(b) · ano-c fire protection improvement 1,065,514 1,057,072 ano-1 pressurizer/hotlegs ......

Name of Respondent

Entergy Arkansas, Inc.

This Re ort Is: Date of Report YearlPeriod of Report

(2) n A Resubmission 0411 812006 (1) d A n Original (Mo, Da, Yr) End of 20051Q4

-ine No.

1

2

Description of Project Construction work in progress - Electric (Account 107)

(a) (b) 142,250 CCS TX ITron, GL & Invoicing Update

White Bluff PBX Replacement 140,107

3 4

2005 Pegasus Smart Client 136,799

Database Management System Upgrades 136,324

5

6

GEO-Tech Software project 135,628

IT Networks Emerging Projects 2005 134,352

7

8

9

Peoplesoft eperformance Implement 134.21 0

PC Purchases 134,145

Pine Bluff Drainaae Improvements 133,181

lo

11

2004 Robo Tag Scheduler 132,136

Reg&State Comm Driven Chgs to CCS 129,972

12

13

14

Alarm System Project-SPL 126,935

Off ice Demographics - IT lnfrastruc 126,113

OB2 TO ORACLE 124,452

ERC FORM NO. 1 (ED. 12-871 Paae 216.2

15

16 17

18

Tulane Hypersim System Stability 121,324

Enhanced Intrusion Prevention 11 5,955 2005 Telecom Capital Replacmnt EA1 114,032 2004 Generator Imbalance 1 12,673

19

20

21

EM0 SarbaneslOxley Compliance 109,780

ENGINEERING REQUEST DATABASE (ERD) 109,680

PC Installs for EA1 - 2005 108,870

22

23

SalesPage Phase 111 Implementation 108,299

WAREHOUSE BARCODING SYSTEM 108,159

24 25 26 27

28

2004 WEB Archicture Reports

Project Novo R1 - Legacy Apps

HR BENEFITS PLAN CHANGES

2005 Field Computer Hardware SWMS

Project Novo R2 - P-Card

1 07,365 105.808 105.71 6 104,642

104,206

29

30

31

Equipment Reliability 103,942

101,017 IT APPLICATION STANDARDIZATION

OTHER GENERAL 8 INTANGIBLE PLANT 8,617,758

32

33

34

PRODUCTION PLANT:

AN02 RVH InsulatiodCEDM Shroud Mod 1 1,410.200 35

36

37

38

39

ANO-2 Pressurizer Replacement 10,771,666 ANO-1 E 5NB FW HEATER TUBE BUNDLE 3,677,387 ANO-1 POISON PANEL ENHANCEMENT 3,097,598

AN02 Thimble Tube Replacement 2,954.089

2,285,327 AN0 C DRY FUEL STORAGE CASKS

40 41

42

43

2,154,427

ANO-2 EHC & TURBINE SUPV INSTR 1,137,036 ANO-2 CEDM Purchase 1,122,258

TOTAL 139.208.328

AN02 RX Vessel Head Risk Mgrnt.

Name of Respondent Entergy Arkansas. Inc.

This Re ort Is: (1) d A n Original (2) 0 A Resubmission

Date of Report (Mo, Da, Yr) 041 812006

YearIPeriod of Report Endof 2005/Q4

Line No.

1

2

3

4

5

6

7

8

9

10

11

Description of Project Construction work in progress - Electric (Account 107)

(a) (b) ANO-C Fire Protection Improvement 1,065,514

1,057,072

ANO-1 Pressurizer/Hotlegs/ermowel 834,85(:

