 8,467,802,332 8,501,959,338 8,526,679,464 8,206,128,710

15

16 Cost of Debt

17 Interest on Long Term Debt 117.62.c 160,703,840

18Interest on Debt to Assoc. Companies (LTD portion

only) (2) 117.67.c 0

19 Amortization of Debt Discount and Expense 117.63.c 3,622,844

20 Amortization of Loss on Reacquired Debt 117.64.c 1,963,240

21 Less: Amort of Premium on Debt 117.65.c 0

22 Less: Amort of Gain on Reacquired Debt 117.66.c 0

23 Total Interest Expense 166,289,92324

25 Average Cost of Debt (Line 23 / Line 4) 4.71%

26

27 Cost of Preferred Stock

28 Preferred Stock Dividends 118.29.c

29

30 Average Cost of Preferred Stock (Line 28 / Line 6) 0.00%

Note 2. Interest on Debt to Associated Companies (FERC 430) will be populated with interest related to Long-Term Debt only.

Actual

Form 1

Line No. Description Reference December January February March April May June July August September October November December 13 Month Avg.

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

1 Long Term Debt:

2 Acct 221 Bonds 112.18.c,d - 3 Acct 224 Other Long Term Debt 112.21.c,d -

4 Total Long Term Debt - - - - - - - - - - - - - -

5

6 Preferred Stock (1) 112.3.c,d -

7

8 Common Equity- Per Books 112.16.c,d -

9 Less Acct 204 Preferred Stock 112.3.c,d -

10 Less Acct 219 Accum Other Compre. Income 112.15.c,d -

11Less Acct 216.1 Unappropriated Undistributed

Subsidiary Earnings 112.12.c,d -

12 Adjusted Common Equity - - - - - - - - - - - - - -

13

14 Total (Line 4 plus Line 12) - - - - - - - - - - - - - -

15

16 Cost of Debt

17 Interest on Long Term Debt 117.62.c

18Interest on Debt to Assoc. Companies (LTD portion

only) (2) 117.67.c

19 Amortization of Debt Discount and Expense 117.63.c

20 Amortization of Loss on Reacquired Debt 117.64.c

21 Less: Amort of Premium on Debt 117.65.c

22 Less: Amort of Gain on Reacquired Debt 117.66.c

23 Total Interest Expense - 24


26

27 Cost of Preferred Stock

28 Preferred Stock Dividends 118.29.c

29

30 Average Cost of Preferred Stock (Line 28 / Line 6) 0.00%

Note 2. Interest on Debt to Associated Companies (FERC 430) will be populated with interest related to Long-Term Debt only.

Note 1. If and when the Company issues preferred stock, footnote will indicate the authorizing regulatory agency, the docket/case number,

Note 1. If and when the Company issues preferred stock, footnote will indicate the authorizing regulatory agency, the docket/case number,

of 51


Transmission Formula Rate Template WP_H-1


Depreciation and Amortization Rates

Utility Plant, Regulatory Assets, & Regulatory Liabilities Depreciation/

Amortization

Rate

FERC Name (%)

Regulatory Asset Amortization

24 Months

24 Months

Regulatory Liability Amortization

24 Months

Electric Plant Acquisition Adjustment- Calpine Acquisition

114 Transmission Serving Transmission

Rocky Mountain Energy Center 1.82

Electric Transmission

350.2 Land Rights 1.03

352 Structures & Improvements 1.44

353 Station Equipment 1.78

354 Towers & Fixtures 1.18

355 Poles & Fixtures 1.64

356 OH Conductors & Devices 1.79

357 UG Conduit 1.94

358 UG Conductors & Devices 1.88

359 Roads & Trails 0.97

Electric General

302 Franchises and Consents N/A1

303 Electric General Software 5 Yr 20.00


389 General Land Rights N/A2

390 Structures and Improvements 4.88

390.1 General Buildings 2.98

390.2 Partitions 7.69

391 Office, Furniture and Equipment 4.75

391.1 Leased Partitions 5.00

391.2 Computers 20.00

392 Transportation Equipment 9.00

393 Stores Equipment 3.17

San Luis- Calumet Project: The total O&M associated with the project prior to

decision not to proceed, subject to CPUC approval, was $2,625,528. 50% of

this amount will be recovered over a 2 year period beginning with the effective

date of the Formula Rate. The other 50% will be absorbed by the Company.

Mountain Pine Beetle: Amounts deferred from 2010 through 2012 will be

amortized over a 2 year period beginning January 1, 2013. The total amount to

be amortized is $5,926,097.

