1. 2014 Attachment O True-Up Stakeholder Meeting Ameren Illinois Company July 29, 2015

2. 2 AGENDA Main Purpose is to review AIC 2014 Transmission Rate True-Up Calculations Timeline AIC 2014 True Up 2014 AMIL Pricing Zone NITS Charge An additional meeting will be held in October to review the 2016 Projected Transmission Rate calculations.

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 2014 vs Actual 2014

5. 5 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 (Attachment O, Pg 1, Line 7a) $153,084,880 Net Projected Revenue Requirement (2014 Projected Attachment O, Pg 1, Line 7a) $143,000,924 Under/(Over) Recovery of Net Revenue Requirement $10,083,956 Historic Year Actual Divisor for Pricing Zone (Attachment O, Pg 1, Line 15) 7,205,351 Projected Year Divisor for Pricing Zone (2014 Projected Attachment O, Pg 1, Line 15) 7,045,000 Difference between Historic & Projected Yr Divisor 160,351 Prior Year Projected Annual Cost ($ per kw per yr) $20.2982 Prior Year Under/(Over) Divisor True-up $(3,254,838) Total Under/(Over) Recovery $6,829,118 Monthly Interest Rate (to be updated through July, 2015)0.0265% Interest For 24 Months $43,433 Total Under/(Over) Recovery Including Interest $6,872,551 (Amount to be included in Projected 2016 Attachment O)

6. 6 AIC 2014 RATE BASE Page.Line 2014 Projection2014 ActualChangePercent 2.6Total Gross Plant1,327,622,0181,366,240,97438,618,9563% 2.12Total Accum Depreciation465,639,921459,871,993-5,767,928-1% 2.18TOTAL NET PLANT861,982,097906,368,98144,386,8845% 2.18a100% CWIP RECOVERY07,301,137 N/A ADJUSTMENTS TO RATE BASE0N/A 2.20 Account No. 282-229,080,460-248,516,533-19,436,0738% 2.21 Account No. 283-17,757,369-6,008,72911,748,639-66% 2.22 Account No. 19040,041,06235,690,801-4,350,262-11% 2.23 Account No. 255000N/A 2.25 Land Held for Future Use425,0402,363,8671,938,827456% 2.26 CWC4,767,0795,276,084509,00411% 2.27 Materials & Supplies8,000,23811,405,0513,404,81343% 2.28 Prepayments1,049,4811,469,725420,24540% TOTAL ADJUSTMENTS-192,554,928-198,319,736-5,764,8073% 2.30TOTAL RATE BASE669,427,168715,350,38245,923,2147%

7. 7 AIC 2014 EXPENSES Page.Line 2014 Projection2014 ActualChangePercent O&M 3.1 Transmission42,031,09344,551,8392,520,7466% 3.1a Less LSE Expenses2,577,0541,495,616-1,081,438-42% 3.2 Less Account 56513,190,16014,086,181896,0217% 3.3 A&G12,184,79513,067,946883,1527% 3.4 Less FERC Annual Fees000N/A 3.5 Less EPRI, ect.408,626338,476-70,150-17% 3.5a Plus Trans. Reg. Comm. Exp96,587509,156412,569427% 3.8TOTAL O&M38,136,63542,208,6684,072,03311% 3.12TOTAL DEPRECIATION22,612,54524,585,1121,972,5679% TAXES0N/A 3.13 Payroll894,566747,864-146,701-16% 3.16 Property1,048,910861,889-187,021-18% 3.18 Other388,574304,307-84,266-22% 3.27 Income Taxes31,970,51635,087,8153,117,29910% TOTAL TAXES34,302,56637,001,8762,699,3108% TOTAL EXPENSES95,051,746103,795,6568,743,9109%

8. 8 AIC 2014 CAPITAL STRCUTURE Capital Structure - 2014 Projection Page.Line $%CostWeighted 4.27 Long Term Debt1,972,228,23943%0.06150.0267 4.28 Preferred Stock61,721,3501%0.04900.0007 4.29 Common Stock2,508,477,41755%0.12380.0684 4.3Total4,542,427,006100%0.0957 Capital Structure - 2014 Actual Page.Line $%CostWeighted 4.27 Long Term Debt1,850,078,81642%0.05670.0238 4.28 Preferred Stock61,632,3751%0.04910.0007 4.29 Common Stock2,484,591,82357%0.12380.0700 4.3Total4,396,303,014100%0.0945 Change in Return-0.1217%