ISESP - HP TURBINE UPGRADE 830,94E

ANOC AleNNotify System Sirens 800,907

ANO-1 SUMP SCREEN BLOCKAGE 689,986

ANO-2 2R18 ALLOY 600 662,365

ANO-2 SUMP SCREEN BLOCKAGE-GSI 191 565,70€

ANO-1 Replace lncore Detectors 544,514

ANOl Stator Refurbishment 528,61 C

ANO-C TRANSPORTABLE WASTE CASKS 51 1.75E

ANO-2 POISON PANEL ENHANCEMENT

36 [

AN01 Target Rock Valve Rep1

ANO-1 EFW Bypass Valves Replacement

LKCATH-REPLACE U4 BURNER MANAGEMENT

AN01 Turbine Building Roof Replace

AN02 DESIGNBUILD NEW CPC OPS MODUL

ANO-2 2P-4 Spare Motor Rewind

ANO-2 RCS ZINC INJECTION SYSTEM

500,174

387,361

381,402

298,963

296,640

284,015

278,968

19

20

21

22

23

24

25

26

27 28

29

30

31

32

33

34 35

ANOC Tool Purchase 251,322

ANOC Purchase New MOV Test Equip 226,184

AN02 FW Reg Valve Replacement 202,362

ANO-2 Pressurizer Heater Upgrade 200.276

198,760 AN01 BWST Recirc Piping-Seismic Con

AN02 EVQ Transmitters 190,895

AN01 SW Crossover Piping at Intake 182,678

ANO-1 1R18 ALLOY 600 165,465

Safety Parameter Display Sys Rep1 162,588

153,346

PRIMARY HEATUP WITH ADV AND EFW 140,255

ANO-1 1 R18 FAC REPLACEMENTS 131,887

Large Bore Hot Leg WOL Branch Pipin 130,879

ANOl P75 Spare Pump Overhaul 106.350

AN01 Reroute SG samp to In-Line A 103,923

OTHER PRODUCTION PLANT 1,129,165

ANO-2 Mod Emer Cooling Pond Spillwy

FERC FORM NO. 1 (ED. 12-87) 16.3

J TRANSMISSION & DISTRIBUTION SUBSTATION PLANT

HILLTOP: BUILD NEW RING BUS

EAkPurchase Spare 115kV LTC Xfmr

LR Cammack-Install new Breakers

DELL EHV-RPL FAILED 500KV SW B8311

IPP MAGNET COVE :OVERSEE 500KV GIS

Carpenter Dam - replace breakers

1,350,663

529,115

494,923

343.830 280,437

244,015

1 43 I TOTAL 139,208,328

This Re ort Is: Date of Report (1) d A n Original (Mo, Da, Yr)

Name of Respondent

Entergy Arkansas, Inc. (2) n A Resubmission 0411 812006

Yeadperiod of Report End of 2005tQ4

I 199,460 I ~~ ~ ~ 3 Heber Sprinos So - replace circt br

Line Description of Project No.

(a) 1 AP&L: SALVAGE EQUIPMENT

2 Brvant: Add 2nd Transformer

Construction work in progress - Electric (Account 107)

(b) 224,173

21 7,449

6 I Heber Springs S-Install Circuit Swi I 170,976 I Ritchie: 230/115 XFMR Life Ext.

Cotton Plt: Inst. Animal Mitigation

LR South- Upgrade Line Relaying

Murfreesboro-rpl2 circuit breakers

West Memphis EHV Kuhn Rd support

LR Cammack-Const Cable Trench

7

8 - 170,457

161,489

160,603

160,192

160,171

159,747

9

10 -

Colonel Glenn Road Site Purchase

11

12 -

158,693

16

17

18

19

20

13

14 -

Parkin Sub Relay for Kuhn Rd Sub 122,736

Little Rock Gaines-add carrier&rela 105,314

OTHER TRANSMISSION & DISTRIBUTION SUBSTATION PLANT 2,714,368

TRANSMISSION LINES PLANT:

Rerate Harrison E-Summit 161 T-Line

i s I Clarendon: Animal mitiaate bus I 124,457 I

2,602,189

24

25

26

27

21

22 -

Pleasant Hill - Quitman ROW Claims 377,666

SEARCY PRICE-SOUTHSIDE LINE MAINT 287,521

CORNING-TEXAS EASTERN STATION 8 11 5 233,563

PLEASANT HILL- QUITMAN 161 KV LINE 154,412

30

31

32

23 I NEW 115KV LINE TO MAUMEUE I 616,304 I

105,605 Monette Junction-Dell AHTD Relocate

Parkin-Wilson Relocate for AHTD 103.075

OTHER TRANSMISSION LINES PLANT 359,602

34 UNDISTRIBUTED OVERHEADS 18,228,406

43

33 I

TOTAL 139,208,328

I

36

37

38 I I 39 I I

41

42

This Re rt Is: Date of Report Yeartperiod of Report (1) 8 A n Original End of 2005/Q4 (Mo. Da, Yr)

Entergy Arkansas, InC. (2) n A Resubmission 0411 812006

21

22

I U I

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)

1. Explain in a footnote any important adjustments during year. 2. Explain in a footnote any difference between the amount for book cost of plant retired, Line 11, column (c), and that reported for electric plant in service, pages 204-207, column 9d), excluding retirements of non-depreciable property. 3. The provisions of Account 108 in the Uniform System of accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. 4. Show separately interest credits under a sinking fund or similar method of depreciation accounting.

