Tab Schedule/Worksheet Designation Description Date to be Posted

Transcription

1 Westar Energy Inc. (Westar) Rate Formula Template Table of Contents Overview The formula is calculated in two steps. The first step is to fill out Tabs A1 thru A12, and the Actual Gross Rev. Req. tab with data from the previous year's Form 1 information. This information is used to update the formulas in the Actual Net Rev Req tab to calculate the Actual Revenue Requirement (Actual ATRR) for the previous year. The results of this calculation are presented to the customers for review no later than June 15 each year. The TU (Trueup) tab uses the Actual ATRR from the Actual Net Rev Req tab and compares it to the Projected ATRR customers were billed for the same period. Interest is added to the difference and the amount is added to the Projected Net Rev Req tab. The projected O&M and plant balances are calculated in Tabs P1 thru P5. These sheets feed into the Projected Gross Rev Req tab and ultimately into the Projected Net Rev Req tab. The BPF tab retrieves project specific data from A9, A11 and P4 to calculate the amount of revenue requirements associated with those projects which are contained in the total Projected Net Revenue Requirement amount. The EPP tab does the same process for Economic Portfolio projects by combining data from A11, A12 and P5. The total revenue requirements for these two groups of upgrades (lines 9 and 9a) are subtracted from the Westar Revenue Requirement (line 8) to obtain the Zonal ATRR (line 10). This calculation is shown on the Projected Net Rev Req tab. The Westar tariff rates are calculated based on the Westar Revenue Requirements and the specific pointtopoint charges are shown on the same tab. The SPP rates are set on the BPF Revenue Requirements, Economic Portfolio Revenue Requirements and the Zonal Revenue requirements. The specific charges are calculated in the SPP tariff. Cells highlighted in yellow are data input cells, however, some cells may reference the results from other worksheets in the formula. Such cell references may change from year to year requiring manual adjustment of the reference or the direct entry of the proper value. Cells highlighted in green signify that the data is pulled from other worksheets in the formula and that the reference is static. Tab Schedule/Worksheet Designation Description Date to be Posted Actual Net Rev Req Schedule "Actual Net Rev Req (page 1) Actual net revenue requirements for most recent calendar year June 15 Actual Gross Rev Req Schedule Actual Gross Rev Req (15 pages) Actual gross revenue requirements for most recent calendar year June 15 A1 (Rev. Credit) Worksheet A1 Actual revenue credits June 15 A2 (Divisor) Worksheet A2 Actual transmission load June 15 A3 (Retail Adder) Worksheet A3 Actual Retail Adder June 15 A4 (WEN O&M Exclusions) Worksheet A4 Actual O&M Expense Exclusions (WEN) June 15 A5 (WEN ADIT) Worksheet A5 Actual Accumulated Deferred Income Taxes (ADIT) (WEN) June 15 A6 (WES O&M Exclusions) Worksheet A6 Actual O&M Expense Exclusions (WES) June 15 A7 (WES ADIT) Worksheet A7 Actual Accumulated Deferred Income Taxes (ADIT) (WES) June 15 A8 (Depr CalcOpt) Worksheet A8 Actual Depreciation Rate Calculation June 15 A9 (Actual BPF Summary) Worksheet A9 Actual Base Plan Funded Projects June 15 A10 (Wages & Salaries) Worksheet A10 Actual Wages and Salaries June 15 A11 (Incentive Plant) Worksheet A11 Actual Incentive Return on Incentive Plant June 15 A12 (Act Econ Projects) Worksheet A12 Actual Economic Portfolio Funded Projects June 15 TU (Trueup) Worksheet TU Trueup Adjustment and Interest Calculation October 15 BPF (BPF Summary) BPF Summary Total Actual and Projected BPF projects October 15 EPP (Econ Proj Sum) EPP Summary Total Actual and Projected Economic Portfolio projects October 15 Projected Net Rev Req Projected Net Rev Req (1 page) Projected net revenue requirements for next calendar year October 15 Projected Gross Rev Req Projected Gross Rev Req (5 pages) Projected gross revenue requirements for next calendar year October 15 P1 (Trans Plant) Worksheet P1 Projected transmission plant for next calendar year October 15 P2 (Exp. & Rev. Credits) Worksheet P2 Projected expenses and revenue credits for next calendar year October 15 P3 (Trans. Network Load) Worksheet P3 Projected transmission load for next calendar year October 15 P4 (BPF Projects) Worksheet P4 Projected Base Plan Funded Projects October 15 P5 (Econ. Projects) Worksheet P5 Projected Economic Portfolio Funded Projects October 15

2 Rate Formula Template Utilizing FERC Form 1 Data Actual Net Revenue Requirements For the 12 months ended December 31, 2015 Actual Net Rev Req Page 1 of 1 WESTAR ENERGY, INC. (WESTAR) (1) (2) (3) (4) (5) (6) Line Allocated No. Reference Amount REVENUE REQUIREMENTS 1 GROSS REVENUE REQUIREMENT [Actual Gross Rev, p. 3, ln. 32, col. 7] 244,119,207 REVENUE CREDITS Total Allocator 2 Account No. 454 (Wksht. A1, p. 2, Sec. II, ln. 5, WEN + WES) 2,868, ,868,773 3 Account No. 456 (Wksht. A1, p. 1, Sec. I, ln. 22, Total) 15,988, ,988,197 4 Revenues from Grandfathered Interzonal Transactions (Wksht. A1, p. 2, Sec. III) Revenues from service provided by the ISO at a discount (Wksht. A1, p. 2, Sec. III) TOTAL REVENUE CREDITS (sum lines 25) 18,856,970 7 ACTUAL NET REVENUE REQUIREMENT (line 1 minus line 6) 225,262,237 8 SPP BASE PLAN FUNDED REVENUE REQUIREMENT Collected under SPP Schedule 11 (A9, page 1, line 5) 71,557,296 9 SPP ECONOMIC PORTFOLIO FUNDED REVENUE REQUIREMENT Collected under SPP Schedule 11 (A12, page 1, line 5) 10 SPP ZONAL REVENUE REQUIREMENT (line 7 line 8 line 9) 153,704, Total Net Transmission Plant (Actual Gross Rev, page 1, line14, col 7) 1,467,527, Actual Facility Carrying Charge (line 7 / line 11) %