Technical Services Building- The gain on the sale of TSB will be amortized over

a 24 month period beginning with the effective date of the Formula Rate.

of 51


Transmission Formula Rate Template WP_H-1


Depreciation and Amortization Rates

Utility Plant, Regulatory Assets, & Regulatory Liabilities Depreciation/

Amortization

Rate

FERC Name (%)

394 Tools Shop Equipment 3.80

395 Laboratory Equipment 9.50

396 Power Operated Equipment 9.00

397 Communications Equipment 6.67

398 Miscellaneous Equipment 5.00

Common General

302 Franchises and Consents – Non-Unitized 3.33

302 Franchises and Consents N/A3



389 General Land Rights N/A4

390 Structures and Improvements 2.73

390 Structures and Improvements-Owned Building 1.64

390 Structures and Improvements-TSB 6.06

390 Structures and Improvements- Non-Unitized 6.06

390 1800 Larimer Leasehold Improvements 6.67

390.2 Partitions 3.80

391 Office, Furniture and Equipment 4.75

391 Leased Partitions 5.00

391 Computers 3 Year 33.35

391 Computers 5 Year 20.00

392 Transportation Equipment 9.00

393 Stores Equipment 3.17

394 Tools Shop Equipment 3.80

395 Laboratory Equipment 9.50

396 Power Operated Equipment 9.00

397 Communications Equipment 6.67

398 Miscellaneous Equipment 5.00

Notes:

1 Electric General Franchises are amortized over the life of the Franchise Agreement.

2 No Electric General Rights at December 31, 2010.

3 Common General Franchises are amortized over the life of the Franchise Agreement.4 No Common General Land Rights at December 31, 2010.

The Depreciation Rates were approved in Docket ER08-224-000

of 51


Transmission Formula Rate Template WP_I-1


Transmission System Peak Demand Summary

Delete Delete Add Add Add

Generation TIE Agmt Comanche 3 3rd Party Transmission

Generation Step-up Loss Sales Load IREA Transmission Reserved Transmission

Line System Peak Peak at Peak At Peak at Peak Network Load Capacity Peak

No. Date & Time kW kW kW kW kW kW kW

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

1 Jan-13 4,912,441 (5,980) (149,122) 190,000 311,498 522,648 5,781,485

2 Feb-13 4,904,975 (7,130) (148,800) 190,000 305,031 522,648 5,766,724

3 Mar-13 4,561,043 (5,940) (132,058) 190,000 300,630 522,648 5,436,323

4 Apr-13 4,310,531 (4,580) (85,605) 190,000 296,137 522,648 5,229,131

5 May-13 4,861,810 (4,580) (45,348) 190,000 302,057 522,648 5,826,587

6 Jun-13 5,770,254 (4,580) (65,025) 190,000 343,425 522,648 6,756,722

7 Jul-13 6,457,345 (4,580) (70,166) 190,000 338,156 522,648 7,433,403

8 Aug-13 6,039,876 (8,480) (68,451) 190,000 337,032 522,648 7,012,625

9 Sep-13 5,280,465 (6,790) (61,753) 190,000 326,575 522,648 6,251,145

10 Oct-13 4,589,553 (6,490) (53,005) 190,000 301,187 522,648 5,543,893

11 Nov-13 4,686,425 (5,610) (140,666) 190,000 299,486 522,648 5,552,283

12 Dec-13 5,139,813 (6,800) (189,426) 190,000 317,389 522,648 5,973,624

13 12 Month Total 61,514,531 (71,540) (1,209,425) 2,280,000 3,778,603 6,271,776 72,563,945 14

15 12 Month Average 5,126,211 (5,962) (100,785) 190,000 314,884 522,648 6,046,996

Delete

TIE Agmt

Transmission Sales Load Delete Transmission

Line System Peak Peak At Peak Company Use Peak

No. Date & Time kW (1) kW kW kW

(a) (b) (c) (d)