Nuclear Production 912,674,405 91 2,674,405 Hydraulic Production-Conventional 1 1,001,615 10,990,224 11,391

t Section A. Balances and Changes During Year

231 Hydraulic Production-Pumped Storage 24 Other Production

- tlectric Plant Hela (a%) for Future Use

Line item No. (b)

~

-6,583,147 -6,583,147

r 11 ialance Beainnina of Year

25

26

27

28

I 2,596,592,981 I 2,596,869,1611 -276.18d

Transmission

Distribution 721,150,703 721,750,103

General 57,880,240 57,791,984 88,256

TOTAL (Enter Total of lines 20 thru 27) 2,621,764,582 2,622,040,762 -276,18C

Retirement Costs

7 Other Clearing Accounts

8 Other Accounts (Specify, details in footnote):

9

10 TOTAL Deprec. Prov for Year (Enter Total of 184,410,470 184.41 0,470 lines 3 thru 9)

12 Book Cost of Plant Retired 83,821,516 83,821,516

14 Cost of Removal 83,478,121 83,478,121

1 ~~~ 14 Salvage (Credit) I 5,800,659 I 5,800,654 I TAL Net Chrgs. for Plant Ret. (Enter Total

I 181 Book Cost or Asset Retirement Costs Retired I I I I 19 Balance End of Year (Enter Totals of lines 1 , 2,621,764,582 2,622,040,762 -276,lBC

10, 15, 16, and 18) Section B. Balances at End of Year According to Functional Classification

20 Steam Production 1 569.652.91 01 569.652.91 d

~~

355,988,4561 ~ 356,364,284 -375,82d

FERC FORM NO. 1 (REV. 12-03) Page 219

Name of Respondent This Report is: (1) X An Original

Entergy Arkansas, Inc. (2) - A Resubmission

]Schedule Paqe: 219 Line No.: 3 Column: c

Excludes ESI and EO1 service company depreciation allocations of $2,714,375 (included in the depreciation expense shown on page 336), since these allocations do not offset to accumulated depreciation reserves.

Date of Report Yeadperiod of Report (Mo, Da, Yr)

0411 812006 2005IQ4

;Schedule Page: 21 9 Line No.: 16 Column: c 1 Amount represents the transfer from amortization reserves of $2,270,050, the loss on disposition of assets of $28,990, and amounts recorded in implementing FASB Interpretation No.47, "Accounting for Conditional Asset Retirement Obligations" - An Interpretation of FASB Statement No. 143 of ($38,931).

IFERC FORM NO. 1 (ED. 12-87) 1 Page 21Y Footnote.1

This Re ort IS: (1) d A n Original (2) n A Resubmission 0411 812006

Date of Report (Mo, Da, Yr)

Entergy Arkansas, Inc. \ , J I I

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1) t YearlPeriod of RepoR End of 2005104

(a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturlty and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. 3. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 41 8.1.

Line Description of Investment Date Acquired No. (a) (b)

1 The Arklahoma Cornoration

10

11

12

13

14

Amount of Investment at Beginning of Year

Date of

M"$ity (d)

I I I I

151 I I I I

41

42

I 251 I I I I

J

1 ITotal Cost of Account 123.1 $ TOTAL 11,208,456 I

26

27 I I I I 28 29

30

31

This Re ort Is: (1) d A n Original


Name of Respondent

Entergy Arkansas, Inc. (2) n A Resubmission 0411 812006

Y earlperiod of Report

End of 20051Q4

in column (f). 8. Report on Line 42, column (a) the TOTAL cost of Account 123.1

, , I I I

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1) (Continued)

4. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and State the name of pledgee and purpose of the pledge. 5. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. 6. Report column (f) interest and dividend revenues form investments, including such revenues form securities disposed of during the year. 7. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or I the other amount at which carried in the books of account if difference from cost) and the selling price thereof, not including interest adjustment includible

L

Equity in Subsidiary Revenues for Year Amount of Investment at End f Year

(r) r$) Eamin s of Year l e )

Line No.