3 Rate Formula Template Utilizing FERC Form 1 Data Actual Gross Revenue Requirements For the 12 months ended December 31, 2015 Actual Gross Rev Page 1 of 5 WESTAR ENERGY, INC. (Westar Energy and Kansas Gas and Electric) (WESTAR) (1) (2) (3) (4) (5) (6) (7) Kansas Gas and Line Form No. 1 Westar Energy, Inc Electric Company Transmission No. RATE BASE: Page, Line, Col. (WEN) (WES) Company Total Allocator (Col 5 times Col 6) PLANT IN SERVICE 1 Production g 3,221,663,445 3,498,015,228 6,719,678,673 2 Transmission g 1,101,136, ,268,612 1,995,405,034 TP ,994,671,079 3 Distribution g 1,221,729, ,018,197 2,199,747,884 4 General g 202,161, ,053, ,215,429 W/S ,810,710 4a Intangible 205.5g 85,598,394 29,670, ,269,156 W/S ,082,600 5 Common W/S TOTAL GROSS PLANT (sum lines 15) 5,832,289,624 5,511,026,552 11,343,316,176 2,013,564,389 ACCUMULATED DEPRECIATION (Note Q) 7 Production c 1,034,150,934 1,216,729,530 2,250,880,464 8 Transmission c 288,717, ,620, ,337,511 TP ,143,544 9 Distribution c 384,446, ,998, ,445, General c 98,313,506 65,308, ,622,139 W/S ,214,644 10a Intangible Workpaper 30,885,972 17,672,370 48,558,342 W/S ,141, Common W/S TOTAL ACCUM. DEPRECIATION (sum lines 711) 1,836,514,479 1,846,329,214 3,682,843, ,499,287 NET PLANT IN SERVICE 13 Production (line 1 less line 7) 2,187,512,511 2,281,285,698 4,468,798, Transmission (line 2 less line 8) 812,419, ,648,258 1,468,067,523 1,467,527, Distribution (line 3 less line 9) 837,282, ,019,870 1,507,302, General (line 4 less line 10) 103,848,170 45,745, ,593,290 6,596,066 16a Intangible (line 4a less line 10a) 54,712,422 11,998,392 66,710,814 2,941, Common (line 5 less line 11) 18 TOTAL NET PLANT (sum lines 1317) 3,995,775,145 3,664,697,338 7,660,472,483 1,477,065,102 ADJUSTMENTS TO RATE BASE 19 Accumulated Deferred Income Taxes (Wkshts. A5 & A7, p. 1, Subtotal, To (172,468,643) (120,515,692) (292,984,335) DA (292,984,335) 19a Unamortized Extraordinary Property Loss Account (Note S) TE b Transmission Storm Damage Reserve Account (Note S) 911, ,555 1,575,338 TE ,415, TOTAL ADJUSTMENTS (line 19 + line 19a line 19b) (173,380,426) (121,179,247) (294,559,673) (294,399,495) 21 LAND HELD FOR FUTURE USE 214.x.d (Note B) TP WORKING CAPITAL 22 CWC calculated (Note C) 3,263, Materials & Supplies c (Note B) 18,835,923 11,035,772 29,871,695 TP ,860,708 23a Stores Expense c (Note B) 361, , ,822 W/S , Prepayments (Account 165) c (Note C) 11,055,534 5,622,081 16,677,615 GP ,960, TOTAL WORKING CAPITAL (sum lines 23 24) 30,252,600 17,131,532 47,384,132 36,121, Rate Base (sum lines 18, 20, 21, & 25) 1,218,787,228 Rate Formula Template Actual Gross Rev

4 Utilizing FERC Form 1 Data Actual Gross Revenue Requirements For the 12 months ended December 31, 2015 Page 2 of 5 WESTAR ENERGY, INC. (Westar Energy and Kansas Gas and Electric) (WESTAR) (1) (2) (3) (4) (5) (6) (7) Kansas Gas and Line Form No. 1 Westar Energy, Inc Electric Company Transmission No. Page, Line, Col. (WEN) (WES) Company Total Allocator (Col 5 times Col 6) O&M 1 Transmission (Note D) (Worksheet A4 & Worksheet A6) 14,509,545 10,819,923 25,329, ,329,469 2 Less Account b thru b 2,002, ,882 2,567, ,567,086 2a Less Account 565 (Note E) b 3,549,713 3,531,068 7,080, ,080,781 3 A&G b 114,098, ,387, ,485,242 W/S ,721,927 3a Less: Actual PBOP (Note R) 724, ,691 1,161,908 W/S ,232 4 Plus: PBOP adder (Note R) 9,697,558 6,642,051 16,339,609 W/S ,468 5 Less FERC Annual Fees Included as part of line 6b W/S Less EPRI 335 (Note F) 453, ,503 W/S ,996 6a Less Total Advertising Costs (b) (Note F) 1,598,849 36,753 1,635,602 W/S ,119 6b Less Total Regulatory Commission Expenses (b) (Note F) 2,267,221 1,357,629 3,624,850 W/S ,832 7 Plus Transmission Related Reg. Comm. Exp. 351.h (Note F) 288,500 32, ,958 TE ,324 8 Plus Safety Advertising (Note F) W/S Common CE Transmission Lease Payments TOTAL O&M (sum lines 1, 3, 4, 710 less lines 2, 2 128,451, ,500, ,951,548 26,109,141 DEPRECIATION EXPENSE 12 Transmission f or Worksheet A8 29,365,620 22,031,920 51,397,540 TP ,378, General f 7,346,766 4,608,233 11,954,999 W/S ,136 13a Intangible 336.1f 11,590,770 2,338,768 13,929,538 W/S , Common b CE a Amortization of Property Loss Acct. 407Unrecovered Plant and TE Regulatory Study Costs (Note S) 15 TOTAL DEPRECIATION (Sum lines 1214a) 48,303,156 28,978,921 77,282,077 52,519,970 TAXES OTHER THAN INCOME TAXES (Note G) LABOR RELATED 16 Payroll 263.i 11,969,570 2,472,183 14,441,753 W/S , Highway and vehicle 263.i W/S PLANT RELATED 18 Property (Note P) 263.i 97,701,225 43,072, ,773,801 GP ,988, Gross Receipts 263.i NA Other 263.i 20, ,530 GP , Payments in lieu of taxes GP TOTAL OTHER TAXES (sum lines 16 22) 109,691,060 45,545, ,236,084 25,629,340 INCOME TAXES (Note H) 23 T=1 {[(1 SIT) * (1 FIT)] / (1 SIT * FIT * p)} = 39.55% 24 CIT=(T/1T) * (1(WCLTD/R)) = 45.44% where WCLTD=(page 5, line 21) and R= (page 5, line 24) and FIT, SIT & p are as given in Note H / (1 T) = (from line 23) Amortized Investment Tax Credit (266.8f) (enter negative) (1,240,527) (1,638,853) (2,879,380) 27 Income Tax Calculation = line 24 * line 30 NA 43,983, ITC adjustment (line 25 * line 26) (4,763,242) NP (918,431) 29 Total Income Taxes (line 27 plus line 28) 43,064, RETURN NA 96,795,862 [ Rate Base (page 2, line 16) * Rate of Return (page 4, line 24) plus Incentive Return (page 4, line 28)] 31 Interest on Network Credits DA GROSS REV. REQUIREMENT (sum lines 11,15, 22, 29, 30 & 31) 478,469, ,119,207