9. 9 AIC 2014 TOTAL REVENUE REQUIREMENT Page.Line 2014 Projection2014 ActualChangePercent 2.30TOTAL RATE BASE669,427,168715,350,38245,923,2147% 4.30Rate of Return9.57%9.45%-0.12%-1% 3.28Return64,074,87467,599,5323,524,6586% Total Expenses95,051,746103,795,6568,743,9109% 3.29TOTAL GROSS REV. REQ.159,126,620171,395,18812,268,5688% 3.30Less ATT. GG Adjustment5,567,6625,966,673399,0117% 3.30aLess ATT. MM Adjustment01,209,584 N/A 3.31GROSS REV. REQ. UNDER ATT. O153,558,958164,218,93110,659,9737%

10. 10 AIC 2014 TRUE UP & NET REVENUE REQUIREMENT * AIC did not use a projected calculation in 2012, so there is no prior year True-up included in 2014. Page.Line 2014 Projection2014 ActualChangePercent 1.1Gross Revenue Requirement153,558,958164,218,93110,659,9737% 1.6Total Revenue Credits10,558,03411,134,050576,0165% 1.6aHistoric Year Actual ATRR *000N/A 1.6bProjected ATRR from Prior Year000N/A 1.6cPrior Year ATRR True-Up000N/A 1.6dPrior Year Divisor True-Up000N/A 1.6eInterest on Prior Year True-Up000N/A 1.7aNET REVENUE REQUIREMENT143,000,924153,084,88010,083,9567% 1.7bPrairie Power000N/A 1.7AIC Adjusted Revenue Requirement143,000,924153,084,88010,083,9567%

11. 11 AIC 2014 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)1,329,522,359 2Net Transmission Plant - TotalAttach O, p 2, line 14 and 23b col 5 (Note B) 884,276,054 O&M EXPENSE 3Total O&M Allocated to TransmissionAttach O, p 3, line 8 col 542,208,668 4Annual Allocation Factor for O&M(line 3 divided by line 1 col 3)3.17% GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE 5Total G&C Depreciation ExpenseAttach O, p 3, lines 10 & 11, col 5 (Note H)1,890,002 6Annual Allocation Factor for G&C Depreciation Expense(line 5 divided by line 1 col 3)0.14% TAXES OTHER THAN INCOME TAXES 7Total Other TaxesAttach O, p 3, line 20 col 51,914,061 8Annual Allocation Factor for Other Taxes(line 7 divided by line 1 col 3)0.14% 9Annual Allocation Factor for ExpenseSum of line 4, 6, and 83.46% INCOME TAXES 10Total Income TaxesAttach O, p 3, line 27 col 535,087,815 11Annual Allocation Factor for Income Taxes(line 10 divided by line 2 col 3)3.97% RETURN 12Return on Rate BaseAttach O, p 3, line 28 col 567,599,532 13Annual Allocation Factor for Return on Rate Base(line 12 divided by line 2 col 3)7.64% 14Annual Allocation Factor for ReturnSum of line 11 and 1311.61%

12. 12 AIC 2014 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 $ 3,424,4873.46%$118,516.25 $ 3,046,429 1bSidney-Paxton 138kV Reconductor 18 miles870 $ 5,994,4793.46%$207,459.73 $ 5,294,859 1cCoffeen Plant-Coffeen, North - 2nd. Bus tie2829 $ 5,592,5583.46%$193,549.86 $ 5,243,540 1dLatham - Oreana 8.5 mile 345kV line2068 $ 21,649,0513.46%$749,240.47 $ 21,431,303 1eBrokaw-S. Bloom 345/138kV Trans & 345kV line2069 $ 106,6833.46%$3,692.13 $ 106,522 1fFargo-Mapleridge-20 mile 345kV line & New Sub2472 $ -3.46%$0.00 $ - (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 line72811.61%$353,769$52,502$524,788 $ -524,788 1bSidney-Paxton 138kV Reconductor 18 miles87011.61%$614,870$99,719$922,049 $ -922,049 1cCoffeen Plant-Coffeen, North - 2nd. Bus tie282911.61%$608,911$98,012$900,473 $ -900,473 1dLatham - Oreana 8.5 mile 345kV line206811.61%$2,488,729$363,763$3,601,732 $ -3,601,732 1eBrokaw-S. Bloom 345/138kV Trans & 345kV line206911.61%$12,370$1,570$17,632 $ -17,632 1fFargo-Mapleridge-20 mile 345kV line & New Sub247211.61%$0 $ -0 2Annual Totals$5,966,673$0$5,966,673 3Rev. Req. Adj For Attachment O$5,966,673

