2015 Attachment O True-Up Stakeholder Meeting Ameren Illinois Company July 21, 2016

Agenda Main Purpose is to review AIC 2015 Transmission Rate True-Up Calculations Protocol Timeline 2015 True Up Calculation Total Revenue Requirement Comparison – Projected vs Actual Attachment O/Schedule 9 True-up Attachment GG Revenue Requirement and True-up Attachment MM Revenue Requirement and True-up 2015 MVP Spend 2015 Significant Projects Placed In Service ROE Complaint Cases An additional meeting will held to review the 2017 Projected Transmission Rate calculations. Tentatively set for September 29th.

(Forward-Looking Protocols) 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 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

AIC Revenue Requirement Comparison Projected 2015 vs Actual 2015

Aic 2015 rate base 2015 Projection 2015 Actual Change Percent 2.6 Page.Line 2015 Projection 2015 Actual Change Percent 2.6 Total Gross Plant 1,597,243,472 1,635,341,596 38,098,124 2% 2.12 Total Accum Depreciation 480,701,771 481,756,402 1,054,631 0% 2.18 TOTAL NET PLANT 1,116,541,701 1,153,585,194 37,043,493 3% 2.18a 100% CWIP RECOVERY 27,739,705 17,864,566 -9,875,139 -36% ADJUSTMENTS TO RATE BASE N/A 2.20 Account No. 282 -285,677,648 -321,604,974 -35,927,326 13% 2.21 Account No. 283 -25,147,591 -8,524,169 16,623,422 -66% 2.22 Account No. 190 38,348,097 49,575,090 11,226,993 29% 2.23 Account No. 255 2.25 Land Held for Future Use 1,209,908 2,363,867 1,153,959 95% 2.26 CWC 5,525,584 5,623,292 97,709 2.27 Materials & Supplies 10,110,433 13,610,312 3,499,879 35% 2.28 Prepayments 1,538,083 1,418,413 -119,670 -8% TOTAL ADJUSTMENTS -254,093,135 -257,538,168 -3,445,033 1% 2.30 TOTAL RATE BASE 890,188,272 913,911,592 23,723,320

Aic 2015 expenses 2015 Projection 2015 Actual Change Percent O&M 3.1 Page.Line 2015 Projection 2015 Actual Change Percent O&M 3.1 Transmission 41,012,814 50,366,858 9,354,044 23% 3.1a Less LSE Expenses 1,685,383 1,703,652 18,269 1% 3.2 Less Account 565 9,206,193 17,772,557 8,566,364 93% 3.3 A&G 14,085,792 13,712,338 -373,454 -3% 3.4 Less FERC Annual Fees N/A 3.5 Less EPRI, ect. 356,844 215,151 -141,693 -40% 3.5a Plus Trans. Reg. Comm. Exp 354,483 598,502 244,019 69% 3.8 TOTAL O&M 44,204,670 44,986,339 781,670 2% 3.12 TOTAL DEPRECIATION 28,851,740 29,977,494 1,125,754 4% TAXES 3.13 Payroll 944,247 678,096 -266,151 -28% 3.16 Property 1,132,036 1,087,748 -44,288 -4% 3.18 Other 378,748 496,575 117,827 31% 3.27 Income Taxes 39,706,388 39,463,856 -242,532 -1% TOTAL TAXES 42,161,419 41,726,275 -435,144 TOTAL EXPENSES 115,217,829 116,690,108 1,472,279

Capital Structure - 2015 Projection Capital Structure - 2015 Actual Aic 2015 Capital strUcture Capital Structure - 2015 Projection Page.Line $ % Cost Weighted 4.27 Long Term Debt 2,210,270,314 45% 0.0594 0.0267 4.28 Preferred Stock 61,721,350 1% 0.0490 0.0006 4.29 Common Stock 2,646,273,821 54% 0.1238 0.0666 4.3 Total 4,918,265,485 100% 0.0939 Capital Structure - 2015 Actual 2,248,152,769 47% 0.0586 0.0273 61,632,375 0.0491 2,509,537,810 52% 0.0645 4,819,322,955 0.0924 Change in Return -0.1501%