5 Rate Formula Template Utilizing FERC Form 1 Data Actual Gross Revenue Requirements For the 12 months ended December 31, 2015 Actual Gross Rev Page 3 of 5 WESTAR ENERGY, INC. (Westar Energy and Kansas Gas and Electric) (WESTAR) SUPPORTING CALCULATIONS (1) (2) (3) (4) (5) (6) (7) Kansas Gas and Line Form No. 1 Westar Energy, Inc Electric Company Transmission No. Page, Line, Col. (WEN) (WES) Company Total Allocator (Col 5 times Col 6) TRANSMISSION PLANT INCLUDED IN FORMULA 1 Total transmission plant (page 3, Line 13, col. 5) 1,101,136, ,268,612 1,995,405,034 1,995,405,034 2 Less transmission plant excluded from ISO rates (Note I) 667,180 66, , ,955 3 Less transmission plant included in OATT Anc. Srv (Notes J&K) 4 Transmission plant included in rates (line 1 less lines 2 & 3) 1,100,469, ,201,837 1,994,671,079 1,994,671,079 5 Percentage of transmission plant included in rates (line 4 divided by line 1) TP= TRANSMISSION EXPENSES 6 Transmission expenses (Page 2, line 1, col. 7) 25,329,469 7 Less transmission other expenses included in Anc. (Note L) (Page 2, line 2, col 7) 2,567,086 8 Included transmission expenses (line 6 less line 7) 22,762,383 9 Percentage of transmission expenses after adjustment (line 8 divided by line 6) Percentage of transmission plant included in ISO Rates (line 5) TP= Percentage of transmission expenses included in rates (line 9 times line 10) TE= GROSS AND NET PLANT ALLOCATORS GROSS PLANT IN SERVICE (ACTUAL HISTORICAL COST) 12 Production (page 1, line 1) 3,221,663,445 3,498,015,228 6,719,678,673 NA 13 Transmission (page 1, line 2) 1,101,136, ,268,612 1,995,405,034 TP ,994,671, Distribution (page 1, line 3) 1,221,729, ,018,197 2,199,747,884 NA 15 General & Intangible (page 1, line 4) 287,760, ,724, ,484,585 W/S ,893, Common (page 1, line 5) CE TOTAL GROSS PLANT (sum lines 1216) 5,832,289,624 5,511,026,552 11,343,316,176 GP = % 2,013,564,389 ACCUMULATED DEPRECIATION (ACTUAL HISTORICAL COST) (Note Q) 18 Production (page 1, line 7) 1,034,150,934 1,216,729,530 2,250,880,464 NA 19 Transmission (page 1, line 8) 288,717, ,620, ,337,511 TP ,143, Distribution (page 1, line 9) 384,446, ,998, ,445,237 NA 21 General & Intangible (page 1, line 10) 129,199,478 82,981, ,180,481 W/S ,355, Common (page 1, line 11) CE TOTAL ACCUM. DEPRECIATION (sum lines 1216) 1,836,514,479 1,846,329,214 3,682,843, ,499,287 NET PLANT IN SERVICE (ACTUAL HISTORICAL COST) 24 Production (line 12 less line 18) 2,187,512,511 2,281,285,698 4,468,798, Transmission (line 13 less line 19) 812,419, ,648,258 1,468,067,523 1,467,527, Distribution (line 14 less line 20) 837,282, ,019,870 1,507,302, General & Intangible (line 15 less line 21) 158,560,592 57,743, ,304,104 9,537, Common (line 16 less line 22) 29 TOTAL NET PLANT (sum lines 2428) 3,995,775,145 3,664,697,338 7,660,472,483 NP = % 1,477,065,102

6 Rate Formula Template Utilizing FERC Form 1 Data Actual Gross Revenue Requirements For the 12 months ended December 31, 2015 Actual Gross Rev Page 4 of 5 WESTAR ENERGY, INC. (Westar Energy and Kansas Gas and Electric) (WESTAR) SUPPORTING CALCULATIONS (1) (2) (3) (4) (5) (6) (7) Kansas Gas and Line Form No. 1 Westar Energy, Inc Electric Company Transmission No. Page, Line, Col. (WEN) (WES) Company Total Allocator (Col 5 times Col 6) WAGES & SALARY ALLOCATOR (W&S) TP Allocation 1 Production (Worksheet A10) 34,526,485 70,956, ,483, Transmission (Worksheet A10) 3,891,218 3,033,584 6,924, ,922,255 3 Distribution (Worksheet A10) 14,735,660 12,139,412 26,875, W&S Allocator 4 Other (Worksheet A10) 10,189,140 7,518,543 17,707, ( / Allocation) 5 Total (sum lines 14) 63,342,503 93,648, ,990,993 6,922,255 = = WS COMMON PLANT ALLOCATOR (CE) (Note M) % Electric W&S Allocator 6 Electric c 5,422,661,578 4,233,861,857 9,656,523,435 (line 17 / line 20) (line 16) CE 7 Gas d * = Water e 9 Total (sum lines 6 8) 5,422,661,578 4,233,861,857 9,656,523,435 RETURN (R) 10 Interest on LongTerm Debt c 101,751,759 54,418, ,170, Amort. of Debt Disc. and Expense c 3,677, ,274 4,367, Amortization of Loss on Reacquired Debt c 4,251, ,798 5,130, Less: Amort. of Premium on DebtCredit c 14 Less: Amort. of Gain on Reacquired DebtCredit c 15 Long Term Interest (sum of lines less 13 and 14) 109,681,203 55,986, ,668, ,668, Preferred Dividends (118.29c) (positive number) Development of Common Stock: 17 Proprietary Capital ( c)(WEN F 3,656,721,445 3,656,721,445 3,656,721, Less Preferred Stock (line 28) 19 Less Account ( c) (Note N) 20 Common Stock (sum of lines 17 19) 3,656,721,445 Cost WEN WES % (Note O) Weighted 21 Long Term Debt (112, sum of 18.c., 19c and 21.c) 2,230,500, ,440,000 3,201,940, % =WCLTD 22 Preferred Stock (112.3.c)(WEN Only) 0.00% Common Stock (line 26)(WEN Only) 3,656,721,445 3,656,721, % Total (sum lines 2123) 6,858,661, % =R Incentive Return 25 Total Incentive Plant (Worksheet A11) 194,004, Less: Total Accumulated Depreciation (Worksheet A11) 79,579, Net Incentive Plant (line 25 less line 26) 114,425, Incentive Return (Worksheet A11) 427,044

