1. 2016 Attachment O Projection Stakeholder Meeting Ameren Illinois Company September 24, 2015

2. 2 AGENDA Main Purpose is to review AIC 2016 Projected Transmission Rate Calculations Timeline AIC 2016 Projected Calculations Attachment O Attachment GG Attachment MM 2016 AMIL Pricing Zone NITS Charge

3. 3 NEW PROTOCOL TIMELINE Date Schedule (Forward-Looking Protocols) June 1  Posting of annual true-up for prior year September 1  Deadline for annual true-up meeting September 1  Posting of net projected revenue requirement for following year October 15  Deadline for annual projected rate meeting November 1  Deadline for joint meeting on regional cost-shared projects March 15  Transmission Owners submit informational filing to the Commission

4. 4 AIC Revenue Requirement Projected 2015 vs Projected 2016

5. 5 AIC 2016 PROJECTED RATE BASE Page.Line Jan-15Jan-16ChangePercent 2.6Total Gross Plant1,597,243,4721,938,342,678341,099,20621% 2.12Total Accum Depreciation480,701,771502,413,11621,711,3455% 2.18TOTAL NET PLANT1,116,541,7011,435,929,562319,387,86029% 2.18a100% CWIP RECOVERY27,739,70542,507,01814,767,31353% ADJUSTMENTS TO RATE BASE0N/A 2.20 Account No. 282-285,677,648-368,700,067-83,022,41929% 2.21 Account No. 283-25,147,591-6,071,75619,075,835-76% 2.22 Account No. 19038,348,09741,586,3963,238,2998% 2.23 Account No. 255000N/A 2.25 Land Held for Future Use1,209,9082,363,8681,153,96095% 2.26 CWC5,525,5845,834,598309,0146% 2.27 Materials & Supplies10,110,43312,101,1991,990,76620% 2.28 Prepayments1,538,0831,491,166-46,917-3% TOTAL ADJUSTMENTS-254,093,135-311,394,596-57,301,46223% 2.30TOTAL RATE BASE890,188,2721,167,041,984276,853,71231%

6. 6 AIC 2016 PROJECTED EXPENSES Page.Line Jan-15Jan-16ChangePercent O&M 3.1 Transmission41,012,81447,078,2806,065,46615% 3.1a Less LSE Expenses1,685,3831,495,616-189,767-11% 3.2 Less Account 5659,206,19313,231,0754,024,88244% 3.3 A&G14,085,79214,176,89091,0981% 3.4 Less FERC Annual Fees000N/A 3.5 Less EPRI, ect.356,844362,5665,7222% 3.5a Plus Trans. Reg. Comm. Exp354,483510,870156,38644% 3.8TOTAL O&M44,204,67046,676,7832,472,1146% 3.12TOTAL DEPRECIATION28,851,74035,645,2276,793,48724% TAXES 3.13 Payroll944,247892,102-52,145-6% 3.16 Property1,132,0361,216,55484,5177% 3.18 Other378,748421,92643,17811% 3.27 Income Taxes39,706,38850,317,51010,611,12227% TOTAL TAXES42,161,41952,848,09110,686,67225% TOTAL EXPENSES115,217,829135,170,10219,952,27317%

7. 7 AIC 2016 PROJECTED CAPITAL STRUCTURE Capital Structure - 2015 Projection Page.Line $%CostWeighted 4.27 Long Term Debt2,210,270,31444.9%0.05940.0267 4.28 Preferred Stock61,721,3501.3%0.04900.0006 4.29 Common Stock2,646,273,82153.8%0.12380.0666 4.3Total4,918,265,485100.0%0.0939 Capital Structure - 2016 Projection Page.Line $%CostWeighted 4.27 Long Term Debt2,436,021,67046.9%0.05700.0267 4.28 Preferred Stock61,721,3501.2%0.04900.0006 4.29 Common Stock2,698,856,34851.9%0.12380.0643 4.3Total5,196,599,368100.0%0.0916 Change in Return-0.2323%

