1. 2015 Projected Attachment O Stakeholder Meeting Ameren Transmission Company of Illinois (ATXI) and Ameren Illinois Company (AIC) October 1, 2014

2. 2 AGENDA Main Purpose is to review ATXI and AIC 2015 Projected Transmission Rate Calculations Timeline ATXI 2015 Projection AIC 2015 Projection 2015 AMIL Pricing Zone NITS Charge

3. 3 NEW PROTOCOL TIMELINE Date Proposed Schedule (Forward-Looking) 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 ATXI Revenue Requirement Projected 2014 vs Projected 2015

5. 5 ATXI 2015 PROJECTION ATXI Rate Base Page.Line Jan-14Jan-15ChangePercent 2.6Total Gross Plant72,401,00080,778,0008,377,00012% 2.12Total Accum Depreciation3,701,0004,717,0001,016,00027% 2.18TOTAL NET PLANT68,700,00076,061,0007,361,00011% 2.18a100% CWIP RECOVERY166,179,000471,564,000305,385,000184% ADJUSTMENTS TO RATE BASE 2.20 Account No. 282-15,292,000-12,824,0002,468,000-16% 2.21 Account No. 283-1,009,000-2,720,000-1,711,000170% 2.22 Account No. 1902,877,0002,470,000-407,000-14% 2.25 Land Held for Future Use000N/A 2.26 CWC395,500866,625471,125119% 2.27 Materials & Supplies000N/A 2.28 Prepayments0190,000 N/A TOTAL ADJUSTMENTS-13,028,500-12,017,3751,011,125-8% 2.30TOTAL RATE BASE221,850,500535,607,625313,757,125141%

6. 6 ATXI 2015 PROJECTION ATXI Expenses Page.Line Jan-14Jan-15ChangePercent O&M 3.1 Transmission184,000367,000183,00099% 3.1a Less LSE Expenses000N/A 3.2 Less Account 565000N/A 3.3 A&G2,980,0006,566,0003,586,000120% 3.4 Less FERC Annual Fees000N/A 3.5 Less EPRI, ect.68,72050,000-18,720-27% 3.5a Plus Trans. Reg. Comm. Exp68,72050,000-18,720-27% 3.8TOTAL O&M3,164,0006,933,0003,769,000119% 3.12TOTAL DEPRECIATION1,064,0001,132,00068,0006% TAXES0N/A 3.13 Payroll000N/A 3.16 Property000N/A 3.18 Other82,000155,00073,00089% 3.27 Income Taxes10,819,90124,806,31313,986,412129% TOTAL TAXES10,901,90124,961,31314,059,412129% TOTAL EXPENSES15,129,90133,026,31317,896,412118%

7. 7 ATXI 2015 PROJECTION ATXI Actual Capital Structure Capital Structure - 2014 Projection Page.Line $%CostWeighted 4.27 Long Term Debt91,077,00043%0.03860.0165 4.28 Preferred Stock00%0.0000 4.29 Common Stock121,344,00057%0.12380.0707 4.3Total212,421,000100%0.0873 Capital Structure - 2015 Projection Page.Line $%CostWeighted 4.27 Long Term Debt192,308,00044%0.04270.0187 4.28 Preferred Stock00%0.0000 4.29 Common Stock247,121,00056%0.12380.0696 4.3Total439,429,000100%0.0883 Change in Return0.1060%

8. 8 ATXI 2015 PROJECTION Total ATXI Revenue Requirement Page.Line Jan-14Jan-15ChangePercent 2.30TOTAL RATE BASE221,850,500535,607,625313,757,125141% 4.30Rate of Return on ACS8.73%8.83%0.11%1% 3.28Return from ACS19,359,22947,306,34127,947,112144% 2.30a100% CWIP RECOVERY166,179,000471,564,000305,385,000184% 4.30eIncremental Rate of Return on HCS-0.10%-0.02%0.08%-80% 3.28aIncremental Return from HCS-159,215-90,54168,674-43% Total Return19,200,01447,215,80028,015,786146% Total Expenses15,129,90133,026,31317,896,412118% 3.29TOTAL GROSS REV. REQ.34,329,91480,242,11345,912,199134% 3.30Less ATT. GG Adjustment000N/A 3.30aLess ATT. MM Adjustment25,755,41971,386,31445,630,896177% 3.31GROSS REV. REQ. UNDER ATT. O8,574,4968,855,799281,3033%

9. 9 ATXI 2015 PROJECTION ATXI True-up & Net Revenue Requirement Page.Line Jan-14Jan-15ChangePercent 1.1Gross Revenue Requirement8,574,4968,855,799281,3033% 1.6Total Revenue Credits502,000423,000-79,000-16% 1.6aHistoric Year Actual ATRR9,892,7178,860,739(1,031,979)-10% 1.6bProjected ATRR from Prior Year7,270,2637,406,002135,7402% 1.6cPrior Year ATRR True-Up2,622,4541,454,736(1,167,718)-45% 1.6dPrior Year Divisor True-Up30,874(45,647)(76,521)-248% 1.6eInterest on Prior Year True-Up35,4709,706(25,764)-73% 1.7NET REVENUE REQUIREMENT10,761,2949,851,594-909,701-8%