7 Rate Formula Template Utilizing FERC Form 1 Data Actual Gross Revenue Requirements For the 12 months ended December 31, 2015 WESTAR ENERGY, INC. (Westar Energy and Kansas Gas and Electric) (WESTAR) NOTES General Note: References to pages in this formula rate are indicated as: (page#, line#, col.#). References to data from FERC Form 1 are indicated as: page#.line#.col Actual Gross Rev Page 5 of 5 Letter A Reserved for future use. B Identified in Form 1 as being only transmission related. C Cash Working Capital assigned to transmission is oneeighth of O&M allocated to transmission at page 2, line 11, col. 7. Prepayments are the electric related prepayments booked to Account No. 165 and reported on FERC Form 1, p. 111, ln. 57.c. D Transmission O&M expense does not include any SPP charges for Schedule 1A of the SPP OATT. E Transmission By Others, Account 565 includes only costs associated with transmission facilities which are assigned to the Westar pricing zone by SPP. F Industry Association Dues are capped at 1,000,000. Line 6 EPRI Annual Membership Dues listed in Form 1 at p. 335, Line 6a Remove all Advertising expenses in Account Line 6b Remove all Regulatory Commission Expenses itemized at 351.h. Line 6c Add in wholesale Regulatory Commission Expenses directly related to transmission service, ISO filings, or transmission siting itemized at 351.h. Line 6d Add in Safety related advertising that are in Account G Includes only FICA, unemployment, highway, property, gross receipts, and other assessments charged in the current year. Taxes related to income are excluded. Gross receipts taxes are not included in transmission revenue requirement in the Rate Formula Template, since they are recovered elsewhere. H 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". If the utility is taxed in more than one state it must attach a work paper showing the name of each state and how the blended or composite SIT was developed. Furthermore, a utility that 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, f) multiplied by (1/1T) (page 3, line 28). When FIT or SIT statutory tax rate changes take effect on other than a calendar year basis, the rates to be used in the formula rate template shall be weighted averages for the calendar year determined by weighting the statutory tax rates by the number days each such tax rate was in effect during the calendar year for which the costs are being det Inputs Required: FIT = 35.00% SIT= 7.00% (State Income Tax Rate or Composite SIT) p = 0.00% (percent of federal income tax deductible for state purposes) Removes transmission plant determined by Commission order to be statejurisdictional according to the sevenfactor I J test (until FERC Form 1 balances are adjusted to reflect application of sevenfactor test). Unless otherwise specified, OATT refers to the Westar and SPP OATTs. K Removes dollar amount of transmission plant included in the development of OATT ancillary services rates and generation stepup facilities, which are deemed to be included in OATT ancillary services. For these purposes, generation stepup facilities are facilities at a generator substation on which there is no throughflow when the generator is shut down. L Removes dollar amount of transmission expenses included in the OATT ancillary services rates. Costs related to Ancillary 1, Scheduling and Control, Acct 561 is shown on Actual Gross Rev, page 2, line 2. M Enter dollar amounts N For Account 216.1, enter zero if the actual balance is negative O Debt cost rate = longterm interest (line 15) / long term debt (line 21). Preferred cost rate = preferred dividends (line 16) / preferred stock (line 22). The approved ROE is 11.3%, no change in ROE may be made absent a filing with FERC. Any incentive ROEs approved by the Commission are shown by project in Worksheet A11. P If the transmission related component of property tax is specifically identified in Form 1, then a TP allocator shall be used. Property tax shall be allocated to transmission by the GP allocator if transmission related property tax is not specifically identified in Q The initial depreciation rates below will be used to calculate depreciation expense and accumulated depreciation balances absent an appropriate filing with FERC. Depreciation Rate Nonincentive Plant WichitatoRenoto Summit Future Incentive Project FERC Account Number Land and Land Rights 351 (reserved) 352 Structures and Improvements Station Equipment Towers and Fixtures Poles and Fixtures Overheard Conductors and Devices Underground Conduit Underground Conductors and Devices Roads and Trails The incentive depreciation rates will be applied to assets recorded in the WichitatoRenotoSummit location code in WES's R The initial PostEmployment Benefits Other than Pensions (PBOP) expense set forth below will be used in lieu of the actual PBOP expense incurred in the year absent an appropriate filing with FERC. WEN WES TOTAL PostEmployment Benefits Other than Pensions 9,697,558 6,642,051 16,339,609 S Page 1 line 19a is the unamortized balance related to the recovery of transmission expense for the December 2007 ice storm booked in Account Accrued transmission expenses for the December 2007 ice storm shall be amortized in the transmission O&M accounts over 36 months beginning June 1, The total amount to be amortized in the transmission O&M accounts shall be 6,647,679, developed as follows: WEN WES Total Total transmission expenses accrued for the December 2007 ice storm 6,758,037 6,758,037 Less total transmission storm damage reserve as of December , , ,973 Total transmission expense to be amortized 6,647,679 (147,615) 6,500,064 * All future accruals of transmission storm damage reserves will be subtracted from rate base until they are applied to offset the December 2007 ice storm damage expenses.

8 Worksheet A1 WE Revenue Credit Page 1 of 3 I. Account 456 ( see Note A in Section IV on page 3 of 3 ) Westar Energy, Inc. Determination of Revenue Credits For the 12 months ended December 31, 2015 Line No. Company WESTAR TOTAL EDORA ENEL BPW MKEC SWPP MoPEP OMPA OPSI OZMO SPRM TEA KCBPUPS KPP AECC KMEA Transmission Service 85,159,252 85,159, Trans Service Retail Only 170,171, ,171, Anc 1 1,053,844 23,245 83, ,667 32,580 29, Anc 1 Retail Only 2,593,014 2,593, Anc 2 115, , n/a Anc 2 Retail Only Anc 3 8a Anc 3a Anc Anc Anc SPP Losses (4,540) (4,540) Dist. Facilities Charge 1,454,077 1,454,077 13a 456.xxxx Trans. Fac. Charge Trans Studies 15 Total 260,542,753 23,245 83, ,374,575 32,580 29, Less: 17 Accounts through less TFC 5,212,035 23,245 83,081 5,043,858 32,580 29, Revenue for Demands in Divisor ,171,054 69,171, Revenue for Demands in Divisor ,171, ,171, Sub Total Revenue Credit 15,988,197 15,988, Previous Years Adjustmen 21a Rev. Adj. not captured in or (Note B 21b Ratio of Rev Credit to Trans Rev. [(line 20/(line1+line2 6.26% 21c Rev. Adj. Alloc. To Rev Credit (line 21a * 21b) 22 Total Revenue Credit (lines 20 21c) 15,988,197