8. 8 AIC 2016 PROJECTED TOTAL REVENUE REQUIREMENT Page.Line Jan-15Jan-16ChangePercent 2.30TOTAL RATE BASE890,188,2721,167,041,984276,853,71231% 4.30Rate of Return9.39%9.16%-0.23%-2% 3.28Return83,616,156106,909,86723,293,71128% Total Expenses115,217,829135,170,10219,952,27317% 3.29TOTAL GROSS REV. REQ.198,833,985242,079,96943,245,98422% 3.30Less ATT. GG Adjustment10,174,12914,763,9744,589,84545% 3.30aLess ATT. MM Adjustment5,684,13111,937,0116,252,879110% 3.31GROSS REV. REQ. UNDER ATT. O182,975,725215,378,98532,403,26018%

9. 9 AIC 2016 PROJECTED TRUE UP & NET REVENUE REQUIREMENT Page.Line Jan-15Jan-16ChangePercent 1.1Gross Revenue Requirement182,975,725215,378,98532,403,26018% 1.6Total Revenue Credits12,163,78113,373,3021,209,52110% 1.6aHistoric Year Actual ATRR123,689,426153,102,51229,413,08624% 1.6bProjected ATRR from Prior Year133,507,911143,000,9249,493,0137% 1.6cPrior Year ATRR True-Up-9,818,48510,101,58819,920,073-203% 1.6dPrior Year Divisor True-Up-822,872-3,254,838-2,431,966296% 1.6eInterest on Prior Year True-Up-691,60343,217734,820-106% 1.7aNET REVENUE REQUIREMENT159,478,984208,895,64949,416,66531% 1.7bPrairie Power000N/A 1.7AIC Adjusted Revenue Requirement159,478,984208,895,64949,416,66531%

10. 10 AIC 2014 ATTACHMENT O TRUE UP Ameren Illinois Company - AIC Attachment O Revenue Requirement True-Up Year Ended December 31, 2014 Attachment O Net Actual Revenue Requirement (2014 Actual Attachment O, Pg 1, Line 7a) $ 153,102,512 Net Projected Revenue Requirement (2014 Projected Attachment O, Pg 1, Line 7a) $ 143,000,924 Under/(Over) Recovery of Net Revenue Requirement $ 10,101,588 Historic Year Actual Divisor for Pricing Zone (2014 Actual Attachment O, Pg 1, Line 15) 7,205,351 Projected Year Divisor for Pricing Zone (2014 Projected Attachment O, Pg 1, Line 15) 7,045,000 Difference between Historic & Projected Yr Divisor 160,351 Prior Year Projected Annual Cost ($ per kw per yr) $ 20.2982 Prior Year Under/(Over) Divisor True-up $ (3,254,838) Total Under/(Over) Recovery $ 6,846,750 Monthly Interest Rate (updated through July, 2015)0.0263% Interest For 24 Months $ 43,217 Total Under/(Over) Recovery Including Interest $ 6,889,966

11. 11 AIC 2016 PROJECTED ATTACHMENT GG AIC Attachment GG Calculation - Page 1 (1)(2)(3)(4) Attachment O LinePage, Line, Col.TransmissionAllocator No. 1Gross Transmission Plant - TotalAttach O, p 2, line 2 col 5 (Note A)1,917,040,601 2Net Transmission Plant - TotalAttach O, p 2, line 14 and 23b col 5 (Note B) 1,436,058,340 O&M EXPENSE 3Total O&M Allocated to TransmissionAttach O, p 3, line 8 col 546,676,783 4Annual Allocation Factor for O&M(line 3 divided by line 1 col 3)2.43% GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE 5Total G&C Depreciation ExpenseAttach O, p 3, lines 10 & 11, col 5 (Note H)4,409,668 6Annual Allocation Factor for G&C Depreciation Expense(line 5 divided by line 1 col 3)0.23% TAXES OTHER THAN INCOME TAXES 7Total Other TaxesAttach O, p 3, line 20 col 52,530,581 8Annual Allocation Factor for Other Taxes(line 7 divided by line 1 col 3)0.13% 9Annual Allocation Factor for ExpenseSum of line 4, 6, and 82.80% INCOME TAXES 10Total Income TaxesAttach O, p 3, line 27 col 550,317,510 11Annual Allocation Factor for Income Taxes(line 10 divided by line 2 col 3)3.50% RETURN 12Return on Rate BaseAttach O, p 3, line 28 col 5106,909,867 13Annual Allocation Factor for Return on Rate Base(line 12 divided by line 2 col 3)7.44% 14Annual Allocation Factor for ReturnSum of line 11 and 1310.95%

