2013 Attachment O True-Up Stakeholder MeetingAmeren Transmission Company of Illinois and Ameren Illinois Company

August 22, 2014

2

AGENDA

Main Purpose is to review ATXI and AIC 2013 Transmission Rate Actuals and True-Up Calculations

• Timeline• ATXI 2013 True Up• AIC 2013 True Up• 2014 AMIL Pricing Zone NITS Charge

There will be a meeting held on October 1 to review the 2015

Transmission Rate calculations.

3

NEW PROTOCOL TIMELINE

DateProposed 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

ATXI Revenue Requirement

Projected 2013 vs Actual 2013

5

ATXI 2013 TRUE UP

Ameren Transmission Company of IllinoisAttachment O Revenue Requirement True-Up

For the Year Ended 12/31/2013

Attachment ONet Actual Revenue Requirement (Attachment O, Pg 1, Line 7) $ 8,951,929

Net Projected Revenue Requirement (2013 Projected Attachment O, Pg 1, Line 7) $ 7,406,002

Under/(Over) Recovery of Net Revenue Requirement $ 1,545,927

Historic Year Actual Divisor for Pricing Zone (AIC Attachment O, Pg 1, Line 15) 7,219,333 Projected Year Divisor for Pricing Zone (AIC 2013 Projected Attachment O, Pg 1, Line 15) 7,175,041 Difference between Historic & Projected Yr Divisor 44,292 Prior Year Projected Annual Cost ($ per kw per yr) $ 1.03 Prior Year Under/(Over) Divisor True-up $ (45,719)

Total Under/(Over) Recovery $ 1,500,209

Monthly Interest Rate (to be updated through July, 2014) 0.03%Interest For 24 Months $ 12,530

Total Under/(Over) Recovery Including Interest $ 1,512,738

6

ATXI 2013 TRUE UP

ATXI Rate Base

Page.Line 2013 Projection 2013 Actual Change Percent2.6 Total Gross Plant 63,438,000 65,513,376 2,075,376 3%

2.12 Total Accum Depreciation 2,652,000 2,652,407 407 0%2.18 TOTAL NET PLANT 60,786,000 62,860,969 2,074,969 3%

2.18a 100% CWIP RECOVERY 33,665,000 30,479,705 -3,185,295 -9%

ADJUSTMENTS TO RATE BASE 2.20 Account No. 282 -12,172,000 -11,913,988 258,012 -2%2.21 Account No. 283 -8,000 -1,015,112 -1,007,112 12589%2.22 Account No. 190 3,984,000 2,009,733 -1,974,267 -50%2.25 Land Held for Future Use 0 0 0 N/A2.26 CWC 115,500 502,111 386,611 335%2.27 Materials & Supplies 0 0 0 N/A2.28 Prepayments 0 0 0 N/A

TOTAL ADJUSTMENTS -8,080,500 -10,417,256 -2,336,756 29%

2.30 TOTAL RATE BASE 86,370,500 82,923,418 -3,447,082 -4%

7

ATXI 2013 TRUE UP

ATXI Expenses

Page.Line 2013 Projection 2013 Actual Change PercentO&M

3.1 Transmission 41,000 625,430 584,430 1425%3.1a Less LSE Expenses 0 0 0 N/A3.2 Less Account 565 0 0 0 N/A3.3 A&G 883,000 3,391,462 2,508,462 284%3.4 Less FERC Annual Fees 0 0 0 N/A3.5 Less EPRI, ect. 0 4,594 4,594 N/A3.5a Plus Trans. Reg. Comm. Exp 0 4,594 4,594 N/A3.8 TOTAL O&M 924,000 4,016,892 3,092,892 335%

3.12 TOTAL DEPRECIATION 1,006,000 1,005,926 -74 0%

TAXES3.13 Payroll 0 0 0 N/A3.16 Property 0 13,719 13,719 N/A3.18 Other 25,000 23,296 -1,704 -7%3.27 Income Taxes 4,189,084 4,004,852 -184,232 -4%

TOTAL TAXES 4,214,084 4,041,867 -172,217 -4%

TOTAL EXPENSES 6,144,084 9,064,685 2,920,600 48%

8

ATXI 2013 TRUE UP

ATXI Actual Capital Structure

Capital Structure - 2013 Projection

Page.Line $ % Cost Weighted4.27 Long Term Debt 39,000,000 44% 0.0356 0.01574.28 Preferred Stock 0 0% 0.0000 0.00004.29 Common Stock 49,540,000 56% 0.1238 0.06934.3 Total 88,540,000 100% 0.0849