9 WEN (KPL) TOTAL EDORA ENEL BPW MKEC SWPP MoPEP OMPA OPSI OZMO SPRM TEA KCBPUPS KPP AECC KMEA Transmission Service 42,579,626 42,579, Trans Service Retail Only 85,085,733 85,085, Anc 1 526,922 11,623 41, ,833 16,290 14, Anc 1 Retail Only 1,296,507 1,296, Anc 2 115, , n/a Anc 2 Retail Only Anc 3 30a Anc 3a Anc Anc Anc SPP Losses (2,270) (2,270) Dist. Facilities Charge 727, ,038 36a 456.xxxx Trans. Fac. Charge Trans Studies 37 Total 130,329,197 11,623 41, ,245,108 16,290 14,636 Company WES (KGE) TOTAL EDORA ENEL BPW MKEC SWPP MoPEP OMPA OPSI OZMO SPRM TEA KCBPUPS KPP AECC KMEA Transmission Service 42,579,626 42,579, Trans Service Retail Only 85,085,733 85,085, Anc 1 526,922 11,623 41, ,833 16,290 14, Anc 1 Retail Only 1,296,507 1,296, Anc n/a Anc 2 Retail Only Anc 3 45a Anc 3a Anc Anc Anc SPP Losses (2,270) (2,270) Dist. Facilities Charge 727, ,038 50a 456.xxxx Trans. Fac. Charge Trans Studies 52 Total 130,213,556 11,623 41, ,129,468 16,290 14,636 Worksheet A1 WE Revenue Credit Page 2 of 3 Westar Energy, Inc. Determination of Revenue Credits For the 12 months ended December 31, 2015 II. Account 454 WEN WES Line No. Balance at End of Year Balance at End of Year REVENUE CREDITS REVENUE CREDITS 1 Account 454 (Rent from Electric Property) b 4,789,173 Account 454 (Rent from Electric Property) 2,182, b Excluded: Excluded: 2 Distribution rental (see below) 1,450,501 Land rental for Gordon Evans CTs 1,417, Other Electric Property Rents ,020 Other Electric Property Rents 37, Distribution rental (see below) 697,764 5 Included in template 2,839,652 Included in template 29,121 Distribution rental developed as follows: Distribution rental developed as follows: 6 Description 1,506,512 (Sum ) Description 718,469 (Sum ) 7 Distribution pole attachment ratio Distribution pole attachment Distribution rental 1,450,501 Distribution rental 697,764 Per Attachments Ratio Per Attachments Ratio 9 Transmission 5, Transmission 3, Distribution 148, Distribution 103, Total 154, Total 106, For both WEN and WES, only nontransmission related items included. Determined by the ratio of pole attachments on transmission vs distribution. III. Revenue from Grandfathered Interzonal Transactions and service provided by the RTO at a discount in Account 454 Company Revenues from Grandfathered Interzonal Transactions Revenues from service provided by the ISO at a discount

10 Worksheet A1 WE Revenue Credit Page 3 of 3 IV. Notes Westar Energy, Inc. Determination of Revenue Credits For the 12 months ended December 31, 2015 A Account 456 revenue treated as a credit to cost of service in this formula is from subaccount , Transmission Service. Revenue from Grandfathered pointtopoint (GFA all Companies in Section I except SWPP). Revenue from Grandfathered pointtopoint (GFA all Companies in Section I except SWPP). Wholesale NITS Revenues The content in these categories can change over time SWPP Allocated NITS: From NITS customers outside the Westar Zone SWPP Individual NITS: Cities of Alma, Blue Mound, Bronson, Elsmore, Elwood, Herington, LaHarpe, McPherson, Mindenmines, Moran, Morrill, Mulberry, Muscotah, Robinson, Savonburg, Scranton, Toronto, Vermillion, and Wathena; Doniphan Electric Cooperative. SWPP NITS Bought by Others: Kansas Electric Power Cooperative (KEPCO), Kansas Municipal Energy Association (KMEA), Kansas Power Pool (KPP), Kaw Valley Electric Cooperative,Nemaha Marshall Electric Cooperative, Southwind Energy Group (SEG), Kansas City Greater Missouri Operations (KCPLGMO (aka UCU)) Month SWPP Allocated NITS SWPP Individual NITS SWPP NITS Bought by Others Total January 3,367, ,806 2,226,191 6,196,791 February 2,807, ,732 2,259,567 5,658,995 March 2,912, ,826 2,259,705 5,756,572 April 3,208, ,818 2,259,677 6,052,834 May 2,815, ,819 2,259,678 5,660,270 June 2,822, ,708 2,259,480 5,666,792 July 2,812, ,799 2,260,422 5,658,072 August 2,820, ,699 2,260,033 5,665,316 September 2,806, ,742 2,260,201 5,651,467 October 2,795, ,742 2,260,202 5,640,241 November 2,937, ,724 2,229,208 5,743,328 December 2,993, ,092 2,246,094 5,820,377 Total 35,100,089 7,030,507 27,040,459 69,171,054 Monthly loads associated with the remaining revenue for Transmission Service (subaccount ) from SWPP (e.g., retail) are also included in the DIVISOR. However, the associated revenue is included as a revenue credit to offset the associated SWPP expenses booked to account 566, Miscellaneous Transmission Expense. Revenue from Grandfathered Agreements involving interzonal transactions whose rates have been changed to eliminate or mitigate pancaking are included in Section III above and the corresponding loads are included in the DIVISOR Revenue from Grandfathered Agreements involving interzonal transactions whose rates have not been changed to eliminate or mitigate pancaking are not included in Section III above and the corresponding loads are not included in the DIVISOR. Revenue credits do not include revenues associated with FERC annual charges, gross receipts taxes, ancillary services and/or facilities not included in this template, e.g., directly assigned facilities, GSUs, etc. Account 454 (Rent from Electric Property) includes income related only to transmission facilities, such as pole attachments, rentals and special use. B C Line 21a represents a refund or surcharge that is done by SPP where the increase or decrease in revenue is not reflected in the or revenues. If a value is entered into this line, a support worksheet will be included with the posted formula. Refunds will be entered as a negative value, surcharges as a positive value. The adjustment does not included any refunds or surcharges associated with the sale of ancillary services. Line 21b is the ratio of the amount of the revenue credit on line 20 to the total amount of revenue collected from the transmission charges, excluding ancillary revenues. The Transmission Facilities Charge is the revenue from transmission customers that pay for direct assigned costs related to transmission facilities. This revenue is anticipated from the implementation of the SPP definition of transmission (Attachment AI) which requires the direct assignment of costs related to 1) single customer radial facilities and 2) those facilities which are booked into transmission accounts, but operate at less than 60 kv and have not been determined to be transmission facilities by the Commission using the seven factor test.

11 Worksheet A2 WE Divisor Page 1 of 5 Westar Energy, Inc. Determination of Transmission Network Load (MW) For the 12 months ended December 31, 2015 I. Westar Energy Date Hour Ending Company Transmission Peak Load Adjustment Westar's Transmission System Peak Load Less: GFA PTP Scheduled Load Plus: GFA PTP Contract Demand Less: NonFirm Sales to Cities Plus: NonWestar Generation Plus: NonControl Area Transmission Load Less: Load Not Connected to the Westar Transmission System Westar's Transmission Network Load (ef+gh+i+jk) Percentage of Maximum Transmission Network Load During Year (a) (b) ( c ) (d) (e) (f) (g) (h) (i) (j) (k) (l) (l) 01/07/ n/a n/a 3,765 3, % 02/04/ n/a n/a 3,539 3, % 03/05/ n/a n/a 3,380 3, % 04/07/ n/a n/a 3,094 3, % 05/27/ n/a n/a 3,464 3, % 06/24/ n/a n/a 5,110 5, % 07/24/ n/a n/a 5,426 5, % 08/03/ n/a n/a 5,021 5, % 09/03/ n/a n/a 4,865 4, % 10/08/ n/a n/a 3,630 3, % 11/30/ n/a n/a 3,146 3, % 12/28/ n/a n/a 3,355 3, % Total n/a n/a 47,795 47,795 12CP n/a n/a 3,983 3,983