12. 12 AIC 2016 PROJECTED ATTACHMENT GG AIC Attachment GG Calculation - Page 2 (1)(2)(3)(4)(5)(6) Line No. Project Name MTEP Project Number Project Gross Plant Annual Allocation Factor for Expense Annual Expense ChargeProject Net Plant (Note C)(Page 1 line 9)(Col. 3 * Col. 4)(Note D) 1aWood River-Roxford 1502 138kV line728 $ 3,424,4872.80%$95,778.27 $ 2,941,428 1bSidney-Paxton 138kV Reconductor 18 miles870 $ 5,994,4792.80%$167,657.47 $ 5,095,420 1cCoffeen Plant-Coffeen, North - 2nd. Bus tie2829 $ 5,592,5582.80%$156,416.28 $ 5,046,129 1dLatham - Oreana 8.5 mile 345kV line2068 $ 23,567,2312.80%$659,143.57 $ 22,559,921 1eBrokaw - South Bloomington 345/138kV Transformer & line extension2069 $ 29,776,0422.80%$832,795.62 $ 29,271,494 1fFargo-Mapleridge-20 mile 345kV line & New Sub2472 $ 30,285,9672.80%$847,057.53 $ 30,149,872 (1)(2)(7)(8)(9)(10)(11)(12) Line No. Project Name MTEP Project Number Annual Allocation Factor for Return Annual Return Charge Project Depreciation Expense Annual Revenue Requirement True-Up Adjustment Network Upgrade Charge (Page 1 line 14)(Col. 6 * Col. 7)(Note E)(Sum Col. 5, 8 & 9)(Note F) Sum Col. 10 & 11 (Note G) 1aWood River-Roxford 1502 138kV line72810.95%$322,043.33$52,500$470,321.60 $ (20,657)449,665 1bSidney-Paxton 138kV Reconductor 18 miles87010.95%$557,873.94$99,720$825,251.41 $ (45,173)780,078 1cCoffeen Plant-Coffeen, North - 2nd. Bus tie282910.95%$552,477.30$98,904$807,797.58 $ (2,536)805,262 1dLatham - Oreana 8.5 mile 345kV line206810.95%$2,469,981.27$398,220$3,527,344.85 $ 262,8693,790,214 1eBrokaw - South Bloomington 345/138kV Transformer & line extension206910.95%$3,204,800.32$477,312$4,514,907.94 $ -4,514,908 1fFargo-Mapleridge-20 mile 345kV line & New Sub247210.95%$3,300,969.87$470,323$4,618,350.76 $ -4,618,351 2Annual Totals$14,763,974$194,503$14,958,477 3Rev. Req. Adj For Attachment O$14,763,974

13. 13 AIC 2014 ATTACHMENT GG TRUE-UP AIC 2014 Attachment GG True Up (a)(b)(c)(d)(e)(f)(g)(h)(i)(j)(k) Actual ProjectedAttachment GGActualTrue-UpApplicableTrue-Up MTEPActualAnnualRevenuesAnnualAdjustmentInterestAdjustmentTotal LineProject Attachment GGRevenueAllocatedRevenuePrincipalRate onInterestTrue-Up No.NameNumberRevenuesRequirement 1 to Projects 1 Requirement 1 Under/(Over) Adjustment Projected[Col. (d), line 1Actual Attachment GGx (Col. (e), line 2x /Attachment GGCol. (h) x Col. (i) p 2 of 2, Col. 10 2 Col. (e), line 3)] 2 p 2 of 2, Col. 10 2 Col. (g) - Col. (f)Line 5x 24 months 2 Col. (h) + Col. (j) 1 Actual Attachment GG revenues for True-Up Year 1 $ 5,755,759 2aWood River-Roxford 1502 138kV line728 527,494 545,315 524,788 (20,527)0.0263% (130) (20,657) 2bSidney-Paxton 138kV Reconductor 18 miles870 935,340 966,939 922,049 (44,890)0.0263% (283) (45,173) 2cCoffeen Plant-Coffeen, North - 2nd. Bus tie2829 873,483 902,993 900,473 (2,520)0.0263% (16) (2,536) 2dLatham - Oreana 8.5 mile 345kV line2068 3,231,345 3,340,512 3,601,732 261,2200.0263% 1,649 262,869 2eBrokaw-S. Bloom 345/138kV Trans & 345kV line2069 - - - -0.0263% - - 2fFargo-Mapleridge-20 mile 345kV line & New Sub2472 - - - -0.0263% - - 3Subtotal $ 5,567,662 $ 5,755,759 $ 5,949,042 4Under/(Over) Recovery $ 193,283 $ 1,220 $ 194,503 5Applicable Interest rate per month (expressed to four decimal places)Interest Rate updated through July 20150.0263% 1 Amount excludes True-Up Adjustment, as reported in True-Up Year projected Attachment GG, page 2, column 11. 2 Rounded to whole dollars.