Capital Structure - 2013 Actual

Page.Line $ % Cost Weighted4.27 Long Term Debt 35,923,077 44% 0.0384 0.01704.28 Preferred Stock 0 0% 0.0000 0.00004.29 Common Stock 44,946,030 56% 0.1238 0.06884.3 Total 80,869,107 100% 0.0858

Change in Return 0.0901%

9

ATXI 2013 TRUE UP

Total ATXI Revenue Requirement

Page.Line 2013 Projection 2013 Actual Change Percent2.30 TOTAL RATE BASE 86,370,500 82,923,418 -3,447,082 -4%4.30 Rate of Return on ACS 8.49% 8.58% 0.09% 1%3.28 Return from ACS 7,336,763 7,118,653 -218,111 -3%

2.30a 100% CWIP RECOVERY 33,665,000 30,479,705 -3,185,295 -9%4.30e Incremental Rate of Return on HCS 0.00% 0.04% 0.03% 752%3.28a Incremental Return from HCS 1,422 10,971 9,548 671%

Total Return 7,338,185 7,129,623 -208,562 -3%Total Expenses 6,144,084 9,064,685 2,920,600 48%

3.29 TOTAL GROSS REV. REQ. 13,482,270 16,194,308 2,712,038 20%

3.30 Less ATT. GG Adjustment 0 0 0 N/A3.30a Less ATT. MM Adjustment 5,588,351 6,647,570 1,059,219 19%3.31 GROSS REV. REQ. UNDER ATT. O 7,893,919 9,546,738 1,652,819 21%

10

ATXI 2013 TRUE UP

ATXI True-up & Net Revenue Requirement

Page.Line 2013 Projection 2013 Actual Change Percent1.1 Gross Revenue Requirement 7,893,919 9,546,738 1,652,819 21%1.6 Total Revenue Credits 487,917 594,809 106,892 22%

1.6a Historic Year Actual ATRR 0 0 0 N/A1.6b Projected ATRR from Prior Year 0 0 0 N/A1.6c Prior Year ATRR True-Up 0 0 0 N/A1.6d Prior Year Divisor True-Up 0 0 0 N/A1.6e Interest on Prior Year True-Up 0 0 0 N/A

1.7 NET REVENUE REQUIREMENT 7,406,002 8,951,929 1,545,928 21%

11

ATXI 2013 ACTUALS

ATXI Attachment MM Calculation - Page 1

(1) (2) (3) (4)Attachment O

Line Page, Line, Col. Transmission AllocatorNo.

1 Gross Transmission Plant - Total Attach O, p 2, line 2 + 18a col 5 (Note A) 95,993,081 1a Transmission Accumulated Depreciation Attach O, p 2, line 8 col 5 (Note A) 2,652,407 2 Net Transmission Plant - Total Line 1 minus Line 1a (Note B) 93,340,674

O&M TRANSMISSION EXPENSE3 Total O&M Allocated to Transmission Attach O, p 3, line 8 col 5 4,016,892 3a Transmission O&M Attach O, p 3, line 1 col 5 625,430 3b Less: LSE Expenses included in above, if any Attach O, p 3, line 1a col 5, if any - 3c Less: Account 565 included in above, if any Attach O, p 3, line 2 col 5, if any - 3d Adjusted Transmission O&M Line 3a minus Line 3b minus Line 3c 625,430

4 Annual Allocation Factor for Transmission O&M (Line 3d divided by line 1a, col 3) 23.58% 23.58%

OTHER O&M EXPENSE4a Other O&M Allocated to Transmission Line 3 minus Line 3d 3,391,462 4b Annual Allocation Factor for Other O&M Line 4a divided by Line 1, col 3 3.53% 3.53%

GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE5 Total G&C Depreciation Expense Attach O, p 3, lines 10 & 11, col 5 (Note H) - 6 Annual Allocation Factor for G&C Depreciation Expense (line 5 divided by line 1 col 3) 0.00% 0.00%

TAXES OTHER THAN INCOME TAXES7 Total Other Taxes Attach O, p 3, line 20 col 5 37,015 8 Annual Allocation Factor for Other Taxes (line 7 divided by line 1 col 3) 0.04% 0.04%