1 -

2 -

3 -

4 -

5 -

6 -

7 -

8 -

9 -

10 -

11 -

12 -

13 12 Month Total - - - - 14

15 12 Month Average - - - -

Footnote 1. Amount in column (a) includes the Lamar DC tie

Estimated System Peak Demand Summary

Actual System Peak Demand Summary

of 51


Transmission Formula Rate Template Schedule 1

Ancillary Services, Schedule No. 1 -

Scheduling System Control and Dispatch Service

Line No. Description Reference Amount

1 A. Schedule 1 - Projected ARR for Billing Period 01/01/2013 to 12/31/2013

2 Total Load Dispatch and Scheduling (Account 561) WP_C-1 Lines 2 through 9 $5,346,588

3 Less: Scheduling, System Control & Dispatch Services (Account 561.4) WP_C-1 Line 5 $0

4 Less: Reliability, Planning and Standards Development (Account 561.5) WP_C-1 Line 6 ($583,681)

5 Less: Transmission Service Studies (Account 561.6) WP_C-1 Line 7 ($759,431)

6 Less: Generation Interconnection Studies (Account 561.7) WP_C-1 Line 8 ($673,493)

7 Less: Reliability, Planning & Standards Development Services (Account 561.8) WP_C-1 Line 9 ($118,205)

8 Total 561 Costs for Projected Schedule 1 ARR Sum Lines 2 through 6 $3,211,779

9

10 Less: Schedule 1 Point to Point Projected Revenues WP_F-1 Line 37 $25,079

11

12 Projected Schedule 1 ARR Without True-up Adjustments (Ln 8 - Ln 10) $3,186,700

13

14 Prior Year True-up Adjustment Input from Prior Year True-up

15 Interest On Prior Year True-up Adjustment Input from Prior Year

16

17 Projected Schedule 1 ARR ( Ln 12 + Ln 14 + Ln 15) $3,186,700

18

19 B. Schedule 1 Rate Calculations

20 Projected Average 12-Mo. Demand WP_I-1 Line 15 6,046,996 kW

21

22 Monthly Point to Point Rate in $/kW - Month ((Line 17 /Line 20) /12) $0.0440 kW

23 Weekly Point to Point Rate in $/kW - Weekly ((Line 17 /Line 20) /52) $0.0100 kW

24 Daily Point to Point Rate in $/kW - Day ((Line 17 /Line 20) /365) $0.0010 kW

25 Hourly Point to Point Rate in $/mW - Hourly ((Line 17 /Line 20) /8760 * 1000) $0.0600 mW

26

27

28

29 C. Schedule 1 - Actual ARR for the Billing Period 01/01/2013 to 12/31/2013

30 Total Load Dispatch and Scheduling (Account 561) WP_C-1 Lines 2 through 9 $0

31 Less: Scheduling, System Control & Dispatch Services (Account 561.4) WP_C-1 Line 5 $0

32 Less: Reliability, Planning and Standards Development (Account 561.5) WP_C-1 Line 6 $0

33 Less: Transmission Service Studies (Account 561.6) WP_C-1 Line 7 $0

34 Less: Generation Interconnection Studies (Account 561.7) WP_C-1 Line 8 $0

35 Less: Reliability, Planning & Standards Development Services (Account 561.8) WP_C-1 Line 9 $0

36 Total 561 Costs for Actual Schedule 1 ARR Sum Lines 30 through 35 $0

37

38 Less: Schedule 1 Point to Point Actual Revenues Billed WP_F-1 Line 36 $0

39

40 Actual Schedule 1 ARR (Ln 36 - Ln 38) $0

41

42 True Up from Billing Period to be Included in Projected Schedule 1 ARR:

43 Revenue Requirement True-Up:

44 Actual Schedule 1 ARR calculated above (Ln 40) $0

45 Projected Schedule 1 ARR calculated above (Ln 12) $3,186,700

46 ARR True-up Amount (Over recovery = credit; under recovery = debit) (Ln 44 - Ln 45) ($3,186,700)

47

48 Volume True-Up:

49 Actual Divisor Load for the Billing Period WP_I-1 Line 15 0 kW

50 Projected Divisor Load for the Billing Period (Ln 20) 6,046,996 kW

51 Volume Adjustment (Ln 50 - Ln 49) 6,046,996

52

53 Projected Zonal Rate per kw-yr for the Billing Period (Ln 45 / Ln 50) $0.5270

54 Actual Zonal Rate per kw-yr for the Billing Period (Ln 44 / Ln 49) $0.0000

55

56 Volume Revenue Adjustment (Over recovery = credit; under recovery = debit) (Ln 51 * Ln 53) $3,186,700

57

58 Net Schedule 1 True-up Adjustment (Over Recovery = credit; under recovery = debit) (Ln 46 + Ln 56) ($0)

59

60 Interest True-up Amount (Ln 95) $0

61

62 D. Interest Calculation:

63 FERC Monthly

64 Quarterly Interest