14. 14 AIC 2016 PROJECTED ATTACHMENT MM AIC Attachment MM Calculation - Page 1 (1)(2)(3)(4) Attachment O LinePage, Line, Col.TransmissionAllocator No. 1Gross Transmission Plant - TotalAttach O, p 2, line 2 col 5 (Note A) 1,917,040,601 1aTransmission Accumulated DepreciationAttach O, p 2, line 8 col 5 480,982,260 2Net Transmission Plant - TotalLine 1 minus Line 1a (Note B) 1,436,058,340 O&M TRANSMISSION EXPENSE 3Total O&M Allocated to TransmissionAttach O, p 3, line 8 col 5 46,676,783 3aTransmission O&MAttach O, p 3, line 1 col 5 47,078,280 3bLess: LSE Expenses included in above, if anyAttach O, p 3, line 1a col 5, if any 1,495,616 3cLess: Account 565 included in above, if anyAttach O, p 3, line 2 col 5, if any 13,231,075 3dAdjusted Transmission O&MLine 3a minus Line 3b minus Line 3c 32,351,589 4Annual Allocation Factor for Transmission O&M(Line 3d divided by line 1a, col 3)6.73% OTHER O&M EXPENSE 4aOther O&M Allocated to TransmissionLine 3 minus Line 3d 14,325,194 4bAnnual Allocation Factor for Other O&MLine 4a divided by Line 1, col 30.75% GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE 5Total G&C Depreciation ExpenseAttach O, p 3, lines 10 & 11, col 5 (Note H) 4,409,668 6Annual Allocation Factor for G&C Depreciation Expense(line 5 divided by line 1 col 3)0.23% TAXES OTHER THAN INCOME TAXES 7Total Other TaxesAttach O, p 3, line 20 col 5 2,530,581 8Annual Allocation Factor for Other Taxes(line 7 divided by line 1 col 3)0.13% 9Annual Allocation Factor for Other ExpenseSum of line 4b, 6, and 81.11% INCOME TAXES 10Total Income TaxesAttach O, p 3, line 27 col 5 50,317,510 11Annual Allocation Factor for Income Taxes(line 10 divided by line 2 col 3)3.50% RETURN 12Return on Rate BaseAttach O, p 3, line 28 col 5 106,909,867 13Annual Allocation Factor for Return on Rate Base(line 12 divided by line 2 col 3)7.44% 14Annual Allocation Factor for ReturnSum of line 11 and 1310.95%