12 Worksheet A2 WE Divisor Page 2 of 5 II. WEN Date 1 Hour Ending 1 Company Transmission Peak Load 1 Adjustment 2 Load at Westar's Transmission System Peak Load 3 Less: GFA PTP Scheduled Load 4 Plus: GFA PTP Contract Demand 5 Less: NonFirm Sales to Cities 6 Plus: NonWestar Generation 7 Plus: NonControl Area Transmission Load 8 Less: Load Not Connected to the Westar Transmission System 9 Westar's Transmission Network Load (ef+gh+i+jk) (a) (b) ( c ) (d) (e) (f) (g) (h) (i) (j) (k) (l) 01/07/ , ,983 1,983 02/04/ , ,879 1,879 03/05/ , ,786 1,786 04/07/ , ,581 1,581 05/27/ , ,730 1,730 06/24/ , ,623 2,623 07/24/ , ,849 2,849 08/03/ , ,649 2,649 09/03/ , ,555 2,555 10/08/ , ,890 1,890 11/30/ , ,633 1,633 12/28/ , ,759 1,759 Total 24,917 24,917 24,917 12CP 2,076 2,076 2,076 III. WES Westar Energy, Inc. Notes to the Determination of WEN's and WES' Contribution to Transmission Network Load (MW, unless otherwise noted) For the 12 months ended December 31, 2015 Date 1 Hour Ending 1 Company Transmission Peak Load 1 Adjustment 2 Load at Westar's Transmission System Peak Load 3 Less: GFA PTP Scheduled Load 4 Plus: GFA PTP Contract Demand 5 Less: NonFirm Sales to Cities 6 Plus: NonWestar Generation 7 Plus: NonControl Area Transmission Load 8 Less: Load Not Connected to the Westar Transmission System 9 Westar's Transmission Network Load (ef+gh+i+jk) (a) (b) ( c ) (d) (e) (f) (g) (h) (i) (j) (k) (l) 01/07/ , ,782 1,782 02/04/ , ,660 1,660 03/05/ , ,594 1,594 04/07/ , ,513 1,513 05/27/ , ,734 1,734 06/24/ , ,487 2,487 07/24/ , ,577 2,577 08/03/ , ,372 2,372 09/03/ , ,310 2,310 10/08/ , ,740 1,740 11/30/ , ,513 1,513 12/28/ , ,596 1,596 Total 22,878 22,878 22,878 12CP 1,907 1,907 1,907

13 Worksheet A2 WE Divisor Page 3 of 5 Westar Energy, Inc. Notes to the Determination of WEN's and WES' Contribution to Transmission Network Load (MW, unless otherwise noted) For the 12 months ended December 31, 2015 Note: 1 These are the dates, times and loads at the time of WEN's and WES' transmission peak, as reported in FERC Form 1, page 400. Note: 2 Note: 3 Note: 4 This is the difference between "Company Transmission Peak Load" and "Load at Transmission System Peak Load." These are the WEN and WES values that, when added together, equal the transmission system peak load in Westar's Energy Accounting System, Monthly Min/Max Load Values report. "GFA PTP Scheduled Load" is the load in MW scheduled by Grandfathered Agreements' (GFA) customers taking firm pointtopoint (PTP) service at the time of Westar's monthly transmission system peak load. These amounts are assigned equally between WEN and WES in Sections II and III above. Details are as follows: GFA PTP Firm n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a Schedules Jan /07/2015 Feb /04/2015 Mar /05/2015 Apr /07/2015 May /27/2015 Jun /24/2015 Jul /24/2015 Aug /03/2015 Sep /03/2015 Oct /08/2015 Nov /30/2015 Dec /28/2015 Note: 5 "GFA PTP Contract Demand" is the contract demand in MW for these customers. These amounts are assigned equally between WEN and WES in Sections II and III above. Details are as follows: GFA PTP Firm n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a Schedules Jan /07/2015 Feb /04/2015 Mar /05/2015 Apr /07/2015 May /27/2015 Jun /24/2015 Jul /24/2015 Aug /03/2015 Sep /03/2015 Oct /08/2015 Nov /30/2015 Dec /28/2015

14 Worksheet A2 WE Divisor Page 4 of 5 Westar Energy, Inc. Notes to the Determination of WEN's and WES' Contribution to Transmission Network Load (MW, unless otherwise noted) For the 12 months ended December 31, 2015 Note: 6 "NonFirm Sales to Cities" are MW loads at the time of Westar's monthly transmission system peak load associated with nonfirm GFA transmission service or loads solely utilizing SPP PTP transmission service. WES WEN Contract Type Total Part. Req. Customer Future use Future use Future use Future use Future use Total (MW) Future use Future use Future use Future use Future use Total (MW) Demand (MW) (a+b+c+d+e) (g+h+i+j+k) (f+l) (a) (b) ( c ) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) Jan /07/ Feb /04/ Mar /05/ Apr /07/ May /27/ Jun /24/ Jul /24/ Aug /03/ Sep /03/ Oct /08/ Nov /30/ Dec /28/ Note: 7 "NonWestar Generation" in MW is shown below. Only generators operating synchronously with the transmission system, and not already included in the transmission peak value, shall be included. WES WEN Contract Type Total Gen. Customer Future use Future use Future use Future use Future use Total (MW) Future use Future use Future use Future use Future use Total (MW) (MW) (a+b+c+d+e) (g+h+i+j+k) (f+l) (a) (b) ( c ) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) Jan /07/2015 Feb /04/2015 Mar /05/2015 Apr /07/2015 May /27/2015 Jun /24/2015 Jul /24/2015 Aug /03/2015 Sep /03/2015 Oct /08/2015 Nov /30/2015 Dec /28/2015

15 Worksheet A2 WE Divisor Page 5 of 5 Westar Energy, Inc. Notes to the Determination of WEN's and WES' Contribution to Transmission Network Load (MW, unless otherwise noted) For the 12 months ended December 31, 2015 Note: 8 "NonControl Area Transmission Load" in kw is load on Westar's transmission system that is electronically transferred to control areas other than Westar. Details are as follows: WES WEN Total Load. Future use Future use Future use Future use Future use Total (MW) Future use Future use Future use Future use Future use Total (MW) (MW) (a+b+c+d+e) (g+h+i+j+k) (f+l) (a) (b) ( c ) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) Jan /07/2015 Feb /04/2015 Mar /05/2015 Apr /07/2015 May /27/2015 Jun /24/2015 Jul /24/2015 Aug /03/2015 Sep /03/2015 Oct /08/2015 Nov /30/2015 Dec /28/2015 Note: 9 "Load in Westar's Balancing area and included in the Transmission peak number, but is physically connected to a different SPP Transmission Owner's system." WES WEN Total Load. Future use Future use Future use Future use Future use Total (MW) Future use Future use Future use Future use Future use Total (MW) (MW) (a+b+c+d+e) (g+h+i+j+k) (f+l) (a) (b) ( c ) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) Jan /07/2015 Feb /04/2015 Mar /05/2015 Apr /07/2015 May /27/2015 Jun /24/2015 Jul /24/2015 Aug /03/2015 Sep /03/2015 Oct /08/2015 Nov /30/2015 Dec /28/2015