1

Gain or Loss from Investment Dis sed of

Yh)

I 28

I I I I 29

-2,849 -2,849

30

31

32

139,735 3

204,607 4

5

61 2,878

61 2,878

1 0,994,000 8

11,001,000 9

10

-2,849 61 2,878 11,205,607 42

This Re ort Is: Date of Report (Mo, Da, Yr) (1) d A n Original

(2) R A Resubmission 0411 812006

Name of Respondent

Entergy Arkansas, Inc. I U 1 I

MATERIALS AND SUPPLIES

1. For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. 2. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.

Line I Account I Balance I Balance I Department or

YearlPeriod of Report

End of 2005lQ4

No.

1

Beginning of Year End of Year Depahents which Use Material

(a) (b) (c) (d) Fuel Stock (Account 151) 3,727,205 11,699,836 Electric

2

3

7 I Production Plant (Estimated) 17,543,980 17,961,473 1 Electric

8 I Transmission Plant (Estimated) 797.453 I 816.430 I Electric I

Fuel Stock Expenses Undistributed (Account 152) 570,330 642,309 Electric

Residuals and Extracted Products (Account 153)

I 9 I Distribution Plant (Estimated) I 5,582.1 75 I 5,715,014 I Electric I

4

5

6

I 10 I Assigned to - Other (provide details in footnote) I 4,784,722 I 4,898,584 I Electric I

Plant Materials and Operating Supplies (Account 154)

Assigned to - Construction (Estimated) 51,037,031 52,251,556 Electric

Assigned to - Operations and Maintenance

1 1

12

13

~

TOTAL Account 154 (Enter Total of lines 5 thru 10)

Merchandise (Account 155)

Other Materials and Supplies (Account 156)

~ 79,745,361 81,643,057

14

15

16

FERC FORM NO. 1 (ED. 12-96)

Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)

Stores Expense Undistributed (Account 163) 5,330,981 6,231,744 Electric

Page 227

17

18

19

20

!

TOTAL Materials and Supplies (Per Balance Sheet) 89,373,877 100,216,946

BLANK PAGE

This Re rt Is: Date of Report Yeadperiod of Report (1) $An Original (2) A Resubmission 04/18/2006

(Mo, Da, Yr) End of 2005lQ4

Name of Respondent


Allowances (Accounts 158.1 and 158.2)

1. Report below the particulars (details) called for concerning allowances. 2. Report all acquisitions of allowances at cost. 3. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. 4. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). 5. Report on line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40.

I I I I

I

23 1 I I I I

43 Net Sales Proceeds (Assoc. Co.) 44 Net Sales Proceeds (Other) 435.29 306,234 45 Gains 43529 306,234 46 Losses

FERC FORM NO. 1 (ED. 12-95) Page 228

This Re ort Is: Date of Report YearIPeriod of Report (1) d A n Original (Mo, Da, Yr)

Entergy Arkansas, Inc. (2) n A Resubmission 0411 a12006 End of 20051Q4

Name of Respondent

I U I I

Allowances (Accounts 158.1 and 158.2) (Continued)

6. Report on Lines 5 allowances returned by the EPA. Report on Line 39 the EPAs sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gaindlosses resulting from the EPAs sale or auction of the withheld allowances. 7. Report on Lines 8-14 the names of vendorshransferors of allowances acquire and identify associated companies (See "associated company" under "Definitions' in the Uniform System of Accounts). 8. Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of an identify associated companies. 9. Report the net costs and benefits of hedging transactions on a separate line under purchasedtransfers and saledtransfers. 10. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.

2007 I 2008 I Future Years I Totals Line No. Arnt. No. I Amt. No. Amt. No. I Amt. No.

Date of Report This Re rt Is: (1) &A" Originat (Mo, Da, Yr)

Name of Respondent

Entergy Arkansas, Inc. (2) 0 A Resubmission 0411 812006

YearIPeriod of Report End of 20051Q4

Current OuarterPlear

- 18

19 2c 21

25

23

24

25 26

27

- -

- - - -

I

I TCNlce Storm Settlement - 30 Year Retail 14219,736 407 526,656 13,693,080

1 I Accumulated Provision for Property Insurance 29,027,357 36249,967 Various 18,826,956 46,450,368

I

FERC FORM NO. 1 / 3 4 (REV. 02-04) Page 232

1

I !

Additional Minimum Pension Asset 70,848,032 68,465,529 139,313,561 I

l AssetRetirementObfrgafion 141,184,818 52,726,608 230 89236.831 104,674,595

Other 194,482 407 9724 1 97,241

Name of Respondent This Report is: Date of Report (Mo, Da, Yr) (1) X An Original

Entergy Arkansas, Inc. (2) - A Resubmission 0411 812006

bchedule Page: 232 Line No.: 23 Column: a

Entergy Arkansas' accumulated benefit obgligation at December 31, 2005 exceeded plan assets. As a result, Entergy Arkansas was required to recognize an additional minimum liability as prescribed by SFAS 87. At December 31, 2005, Entergy Arkansas increased the additional minimum pension liability, decreased the intangible asset, and increased the regulatory asset.