65 Months Interest Rates Rate

66 January - Yr 2013 0.00% 0.00%

67 February 0.00% 0.00%

68 March 0.00% 0.00%

69 April 0.00% 0.00%

70 May 0.00% 0.00%

71 June 0.00% 0.00%

72 July 0.00% 0.00%

73 August 0.00% 0.00%

74 September 0.00% 0.00%

75 October 0.00% 0.00%

76 November 0.00% 0.00%

77 December 0.00% 0.00%

78 January - Yr 2014 0.00% 0.00%

79 February 0.00% 0.00%

80 March 0.00% 0.00%

81 April 0.00% 0.00%

82 May 0.00% 0.00%

83 June 0.00% 0.00%

84 July 0.00% 0.00%

85 August 0.00% 0.00%

86 September 0.00% 0.00%

87 Average Monthly Interest Rate 0.00%

88

89 Over/Under Recovery Amount (Line 58) ($0)

90 Average Monthly Interest Rate (Line 87) 0.00%

91 Monthly Interest Recovery Amount (Line 89 * Line 90) $0

92

93 Number of Months for Interest Recovery Amount 24

94

95 Interest Recovery Amount (Line 93 * Line 91) $0

96

97 Note:




of 51




Reactive Supply and Voltage Control From Generation Source Services

Line No Amount Reference/Notes

1 Annual Cost of Reactive Power Equipment

2 Acct 314 Steam Turbogenerators 421,258,192 Most recent FF1, Pg 205, Ln 12

3 Acct 344 CT Generators 1,155,527,153 Most recent FF1, Pg 205, Ln 41

4 Subtotal of Production Accounts 314 & 344 $1,576,785,345 Line 2 + Line 3

5 Percent of Production Plant for Dual Use 20%

6 Dual use of Production Accounts 314 & 344 $315,357,069 Line 4 * Line 5

7 Generation Step Ups $63,885,604 Most recent FF1, Footnote, Page 204, Line 58

8 Acquisition Adjustment related to Generation Step Ups 10,104,476 WP_B-4 Col. (b), Line 2

9 Total Dual Use Production Plant $389,347,149 Line 6 + Line 7 + Line 8

10 Dual Use Plant Alloc. To Reactive Power $108,043,847 Line 33 * Line 9

11 Fixed Charge Rate (including O&M) for all Production Plant 0.17768 WP_FCR Line 21

12 Annual Cost of Reactive Power Equipment $19,197,231 Line 10 * Line 11

13 Revenue Requirement for Real Power losses related to reactive power equipment

14 Total Production Plant Investment $4,513,979,169 WP_FCR Line 50

15 Less: Dual Use Plant Alloc. To Reactive Power $108,043,847 Line 10

16 Net Production Plant $4,405,935,322 Line 14 - Line 15

17 Fixed Charge Rate (including O&M) for all Production Plant 0.17768 WP_FCR Line 21

18 Total Production Plant Revenue Requirement including O&M $782,846,588 Line 16 * Line 17

19 Real Power Losses 0.30%

20 Revenue Requirement for Real Power losses related to reactive power equipment $2,348,540 Line 18 * Line 19

21 Total Revenue Requirement for Reactive Power $21,545,770 Line 12 + Line 20

22 Average of 12 Month Coincident Peaks 6,014,086 Prior Year's True-up Formula Template

23 Rates

24 Annual Reactive Power Charge $3.58255 $ per kW - Year (Line 21 / Line 22)

25 Monthly Point-to-Point Delivery $0.299 $ per kW - Month (Line 24 / 12)

26 Weekly Point-to-Point Delivery $0.069 $ per kW - Week (Line 24 / 52)

27 Daily Point-to-Point Delivery $0.0115 $ per kW - day (Line 26 / 6)

28 Hourly Point-to-Point Delivery $0.7190 $ per MWh ((Line 25 / 16) X 1000)

29 Network Integration Delivery $0.299 $ per kW - Month (Line 25)

30 PSCO Total Rated Capacity = 6,273,000 kVA

31 PSCO Total Generator Net Max. = 5,332,050 kW

32 PSCO Total VAR Rating = 3,304,508 kVAR

33 % of Plant dedicated to VAR Production is = (kVAR^2 / kVA^2) X 100 = 27.7500%

Description

of 51




Regulation and Frequency Response Service

Unity =

Total dual use Total Cost for Plants Selected

Total dual use for VAR Production Reg. and Freq. for Regulation Prod. FCR Annual Cost of Gen. Gen. Max

for VAR Production Cost of plant / per Plant Response Serv.. and Frequency with O&M Plnt.. to provide Svc. Name Plate

Line No Plant Total Cost (1) (2) Total Cost ( b x c ) ( a ) - ( d ) Resp. Service (3) (4) ( e ) * ( f ) * (g) (kW) (1)

( a ) ( b ) ( c ) = ( a ) / Ln 19 ( d ) ( e ) ( f ) ( g ) ( h ) ( i )