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 GG Col. (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)0.0265% (131) (20,658) 2bSidney-Paxton 138kV Reconductor 18 miles870 935,340 966,939 922,049 (44,890)0.0265% (286) (45,176) 2cCoffeen Plant-Coffeen, North - 2nd. Bus tie2829 873,483 902,993 900,473 (2,520)0.0265% (16) (2,536) 2dLatham - Oreana 8.5 mile 345kV line2068 3,231,345 3,340,512 3,601,732 261,2200.0265% 1,661 262,881 2eBrokaw-S. Bloom 345/138kV Trans & 345kV line2069 - - 17,632 0.0265% 112 17,744 2fFargo-Mapleridge-20 mile 345kV line & New Sub2472 - - - -0.0265% - - 3Subtotal $ 5,567,662 $ 5,755,759 $ 5,966,674 4Under/(Over) Recovery $ 210,915 $ 1,340 $ 212,255 5Applicable Interest rate per month (expressed to four decimal places)Interest Rate to be updated through July 20150.0265% 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 2014 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) 1,329,522,359 1aTransmission Accumulated DepreciationAttach O, p 2, line 8 col 5 445,246,305 2Net Transmission Plant - TotalLine 1 minus Line 1a (Note B) 884,276,054 O&M TRANSMISSION EXPENSE 3Total O&M Allocated to TransmissionAttach O, p 3, line 8 col 5 42,208,668 3aTransmission O&MAttach O, p 3, line 1 col 5 44,551,839 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 14,086,181 3dAdjusted Transmission O&MLine 3a minus Line 3b minus Line 3c 28,970,042 4Annual Allocation Factor for Transmission O&M(Line 3d divided by line 1a, col 3)6.51% OTHER O&M EXPENSE 4aOther O&M Allocated to TransmissionLine 3 minus Line 3d 13,238,626 4bAnnual Allocation Factor for Other O&MLine 4a divided by Line 1, col 31.00% GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE 5Total G&C Depreciation ExpenseAttach O, p 3, lines 10 & 11, col 5 (Note H) 1,890,002 6Annual Allocation Factor for G&C Depreciation Expense(line 5 divided by line 1 col 3)0.14% TAXES OTHER THAN INCOME TAXES 7Total Other TaxesAttach O, p 3, line 20 col 5 1,914,061 8Annual Allocation Factor for Other Taxes(line 7 divided by line 1 col 3)0.14% 9Annual Allocation Factor for Other ExpenseSum of line 4b, 6, and 81.28% INCOME TAXES 10Total Income TaxesAttach O, p 3, line 27 col 5 35,087,815 11Annual Allocation Factor for Income Taxes(line 10 divided by line 2 col 3)3.97% RETURN 12Return on Rate BaseAttach O, p 3, line 28 col 5 67,599,532 13Annual Allocation Factor for Return on Rate Base(line 12 divided by line 2 col 3)7.64% 14Annual Allocation Factor for ReturnSum of line 11 and 1311.61%

15. 15 AIC 2014 ATTACHMENT MM AIC Attachment MM Calculation - Page 2 (1)(2)(3)(4)(5)(6)(7)(8)(9) 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 Annual Expense Charge (Note C) Page 1 line 4(Col 4 * Col 5)Page 1 line 9(Col 3 * Col 7)(Col 6 + Col 8) Multi-Value Projects (MVP) 1aPana-Sugar Creek - CWIP2237 $ 786,204 $ -6.51% $ -1.28%$10,078.08 1b Pana-Sugar Creek - Plant in Service2237 $ 31,702 $ 276.51% $ 21.28%$406.38$408.14 1c Pana-Sugar Creek - Land2237 $ 11,763 $ -6.51% $ -1.28%$150.79 1dSidney-Rising - CWIP2239 $ 94,021 $ -6.51% $ -1.28%$1,205.22 1e Sidney-Rising - Plant in Service2239 $ - 6.51% $ -1.28%$0.00 1fPalmyra-Pawnee - CWIP3017 $ 6,396,360 $ -6.51% $ -1.28%$81,992.74 1g Palmyra-Pawnee - Plant in Service3017 $ 1,820,831 $ 2,8236.51% $ 1841.28%$23,340.61$23,524.31 1hFargo-Galesburg-Oak Grove - CWIP3022 $ 72 $ -6.51% $ -1.28%$0.92 1i Fargo-Galesburg-Oak Grove - Plant3022 $ - 6.51% $ -1.28%$0.00 1jPawnee-Pana - CWIP3169 $ 24,481 $ -6.51% $ -1.28%$313.81 1k Pawnee-Pana - Plant in Service3169 $ - 6.51% $ -1.28%$0.00