Year/Period of Report

2005lQ4

!Schedule Page: 232 Line No.: 25 Column: a I In the third quarter of 2005, Entergy Arkansas recorded a revision to its estimated decommissioning cost liability for AN0 2 in accordance with the receipt of approval by the NRC of Entergy Arkansas' application for a life extension for the unit. The revised estimate resulted in an $87.2 million reduction in its decommissioning liability, along with a corresponding reduction in the related regulatory asset.

IFERC FORM NO. 1 (ED. 12-87)

, Page 232.F. ornote.1

This Re ort Is: (1) d A n Original (21 r l A Resubmission 04/18/2006


Name of Respondent

Entergy Arkansas, Inc. ~I I I

MISCELLANEOUS DEFFERED DEBITS (Account 186)

1 . Report below the particulars (details) called for concerning miscellaneous deferred debits. 2. For any deferred debit being amortized, show period of amortization in column (a) 3. Minor item (1 % of the Balance at End of Year for Account 186 or amounts less than $50,000, whichever is less) may be grouped by classes.

YearIPeriod of Report End of 2005/Q4

Line Description of Miscellaneous Balance at Debits CREDITS No. Amount Deferred Debits Beginning of Year Account

(e) 4,230,803

Ch?rd (a) (b) (c) 1 Employee Benefits 7,599,326 6,098,341 232 2 3 White Bluff Dption Price 4,900,000

Balance at End of Year

(f) 9,466,864

4,900,000

16 17 18 19 7n

4 5 6 7

Intangible Asset - Additional Minimum Pension Asset 10,312,853 380,869 253 2,718,004 7,975,718

31 32 33 34 35

22 23 ?A

38 39 40 41 42 43 44

I I

45 I I I I I I 46 I 1

FERC FORM NO. 1 (ED. 12-94} Page 233



FOOTNOTE DATA I

Year/Period of Report

20051Q4

!Schedule Paqe: 233 Line No.: 5 Column: a

Entergy Arkansas' accumulated benefit obligation at December 31, 2005 exceeded plan assets. liability as prescribed by SFAS 87. At December 31, 2005, Entergy Arkansas increased the additional minimum pension liability, decreased the intangible asset, and increased the regulatory asset.

As a result, Entergy Arkansas was required to recognize an additional minimum

LFERC FORM NO. 1 (ED. 12-87) I Page 233 Footnote.1

This Re ort Is: Date of Report YearIPeriod of Report End of 2005/Q4 (1) An Original (Mo, Da, Yr)

qame of Respondent

Entergy Arkansas, InC. (2) n A Resubmission 04/18/2006 I U I

ACCUMULATED DEFERRED INCOME TAXES (Account 190)

. Report the information called for below concerning the respondent’s accounting for deferred income taxes. 1. At Other (Specify), include deferrals relating to other income and deductions.

7 .ine alance o egining a ance at n .. of Year of Year

3 4 I 5 I I

71 Other I 81 TOTAL Electric (Enter Total of lines 2 thru 7) I 61,673,5291 -9,884,gOC

1 I I

I

13

14

15 Other 16 TOTAL Gas (Enter Total of lines 10 thru 15

17 Other (Specty) 18 TOTAL (Acct 190) (Total of lines 8,16 and 17) 61,673,529 -9,884,90(3

Notes



Entergy Arkansas, Inc. (2) - A Resubmission 04/1 a2006

ISchedule Paqe: 234 Line No.: 2 Column: a

Yeadperiod of Report

2005fQ4

Interest on Tax Deficiencies Grand Gulf 1 - Over/Under Recovery Taxable Unbilled Revenue Customer Deposits Accrued SERI Refund Deferred Fuel Cost Removal Cost Obsolete Inventory Nuclear Decommissioning Accrued Dues and Contributions Contract Deferred Revenue Incentive Compensation Teamshar ing Sale Coal Handling Equipment S/L Building Tax Gain AN0 Building Sale/Leaseback Tax Gain Employee Stock Investment Plan Long-Term Incentive Compensation Stock Options W. Markham Service Center Sale/Leaseback Tax Gain Deferred Directors’ Compensation Rate Refund Transition Costs EPA Allowances Severance Accrual Accounts Payable Accrual SFAS 1 0 9 Adjustment State Taxes Contribution Carryforward