Aic 2015 total revenue requirement Page.Line 2015 Projection 2015 Actual Change Percent 2.30 TOTAL RATE BASE 890,188,272 913,911,592 23,723,320 3% 4.30 Rate of Return 9.39% 9.24% -0.15% -2% 3.28 Return 83,616,156 84,472,987 856,831 1% Total Expenses 115,217,829 116,690,108 1,472,279 3.29 TOTAL GROSS REV. REQ. 198,833,985 201,163,095 2,329,110 3.30 Less ATT. GG Adjustment 10,174,129 8,399,463 -1,774,666 -17% 3.30a Less ATT. MM Adjustment 5,684,131 4,587,095 -1,097,036 -19% 3.31 GROSS REV. REQ. UNDER ATT. O 182,975,725 188,176,537 5,200,812

Aic 2015 Net revenue requirement for Schedule 9 Page.Line 2015 Projection 2015 Actual Change Percent 1.1 Gross Revenue Requirement 182,975,725 188,176,537 5,200,812 3% 1.6 Total Revenue Credits 12,163,781 11,262,034 -901,747 -7% 1.6a Historic Year Actual ATRR 123,689,426 0% 1.6b Projected ATRR from Prior Year 133,507,911 1.6c Prior Year ATRR True-Up (9,818,485) 1.6d Prior Year Divisor True-Up (822,872) 1.6e Interest on Prior Year True-Up (691,603) 1.7a NET REVENUE REQUIREMENT 159,478,984 165,581,542 6,102,559 4% 1.7b Prairie Power N/A 1.7 AIC Adjusted Revenue Requirement .

Aic 2015 attachment o true up for Schedule 9 Ameren Illinois Company - AIC Attachment O Revenue Requirement True-Up Year Ended December 31, 2015 Attachment O Net Actual Revenue Requirement (Attachment O, Pg 1, Line 7a) $ 165,581,542 Net Projected Revenue Requirement (2015 Projected Attachment O, Pg 1, Line 7a) $ 159,478,984 Under/(Over) Recovery of Net Revenue Requirement $ 6,102,558 Historic Year Actual Divisor for Pricing Zone (Attachment O, Pg 1, Line 15) 6,922,407 Projected Year Divisor for Pricing Zone (2015 Projected Attachment O, Pg 1, Line 15) 7,095,335 Difference between Historic & Projected Yr Divisor 172,928 Prior Year Projected Annual Cost ($ per kw per yr) $ 22.4766 Prior Year Under/(Over) Divisor True-up $ 3,886,829 Total Under/(Over) Recovery $ 9,989,388 Monthly Interest Rate (to be updated through July, 2016) 0.0130% Interest For 24 Months $ 31,167 Total Under/(Over) Recovery Including Interest $ 10,020,555 (Amount to be included in Projected 2017 Attachment O)

AIC Attachment GG Calculation - Page 1 (1) (2) (3) (4) Attachment O Line Page, Line, Col. Transmission Allocator No. 1 Gross Transmission Plant - Total Attach O, p 2, line 2 col 5 (Note A) 1,601,794,067 2 Net Transmission Plant - Total Attach O, p 2, line 14 and 23b col 5 (Note B) 1,136,688,403 O&M EXPENSE 3 Total O&M Allocated to Transmission Attach O, p 3, line 8 col 5 44,986,339 4 Annual Allocation Factor for O&M (line 3 divided by line 1 col 3) 2.81% GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE 5 Total G&C Depreciation Expense Attach O, p 3, lines 10 & 11, col 5 (Note H) 2,621,393 6 Annual Allocation Factor for G&C Depreciation Expense (line 5 divided by line 1 col 3) 0.16% TAXES OTHER THAN INCOME TAXES 7 Total Other Taxes Attach O, p 3, line 20 col 5 2,262,419 8 Annual Allocation Factor for Other Taxes (line 7 divided by line 1 col 3) 0.14% 9 Annual Allocation Factor for Expense Sum of line 4, 6, and 8 3.11% INCOME TAXES 10 Total Income Taxes Attach O, p 3, line 27 col 5 39,463,856 11 Annual Allocation Factor for Income Taxes (line 10 divided by line 2 col 3) 3.47% RETURN 12 Return on Rate Base Attach O, p 3, line 28 col 5 84,472,987 13 Annual Allocation Factor for Return on Rate Base (line 12 divided by line 2 col 3) 7.43% 14 Annual Allocation Factor for Return Sum of line 11 and 13 10.90%