9 Annual Allocation Factor for Other Expense Sum of line 4b, 6, and 8 3.57% 3.57%

INCOME TAXES10 Total Income Taxes Attach O, p 3, line 27 col 5 4,004,852 11 Annual Allocation Factor for Income Taxes (line 10 divided by line 2 col 3) 4.29% 4.29%

RETURN 12 Return on Rate Base (Note I) Attach O, p 3, line 28 col 5 7,118,653 13 Annual Allocation Factor for Return on Rate Base (line 12 divided by line 2 col 3) 7.63% 7.63%

14 Annual Allocation Factor for Return Sum of line 11 and 13 11.92%

HYPOTHETICAL CAPITAL STRUCTURE (HCS) RETURN15 Annual Allocation Factor HCS Return (Note J) Attach O, p 4, line 30e 0.04% 0.04%

12

ATXI 2013 ACTUALS

ATXI 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 2237 $ 7,603,892   23.58%

$ - 3.57% $271,579.62 $271,579.62

1b   Pana-Sugar Creek - Land - No HCS 2237 $ 1,353,781   23.58%

$ - 3.57% $48,351.48 $48,351.48

1c Sidney-Rising 2239 $ 1,394,397   23.58%

$ - 3.57% $49,802.12 $49,802.12

1d   Sidney-Rising - Land - No HCS 2239 $ 1,097,120   23.58%

$ - 3.57% $39,184.61 $39,184.61

1e Palmyra-Pawnee 3017 $ 15,833,822   23.58%

$ - 3.57% $565,518.77 $565,518.77

1f   Palmyra-Pawnee - Land - No HCS 3017 $ 7,790,997   23.58%

$ - 3.57% $278,262.26 $278,262.26

1g Fargo-Galesburg-Oak Grove 3022 $ 3,559   23.58%

$ - 3.57% $127.11 $127.11

1h  Fargo-Galesburg-Oak Grove - Land - No HCS 3022

$ 284,102   23.58%

$ - 3.57% $10,146.96 $10,146.96

1i Pawnee-Pana 3169 $ 2,078,278   23.58%

$ - 3.57% $74,227.50 $74,227.50

1j   Pawnee-Pana - Land - No HCS 3169 $ 2,809,960   23.58%

$ - 3.57% $100,360.18 $100,360.18

1k Adair-Palmyra 3170 $ 1,838,350   23.58%

$ - 3.57% $65,658.27 $65,658.27

1l   Adair-Palmyra - Land - No HCS 3170 $ 763,788   23.58%

$ - 3.57% $27,279.34 $27,279.34

   

(1) (2) (10) (11) (11a) (12) (13) (14) (15) (16)

Line No.   Project Name

MTEP Project Number

Project Net Plant

Annual Allocation Factor for Return

Annual Allocation Factor for HCS

Return

Annual Return Charge

Project Depreciation

ExpenseAnnual Revenue

RequirementTrue-Up

AdjustmentMVP 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)      