1 Arapahoe 115,239,708$ 389,347,149$ 0.02582210 10,053,761$ 105,185,948$ 1 0.17768 18,689,439$ 152,500

2 Cameo - 389,347,149 0.00000000 - - 0 0.17768 - 0

3 Cherokee 414,074,215 389,347,149 0.09278282 36,124,728 377,949,487 1 0.17768 67,154,065 676,254

4 Comanche 1,506,039,075 389,347,149 0.33746259 131,390,098 1,374,648,977 1 0.17768 244,247,630 1,349,700

5 Craig 89,940,495 389,347,149 0.02015323 7,846,603 82,093,892 0 0.17768 - 0

6 Hayden 243,058,186 389,347,149 0.05446276 21,204,920 221,853,266 1 0.17768 39,418,888 465,390

7 Pawnee 559,733,691 389,347,149 0.12542117 48,832,375 510,901,316 1 0.17768 90,776,946 552,300

8 Valmont 5 136,042,103 389,347,149 0.03048335 11,868,607 124,173,497 1 0.17768 22,063,147 191,675

9 Zuni 30,417,063 389,347,149 0.00681564 2,653,650 27,763,413 1 0.17768 4,933,003 75,000

10 Alamosa 9,195,413 389,347,149 0.00206044 802,228 8,393,185 1 0.17768 1,491,301 53,300

11 Fort Lupton 12,483,763 389,347,149 0.00279727 1,089,110 11,394,653 1 0.17768 2,024,602 100,800

12 Fruita 3,512,277 389,347,149 0.00078701 306,419 3,205,859 1 0.17768 569,617 26,600

13 Valmont 6 8,038,650 389,347,149 0.00180124 701,309 7,337,341 1 0.17768 1,303,699 59,300

14 Fort St. Vrain 1-4 398,841,406 389,347,149 0.08936956 34,795,785 364,045,621 1 0.17768 64,683,626 867,900

15 Fort St. Vrain 5-6 166,728,416 389,347,149 0.03735932 14,545,747 152,182,669 1 0.17768 27,039,817 280,500

16 Blue Spruce 263,746,808 389,347,149 0.05909852 23,009,841 240,736,968 1 0.17768 42,774,144 397,800

17 Rocky Mountain 444,159,326 389,347,149 0.09952408 38,749,418 405,409,908 1 0.17768 72,033,232 685,100

18 Cabin Creek 61,582,066 389,347,149 0.01379887 5,372,552 56,209,513 1 0.17768 9,987,306 300,000

19 TOTAL: 4,462,832,662$ 1.00000000 389,347,149$ 4,073,485,513$ 709,190,463$ 6,234,119

20 Note:

(1) WP_Cost per Unit

21 (2) Schedule 2 Line 9 Average Generation Unit Cost to Provide Service $113.76 per kW year (Col. ( h) ln 19 / Col. ( i ) Ln 19)

(3) 1 = Yes; 2 = No

22 (4) WP_FCR Line 21 Monthly Point-to-Point Delivery $9.480 per kW month (Line 21 / 12)

23 Weekly Point-to-Point Delivery $2.188 per kW week (Line 21 / 52)

24 Daily Point-to-Point Delivery $0.365 per kW day (Line 23 / 6)

25 Hourly Point-to-Point Delivery $22.792 per MWh ((Line 24 / 16) X 1000)

26 Network Integration Delivery $9.480 per kW month (Line 22)

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Transmission Formula Rate Template Schedule 5Ancillary Services, Schedule No. 5 -

Operating Reserve - Spinning Reserve Service

Total dual use Total Cost for Unity =

Total dual use for VAR Production Reg. and Freq. Plants Selected Prod. FCR Annual Cost of Gen. Gen. Max

for VAR Production Cost of plant / per Plant Response Serv.. for Op Res with O&M Plnt.. To provide Svc. Name Plate

Line No. Plant Total Cost (1) (2) Total Cost ( b x c ) ( a ) - ( d ) Spinning Reserve (3) (See FCR Worksheet) ( e ) X ( f ) X (g) (kW) (1)

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

1 Arapahoe 115,239,708$ 389,347,149$ 0.02582210 10,053,761$ 105,185,948$ 1 0.17768 18,689,439$ 152,500

2 Cameo - 389,347,149 0.00000000 - - 0 0.17768 - 0

3 Cherokee 414,074,215 389,347,149 0.09278282 36,124,728 377,949,487 1 0.17768 67,154,065 676,254

4 Comanche 1,506,039,075 389,347,149 0.33746259 131,390,098 1,374,648,977 1 0.17768 244,247,630 1,349,700

5 Craig 89,940,495 389,347,149 0.02015323 7,846,603 82,093,892 0 0.17768 - 0

6 Hayden 243,058,186 389,347,149 0.05446276 21,204,920 221,853,266 1 0.17768 39,418,888 465,390

7 Pawnee 559,733,691 389,347,149 0.12542117 48,832,375 510,901,316 1 0.17768 90,776,946 552,300

8 Valmont 5 136,042,103 389,347,149 0.03048335 11,868,607 124,173,497 1 0.17768 22,063,147 191,675

9 Zuni 30,417,063 389,347,149 0.00681564 2,653,650 27,763,413 1 0.17768 4,933,003 75,000

10 Alamosa 9,195,413 389,347,149 0.00206044 802,228 8,393,185 1 0.17768 1,491,301 53,300

11 Fort Lupton 12,483,763 389,347,149 0.00279727 1,089,110 11,394,653 1 0.17768 2,024,602 100,800

12 Fruita 3,512,277 389,347,149 0.00078701 306,419 3,205,859 1 0.17768 569,617 26,600

13 Valmont 6 8,038,650 389,347,149 0.00180124 701,309 7,337,341 1 0.17768 1,303,699 59,300

14 Fort St. Vrain 1-4 398,841,406 389,347,149 0.08936956 34,795,785 364,045,621 1 0.17768 64,683,626 867,900

15 Fort St. Vrain 5-6 166,728,416 389,347,149 0.03735932 14,545,747 152,182,669 1 0.17768 27,039,817 280,500

16 Blue Spruce 263,746,808 389,347,149 0.05909852 23,009,841 240,736,968 1 0.17768 42,774,144 397,800

17 Rocky Mountain 444,159,326 389,347,149 0.09952408 38,749,418 405,409,908 1 0.17768 72,033,232 685,100

18 Cabin Creek 61,582,066 389,347,149 0.01379887 5,372,552 56,209,513 1 0.17768 9,987,306 300,000

19 TOTAL: 4,462,832,662$ 1.00000000 389,347,149$ 4,073,485,513$ 709,190,463$ 6,234,119

20 Note:



(3) 1 = Yes; 2 = No




25 Hourly Point-to-Point Delivery $22.792 per MW hour ((Line 24 / 16) X 1000)


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Transmission Formula Rate Template Schedule 6Ancillary Services, Schedule No. 6 -