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 Charge Project Net Plant (Note C) (Page 1 line 9) (Col. 3 * Col. 4) (Note D) 1a Wood River-Roxford 1502 138kV line 728 $ 3,424,487 3.11% $ 106,618 $ 2,993,926 1b Sidney-Paxton 138kV Reconductor 18 miles 870 $ 5,994,479 $ 186,632 $ 5,195,141 1c Coffeen Plant-Coffeen, North - 2nd. Bus tie 2829 $ 5,592,558 $ 174,118 $ 5,142,349 1d Latham - Oreana 8.5 mile 345kV line 2068 $ 23,664,187 $ 736,759 $ 23,053,409 1e Brokaw-S. Bloom 345/138kV Trans & 345kV line 2069 $ 16,215,819 $ 504,862 $ 16,123,835 1f Fargo-Mapleridge-20 mile 345kV line & New Sub 2472 $ - $ - (7) (8) (9) (10) (11) (12) 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) 10.90% $ 326,438 $ 52,502 $ 485,558 $ 6,549 $ 492,107 $ 566,443 $ 99,719 $ 852,793 $ 5,886 $ 858,679 $ 560,687 $ 104,272 $ 839,077 $ 26,307 $ 865,384 $ 2,513,588 $ 404,086 $ 3,654,433 $ 610,422 $ 4,264,855 $ 1,758,034 $ 304,705 $ 2,567,602 $ - $ 2,567,602 $ - 2 Annual Totals $ 8,399,463 $ 649,164 $ 9,048,627 3 Rev. Req. Adj For Attachment O

Aic 2015 attachment gg True-up for Schedule 26 (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)   Actual Projected Attachment GG True-Up Applicable MTEP Annual Revenues Adjustment Interest Total Line Project Revenue Allocated Principal Rate on No. Name Number Requirement 1 to Projects 1 Under/(Over) [Col. (d), line 1 x (Col. (e), line 2x / Col. (h) x Col. (i) p 2 of 2, Col. 102 Col. (e), line 3)]2 Col. (g) - Col. (f) Line 5 x 24 months 2 Col. (h) + Col. (j) 1 Actual Attachment GG revenues for True-Up Year 1 $ 10,255,964 2a Wood River-Roxford 1502 138kV line 728 493,742 497,713 485,558 (12,155) 0.2708% (790) (12,945) 2b Sidney-Paxton 138kV Reconductor 18 miles 870 867,016 873,990 852,793 (21,197) (1,378) (22,575) 2c Coffeen Plant-Coffeen, North - 2nd. Bus tie 2829 847,036 853,849 839,077 (14,772) (960) (15,732) 2d Latham - Oreana 8.5 mile 345kV line 2068 3,669,542 3,699,058 3,654,433 (44,625) (2,900) (47,525) 2e Brokaw-S. Bloom 345/138kV Trans & 345kV line 2069 4,296,793 4,331,354 2,567,602 (1,763,752) (114,630) (1,878,382) 2f Fargo-Mapleridge-20 mile 345kV line & New Sub 2472 - 3 Subtotal $ 10,174,129 $ 10,255,964 $ 8,399,463 4 Under/(Over) Recovery $ (1,856,501) $ (120,658) $ (1,977,159) 5 Applicable Interest rate per month (expressed to four decimal places) Interest Rate to be updated through July 2016 Amount excludes True-Up Adjustment, as reported in True-Up Year projected Attachment GG, page 2, column 11. 2 Rounded to whole dollars.

AIC Attachment MM Calculation - Page 1 (1) (2) (3) (4) Attachment O Line Page, Line, Col. Transmission Allocator No. 1 Gross Transmission Plant - Total Attach O, p 2, line 2 col 5 (Note A) 1,601,794,067 1a Transmission Accumulated Depreciation Attach O, p 2, line 8 col 5 465,105,665 2 Net Transmission Plant - Total Line 1 minus Line 1a (Note B) 1,136,688,403 O&M TRANSMISSION EXPENSE 3 Total O&M Allocated to Transmission Attach O, p 3, line 8 col 5 44,986,339 3a Transmission O&M Attach O, p 3, line 1 col 5 50,366,858 3b Less: LSE Expenses included in above, if any Attach O, p 3, line 1a col 5, if any 1,703,652 3c Less: Account 565 included in above, if any Attach O, p 3, line 2 col 5, if any 17,772,557 3d Adjusted Transmission O&M Line 3a minus Line 3b minus Line 3c 30,890,650 4 Annual Allocation Factor for Transmission O&M (Line 3d divided by line 1a, col 3) 6.64% OTHER O&M EXPENSE 4a Other O&M Allocated to Transmission Line 3 minus Line 3d 14,095,690 4b Annual Allocation Factor for Other O&M Line 4a divided by Line 1, col 3 0.88% GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE 5 Total G&C Depreciation Expense Attach O, p 3, lines 10 & 11, col 5 (Note H) 2,621,393 6 Annual Allocation Factor for G&C Depreciation Expense (line 5 divided by line 1 col 3) 0.16% TAXES OTHER THAN INCOME TAXES 7 Total Other Taxes Attach O, p 3, line 20 col 5 2,262,419 8 Annual Allocation Factor for Other Taxes (line 7 divided by line 1 col 3) 0.14% 9 Annual Allocation Factor for Other Expense Sum of line 4b, 6, and 8 1.18% INCOME TAXES 10 Total Income Taxes Attach O, p 3, line 27 col 5 39,463,856 11 Annual Allocation Factor for Income Taxes (line 10 divided by line 2 col 3) 3.47% RETURN 12 Return on Rate Base Attach O, p 3, line 28 col 5 84,472,987 13 Annual Allocation Factor for Return on Rate Base (line 12 divided by line 2 col 3) 7.43% 14 Annual Allocation Factor for Return Sum of line 11 and 13 10.90%