16. 16 AIC 2014 ATTACHMENT MM AIC Attachment MM Calculation - Page 2 (continued) (1)(2)(10)(11)(12)(13)(14)(15)(16) Line No. Project Name MTEP Project Number 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 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 $ 786,20411.61% $ 91,299 $ - $ 101,377 $ - $ 101,377 1b Pana-Sugar Creek - Plant in Service2237 $ 31,67511.61% $ 3,678 $ 352 $ 4,438 $ - $ 4,438 1c Pana-Sugar Creek - Land2237 $ 11,76311.61% $ 1,366 $ - $ 1,517 $ - $ 1,517 1dSidney-Rising - CWIP2239 $ 94,02111.61% $ 10,918 $ - $ 12,123 $ - $ 12,123 1e Sidney-Rising - Plant in Service2239 $ -11.61% $ - 1fPalmyra-Pawnee - CWIP3017 $ 6,396,36011.61% $ 742,783 $ - $ 824,776 $ - $ 824,776 1g Palmyra-Pawnee - Plant in Service3017 $ 1,818,00811.61% $ 211,118 $ 27,545 $ 262,187 $ - $ 262,187 1hFargo-Galesburg-Oak Grove - CWIP3022 $ 7211.61% $ 8 $ - $ 9 $ - $ 9 1i Fargo-Galesburg-Oak Grove - Plant3022 $ -11.61% $ - 1jPawnee-Pana - CWIP3169 $ 24,48111.61% $ 2,843 $ - $ 3,157 $ - $ 3,157 1k Pawnee-Pana - Plant in Service3169 $ -11.61% $ - 2MVP Total Annual Revenue Requirements$1,209,584$0$1,209,584 3Rev. Req. Adj For Attachment O$1,209,584

17. 17 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 0.0265% 645 102,022 2bPana-Sugar Creek - Plant in Service2237 - - 4,438 0.0265% 28 4,466 2cPana-Sugar Creek - Land2237 - - 1,517 0.0265% 10 1,527 2dSidney-Rising - CWIP2239 - - 12,123 0.0265% 77 12,200 2eSidney-Rising - Plant in Service2239 - - - - 0.0265% - - 2fPalmyra-Pawnee - CWIP3017 - - 824,776 0.0265% 5,246 830,022 2gPalmyra-Pawnee - Plant in Service3017 - - 262,187 0.0265% 1,668 263,855 2hFargo-Galesburg-Oak Grove - CWIP3022 - - 9 9 0.0265% - 9 2iFargo-Galesburg-Oak Grove - Plant3022 - - - - 0.0265% - - 2jPawnee-Pana - CWIP3169 - - 3,157 0.0265% 20 3,177 2kPawnee-Pana - Plant in Service3169 - - - - 0.0265% - - 3Subtotal $ - $ 1,209,584 4Under/(Over) Recovery $ 1,209,584 $ 7,694 $ 1,217,278 5Applicable Interest rate per month (expressed to four decimal places)Interest Rate to be updated through July 20150.0265% 1 Amount excludes True-Up Adjustment, as reported in True-Up Year projected Attachment MM, page 2, column 15. 2 Rounded to whole dollars.

18. 18 AIC 2014 MVP SPEND Ameren MVPs Ameren Name2014 CAPEXMTEP #sMTEP Description Illinois Rivers$16.07 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$0 million 3022Fargo-Galesburg-Oak Grove 345 kV Line

19. 19 2014 SIGNIFICANT TRANSMISSION PROJECTS ADDED TO PLANT Project NameTotal Cost Bondville Route 10$36.0 Various ROW projects$19.8 Various IL Rivers$12.3 East Quincy-Meredosia 2$11.7 Hennepin-Oglesby$10.9 Cahokia-Turkey Hill$10.8 Havana-Galesburg-Monmouth$9.2 East Quincy-Meredosia 1$9.1 ADM Decatur$7.4 Fogarty Substation$7.3 Salem West-Mt. Vernon West$6.1 Paxton - Rantoul$5.8

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 Two additional projects 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 14 https://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEP14.aspxhttps://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEP14.aspx 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