10. 10 ATXI 2013 TRUE UP – ATTACHMENT O Ameren Transmission Company of Illinois 2013 Attachment O Revenue Requirement True-Up For the Year Ended 12/31/2013 Attachment O Net Actual Revenue Requirement (Attachment O, Pg 1, Line 7) $ 8,860,739 Net Projected Revenue Requirement (2013 Projected Attachment O, Pg 1, Line 7) $ 7,406,002 Under/(Over) Recovery of Net Revenue Requirement $ 1,454,736 Historic Year Actual Divisor for Pricing Zone (AIC Attachment O, Pg 1, Line 15) 7,219,264 Projected Year Divisor for Pricing Zone (AIC 2013 Projected Attachment O, Pg 1, Line 15) 7,175,041 Difference between Historic & Projected Yr Divisor (44,223) Prior Year Projected Annual Cost ($ per kw per yr) $ 1.0322 Prior Year Under/(Over) Divisor True-up $ (45,647) Total Under/(Over) Recovery $ 1,409,089 Monthly Interest Rate (updated through July, 2014)0.0287% Interest For 24 Months $ 9,706 Total Under/(Over) Recovery Including Interest $ 1,418,795

11. 11 ATXI 2015 PROJECTION ATXI 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 + 18a col 5 (Note A) 552,342,000 1aTransmission Accumulated DepreciationAttach O, p 2, line 8 col 5 4,717,000 2Net Transmission Plant - TotalLine 1 minus Line 1a (Note B) 547,625,000 O&M TRANSMISSION EXPENSE 3Total O&M Allocated to TransmissionAttach O, p 3, line 8 col 5 6,933,000 3aTransmission O&MAttach O, p 3, line 1 col 5 367,000 3bLess: LSE Expenses included in above, if anyAttach O, p 3, line 1a col 5, if any - 3cLess: Account 565 included in above, if anyAttach O, p 3, line 2 col 5, if any - 3dAdjusted Transmission O&MLine 3a minus Line 3b minus Line 3c 367,000 4Annual Allocation Factor for Transmission O&M(Line 3d divided by line 1a, col 3)7.78% OTHER O&M EXPENSE 4aOther O&M Allocated to TransmissionLine 3 minus Line 3d 6,566,000 4bAnnual Allocation Factor for Other O&MLine 4a divided by Line 1, col 31.19% GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE 5Total G&C Depreciation ExpenseAttach O, p 3, lines 10 & 11, col 5 (Note H) - 6Annual Allocation Factor for G&C Depreciation Expense(line 5 divided by line 1 col 3)0.00% TAXES OTHER THAN INCOME TAXES 7Total Other TaxesAttach O, p 3, line 20 col 5 155,000 8Annual Allocation Factor for Other Taxes(line 7 divided by line 1 col 3)0.03% 9Annual Allocation Factor for Other ExpenseSum of line 4b, 6, and 81.22% INCOME TAXES 10Total Income TaxesAttach O, p 3, line 27 col 5 24,806,313 11Annual Allocation Factor for Income Taxes(line 10 divided by line 2 col 3)4.53% RETURN 12Return on Rate Base (Note I)Attach O, p 3, line 28 col 5 47,306,341 13Annual Allocation Factor for Return on Rate Base(line 12 divided by line 2 col 3)8.64% 14Annual Allocation Factor for ReturnSum of line 11 and 1313.17% HYPOTHETICAL CAPITAL STRUCTURE (HCS) RETURN 15Annual Allocation Factor HCS Return (Note J)Attach O, p 4, line 30e-0.02%