15. 15 AIC 2016 PROJECTED ATTACHMENT MM AIC Attachment MM Calculation - Page 2 (1)(2)(3)(4)(5)(6)(7)(8) Line No. Project Name MTEP Project Number Project Gross Plant Project Accumulated Depreciation Transmission O&M Annual Allocation Factor Annual Allocation for Transmission O&M Expense Other Expense Annual Allocation Factor Annual Allocation for Other Expense (Note C) Page 1 line 4(Col 4 * Col 5)Page 1 line 9(Col 3 * Col 7) Multi-Value Projects (MVP) 1aPana-Sugar Creek - CWIP2237 $ 18,938,437 $ -6.73% $ -1.11% $ 210,081 1b Pana-Sugar Creek - Plant in Service2237 $ 20,602,126 $ 190,7246.73% $ 12,8281.11% $ 228,536 1c Pana-Sugar Creek - Land2237 $ 15,627 $ -6.73% $ -1.11% $ 173 1dSidney-Rising - CWIP2239 $ 301,094 $ -6.73% $ -1.11% $ 3,340 1e Sidney-Rising - Plant in Service2239 $ 5,981,345 $ 63,7706.73% $ 4,2891.11% $ 66,350 1fPalmyra-Pawnee - CWIP3017 $ 14,184,258 $ -6.73% $ -1.11% $ 157,344 1g Palmyra-Pawnee - Plant in Service3017 $ 17,212,417 $ 337,9186.73% $ 22,7291.11% $ 190,935 1hFargo-Galesburg-Oak Grove - CWIP3022 $ 204,390 $ -6.73% $ -1.11% $ 2,267 1i Fargo-Galesburg-Oak Grove - Plant in Service3022 $ 3,184,794 $ 30,9236.73% $ 2,0801.11% $ 35,328 1jPawnee-Pana - CWIP3169 $ 8,878,841 $ -6.73% $ -1.11% $ 98,492 1k Pawnee-Pana - Plant in Service3169 $ 3,406,077 $ 12,2046.73% $ 8211.11% $ 37,783 (1)(2)(9)(10)(11)(12)(13)(14)(15)(16) Line No. Project Name MTEP Project Number Annual Expense Charge Project Net Plant Annual Allocation Factor for Return Annual Return Charge Project Depreciation Expense Annual Revenue Requirement True-Up Adjustment MVP Annual Adjusted Revenue Requirement (Col 6 + Col 8)(Col 3 - Col 4)(Page 1 line 14)(Col 10 * Col 11)(Note E) (Sum Col. 9, 12 & 13)(Note F) Sum Col. 14 & 15 (Note G) Multi-Value Projects (MVP) 1aPana-Sugar Creek - CWIP2237 $ 210,081 $ 18,938,43710.95% $ 2,073,482 $ - $ 2,283,563 $ 102,017 $ 2,385,580 1b Pana-Sugar Creek - Plant in Service2237 $ 241,365 $ 20,411,40110.95% $ 2,234,750 $ 315,008 $ 2,791,122 $ 4,466 $ 2,795,588 1c Pana-Sugar Creek - Land2237 $ 173 $ 15,62710.95% $ 1,711 $ - $ 1,884 $ 1,527 $ 3,411 1dSidney-Rising - CWIP2239 $ 3,340 $ 301,09410.95% $ 32,965 $ - $ 36,305 $ 12,200 $ 48,505 1e Sidney-Rising - Plant in Service2239 $ 70,639 $ 5,917,57510.95% $ 647,888 $ 107,339 $ 825,866 $ - $ 825,866 1fPalmyra-Pawnee - CWIP3017 $ 157,344 $ 14,184,25810.95% $ 1,552,969 $ - $ 1,710,313 $ 829,982 $ 2,540,295 1g Palmyra-Pawnee - Plant in Service3017 $ 213,664 $ 16,874,49810.95% $ 1,847,511 $ 243,379 $ 2,304,553 $ 263,842 $ 2,568,395 1hFargo-Galesburg-Oak Grove - CWIP3022 $ 2,267 $ 204,39010.95% $ 22,378 $ - $ 24,645 $ 9 $ 24,654 1i Fargo-Galesburg-Oak Grove - Plant in Service3022 $ 37,408 $ 3,153,87210.95% $ 345,303 $ 43,748 $ 426,459 $ - $ 426,459 1jPawnee-Pana - CWIP3169 $ 98,492 $ 8,878,84110.95% $ 972,103 $ - $ 1,070,595 $ 3,177 $ 1,073,772 1k Pawnee-Pana - Plant in Service3169 $ 38,604 $ 3,393,87410.95% $ 371,580 $ 51,521 $ 461,704 $ - $ 461,704 2MVP Total Annual Revenue Requirements$11,937,011$1,217,220$13,154,231 3Rev. Req. Adj For Attachment O$11,937,011