1a Pana-Sugar Creek 2237 $ 7,603,892 11.92% 0.04%

$ 908,900

$ -

$ 1,180,480

$ - $ 1,180,480

1b   Pana-Sugar Creek - Land - No HCS 2237 $ 1,353,781 11.92% 0.00%

$ 161,332

$ -

$ 209,683

$ - $ 209,683

1c Sidney-Rising 2239 $ 1,394,397 11.92% 0.04%

$ 166,674

$ -

$ 216,476

$ - $ 216,476

1d   Sidney-Rising - Land - No HCS 2239 $ 1,097,120 11.92% 0.00%

$ 130,745

$ -

$ 169,930

$ - $ 169,930

1e Palmyra-Pawnee 3017 $ 15,833,822 11.92% 0.04%

$ 1,892,632

$ -

$ 2,458,151

$ - $ 2,458,151

1f   Palmyra-Pawnee - Land - No HCS 3017 $ 7,790,997 11.92% 0.00%

$ 928,461

$ -

$ 1,206,723

$ - $ 1,206,723

1g Fargo-Galesburg-Oak Grove 3022 $ 3,559 11.92% 0.04%

$ 425

$ -

$ 553

$ -

$ 553

1h  Fargo-Galesburg-Oak Grove - Land - No HCS 3022

$ 284,102 11.92% 0.00%

$ 33,857

$ -

$ 44,004

$ -

$ 44,004

1i Pawnee-Pana 3169 $ 2,078,278 11.92% 0.04%

$ 248,419

$ -

$ 322,646

$ - $ 322,646

1j   Pawnee-Pana - Land - No HCS 3169 $ 2,809,960 11.92% 0.00%

$ 334,866

$ -

$ 435,226

$ - $ 435,226

1k Adair-Palmyra 3170 $ 1,838,350 11.92% 0.04%

$ 219,740

$ -

$ 285,398

$ - $ 285,398

1l   Adair-Palmyra - Land - No HCS 3170 $ 763,788 11.92% 0.00%

$ 91,021

$ -

$ 118,301

$ - $ 118,301

2 MVP Total Annual Revenue Requirements $6,647,570 $0 $6,647,570

3 Rev. Req. Adj For Attachment O $6,647,570

13

ATXI 2013 TRUE UP

ATXI 2013 Attachment MM True Up(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)

Actual Projected Attachment MM Actual True-Up Applicable True-Up MTEP Actual Annual Revenues Annual Adjustment Interest Adjustment Total

Line Project Project Attachment MM Revenue Allocated Revenue Principal Rate on Interest True-Up

No. Name Number Revenues Requirement 1 to Projects 1 Requirement 1 Under/(Over) Under/(Over) Under/(Over) Adjustment Projected [Col. (d), line 1 Actual Attachment MM x (Col. (e), line 2x / Attachment MM Col. (h) x Col. (i)

p 2 of 2, Col. 142 Col. (e), line 3)]2 p 2 of 2, Col. 142 Col. (g) - Col. (f) Line 5 x 24 months 2 Col. (h) + Col. (j)

1Actual Attachment MM revenues for True-Up Year 1 $ 5,146,572

2a Pana-Sugar Creek 2237 1,813,837 1,670,447 1,180,480 (489,967) 0.03% (4,094) (494,061)

2b Pana-Sugar Creek - Land - No HCS 2237 - 209,683 209,683 0.03% 1,752 211,435

2c Sidney-Rising 2239 380,474 350,396 216,476 (133,920) 0.03% (1,119) (135,039)

2d Sidney-Rising - Land - No HCS 2239 - 169,930 169,930 0.03% 1,420 171,350

2e Palmyra-Pawnee 3017 3,107,372 2,861,723 2,458,151 (403,572) 0.03% (3,372) (406,944)

2f Palmyra-Pawnee - Land - No HCS 3017 - 1,206,723 1,206,723 0.03% 10,082 1,216,805

2g Fargo-Galesburg-Oak Grove 3022 - 553 553 0.03% 5 558

2hFargo-Galesburg-Oak Grove - Land - No HCS 3022

- 44,004 44,004 0.03% 368 44,372

2i Pawnee-Pana 3169 286,668 264,006 322,646 58,640 0.03% 490 59,130

2j Pawnee-Pana - Land - No HCS 3169 - 435,226 435,226 0.03% 3,636 438,862

2k Adair-Palmyra 3170 - 285,398 285,398 0.03% 2,385 287,783

2l Adair-Palmyra - Land - No HCS 3170 - 118,301 118,301 0.03% 988 119,289

3 Subtotal $ 5,588,351

$ 5,146,572 $ 6,647,571

4 Under/(Over) Recovery $ 1,500,999 $ 12,541 $ 1,513,540

5 Applicable Interest rate per month (expressed to four decimal places) Interest Rate to be updated through July 2014 0.03%

1 Amount excludes True-Up Adjustment, as reported in True-Up Year projected Attachment MM, page 2, column 15.2 Rounded to whole dollars.