12. 12 ATXI 2015 PROJECTION ATXI Attachment MM Calculation - Page 2 (1)(2)(3)(4)(5)(6)(7)(8)(9) Line No. Project NameMTEP 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 $ 105,255,753 $ -7.78% $ -1.22%$1,280,771.54 1b Pana-Sugar Creek - Plant in Service - No HCS2237 $ 4,781,146 $ 10,5247.78% $ 8191.22%$58,177.87$58,996.71 1c Pana-Sugar Creek - Land - No HCS2237 $ 2,817,325 $ -7.78% $ -1.22%$34,281.73 1dSidney-Rising - CWIP2239 $ 50,796,443 $ -7.78% $ -1.22%$618,100.55 1e Sidney-Rising - Plant in Service - No HCS2239 $ - 7.78% $ -1.22%$0.00 1f Sidney-Rising - Land - No HCS2239 $ 1,277,222 $ -7.78% $ -1.22%$15,541.47 1gAdair-Ottumwa - CWIP2248 $ 1,503,619 $ -7.78% $ -1.22%$18,296.31 1h Adair-Ottumwa - Plant in Service - No HCS2248 $ - 7.78% $ -1.22%$0.00 1i Adair-Ottumwa - Land - No HCS2248 $ 657,995 $ -7.78% $ -1.22%$8,006.61 1jPalmyra-Pawnee - CWIP3017 $ 245,733,043 $ -7.78% $ -1.22%$2,990,125.28 1k Palmyra-Pawnee - Plant in Service - No HCS3017 $ - 7.78% $ -1.22%$0.00 1l Palmyra-Pawnee - Land - No HCS3017 $ 8,177,210 $ -7.78% $ -1.22%$99,501.81 1mFargo-Galesburg-Oak Grove - CWIP3022 $ 14,347,200 $ -7.78% $ -1.22%$174,579.40 1n Fargo-Galesburg-Oak Grove - Plant in Service - No HCS3022 $ - 7.78% $ -1.22%$0.00 1o Fargo-Galesburg-Oak Grove - Land - No HCS3022 $ 3,394,372 $ -7.78% $ -1.22%$41,303.35 1pPawnee-Pana - CWIP3169 $ 27,907,386 $ -7.78% $ -1.22%$339,582.25 1q Pawnee-Pana - Plant in Service - No HCS3169 $ - 7.78% $ -1.22%$0.00 1r Pawnee-Pana - Land - No HCS3169 $ 2,813,762 $ -7.78% $ -1.22%$34,238.38 1sAdair-Palmyra - CWIP3170 $ 26,020,057 $ -7.78% $ -1.22%$316,616.88 1t Adair-Palmyra - Plant in Service - No HCS3170 $ - 7.78% $ -1.22%$0.00 1u Adair-Palmyra - Land - No HCS3170 $ 769,450 $ -7.78% $ -1.22%$9,362.81

13. 13 ATXI 2015 PROJECTION ATXI Attachment MM Calculation - Page 2 (Continued) (1)(2)(10)(11)(11a)(12)(13)(14)(15)(16) Line No. Project Name MTEP Project NumberProject Net Plant Annual Allocation Factor for Return Annual Allocation Factor for HCS Return Annual Return Charge Project Depreciation Expense Annual Revenue RequirementTrue-Up Adjustment MVP Annual Adjusted Revenue Requirement (Col 3 - Col 4)(Page 1 line 14) (Page 1 line 15) (Note J) (Col 10 * (Col 11 + 11a))(Note E) (Sum Col. 9, 12 & 13)(Note F) Sum Col. 14 & 15 (Note G) Multi-Value Projects (MVP) 1aPana-Sugar Creek - CWIP2237 $ 105,255,75313.17%-0.02% $ 13,840,136 $ - $ 15,120,908 $ (492,359) $ 14,628,549 1b Pana-Sugar Creek - Plant in Service - No HCS2237 $ 4,770,62113.17%0.00% $ 628,208 $ 91,212 $ 778,416 1c Pana-Sugar Creek - Land - No HCS2237 $ 2,817,32513.17%0.00% $ 370,992 $ - $ 405,274 $ 211,302 $ 616,576 1dSidney-Rising - CWIP2239 $ 50,796,44313.17%-0.02% $ 6,679,252 $ - $ 7,297,352 $ (134,662) $ 7,162,690 1e Sidney-Rising - Plant in Service - No HCS2239 $ -13.17%0.00% $ - 1f Sidney-Rising - Land - No HCS2239 $ 1,277,22213.17%0.00% $ 168,188 $ - $ 183,729 $ 171,241 $ 354,971 1gAdair-Ottumwa - CWIP2248 $ 1,503,61913.17%-0.02% $ 197,712 $ - $ 216,008 $ - $ 216,008 1h Adair-Ottumwa - Plant in Service - No HCS2248 $ -13.17%0.00% $ - 1i Adair-Ottumwa - Land - No HCS2248 $ 657,99513.17%0.00% $ 86,646 $ - $ 94,653 $ - $ 94,653 1jPalmyra-Pawnee - CWIP3017 $ 245,733,04313.17%-0.02% $ 32,311,571 $ - $ 35,301,697 $ (404,306) $ 34,897,391 1k Palmyra-Pawnee - Plant in Service - No HCS3017 $ -13.17%0.00% $ - 1l Palmyra-Pawnee - Land - No HCS3017 $ 8,177,21013.17%0.00% $ 1,076,796 $ - $ 1,176,298 $ 1,216,042 $ 2,392,340 1mFargo-Galesburg-Oak Grove - CWIP3022 $ 14,347,20013.17%-0.02% $ 1,886,521 $ - $ 2,061,101 $ 557 $ 2,061,658 1n Fargo-Galesburg-Oak Grove - Plant in Service - No HCS3022 $ -13.17%0.00% $ - 1o Fargo-Galesburg-Oak Grove - Land - No HCS3022 $ 3,394,37213.17%0.00% $ 446,980 $ - $ 488,283 $ 44,343 $ 532,626 1pPawnee-Pana - CWIP3169 $ 27,907,38613.17%-0.02% $ 3,669,557 $ - $ 4,009,140 $ 59,313 $ 4,068,452 1q Pawnee-Pana - Plant in Service - No HCS3169 $ -13.17%0.00% $ - 1r Pawnee-Pana - Land - No HCS3169 $ 2,813,76213.17%0.00% $ 370,523 $ - $ 404,762 $ 438,587 $ 843,348 1sAdair-Palmyra - CWIP3170 $ 26,020,05713.17%-0.02% $ 3,421,391 $ - $ 3,738,008 $ 287,601 $ 4,025,609 1t Adair-Palmyra - Plant in Service - No HCS3170 $ -13.17%0.00% $ - 1u Adair-Palmyra - Land - No HCS3170 $ 769,45013.17%0.00% $ 101,323 $ - $ 110,686 $ 119,215 $ 229,901 2MVP Total Annual Revenue Requirements$71,386,314$1,516,874$72,903,188 3Rev. Req. Adj For Attachment O$71,386,314