Operating Reserve - Supplemental Reserve Service

Total dual use Total Cost for Unity = Annual Cost

Total dual use Cost of plant / for VAR Production Oper. Reserve Plants Selected of Selected Plant Gen. Max

for VAR Production Total Cost per Plant Supplemental Oper. Reserve Prod. FCR to Provide Service Name Plate

Line No. Plant Total Cost (1) (2) Col. c, Sched. 3 ( b x c ) ( a ) - ( d ) Spinning Serv. (2) with O&M ( e ) * ( f ) * (g) (kW)

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

1 Arapahoe 115,239,708$ 389,347,149$ 0.025822099 10,053,761$ 105,185,948$ 0 0.17768 -$ 0

2 Cameo - 389,347,149 0.000000000 - - 0 0.17768 - 0

3 Cherokee 414,074,215 389,347,149 0.092782823 36,124,728 377,949,487 0 0.17768 - 0

4 Comanche 1,506,039,075 389,347,149 0.337462591 131,390,098 1,374,648,977 0 0.17768 - 0

5 Craig 89,940,495 389,347,149 0.020153230 7,846,603 82,093,892 0 0.17768 - 0

6 Hayden 243,058,186 389,347,149 0.054462760 21,204,920 221,853,266 0 0.17768 - 0

7 Pawnee 559,733,691 389,347,149 0.125421169 48,832,375 510,901,316 0 0.17768 - 0

8 Valmont 5 136,042,103 389,347,149 0.030483353 11,868,607 124,173,497 0 0.17768 - 0

9 Zuni 30,417,063 389,347,149 0.006815641 2,653,650 27,763,413 0 0.17768 - 0

10 Alamosa 9,195,413 389,347,149 0.002060443 802,228 8,393,185 1 0.17768 1,491,301 53,300

11 Fort Lupton 12,483,763 389,347,149 0.002797273 1,089,110 11,394,653 1 0.17768 2,024,602 100,800

12 Fruita 3,512,277 389,347,149 0.000787006 306,419 3,205,859 1 0.17768 569,617 26,600

13 Valmont 6 8,038,650 389,347,149 0.001801244 701,309 7,337,341 1 0.17768 1,303,699 59,300

14 Fort St. Vrain 1-4 398,841,406 389,347,149 0.089369563 34,795,785 364,045,621 0 0.17768 - 0

15 Fort St. Vrain 5-6 166,728,416 389,347,149 0.037359325 14,545,747 152,182,669 0 0.17768 - 0

16 Blue Spruce 263,746,808 389,347,149 0.059098521 23,009,841 240,736,968 0 0.17768 - 0

17 Rocky Mountain 444,159,326 389,347,149 0.099524082 38,749,418 405,409,908 0 0.17768 - 0

18 Cabin Creek 61,582,066 389,347,149 0.013798874 5,372,552 56,209,513 1 0.17768 9,987,306 300,000

19 TOTAL: 4,462,832,662$ 1.000000000 389,347,149$ 4,073,485,513$ 15,376,525$ 540,000

20 Notes:



(3) 1 = Yes; 2 = No




25 Hourly Point-to-Point Delivery $5.708 per MW hour ((Line 24 / 16) X 1000)


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Transmission Formula Rate Template WP_FCR

Fixed Charge Rate Worksheet ("FCR")

12 Months Ended December 31, 2011

Line No. Production Reference

1 (1) O&M 0.04843 Line 56

2

3 (2) Other Taxes 0.01006 Line 69

4

5 (3) A&G 0.01810 Line 83

6

7 (4) Return 0.08200 Line 67

8

9 (5) Depreciation 0.00415 Line 147

10

11 (6) Composite Income Tax 0.02625 Line 151

12

13 (7) General & Intangible Plant 0.00249 Line 172

14

15 (8) Cash Working Capital 0.00000 Line 178

16

17 (9) ADIT Adjustment -0.01407 Line 199

18

19 (10) Materials & Supplies 0.00028 Line 212

20 `

21 FIXED CHARGE RATE 0.17768

22

23

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12 Months Ended December 31, 2011 24