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) 1a Pana-Sugar Creek - CWIP 2237 $ 6,305,200 $ - 6.64% 1.18% $ 74,710 $ 74,710 1b Pana-Sugar Creek - Plant in Service $ 3,142,653 $ 17,737 $ 1,178 $ 37,237 $ 38,415 1c Sidney-Rising - CWIP 2239 $ 2,243,115 $ 26,578 $ 26,578 1d Sidney-Rising - Plant in Service $ 1,186,198 $ 3,644 $ 242 $ 14,055 $ 14,297 1e Palmyra-Pawnee - CWIP 3017 $ 4,278,302 $ 50,693 $ 50,693 1f Palmyra-Pawnee - Plant in Service $ 12,557,049 $ 141,094 $ 9,371 $ 148,787 $ 158,158 1g Fargo-Galesburg-Oak Grove - CWIP 3022 $ 563,597 $ 6,678 $ 6,678 1h Fargo-Galesburg-Oak Grove - Plant $ 642,506 $ 1,438 $ 95 $ 7,613 $ 7,708 1i Pawnee-Pana - CWIP 3169 $ 4,474,352 $ 53,016 $ 53,016 1j Pawnee-Pana - Plant in Service $ - $ - $ - (10) (11) (12) (13) (14) (15) (16) 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) 10.90% $ 687,477 $ 762,186 $ 3,124,917 $ 340,720 $ 53,119 $ 432,254 $ 244,574 $ 271,153 $ 1,182,554 $ 128,938 $ 18,678 $ 161,913 $ 466,477 $ 517,170 $ 12,415,955 $ 1,353,752 $ 233,209 $ 1,745,119 $ 1,745,119 1k $ 61,451 $ 68,129 1m $ 641,068 $ 69,898 $ 10,695 $ 88,302 1n $ 487,853 $ 540,869 1p $ - 2 MVP Total Annual Revenue Requirements $ 4,587,095 $ 4,587,095 3 Rev. Req. Adj For Attachment O

Aic 2015 attachment MM true-up for Schedule 26-A (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)   Actual Projected Attachment MM True-Up Applicable MTEP Annual Revenues Adjustment Interest Total Line Project Revenue Allocated Principal Rate on No. Name Number Requirement 1 to Projects 1 Under/(Over) [Col. (d), line 1 x (Col. (e), line 2x / Col. (h) x Col. (i) p 2 of 2, Col. 142 Col. (e), line 3)]2 Col. (g) - Col. (f) Line 5 x 24 months 2 Col. (h) + Col. (j) 1 Actual Attachment MM revenues for True-Up Year 1 $ 5,285,615 2a Pana-Sugar Creek - CWIP 2237 1,607,856 1,495,129 762,186 (732,943) 0.2708% (47,635) (780,578) 2b Pana-Sugar Creek - Plant in Service 240,874 223,986 432,254 208,268 13,536 221,804 2d Sidney-Rising - CWIP 2239 410,772 381,973 271,153 (110,820) (7,202) (118,022) 2e Sidney-Rising - Plant in Service - 161,913 10,523 172,436 2f Palmyra-Pawnee - CWIP 3017 799,687 743,621 517,170 (226,451) (14,718) (241,169) 2g Palmyra-Pawnee - Plant in Service 1,992,132 1,852,463 1,745,119 (107,344) (6,977) (114,321) 2h Fargo-Galesburg-Oak Grove - CWIP 3022 76,612 71,241 68,129 (3,112) (202) (3,314) 2i Fargo-Galesburg-Oak Grove - Plant 88,302 5,739 94,041 2j Pawnee-Pana - CWIP 3169 535,820 498,254 540,869 42,615 2,770 45,385 2k Pawnee-Pana - Plant in Service 20,378 18,949 (18,949) (1,232) (20,181) 3 Subtotal $ 5,684,131 $ 5,285,616 $ 4,587,095 4 Under/(Over) Recovery $ (698,521) $ (45,398) $ (743,919) 5 Applicable Interest rate per month (expressed to four decimal places) Interest Rate to be updated through July 2016 Amount excludes True-Up Adjustment, as reported in True-Up Year projected Attachment MM, page 2, column 15. 2 Rounded to whole dollars.