14. 14 ATXI 2013 TRUE UP – ATTACHMENT MM ATXI 2013 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 $ 5,146,572 2a Pana-Sugar Creek2237 1,813,837 1,670,447 1,181,456 (488,991) 0.03% (3,368) (492,359) 2b Pana-Sugar Creek - Land - No HCS2237 - 209,857 0.03% 1,445 211,302 2c Sidney-Rising2239 380,474 350,396 216,655 (133,741) 0.03% (921) (134,662) 2d Sidney-Rising - Land - No HCS2239 - 170,070 0.03% 1,171 171,241 2e Palmyra-Pawnee3017 3,107,372 2,861,723 2,460,183 (401,540) 0.03% (2,766) (404,306) 2f Palmyra-Pawnee - Land - No HCS3017 - 1,207,723 0.03% 8,319 1,216,042 2g Fargo-Galesburg-Oak Grove3022 - 553 0.03% 4 557 2h Fargo-Galesburg-Oak Grove - Land - No HCS3022 - 44,040 0.03% 303 44,343 2i Pawnee-Pana3169 286,668 264,006 322,913 58,907 0.03% 406 59,313 2j Pawnee-Pana - Land - No HCS3169 - 435,587 0.03% 3,000 438,587 2k Adair-Palmyra3170 - 285,634 0.03% 1,967 287,601 2l Adair-Palmyra - Land - No HCS3170 - 118,399 0.03% 816 119,215 3Subtotal $ 5,588,351 $ 5,146,572 $ 6,653,070 4Under/(Over) Recovery $ 1,506,498 $ 10,376 $ 1,516,874 5Applicable Interest rate per month (expressed to four decimal places)Interest Rate updated through July 20140.0287% 1 Amount excludes True-Up Adjustment, as reported in True-Up Year projected Attachment MM, page 2, column 15. 2 Rounded to whole dollars.

15. 15 ATXI 2015 MVP SPEND MVPs Ameren Name2015 CAPEXMTEP #sMTEP Description Illinois Rivers$316.0 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 3170New Palmyra Substation (Maywood) Spoon River$28.2 million 3022Fargo-Galesburg-Oak Grove 345 kV Line Mark Twain$8.0 million 2248Adair - Ottumwa 345 kV Line 3170Adair-Palmyra 345 kV Line

16. 16 AIC Revenue Requirement Projected 2014 vs Projected 2015

17. 17 AIC 2015 PROJECTION AIC Rate Base Page.Line Jan-14Jan-15ChangePercent 2.6Total Gross Plant1,327,622,0181,597,243,472269,621,45420% 2.12Total Accum Depreciation465,639,921480,701,77115,061,8493% 2.18TOTAL NET PLANT861,982,0971,116,541,701254,559,60530% 2.18a100% CWIP RECOVERY027,739,705 N/A ADJUSTMENTS TO RATE BASE 2.20 Account No. 282-229,080,460-285,677,648-56,597,18825% 2.21 Account No. 283-17,757,369-25,147,591-7,390,22242% 2.22 Account No. 19040,041,06238,348,097-1,692,966-4% 2.23 Account No. 255000N/A 2.25 Land Held for Future Use425,0401,209,908784,868185% 2.26 CWC4,767,0795,525,584758,50416% 2.27 Materials & Supplies8,000,23810,110,4332,110,19526% 2.28 Prepayments1,049,4811,538,083488,60247% TOTAL ADJUSTMENTS-192,554,928-254,093,135-61,538,20632% 2.30TOTAL RATE BASE669,427,168890,188,272220,761,10433%