25 (1) O&M Expense: Reference $ Amount

26

27 A. Total Power Production Expenses Pg 321, Ln 80b 1,675,251,633

28

29

30 B. Purchased Power Expenses (Acct. 555) Pg 321.76b 786,117,478

31

32

33 C. Energy Related O&M

34 Account 501 Pg 320, Ln 5b 355,477,657

35 Account 503 Pg 320, Ln 7b 0



38 Account 510 Pg 320, Ln 15b 2,154,373

39 Account 512 Pg 320, Ln 17b 37,546,588

40 Account 513 Pg 320, Ln 18b 15,813,068

41 Account 518 Pg 320, Ln 25b 0

42 Account 528 Pg 320, Ln 35b 0

43 Account 530 Pg 320, Ln 37b 0

44 Account 531 Pg 320, Ln 38b 0

45 Account 544 Pg 321, Ln 56b 198,984

46 Account 547 Pg 321, Ln 63b 255,720,113

47 Total C Sum Line 34 - Line 46 666,910,783

48

49 D. Total Production Plant Investment

50 Total Production Plant Pg 205, Ln 46g 4,513,979,169

51 Less: Production ARO Pg 205, -Ln 15g 461,053

52 Plus Generator Step Ups Schedule 2 Line 7 63,885,604

53 Plus Acquisition Adjustment related to Generation Step Ups Schedule 2 Line 8 10,104,476

54 Total D Sum Line 50 - Line 52 4,588,430,302

55

56 Production O&M FCR (A-B-C)/D = 0.04843

57

58 (2) OTHER TAXES EXPENSE

59

60 A. Other Taxes (Electric Only) Pg 115, Ln 14g 105,912,832

61

62 B. Total Electric Plant in Service

63 Electric Plant in Service (Less ARO) Pg 207, Ln 100g 9,844,527,463

64 Less ARO Pg 207,Ln 15, Ln 44, Ln 74, Ln 98 -8,028,559

65 Common Electric Plant in Service Pg 356 463,629,997

66 Plus Total Acquisition Adjustment WP_B-4 Line 15 225,557,123

67 Total Electric Plant in Service Sum Line 63 - Line 66 10,525,686,024

68

69 Other Taxes FCR A/B 0.01006

70

71 (3) A&G EXPENSE

72

73 A. Production Wages Expense Pg 354, Ln 20b 76,712,057

74

75 B. A&G Wages Expense Pg 323, Ln 181b 39,640,435

76

77 C. Total Wages Expense Pg 354, Ln 28b 187,778,465

78

79 D. Total A&G related O&M Pg 323, Ln 197b 160,364,608

80

81 E. Total Production Plant Investment Line 54 4,588,430,302

82

83 A&G Expense FCR (A/(C-B))*D/E 0.01810

84

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12 Months Ended December 31, 2011 85 (4) RATE OF RETURN WORKSHEET Reference $ Amount

86

87

88 A. Common Equity Calculation

89

90 Proprietary Capital Pg 112 Ln 16c 4,305,718,805

91

92 Less: Preferred Stock Issued Pg 112 Ln 3c 0

93

94 Less: Account No. 216.1 Pg 112 Ln 12c -5,319,014

95

96 Less: Accum other comprehensive Income Pg 112 Ln 15 -12,376,934

97

98 Common Equity = Line 90 - 92 - 94 - 96 4,323,414,753

99

100 B. Rate of Return Calculation

101

102 Long Term Debt p.112, sum of 18d thru 21c 3,303,250,000

103

104 Preferred Stock (Pg.112 Ln 3c) 0

105

106 Common Equity Line 98 4,323,414,753

107

108 Total Capital = Line 102 + 104 + 106 7,626,664,753

109

110 C. Cost of Debt

111 Interest on Long Term Debt Pg 117 Ln 62c 177,137,084

112 Interest on Debt to Assoc. Companies (LTD portion only) Pg 117 Ln 67c 0

113 Amortization of Debt Discount and Expense Pg 117 Ln 63c 3,432,682

114 Amortization of Loss on Reacquired Debt Pg 117 Ln 64c 1,911,983

115 Less: Amort of Premium on Debt Pg 117 Ln 65c 0

116 Less: Amort of Gain on Reacquired Debt Pg 117 Ln 66c 0

117 Total Interest Expense 182,481,749

118


120

121 D. Cost of Preferred Stock

122 Preferred Stock Dividends Pg 118 Ln 29c 0

123

124 Average Cost of Preferred Stock (Line 122 / Line 104) 0

125

126 CAPITAL STRUCTURE

127 Weighted Cost

128 Amount % % Of Capital %

129 Long Term Debt $3,303,250,000 43.31% 5.52% 2.39%

130 Preferred Stock $0 43.31% 0.00% 0.00%

131 Common Equity $4,323,414,753 56.69% 10.25% 5.81%

132 Total $7,626,664,753 100% ROR= 8.20%

133

134

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12 Months Ended December 31, 2011 135