14

ATXI 2013 MVP SPEND

Ameren MVPsAmeren Name 2013 CAPEX MTEP #s MTEP Description

Illinois Rivers $59 million

2237 Pana - Mt. Zion - Kansas - Sugar Creek 345 kV line2239 Sidney to Rising 345 kV line3017 Palmyra-Quincy-Meredosia - Ipava & Meredosia-Pawnee 345 kV Line3169 Pawnee to Pana - 345 kV Line3170 New Palmyra Substation (Maywood)

Spoon River $3 million

3022 Fargo-Galesburg-Oak Grove 345 kV Line   

Mark Twain $0 million

2248 Adair - Ottumwa 3453170 Adair-Palmyra 345 kV Line

15

AIC Revenue Requirement

Projected 2013 vs Actual 2013

16

AIC 2013 TRUE UP

Ameren Illinois Company - AICAttachment O Revenue Requirement True-Up

Year Ended December 31, 2013

Attachment ONet 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) $ 18.61 Prior Year Under/(Over) Divisor True-up $ (822,872)

Total Under/(Over) Recovery $ (10,641,357)

Monthly Interest Rate (to be updated through July, 2014) 0.27%Interest For 24 Months $ (691,603)

Total Under/(Over) Recovery Including Interest $ (11,332,960)

17

AIC 2013 TRUE UP

AIC Rate Base

Page.Line 2013 Projection 2013 Actual Change Percent

2.6 Total Gross Plant 1,196,828,998 1,105,214,365 -91,614,633 -8%2.12 Total Accum Depreciation 446,390,099 449,948,634 3,558,534 1%2.18 TOTAL NET PLANT 750,438,898 655,265,731 -95,173,167 -13%

2.18a 100% CWIP RECOVERY 0 0 0 N/A

ADJUSTMENTS TO RATE BASE 0 N/A

2.20 Account No. 282 -220,140,173 -178,790,125 41,350,047 -19%2.21 Account No. 283 -10,556,597 -3,195,318 7,361,279 -70%2.22 Account No. 190 47,301,777 22,884,353 -24,417,424 -52%2.23 Account No. 255 0 0 0 N/A2.25 Land Held for Future Use 528,800 2,358,687 1,829,887 346%2.26 CWC 4,399,010 4,818,359 419,349 10%

2.27 Materials & Supplies 4,093,957 9,297,907 5,203,950 127%2.28 Prepayments 932,348 1,089,692 157,343 17%

TOTAL ADJUSTMENTS -173,440,877 -141,536,445 31,904,432 -18%

2.30 TOTAL RATE BASE 576,998,022 513,729,286 -63,268,735 -11%

18

AIC 2013 TRUE UP

AIC ExpensesPage.Line 2013 Projection 2013 Actual Change Percent

O&M3.1 Transmission 39,184,517 39,359,186 174,669 0%3.1a Less LSE Expenses 3,090,097 1,685,383 -1,404,714 -45%3.2 Less Account 565 11,657,490 11,099,804 -557,686 -5%3.3 A&G 11,319,374 11,962,118 642,744 6%3.4 Less FERC Annual Fees 0 0 0 N/A3.5 Less EPRI, ect. 596,873 342,724 -254,149 -43%3.5a Plus Trans. Reg. Comm. Exp 32,649 353,476 320,827 983%3.8 TOTAL O&M 35,192,080 38,546,869 3,354,789 10%

3.12 TOTAL DEPRECIATION 22,002,475 19,686,582 -2,315,893 -11%

TAXES 0 N/A3.13 Payroll 875,947 783,109 -92,838 -11%

3.16 Property 1,001,216 893,412 -107,804 -11%3.18 Other 367,419 265,149 -102,270 -28%3.27 Income Taxes 26,404,240 25,071,011 -1,333,228 -5%

TOTAL TAXES 28,648,821 27,012,681 -1,636,140 -6%

TOTAL EXPENSES 85,843,376 85,246,132 -597,244 -1%

19

AIC 2013 TRUE UP

Total AIC Capital Structure

Capital Structure - 2013 Projection

Page.Line $ % Cost Weighted4.27 Long Term Debt 1,693,174,717 45% 0.0755 0.03424.28 Preferred Stock 61,721,350 2% 0.0490 0.00084.29 Common Stock 1,977,269,372 53% 0.1238 0.06564.3 Total 3,732,165,439 100% 0.1006

Capital Structure - 2013 Actual

Page.Line $ % Cost Weighted4.27 Long Term Debt 1,725,866,469 42% 0.0785 0.03314.28 Preferred Stock 61,632,375 2% 0.0491 0.00074.29 Common Stock 2,307,081,968 56% 0.1238 0.06984.3 Total 4,094,580,813 100% 0.1036