16. 16 AIC 2014 ATTACHMENT MM TRUE-UP AIC 2014 Attachment MM True Up (a)(b)(c)(d)(e)(f)(g)(h)(i)(j)(k) Actual ProjectedAttachment MMActualTrue-UpApplicableTrue-Up MTEPActualAnnualRevenuesAnnualAdjustmentInterestAdjustmentTotal LineProject Attachment MMRevenueAllocatedRevenuePrincipalRate onInterestTrue-Up No.NameNumberRevenuesRequirement 1 to Projects 1 Requirement 1 Under/(Over) Adjustment Projected[Col. (d), line 1Actual Attachment MMx (Col. (e), line 2x /Attachment MMCol. (h) x Col. (i) p 2 of 2, Col. 14 2 Col. (e), line 3)] 2 p 2 of 2, Col. 14 2 Col. (g) - Col. (f)Line 5x 24 months 2 Col. (h) + Col. (j) 1 Actual Attachment MM revenues for True-Up Year 1 $ - 2aPana-Sugar Creek - CWIP2237 - - 101,377 0.0263% 640 102,017 2bPana-Sugar Creek - Plant in Service2237 - - 4,438 0.0263% 28 4,466 2cPana-Sugar Creek - Land2237 - - 1,517 0.0263% 10 1,527 2dSidney-Rising - CWIP2239 - - 12,123 0.0263% 77 12,200 2eSidney-Rising - Plant in Service2239 - - - -0.0263% - - 2fPalmyra-Pawnee - CWIP3017 - - 824,776 0.0263% 5,206 829,982 2gPalmyra-Pawnee - Plant in Service3017 - - 262,187 0.0263% 1,655 263,842 2hFargo-Galesburg-Oak Grove - CWIP3022 - - 9 90.0263% - 9 2iFargo-Galesburg-Oak Grove - Plant3022 - - - -0.0263% - - 2jPawnee-Pana - CWIP3169 - - 3,157 0.0263% 20 3,177 2kPawnee-Pana - Plant in Service3169 - - - -0.0263% - - 3Subtotal $ - $ 1,209,584 4Under/(Over) Recovery $ 1,209,584 $ 7,636 $ 1,217,220 5Applicable Interest rate per month (expressed to four decimal places)Interest Rate updated through July 20150.0263% 1 Amount excludes True-Up Adjustment, as reported in True-Up Year projected Attachment MM, page 2, column 15. 2 Rounded to whole dollars.

17. 17 AMIL PRICING ZONE SCHEDULE 9 CHARGE Page.Line Jan-15Jan-16ChangePercent 1.7AIC Adjusted Revenue Requirement159,478,984208,895,64949,416,66531% 1.7ATXI Adjusted Revenue Requirement9,851,5948,495,791-1,355,803-14% 1.7PPI Adjusted Revenue Requirement *3,863,0364,421,778558,74214% Total Revenue Requirement173,193,614221,813,21848,619,60428% 1.15Ameren Illinois Divisor7,095,3357,118,19722,8610%.Annual Cost ($/kW/Yr)24.41031.1616.75228%.Network & P-to-P Rate ($/kW/Mo)2.0342.5970.56328% * PPI uses a historical Attachment O which is updated June 1 st each year. The amount shown for 2015 is the ATRR revised in effective 6/1/14. The amount shown for 2016 is the ATRR effective 6/1/15. PPI has filed at FERC to begin using forward looking Attachment O effective 1/1/16. However, the new ATRR is not posted yet.

18. 18 AIC 2016 PROJECTED MVP SPEND Ameren MVPs Ameren Name2016 CAPEXMTEP #sMTEP Description Illinois Rivers$53.1 million 2237Pana - Mt. Zion - Kansas - Sugar Creek 345 kV line 2239Sidney to Rising 345 kV line 3017Palmyra-Quincy-Meredosia - Ipava & Meredosia-Pawnee 345 kV Line 3169Pawnee to Pana - 345 kV Line Spoon River$.9 million 3022Fargo-Galesburg-Oak Grove 345 kV Line

19. 19 2016 PROJECTED SIGNIFICANT TRANSMISSION PROJECTS Project NameTotal Cost Illinois Rivers$68.0 Fargo - Mapleridge$56.4 Pinckneyville - West Frankfort$16.6 Grand Tower - Makanda$15.8 Cahokia - Buck Knob$13.4 Sidney - Bunsonville$12.0 Macomb West Tap$11.7 Brokaw - Gibson City$9.6 Jacksonville NW - Meredosia$8.0 Keemin Substation$7.4 Effingham - Neoga S.$6.7 Baldwin - Prairie State$6.0 Madison Industrial - Madison State$5.8 S. Belleville - Tilden$5.3 Gibson City - Paxton$5.1

20. QUESTIONS?

21. 21 Appendix Supplemental Background Information (Not covered during presentation)