AIC 2015 MVP SPEND Ameren MVPs Ameren Name 2015 CAPEX MTEP #s MTEP Description Illinois Rivers $40.04 million   2237 Pana - Mt. Zion - Kansas - Sugar Creek 345 kV line 2239 Sidney to Rising 345 kV line 3017 Palmyra-Quincy-Meredosia - Ipava & Meredosia-Pawnee 345 kV Line 3169 Pawnee to Pana - 345 kV Line Spoon River $3.07 million 3022 Fargo-Galesburg-Oak Grove 345 kV Line

2015 Significant transmission projects added to plant Project Name   Total Cost S Bloomington-Brokaw $29.7 Cahokia-Turkey Hill $26.1 Powerton-Diamond Star Edwards Switchyard Rebuild $23.2 Illinois Rivers Connections (MVP) $20.2 Mason City West - Latham $18.2 Pana N–Ramsey E $11.7 Bunsonville Substation $11.4 Newton-Robinson $11.1 Havana-Galesburg-Monmouth $10.9 Pana North-Taylorville South $8.3 Sidney-Eugene $7.6 Physical Security Projects $7.5 Woodhall Substation $7.2 Castro Breaker Station $7.0 Kansas West XFmr Replacement $6.9 Meppin - South Quincy $5.7 Marion South Substation $5.0

ROE complaints Current ROE is 12.38% MISO ROE Complaints 1st Complaint (EL14-12) Covers November 12, 2013 through Feb 11, 2015 Received initial decision from administrative law judge on December 22, 2015 with a recommended Base ROE at 10.32% Expect final FERC order in October 2016 2nd Complaint (EL15-45) Covers February 12, 2015 through May 11, 2016 Received initial decision on June 30, 2016 with a recommended Base ROE at 9.70% Expect final FERC order in first half of 2017

FERC approved a 50 basis point adder for participation in an RTO ROE complaints FERC approved a 50 basis point adder for participation in an RTO Effective January 6, 2015, but will not be used until after final orders in the ROE complaints are issued Refunds will be required, but format is not yet determined Will impact Schedules 7,8, 9, 26, 37, 38, 26A Amounts could be either be rolled into the future revenue requirements and reduce future rates actual refunds to all customers requiring MISO to calculate adjustments for all months beginning with November 13

QUESTIONS?

Appendix Supplemental Background Information (Not covered during presentation)

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)

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

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

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 10% Ameren MVPs will primarily be built by ATXI AIC will be responsible for modifications needed to its existing facilities

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

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

Brief history of development 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 10% of each MVP no matter where project is located or who builds it

Appendix - MAP OF AMEREN MVPs

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

Appendix - Miso web links Transmission Pricing - Attachments O, GG & MM Information https://www.misoenergy.org/MarketsOperations/TransmissionSettlements/Pages/TransmissionPricing.aspx Ameren OASIS http://www.oasis.oati.com/AMRN/index.html MTEP 15 https://www.misoenergy.org/Planning/TransmissionExpansionPlanning/Pages/MTEP15.aspx MTEP 16 https://www.misoenergy.org/Planning/TransmissionExpansionPlanning/Pages/MTEP16.aspx Schedule 26 & 26-A Indicative Charges https://www.misoenergy.org/Planning/TransmissionExpansionPlanning/Pages/MTEPStudies.aspx

Additional questions on these topics can be sent to Ameren at: Appendix – AiC Additional questions on these topics can be sent to Ameren at: MISOFormulaRates@ameren.com