Change in Return 0.2923%

20

AIC 2013 TRUE UP

Total AIC Revenue Requirement

Page.Line 2013 Projection 2013 Actual Change Percent2.30 TOTAL RATE BASE 576,998,022 513,729,286 -63,268,735 -11%4.30 Rate of Return 10.06% 10.36% 0.29% 3%3.28 Return 58,068,885 53,202,941 -4,865,944 -8%

Total Expenses 85,843,376 85,246,132 -597,244 -1%3.29 TOTAL GROSS REV. REQ. 143,912,261 138,449,073 -5,463,188 -4%

3.30 Less ATT. GG Adjustment 2,393,291 3,162,192 768,901 32%3.30a Less ATT. MM Adjustment 0 0 0 N/A3.31 GROSS REV. REQ. UNDER ATT. O 141,518,970 135,286,881 -6,232,089 -4%

21

AIC 2013 TRUE UP

AIC True-up & Net Revenue Requirement

Page.Line 2013 Projection 2013 Actual Change Percent1.1 Gross Revenue Requirement 141,518,970 135,286,881 -6,232,089 -4%1.6 Total Revenue Credits 8,011,058 11,597,455 3,586,397 45%

1.6a   Historic Year Actual ATRR 0 0 0 N/A1.6b   Projected ATRR from Prior Year 0 0 0 N/A1.6c Prior Year ATRR True-Up 0 0 0 N/A1.6d Prior Year Divisor True-Up 0 0 0 N/A1.6e   Interest on Prior Year True-Up 0 0 0 N/A

1.7a NET REVENUE REQUIREMENT 133,507,911 123,689,426 -9,818,485 -7%1.7b Prairie Power 583,724 243,218 -340,506 -58%1.7 AIC Adjusted Revenue Requirement 134,091,635 123,932,645 -10,158,991 -8%

22

AIC 2013 ACTUAL

AIC Attachment GG Calculation - Page 1 (1) (2) (3) (4)

Attachment OLine Page, Line, Col. Transmission AllocatorNo.

1 Gross Transmission Plant - Total Attach O, p 2, line 2 col 5 (Note A) 1,066,926,3202 Net Transmission Plant - Total Attach O, p 2, line 14 and 23b col 5 (Note B) 630,842,437

O&M EXPENSE3 Total O&M Allocated to Transmission Attach O, p 3, line 8 col 5 38,546,8694 Annual Allocation Factor for O&M (line 3 divided by line 1 col 3) 3.61% 3.61%

GENERAL AND COMMON (G&C) DEPRECIATION EXPENSE5 Total G&C Depreciation Expense Attach O, p 3, lines 10 & 11, col 5 (Note H) 1,451,5596 Annual Allocation Factor for G&C Depreciation Expense (line 5 divided by line 1 col 3) 0.14% 0.14%

TAXES OTHER THAN INCOME TAXES7 Total Other Taxes Attach O, p 3, line 20 col 5 1,941,6708 Annual Allocation Factor for Other Taxes (line 7 divided by line 1 col 3) 0.18% 0.18%

9 Annual Allocation Factor for Expense Sum of line 4, 6, and 8 3.93%

INCOME TAXES10 Total Income Taxes Attach O, p 3, line 27 col 5 25,071,01111 Annual Allocation Factor for Income Taxes (line 10 divided by line 2 col 3) 3.97% 3.97%

RETURN 12 Return on Rate Base Attach O, p 3, line 28 col 5 53,202,94113 Annual Allocation Factor for Return on Rate Base (line 12 divided by line 2 col 3) 8.43% 8.43%

14 Annual Allocation Factor for Return Sum of line 11 and 13 12.41%

23

AIC 2013 ACTUAL

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 Charge

Project Net Plant

Annual Allocation Factor for

Return

Annual Return Charge

Project Depreciation

ExpenseAnnual Revenue

RequirementTrue-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)         

1a Wood River-Roxford 1502 138kV line 728 $ 3,424,487 3.93% $134,614.10

$ 3,098,644 12.41% $384,474.94 $51,625 $570,713.86

$ - 570,714

1bSidney-Paxton 138kV Reconductor 18 miles 870

$ 5,994,479 3.93% $235,638.61

$ 5,394,578 12.41% $669,350.85 $99,719 $1,004,707.98

$ - 1,004,708

1c Coffeen Plant-Coffeen, North - 2nd. Bus tie 2829 $ 5,592,558 3.93% $219,839.41