18. 18 AIC 2015 PROJECTION AIC Expenses Page.Line Jan-14Jan-15ChangePercent O&M 3.1 Transmission42,031,09341,012,814-1,018,279-2% 3.1a Less LSE Expenses2,577,0541,685,383-891,671-35% 3.2 Less Account 56513,190,1609,206,193-3,983,967-30% 3.3 A&G12,184,79514,085,7921,900,99716% 3.4 Less FERC Annual Fees000N/A 3.5 Less EPRI, ect.408,626356,844-51,782-13% 3.5a Plus Trans. Reg. Comm. Exp96,587354,483257,897267% 3.8TOTAL O&M38,136,63544,204,6706,068,03516% 3.12TOTAL DEPRECIATION22,612,54528,851,7406,239,19528% TAXES0N/A 3.13 Payroll894,566944,24749,6816% 3.16 Property1,048,9101,132,03683,1268% 3.18 Other388,574378,748-9,825-3% 3.27 Income Taxes31,970,51639,706,3887,735,87224% TOTAL TAXES34,302,56642,161,4197,858,85323% TOTAL EXPENSES95,051,746115,217,82920,166,08321%

19. 19 AIC 2015 PROJECTION Total AIC Capital Structure 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 - 2015 Projection Page.Line $%CostWeighted 4.27 Long Term Debt2,210,270,31445%0.05940.0267 4.28 Preferred Stock61,721,3501%0.04900.0006 4.29 Common Stock2,646,273,82154%0.12380.0666 4.3Total4,918,265,485100%0.0939 Change in Return-0.1785%

20. 20 AIC 2015 PROJECTION Total AIC Revenue Requirement Page.Line Jan-14Jan-15ChangePercent 2.30TOTAL RATE BASE669,427,168890,188,272220,761,10433% 4.30Rate of Return9.57%9.39%-0.18%-2% 3.28Return64,074,87483,616,15619,541,28230% Total Expenses95,051,746115,217,82920,166,08321% 3.29TOTAL GROSS REV. REQ.159,126,620198,833,98539,707,36525% 3.30Less ATT. GG Adjustment5,567,66210,393,6454,825,98387% 3.30aLess ATT. MM Adjustment05,819,860 N/A 3.31GROSS REV. REQ. UNDER ATT. O153,558,958182,620,48029,061,52219%

21. 21 AIC 2015 PROJECTION AIC True-up & Net Revenue Requirement Page.Line Jan-14Jan-15ChangePercent 1.1Gross Revenue Requirement153,558,958182,620,48029,061,52219% 1.6Total Revenue Credits10,558,03412,163,7811,605,74715% 1.6aHistoric Year Actual ATRR0123,689,426 N/A 1.6bProjected ATRR from Prior Year0133,507,911 N/A 1.6cPrior Year ATRR True-Up0(9,818,485) N/A 1.6dPrior Year Divisor True-Up0(822,872) N/A 1.6eInterest on Prior Year True-Up0(691,603) N/A 1.7aNET REVENUE REQUIREMENT143,000,924159,123,73816,122,81411% 1.7bPrairie Power000N/A 1.7AIC Adjusted Revenue Requirement143,000,924159,123,73816,122,81411%

22. 22 AIC 2013 TRUE UP – ATTACHMENT O Ameren Illinois Company - AIC 2013 Attachment O Revenue Requirement True-Up (WP 15) Year Ended December 31, 2013 Attachment O Net Actual Revenue Requirement (Attachment O, Pg 1, Line 7a) $ 123,689,426 Net Projected Revenue Requirement (2013 Projected Attachment O, Pg 1, Line 7a) $ 133,507,911 Under/(Over) Recovery of Net Revenue Requirement $ (9,818,485) Historic Year Actual Divisor for Pricing Zone (Attachment O, Pg 1, Line 15) 7,219,264 Projected Year Divisor for Pricing Zone (2013 Projected Attachment O, Pg 1, Line 15) 7,175,041 Difference between Historic & Projected Yr Divisor (44,223) Prior Year Projected Annual Cost ($ per kw per yr) $ 18.6073 Prior Year Under/(Over) Divisor True-up $ (822,872) Total Under/(Over) Recovery $ (10,641,357) Monthly Interest Rate (updated through July, 2014)0.2708% Interest For 24 Months $ (691,603) Total Under/(Over) Recovery Including Interest $ (11,332,960)

23. 23 AIC 2015 PROJECTION 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)1,542,816,240 2Net Transmission Plant - TotalAttach O, p 2, line 14 and 23b col 5 (Note B) 1,079,289,894 O&M EXPENSE 3Total O&M Allocated to TransmissionAttach O, p 3, line 8 col 544,204,670 4Annual Allocation Factor for O&M(line 3 divided by line 1 col 3)2.87% GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE 5Total G&C Depreciation ExpenseAttach O, p 3, lines 10 & 11, col 5 (Note H)2,743,077 6Annual Allocation Factor for G&C Depreciation Expense(line 5 divided by line 1 col 3)0.18% TAXES OTHER THAN INCOME TAXES 7Total Other TaxesAttach O, p 3, line 20 col 52,455,031 8Annual Allocation Factor for Other Taxes(line 7 divided by line 1 col 3)0.16% 9Annual Allocation Factor for ExpenseSum of line 4, 6, and 83.20% INCOME TAXES 10Total Income TaxesAttach O, p 3, line 27 col 539,706,388 11Annual Allocation Factor for Income Taxes(line 10 divided by line 2 col 3)3.68% RETURN 12Return on Rate BaseAttach O, p 3, line 28 col 583,616,156 13Annual Allocation Factor for Return on Rate Base(line 12 divided by line 2 col 3)7.75% 14Annual Allocation Factor for ReturnSum of line 11 and 1311.43%