16 Worksheet A3 WE Retail Adder Page 1 of 1 Westar Energy, Inc. Items Deemed to be Allocated Exclusively to the Retail Jurisdiction For the 12 months ended December 31, 2015 Line No WEN WES Total 1 Rate Base 2 ADIT Retail [A5, pg 1, line 4 & A7, pg1, line4 24,609,859 27,047,430 51,657,289 3 Total 24,609,859 27,047,430 51,657,289 4 Alloc. Fact. Gross Plant (Actual Gross Rev, pg 3, line % % 5 Transmission Related [ line 3 x line 4 ] 4,368,523 4,801,219 9,169,742 6 Rate of Return [Actual Gross Rev, pg 4, line % 7.907% 7 Return [ line 5 x line 6 ] 345, , ,046 8 Income Tax Factor [Actual Gross Rev, pg 2, line % % 9 Income Taxes [ line 7 x line 8 ] 156, , , Other Expenses 11 Item 1 12 Item 2 13 Item 3 14 Item 4 15 Total [ sum of lines 11 through 14 ] 16 Revenue Requirement [ line 7 + line 9 + line 15 ] 502, ,131 1,054,502

17 Worksheet A4 WEN O&M Exclusions Page 1 of 1 Page. Line No. Col. Westar Energy, Inc. Determination of O&M Exclusions from the Formula Rate For the 12 months ended December 31, b O&M Transmission ( b) 129,031,107 Exclude: Network service for Westar Retail load including ancillaries and schedule 12 (Account ) 114,521,562 Total (Included in Sch. WEN, p. 2, ln. 1, col. 3) 14,509,545

18 Worksheet A5 WEN ADIT Page 1 of 7 Westar Energy, Inc. Allocation of ADIT For the 12 months ended December 31, 2015 Line No. Summary 100% 100% 100% Total NonTrans. Transmission Plant Labor Retail ADIT Related Related Related Related Related 1 Less ADIT282 (12,548,521) (984,264,986) (235,424) 22,950,280 2 Less ADIT283 (67,180,863) (37,345,402) (109,934,729) (659,702) 3 Plus ADIT ,025,775 2,695,501 33,047, ,353,382 2,319,281 4 Subtotal 300,296,391 2,695,501 (988,562,905) 7,183,228 24,609,859 (653,777,925) 5 Wages & Salary Allocator 4.409% 6 Gross Plant Allocator % % 7 ADIT 2,695,501 (175,480,876) 316,732 (172,468,643)

19 Worksheet A5 WEN ADIT Page 2 of 7 ADIT190 (A) (B) (C) (D) (E) (F) (G) (G) 100% 100% 100% Retail In In 2015 NonTrans. Transmission Plant Labor [Allocate Adjustment Adjustment YE Balance Related Related Related Related by Plant] to Ratebase to Ratebase Current Deferred Tax Asset Reclass No Cur vs L/T Reclass (for financial reporting) Accumulated Deferred Income Tax Utility Oper Other Vulcan Contracts Westar Energy, Inc. Allocation of ADIT For the 12 months ended December 31, 2015 Consideration payment related to 2003 unit participation agreement tax deductible when paid; amortized for books. No KS Dept Revenue Excavation Refund No Taxable refunds not recognized on books Pensions 679, ,528 Yes Pension accrual per books vs. actual contributions for tax Deferred Compensation salaried WE 394, ,139 Yes Deferred compensation interest accrued on books, deductible for tax when paid Bad Debts No Book accrual for bad debts vs. direct write off method for tax Property Insurance 1,879,851 1,879,851 Yes Book accrual for property insurance vs. actual costs for tax Injuries and Damages 495, ,999 Yes Book accrual for 3rd party injuries and damages vs. actual costs for tax Group Medical Insurance 531, ,304 Yes Book accrual for group medical claims vs. actual costs for tax Environmental 354, ,719 Yes Book accrual for environmental reserve vs. actual costs for tax Vacation Pay Accrual 4,645,877 4,645,877 Yes Accrued vacation pay per books vs. vacations paid within 2 1/2 months of year end for ta Legal Expenses 39,995 39,995 Yes Legal expenses accrued on books vs. actual payments for tax Ad Valorem Tax R/L (11,154,670) (11,154,670) Yes Regulatory Liability recorded for ad valorem taxes not recognized for tax purposes Tax Credit Carryover 80,885,520 80,885,520 No General business credits to be utilized in future years Deferred Compensation Plan 2,161,901 2,161,901 Yes Book accrual for deferred compensation vs. actual payments for tax Inventory Valuation 200, ,455 Yes Book accrual for inventory reserve vs. actual losses for tax Fly Ash Contract Liability for Deferred Tax Revenue from Fly Ash Contract deferred on books and amortized over 10 years; No recognized for tax upon receipt DIT R/L Sale of Wichita SCC Book recognition of gain beginning 2/2006 on 2004 Sale of land at Wichita SCC per Yes 12/05 rate order s/b WES only (This balance will get transferred to WES) Westar Generation Power Purchase 4,033,939 4,033,939 Regulatory liability recorded for power purchased from Westar Generating; not No recognized for tax Alternative Minimum Tax 26,724,906 26,724,906 No Alternative minimum tax credits to be used in future years PODS Regulatory/Liability1 No Regulatory liability recorded for IT assets transferred to Protection One; not recognized fo R/L Kansas Tax Credits 243,463, ,463,993 No Deferred taxes associated with Kansas High Performance Incentives Tax Credits Severance Yes Book accrual for severance costs vs. actual payments for tax General Tax Reserve 292, ,678 Yes Book reserve set up for potential nonincome tax issues; deductible for tax when paid State Tax Credits 15,250,084 15,250,084 No Kansas income tax credits to be utilized in future years Federal NOL Tax Benefits 37,712,121 37,712,121 Yes Federal net operating loss tax benefits to be utilized in future years State NOL Tax Benefit 3,307,336 3,307,336 Yes State net operating loss tax benefits to be utilized in future years Injuries and Damages R/L (0) (0) Book accrual for amounts collected from customers in excess of estimated injuries & Yes damages claims; not recognized for tax Section 467 Railcar Lease (6,556) (6,556) No Book accrual railcar lease expense vs. prescribed costs for tax per IRC Sec R/L AB Wholesale Sales 0 0 Book accrual for refunds to wholesale customers due to excess prices charged on sales No of power within our control area; not recognized for tax R/L Sale of Olathe 0 0 Book accrual for refund to customers for gain on sale of Olathe properties; not No recognized for tax Reg Asset Unrecognized Pension Exp 103,783, ,783,735 Yes Book accrual to recognize funded status of pension plan; not recognized for tax Reg Asset Unrecognized Post Retirement Ex (3,592,521) (3,592,521) No Book accrual to recognize funded status of post retirement plan; not recognized for tax Terminal Net Salvage Refund (57,238) (57,238) Book accrual for refunds to customers for amounts previously collected in rates for Yes terminal net salvage; not recognized for tax OneOk PPA Fair Value 2,592,494 2,592,494 No Booktax basis difference Spring Creek plant UTB Fed Ben on State Liab Pre 2008 (0) (0) Yes Book accrual for federal tax benefit on state taxes on uncertain income tax positions UTB Contra Tax Credits Pre 2008 No Book accrual for federal tax benefits on uncertain income tax positions UTB Liab Interest Fed No Book accrual for federal interest on uncertain income tax positions UTB Liab Interest State 16,826 16,826 Yes Book accrual for state interest on uncertain income tax positions Loss Cont TOTI Interest Fed and State\ 22,913 22,913 Book accrual for federal and state interest on loss contingencies related to taxes other Yes than income taxes MKEC Capital Lease 871, ,059 No Book depreciation and interest expense on capital lease vs operating lease for tax MKEC Consent Fees 1,017,214 1,017,214 No Fee from Aquila transaction deferred on books and amortized over term of lease LEC Environmental Liability 16,537 16,537 No Deferred Income tax associated with the accrued environmental liability for Lawrence Ene R/L FERC Transmission Settlement 0 0 Yes Regulatory liability FERC revenue refund LongTm Incentive Prog PWR MKT 100, ,019 Yes Book accrual for long term incentives vs. actual payments for tax