$ 5,341,446 12.41% $662,758.36 $97,898 $980,495.36

$ - 980,495

1d Latham - Oreana 8.5 mile 345kV line 2068 $ 3,432,457 3.93% $134,927.39

$ 3,426,302 12.41% $425,130.21 $46,217 $606,274.58

$ - 606,275

                                                                                                                                                                  

2 Annual Totals $3,162,192 $0 $3,162,192

3 Rev. Req. Adj For Attachment O $3,162,192

24

AIC 2013 TRUE UP

AIC 2013 Attachment GG True Up(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)

Actual Projected Attachment GG Actual True-Up Applicable True-Up MTEP Actual Annual Revenues Annual Adjustment Interest Adjustment Total

Line Project Project Attachment GG Revenue Allocated Revenue Principal Rate on Interest True-Up

No. Name Number Revenues Requirement 1 to Projects 1 Requirement 1 Under/(Over)Under/(Over) Under/(Over) Adjustment

Projected [Col. (d), line 1 Actual Attachment GG x (Col. (e), line 2x / Attachment GG Col. (h) x Col. (i)

p 2 of 2, Col. 102 Col. (e), line 3)]2 p 2 of 2, Col. 102 Col. (g) - Col. (f) Line 5 x 24 months 2 Col. (h) + Col. (j)

1Actual Attachment GG revenues for True-Up Year 1 $ 2,517,438

2a Wood River-Roxford 1502 138kV line 728 536,385 564,209 570,714 6,505 0.03% 49 6,554

2b Sidney-Paxton 138kV Reconductor 18 miles 870 949,603 998,862 1,004,708 5,846 0.03% 44 5,890

2c Coffeen Plant-Coffeen, North - 2nd. Bus tie 2829 907,302 954,367 980,495 26,128 0.03% 198 26,326

2d Latham - Oreana 8.5 mile 345kV line 2068 - - 606,275 606,275 0.03% 4,598 610,873

3 Subtotal $ 2,393,290 $ 2,517,438 $ 3,162,192

4 Under/(Over) Recovery $ 644,754 $ 4,889 $ 649,643

5 Applicable Interest rate per month (expressed to four decimal places) Interest Rate to be updated through July 2014 0.0316%

1 Amount excludes True-Up Adjustment, as reported in True-Up Year projected Attachment GG, page 2, column 11.2 Rounded to whole dollars.

25

SCHEDULE 9 NITS RATE FOR 2013*

Page.Line 2013 Projection 2013 Actual Change Percent1.7 AIC Adjusted Revenue Requirement 134,091,635 123,932,645 -10,158,991 -8%1.7 ATXI Adjusted Revenue Requirement 7,406,002 8,951,929 1,545,928 21%

Total Revenue Requirement 141,497,637 132,884,574 -8,613,063 -6%1.15 Ameren Illinois Divisor 7,175,041 7,219,264 44,224 1%

. Annual Cost ($/kW/Yr) 19.721 18.407 (1.314) -7%

. Network & P-to-P Rate ($/kW/Mo) 1.643 1.534 (0.109) -7%

* PPI became a TO in the AMIL pricing zone effective 6/1/13 so the actual AMIL 2013 rate would be higher than shown above.

QUESTIONS?

27

Appendix

supplemental background information not covered in presentation

28

APPENDIX - AIC AND ATXI

• Both AIC and ATXI are transmission owning subsidiaries of Ameren

Corporation, as well as 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 their Attachment O net revenue requirements equals the

total revenue requirement for AMIL pricing zone to be collected under Schedule 9 (NITS)

29

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

30

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

• ATXI has no Attachment GG projects

31

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

32

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

33

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

34

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

35

APPENDIX - MAP OF AMEREN MVPS

36

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

37

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 13• https://

www.misoenergy.org/Planning/TransmissionExpansionPlanning/Pages/MTEP13.aspx

• MTEP 14• https://

www.misoenergy.org/Planning/TransmissionExpansionPlanning/Pages/MTEP14.aspx

• Schedule 26 & 26-A Indicative Charges • https

://www.misoenergy.org/Planning/TransmissionExpansionPlanning/Pages/MTEPStudies.aspx

38

APPENDIX - AIC AND ATXI

• Additional questions can be sent to Ameren’s Formula Rates email address– MISOFormulaRates@ameren.com