24. 24 AIC 2015 PROJECTION AIC Attachment GG Calculation - Page 2 (1)(2)(3)(4)(5)(6)(7)(8)(9)(10)(11)(12) Line No. Project Name MTEP Project Number Project Gross Plant Annual Allocation Factor for Expense Annual Expense ChargeProject Net Plant Annual Allocation Factor for Return Annual Return Charge Project Depreciation Expense Annual Revenue Requirement True-Up Adjustment Network Upgrade Charge (Note C)(Page 1 line 9)(Col. 3 * Col. 4)(Note D)(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 line728 $ 3,424,4873.20%$109,656.07 $ 2,993,93011.43%$342,094.43$52,500$504,250.51 $ 6,549510,800 1bSidney-Paxton 138kV Reconductor 18 miles870 $ 5,994,4793.20%$191,950.22 $ 5,195,13811.43%$593,610.34$99,720$885,280.55 $ 5,886891,167 1cCoffeen Plant-Coffeen, North - 2nd. Bus tie2829 $ 5,592,5583.20%$179,080.24 $ 5,145,65311.43%$587,956.05$97,896$864,932.29 $ 26,307891,239 1dLatham - Oreana 8.5 mile 345kV line2068 $ 23,646,1563.20%$757,177.53 $ 23,120,89711.43%$2,641,855.37$350,082$3,749,114.90 $ 610,4224,359,537 1eBrokaw - South Bloomington 345/138kV Transformer & line extension2069 $ 27,401,1393.20%$877,416.47 $ 27,164,63911.43%$3,103,904.17$408,746$4,390,067.05 $ -4,390,067 2Annual Totals$10,393,645$649,164$11,042,809 3Rev. Req. Adj For Attachment O$10,393,645

25. 25 AIC 2013 TRUE UP – ATTACHMENT GG AIC 2013 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 $2,517,438 2aWood River-Roxford 1502 138kV line728536,385564,209570,7146,5050.03%446,549 2bSidney-Paxton 138kV Reconductor 18 miles870949,603998,8621,004,7085,8460.03%405,886 2cCoffeen Plant-Coffeen, North - 2nd. Bus tie2829907,302954,367980,49526,1280.03%17926,307 2dLatham - Oreana 8.5 mile 345kV line2068 606,275 0.03%4,147610,422 3Subtotal$2,393,290$2,517,438$3,162,192 4Under/(Over) Recovery$644,754$4,410$649,164 5Applicable Interest rate per month (expressed to four decimal places)Interest Rate updated through July 20140.0285% 1 Amount excludes True-Up Adjustment, as reported in True-Up Year projected Attachment GG, page 2, column 11. 2 Rounded to whole dollars.

26. 26 AIC 2015 PROJECTION 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) 1,542,816,240 1aTransmission Accumulated DepreciationAttach O, p 2, line 8 col 5 463,526,346 2Net Transmission Plant - TotalLine 1 minus Line 1a (Note B) 1,079,289,894 O&M TRANSMISSION EXPENSE 3Total O&M Allocated to TransmissionAttach O, p 3, line 8 col 5 44,204,670 3aTransmission O&MAttach O, p 3, line 1 col 5 41,012,814 3bLess: LSE Expenses included in above, if anyAttach O, p 3, line 1a col 5, if any 1,685,383 3cLess: Account 565 included in above, if anyAttach O, p 3, line 2 col 5, if any 9,206,193 3dAdjusted Transmission O&MLine 3a minus Line 3b minus Line 3c 30,121,238 4Annual Allocation Factor for Transmission O&M(Line 3d divided by line 1a, col 3)6.50% OTHER O&M EXPENSE 4aOther O&M Allocated to TransmissionLine 3 minus Line 3d 14,083,432 4bAnnual Allocation Factor for Other O&MLine 4a divided by Line 1, col 30.91% GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE 5Total G&C Depreciation ExpenseAttach O, p 3, lines 10 & 11, col 5 (Note H) 2,743,077 6Annual Allocation Factor for G&C Depreciation Expense(line 5 divided by line 1 col 3)0.18% TAXES OTHER THAN INCOME TAXES 7Total Other TaxesAttach O, p 3, line 20 col 5 2,455,031 8Annual Allocation Factor for Other Taxes(line 7 divided by line 1 col 3)0.16% 9Annual Allocation Factor for Other ExpenseSum of line 4b, 6, and 81.25% INCOME TAXES 10Total Income TaxesAttach O, p 3, line 27 col 5 39,706,388 11Annual Allocation Factor for Income Taxes(line 10 divided by line 2 col 3)3.68% RETURN 12Return on Rate BaseAttach O, p 3, line 28 col 5 83,616,156 13Annual Allocation Factor for Return on Rate Base(line 12 divided by line 2 col 3)7.75% 14Annual Allocation Factor for ReturnSum of line 11 and 1311.43%