20 Worksheet A5 WEN ADIT Page 3 of 7 Westar Energy, Inc. Allocation of ADIT For the 12 months ended December 31, 2015 CONTINUE ADIT190 (A) (B) (C) (D) (E) (F) (G) (G) 100% 100% 100% Retail In In 2015 NonTrans. Transmission Plant Labor [Allocate Adjustment Adjustment YE Balance Related Related Related Related by Plant] to Ratebase to Ratebase Cash Flow Hedge No Taxable income from hedge transaction amortized to income for book purposes Reg Liab #6 Oil Sale 147, ,959 No Book accrual for refund to customers for gain on sale of #6 oil; not recognized for tax Long Term Rail Car Lease (2,502) (2,502) No Book accrual railcar lease expense vs. actual costs for tax Short Term Incentive Program 2,933,928 2,933,928 Yes Book accrual for short term incentives vs. actual payments for tax Long Term Incentive Program (1,145,503) (1,145,503) Yes Book accrual for long term incentives (RSU's) vs. actual payments for tax BOA Office & Call CTR Lease (63,500) (63,500) Yes Book accrual office lease expense vs. prescribed costs for tax per IRC Sec 467 Oklahoma Municipal Power Agreement Revenue from OMPA deferred on books and amortized over term of contract; (0) (0) Sale (OMPA) No recognized for tax upon receipt Emission Allowances 577, ,547 Emission allowances withheld by EPA and sold at auction by them. Recorded as No regulatory liability on books; recognized as capital gain for tax Post Retirement Benefit Plans 7,050,168 7,050,168 No Excluded WE Salary Continuation Plan 3,268,454 3,268,454 Yes Book accrual for Salary Continuation Plan vs. actual payments for tax Charitable Contributions Carry forward 2,173,072 2,173,072 Charitable contributions expensed on books deductible for tax subject to limitation of No 10% of taxable income Accrued Interest No Book accrual for interest on tax receivable KCC Accrual 2,207,568 2,207,568 Yes Accrual for KCC ROE transmission rate change Miscellaneous Accruals 2,319,281 2,319,281 No Book accrual for potential sales tax exposure; deductible for tax when paid Cap Loss CF No Deferred income taxes related to capital loss carryforwards VA Cap Loss CF No Valuation allowance on deferred income taxes related to capital loss carryforwards Property Insurance Reserve Transm 360, ,610 Yes Book accrual for property insurance vs. actual costs for tax Transmission allocation Environmental Reserve Transm 46,193 46,193 Yes Book accrual for environmental reserve vs. actual costs for tax Transmission allocation Valuation Reserve Reg Liab KS Tax CR No Valuation Allowance on deferred taxes associated with Kansas High Performance Incent Reg Liab KS Tax Credits Fed (5,337,529) (5,337,529) Deferred federal income taxes associated with KS High Performance Incentive Program No State Tax Credits Fed Effect No Deferred federal effect of KS High Performance Incentive Program VA State Tax Credits No Valuation Allowance associated with the pre 2008 Kansas High Performance Incentive Program VA State Tax Credits Fed Effect No Valuation Allowance associated with the federal effect of the pre 2008 Kansas High Performance Incentiv Program Inj & Damages Reserve Transm 81,129 81,129 Yes Book accrual for 3rd party injuries and damages vs. actual costs for tax Transmission al Clipper Wind Farm Agmt No Deferred income taxes on annual cash adjustments associated with the Flat Ridge Wind Adv Pmts Power Mkt (0) (0) No Deferred income taxes on advance power purchase payments made to the power market MKEC Revenue Reserves No Deferred income taxes on MKEC disputed revenue reserve HVAC Heat Pump Program 25,831 25,831 No Deferred income taxes on the accruement of rebates and credits for the HVAC Heat Pum Prairie Wind Equity 0 0 No Deferred income taxes on investment in Prairie Wind Transmission, LLC Other Deferred Kansas Tax Credits 7,500 7,500 No Deferred income tax associated with deferred Kansas tax credits other than HPIP credits Post Ret Med Expense Tracker 4,142,845 4,142,845 Book accrual for the excess of the amounts collected from customers for postretirement medical and LTD expense according to GAAP No Small Business Lighting (15,784) (15,784) No Includes the small business lighting energy efficiency iniative Capital Loss Carryforward (0) No Nonutility related Bad Debt Writeoff No Nonutility related Russell Inv Exec Plan 11,312,114 No Nonutility related Call Opt on Put/Call Bonds No Nonutility related VA P1 Stock Redemption CLCF No Nonutility related Deferred Income Tax on PODS Regulatory/L No Nonutility related Power Marketing Incentives 639,390 No Nonutility related Restricted Stock Expenses (144,966) No Nonutility related Power Marketing Mark to Market Deferred T (507,204) No Nonutility related Deferred Compensation Interest salaried No Nonutility related Short Term Incentive 134,095 No Nonutility related Subsidiary Acquisition Costs No Nonutility related Coal Contract Mark to Market Liability No Nonutility related Wholesale Sales MTM No Nonutility related Legal Expense 1 No Nonutility related Restructuring Expense No Nonutility related Long Tm Incentive Program PWR Mkt 182,702 No Nonutility related Impairment of Plane Lease No Nonutility related WR Bermuda 0 No Nonutility related Severance Benefit 3,153,934 No Nonutility related Valuation Allowance WR Bermuda No Nonutility related DIT MISO RSG Settlement 17,086 No Nonutility related