136

137 (5) DEPRECIATION EXPENSE Reference $ Amount

138

139 Production Depreciation Expense Pg 336 Lns 2-6b 118,069,816

140

141 Total Production Plant Investment Line 54 4,588,430,302

142

143 SLDp = Line 139 / 141 0.02573

144

145 n = 1 / Line 143 38.862

146

147 SFDp = R/(1+R)^n-1 0.00415

148

149 (6) COMPOSITE INCOME TAX EXPENSE

150

151 Production CIT= 0.02625

152 Formula: (35/65+State Tx)/(1-State Tx)*(ROR+SFD-SLD)*(1-Wtd.LTD/ROR)

153 State Tax Rate 0.0463

154

155

156

157

158

159

160

161

162 (7) General & Intangible Plant

163

164 Production Wages Expense Line 73 76,712,057

165 Total Wage Expense Less A&G Wage expenses Line 77 - Line 75 148,138,030

166 Production W/S Allocator Line 164 / Line 165 51.78%

167 General & Intangible plant Pg 205 and 207, Lns5G + 96 G 202,751,618

168 General & Intangible plant allocated to Production Line 166 * Line 167 104,993,253

169 Revenue Requirement FCR Line 3 + 7 + 9 + 11 + 17 + 19 10.866%

170 General & Intangible Plant Revenue Requirement Line 168 * Line 169 11,408,794

171 Total Production Plant Investment Line 50 4,588,430,302

172 General & Intangible Plant FCR Line 170 / Line 171 0.00249

173

174

175

176 (8) Cash Working Capital

177

178 Cash Working Capital will be set at and remain $0 until such time as PSCo files and receives FERC approval.179

180

181 (9) ACCUMULATED DEFERRED INCOME TAX

182

183 Total Production plant Line 54 4,588,430,302

184 Total Electric Plant Line 67 10,525,686,024

185 Accumulated Deferred Income Tax

186 Account 190 Pg 234 Ln 2k + 3k 419,283,876

187 Account 281 Pg 273 Ln 4k -58,459,018

188 Account 282 Pg 275 Ln 2k -1,559,097,063

189 Account 283 Pg 277 Ln 9k -170,223,486

190 Total ADIT -1,368,495,691

191

192 A. Production share of ADIT (Line 183 / 184) * Line 190 (596,564,165)

193

194

195 B. Return and Taxes Line 7 + 11 10.825%

196

197 C. Production Plant (plus step ups) 4,588,430,302

198

199 (A x B) / C = (0.014074)

200

201 (10) Materials & Supplies

202

203

204

205 A. Total Non-Fuel M&S Pg 227 Ln 7 33,337,470

206 B. ROR Line 132 8.20%

207 C. Return on M&S Line 205 * 206 2,733,673

208 D. Total Prod Plnt Line 50 4,513,979,169

209

210 E. Total Plnt in Service Line 63 9,844,527,463

211 F. % of Prod Plant Line 208 / 210 0.4585

212 G. Prod M&S Factor (Line 207 * 211) / Line 208 0.00028

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Transmission Formula Rate Template WP_Cost per Unit

Cost Per Unit

Name Percent of Non VAR Total Cost

Line No Plant Total Cost (1) Plate kW (2) Name Plate Step Ups W/ Step Ups

(a) (b) (c) (d) (e) = (d) * Ln 22 (f) = (b) + (e)

1 Arapahoe 113,949,771 152500 0.02413 1,289,937$ $115,239,708

2 Cameo - 0 0.00000 -$ $0

3 Cherokee 408,355,296 676254 0.10698 5,718,919$ $414,074,215

4 Comanche 1,494,624,224 1349700 0.21353 11,414,851$ $1,506,039,075

5 Craig 89,205,450 86900 0.01375 735,045$ $89,940,495

6 Hayden 239,122,086 465390 0.07363 3,936,100$ $243,058,186

7 Pawnee 555,062,546 552300 0.08738 4,671,145$ $559,733,691

8 Valmont 5 134,421,262 191675 0.03032 1,620,841$ $136,042,103

9 Zuni 29,782,519 75000 0.01187 634,544$ $30,417,063

10 Alamosa 8,744,763 53300 0.00843 450,650$ $9,195,413

11 Fort Lupton 11,631,111 100800 0.01595 852,652$ $12,483,763

12 Fruita 3,287,220 26600 0.00421 225,057$ $3,512,277

13 Valmont 6 7,537,216 59300 0.00938 501,434$ $8,038,650

14 Fort St. Vrain 1-4 391,501,646 867900 0.13730 7,339,760$ $398,841,406

15 Fort St. Vrain 5-6 164,355,957 280500 0.04438 2,372,459$ $166,728,416

16 Blue Spruce 260,382,707 397800 0.06293 3,364,101$ $263,746,808

17 Rocky Mountain 438,365,566 685100 0.10838 5,793,760$ $444,159,326

18 Cabin Creek 59,044,957 300000 0.04746 2,537,109$ $61,582,066

19 Total $4,409,374,297 6,321,019 1.00001 53,458,365$ 4,462,832,662$

20 Non VAR Related Percent (1- Schedule 2 Line 26) 72.250%

21 GSU's (Schedule 2, Line 7 + Line 8) 73,990,080

22 Recoverable Non VAR GSU (Line 19 * Line 20) 53,457,830

(1) FERC Form 1 Pages 402-403, Line 17

(2) FERC Form 1 Pages 402-403, Line 5

public service company of colorado transmission formula ... pdfs/sec.2a(i...35 schedule 2- reactive...

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