27. 27 AIC 2015 PROJECTION AIC Attachment MM Calculation - Page 2 (1)(2)(3)(4)(5)(6)(7)(8)(9) Line No. Project Name MTEP Project NumberProject 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 $ 13,000,509 $ -6.50% $ -1.25%$162,475.50 1b Pana-Sugar Creek - Plant in Service2237 $ 1,688,470 $ 11,2696.50% $ 7321.25%$21,101.86$21,834.14 1dSidney-Rising - CWIP2239 $ 3,321,345 $ -6.50% $ -1.25%$41,508.93 1e Sidney-Rising - Plant in Service2239 $ - 6.50% $ -1.25%$0.00 1jPalmyra-Pawnee - CWIP3017 $ 6,465,961 $ -6.50% $ -1.25%$80,809.16 1k Palmyra-Pawnee - Plant in Service3017 $ 14,548,742 $ 109,5756.50% $ 7,1201.25%$181,824.73$188,945.22 1mFargo-Galesburg-Oak Grove - CWIP3022 $ 619,451 $ -6.50% $ -1.25%$7,741.67 1n Fargo-Galesburg-Oak Grove - Plant in Service3022 $ - 6.50% $ -1.25%$0.00 1pPawnee-Pana - CWIP3169 $ 4,332,438 $ -6.50% $ -1.25%$54,145.19 1q Pawnee-Pana - Plant in Service3169 $ 147,399 $ 1666.50% $ 111.25%$1,842.14$1,852.92 (1)(2)(10)(11)(12)(13)(14)(15)(16) Line No. Project Name MTEP Project NumberProject Net Plant Annual Allocation Factor for Return Annual Return Charge Project Depreciation Expense Annual Revenue RequirementTrue-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 $ 13,000,50911.43% $ 1,485,473 $ - $ 1,647,948 $ - $ 1,647,948 1b Pana-Sugar Creek - Plant in Service2237 $ 1,677,20111.43% $ 191,641 $ 32,574 $ 246,049 $ - $ 246,049 1dSidney-Rising - CWIP2239 $ 3,321,34511.43% $ 379,506 $ - $ 421,015 $ - $ 421,015 1e Sidney-Rising - Plant in Service2239 $ -11.43% $ - 1jPalmyra-Pawnee - CWIP3017 $ 6,465,96111.43% $ 738,818 $ - $ 819,627 $ - $ 819,627 1k Palmyra-Pawnee - Plant in Service3017 $ 14,439,16711.43% $ 1,649,858 $ 197,883 $ 2,036,686 $ - $ 2,036,686 1mFargo-Galesburg-Oak Grove - CWIP3022 $ 619,45111.43% $ 70,780 $ - $ 78,522 $ - $ 78,522 1n Fargo-Galesburg-Oak Grove - Plant in Service3022 $ -11.43% $ - 1pPawnee-Pana - CWIP3169 $ 4,332,43811.43% $ 495,036 $ - $ 549,181 $ - $ 549,181 1q Pawnee-Pana - Plant in Service3169 $ 147,23311.43% $ 16,823 $ 2,156 $ 20,832 $ - $ 20,832 2MVP Total Annual Revenue Requirements$5,819,860$0$5,819,860 3Rev. Req. Adj For Attachment O

28. 28 AIC 2015 MVP SPEND MVPs Ameren Name2015 CAPEXMTEP #sMTEP Description Illinois Rivers$46.4 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 3170New Palmyra Substation (Maywood) Spoon River$1.7 million 3022Fargo-Galesburg-Oak Grove 345 kV Line