22. 22 APPENDIX – AMIL PRICING ZONE Both AIC and ATXI are transmission owning subsidiaries of Ameren Corporation, as well as a MISO Transmission Owners (TOs) AIC will continue to build and own traditional reliability projects ATXI is in the process of building and will own new regional transmission projects Prairie Power, Inc. became a TO in the AMIL pricing zone effective June 1, 2013. The sum of all there Attachment O net revenue requirements equals the total revenue requirement for AMIL pricing zone to be collected under Schedule 9 (NITS)

23. 23 APPENDIX - MISO ATTACHMENTS O, GG & MM Calculate rates for Schedules 9, 26 & 26-A Attachment GG - Schedule 26 Attachment MM - Schedule 26-A Attachment O - net revenue requirement billed under Schedule 9 Schedules 26 and 26-A are billed by MISO Schedule 9 is billed by Ameren

24. 24 APPENDIX - MISO ATTACHMENT GG Cost Recovery for certain Network Upgrades Eligible projects Market Efficiency Generator Interconnections Cost shared based upon project type MISO-wide based on load Subregional based on LODF (Line Outage Distribution Factor) AIC has four Attachment GG projects completed One additional project is under construction These projects were approved by MISO under prior Tariff provisions which allowed limited cost sharing for certain reliability projects

25. 25 APPENDIX - MISO ATTACHMENT MM Cost recovery for Multi-Value Projects (MVPs) Very similar format as Attachment GG Criteria for being considered Developed through planning process and support energy policy Multiple types of economic value across multiple pricing zones with benefit to costs > 1 Address at least one: Projected NERC violation Economic-based issue Cost shared across MISO based on load AMIL Zone is approximately 9% Ameren MVPs will primarily be built by ATXI AIC will be responsible for modifications needed to its existing facilities

26. 26 APPENDIX - MISO ATTACHMENT O, GG & MM All transmission costs included in Attachment O calculation Schedule 9 based on net revenue requirement – reductions for: Costs recovered in Schedules 26 & 26-A Revenue Credits Point-to-Point revenue in Schedules 7 & 8 Rental revenue Revenue from generator interconnections

27. 27 APPENDIX - MISO TRANSMISSION EXPANSION PLAN (MTEP) Developed on an annual basis building upon previous analysis MISO, Transmission Owners & Stakeholders Includes subregional planning meetings MTEP goals Ensure the reliability of the transmission system Ensure compliance with NERC Standards Provide economic benefits, such as increased market efficiency Facilitate public policy objectives, such as meeting Renewable Portfolio Standards Address other issues or goals identified through the stakeholder process Multiple future scenarios analyzed End result – comprehensive, cohesive plan for MISO footprint MTEP approved by MISO Board of Directors

28. 28 MISO MVPS Brief history of development Began investigating value added expansion in 2003 2008 Regional Generation Outlet Study (RGOS) - formed basis of Candidate MVP portfolio Portfolio refined due to additional analysis MISO approved portfolio of 17 Projects Seven transmission line segments (MTEP proj numbers) in Ameren territory Ameren identifies these three projects as: Illinois Rivers (four line segments) Spoon River Mark Twain (two line segments) Broadly cost-shared, AMIL pricing zone allocated 9% of each MVP no matter where project is located or who builds it

29. 29 APPENDIX - MAP OF AMEREN MVPS

30. 30 APPENDIX - RATE INCENTIVES FERC approved the following rate incentives for Illinois Rivers in Docket No. EL10-80 –CWIP (no AFUDC) –Abandonment (requires additional filing prior to recovery) –Hypothetical capital structure during construction for ATXI FERC approved similar incentives for Spoon River and Mark Twain Projects in Docket No. ER12-2216

31. 31 APPENDIX - MISO WEB LINKS Transmission Pricing - Attachments O, GG & MM Information https://www.misoenergy.org/MarketsOperations/TransmissionSettlement s/Pages/TransmissionPricing.aspxhttps://www.misoenergy.org/MarketsOperations/TransmissionSettlement s/Pages/TransmissionPricing.aspx Ameren OASIS http://www.oasis.oati.com/AMRN/index.html MTEP 15 https://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEP15.aspxhttps://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEP15.aspx Schedule 26 & 26-A Indicative Charges https://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEPStudies.aspxhttps://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEPStudies.aspx

32. 32 APPENDIX – AIC Additional questions on these topics can be sent to Ameren at: –MISOFormulaRates@ameren.com