29. 29 AIC PROJECTIONS FOR 2015 Significant Line Expansion Projects (> $25 Million) Project NameTotal CostISDMTEPMISO ID#MTEP Description Latham-Oreana (Attach GG) $24 M 2013/ 2014 MTEP082068 Convert Oreana 345 kV Bus to 6-Position Ring Bus with 3000 A Capability; Construct 8.5 miles of 345 kV line (2-954 kcmil ACSR conductor or equivalent capability) from Oreana Substation to 345 kV Line 4571 tap to Latham Substation. 3-345 kV PCB's at Oreana Substation. Brokaw-S Bloomington (Attach GG) $28 M2014MTEP082069 South Bloomington Area 345/138 kV Substation - Install 345/138 kV, 560 MVA Transformer. Extend new 345 kV line approximately 5 miles from Brokaw Substation to South Bloomington Substation. Install 1-138 kV PCB at South Bloomington Substation, and 2-345 kV PCB's at Brokaw Substation. Fargo-Mapleridge (Attach GG) $47 M2016MTEP092472 Tap existing 345kV line from Duck Creek to Tazewell and create new Mapleridge Substation. Build a new supply line to the Fargo Substation by extending 20 miles of 345kV from the new Mapleridge Substation. Install 560 MVA 345/138kV Transformer at Fargo. Bondville-SW Campus$38 M2014MTEP102992 Bondville-S.W. Campus 138 kV - Construct 8 miles of new 138 kV line. Construct 138 kV Ring Bus at Bondville (2 new PCB's) and a 138 kV Ring Bus at Champaign S.W. Campus (4 new PCB's). Edwards Substation$29M2015MTEP144315 Rebuild 138 kV switchyard at Edwards Plant. Arrange as breaker-and-a-half scheme. Replace 15-138 kV Breakers. Cahokia-Turkey Hill$34M 2014/ 2015 MTEP133013 Convert the Turkey Hill-Cahokia 138kV line 1492 line to 345kV operation (approximately 19 miles). Install a new 345kV breaker position at both Turkey Hill and Cahokia to accommodate this new line. Havana-Danvers-1352 138 kV Rebuild $32M2015MTEP144493 Rebuild the Havana-Danvers 138 kV line 1352 from Powerton Tap to Danvers (29.8 miles) and install conductor having a minimum summer emergency capability of 1200 A. Rebuild Danvers-West Washington line 1364 from Danvers to Diamond Star Tap for 1200 A capability.

30. 30 AIC PROJECTIONS FOR 2014 - 2015 Modifications to Existing Facilities Category2014-2015 CAPEXProjectsDescription Reliability/aging infrastructure replacement $416 million366 These projects are primarily driven by the need to upgrade the transmission system based on meeting NERC standards or Ameren Planning Criteria and Guidelines. The NERC TPL standards set forth a set of tests that a transmission system must meet for a list of plausible scenarios, including contingent scenarios. Ameren Planning Criteria and Guidelines (C&G) are filed each year at FERC and constitute an additional, or complementary, set of tests that the transmission system must meet. Clearance for planned line rating$143 million148 These projects are primarily driven by the need to upgrade the transmission system to support expected flows on the transmission circuits. Load growth, plant additions/retirements, and flow changes due to future system expansions are primary inputs into the decision to either increase ground clearances using existing wire or in some cases, increasing ground clearances with wire replacement, in order to achieve higher circuit ratings. Right of way expansion$19 million34 These projects are driven by the need to increase the rights and rights-of-way associated with 40 transmission corridors. The primary benefit of this set of projects is increased reliability of the system in the area of vegetation. In many cases, the existing rights-of-way are much narrower than the widths specified in Ameren's Planning Criteria and Guidelines for reliable circuit operation. The 2003 blackout and the recent 2011 Northeast US major outage event had vegetation as an incipient cause. After both events, and with the adoption of the FAC-003 standard, FERC has emphasized the need for increased vegetation management efforts which these projects support. Improved Reliability$3 million12 These projects are driven by the need to address reliability concerns driven by system topology, configuration, or condition. Operating issues, including outages, usually identify these kinds of projects. The majority of these projects involve additions of equipment in substations, e.g. relaying and/or circuit breakers.

31. 31 SCHEDULE 9 NITS RATE FOR 2015 * PPI has a historical Attachment O so their rates changes each June 1st. The amount shown for 2014 is the ATRR revised in March 14. The amount shown for 2015 is the ATRR effective 6/1/14 - 5/31/15 Page.Line Jan-14Jan-15ChangePercent 1.7AIC Adjusted Revenue Requirement143,000,924159,123,73816,122,81411% 1.7ATXI Adjusted Revenue Requirement10,761,2949,851,594-909,701-8% 1.7PPI Adjusted Revenue Requirement *2,734,1423,863,0371,128,89541% Total Revenue Requirement156,496,360172,838,36916,342,00910% 1.15Ameren Illinois Divisor7,045,0007,095,33550,3351%.Annual Cost ($/kW/Yr)22.21424.3592.14610%.Network & P-to-P Rate ($/kW/Mo)1.8512.0300.17910%

32. QUESTIONS?

33. 33 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 13 https://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEP13.aspxhttps://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEP13.aspx MTEP 14 https://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEP14.aspxhttps://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEP14.aspx Schedule 26 & 26-A Indicative Charges https://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEPStudies.aspxhttps://www.misoenergy.org/Planning/TransmissionExpansionPlanning/ Pages/MTEPStudies.aspx

34. 34 APPENDIX - AIC AND ATXI Additional questions can be sent to Ameren’s Formula Rates email address –MISOFormulaRates@ameren.com