Total

Balance at Beg of Year

$1 ,473 ,637 ( 5 , 388 ,262)

( 3 2 7 , 8 3 9 ) 40 ,880 ,198

( 4 1 , 0 6 6 , 7 6 7 ) (2 ,899 ,208)

588,905

12,070,004 -

( 1 0 6 , 5 7 8 ) 5 , 743

7,975,247 ( 6 , 4 9 3 , 7 6 5 )

69 ,679 222,329 367 ,348

2 5 , 8 0 9 1 9 2 , 6 7 3

1 , 5 0 4 4 4 6 , 0 7 1

1 ,903 ,789 ( 2 , 7 2 8 , 3 4 9 )

215 ( 1 , 7 7 7 , 1 9 2 )

51,904,239 6,383,108

965 ,242

$61,673,529

( 3 , 0 1 4 , 2 5 1 )

-

------------ ------------ ------------


$ 1 , 4 7 3 , 6 3 7 867,662

(1 ,454 ,094) 3 0 , 8 8 2 , 0 0 1

( 4 1 , 0 9 7 , 9 6 3 ) ( 8 0 , 1 0 9 , 4 1 1 )

517 ,985 2 0 6 , 5 1 8

12,070,004 ( 1 0 6 , 5 7 8 )

7 ,530 9,544,617

( 6 , 4 9 3 , 7 6 5 ) 7 ,795

1 4 8 , 6 0 1 335 ,164

25 ,809 1 4 1 , 8 7 1

( 3 , 0 4 3 , 9 7 3 ) ( 5 8 4 )

350 ,740 669 ,127

1 , 3 1 4 69,229

1 4 6 , 2 5 1 2 , 6 9 8 , 1 9 1

51 ,569 ,755 9 ,722 ,425

965,242 ------------ ( $ 9 , 8 8 4 , 9 0 0 ) _ _ _ _ _ _ _ _ _ _ - - ----_-------

IFERC FORM NO. 1 (ED. 12-87) I

Page 234 Footnote.1



Entergy Arkansas, Inc. (2) n A Resubmission 0411 812006 . . I I

CAPITAL STOCKS (Account 201 and 204)

1. Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (Le., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. 2. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year.

YearlPeriod of Report End of 20051Q4

Line Class and Series of Stock and Number of shares Par or Stated No. Name of Stock Series Authorized by Charter Value per share

Call Price at End of Year

1 (a) (b) (c) (d)

ACCOUNT 201 : Common Stock

I 19 I Unissued Series: I I I

2

3 A

Common - par value 325,000,000 0.01

Total Account 201 : Common Stock 325,000,000

26 27 28

16-Total Account204: Preferred Stock 17 18

I I I

1,613.500

33 34 35

~

20 21

22

I 371 I I I

$1 00 par value 2,716,500 $25 par value 9,000,000

$.01 parvalue 14,400,000

I I I I

42

L I I I I

1.


This Re ort Is: Date of Report YearIPeriod of Report (1 ) d A n Original (2) n A Resubmission OW1 W2006

CAPITAL STOCKS (Account 201 and 204) (Continued)

End of 2005lQ4 (Mo, Da, Yr) Name of Respondent ~


3. Give particulars (details) concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. '4. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or non-cumulative. 5. State in a footnote if any capital stock which has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purposes of pledge.

~~~

OUTSTANaNGPER BALANCE SHE.ET (Total amount outstanding without reduction

for amounts held by respondent) Shares Amount

(e) (f)

~~~

HELD BY WONDENT Line IN SINKING AND OTHER FUNDS - ' No. AS REACQUIRED STOCK (Account 217)

Amount ?ETt S h t y (i) 1

s?:ies 46,9ao,i 96 46,980,196

75,000 I 7,500,000 I I I I I 91

469,802 2 469,802 3

4

I 100,000 I 10,000,000 1 I I I I 101

70,000 93,500 75,000

7,000,000 6 9,350,000 7 7,500,000 8

100,000 150,000 200,000 150,000

28 29 30 31

10,000,000 1 1

15,000,000 12 20,000,000 13 15,000,000 14

600,000 1,613,500

I 421

6,000 15 101,356,000 16

17 18 19

I 37 38



YearlPeriod of Report End of 2005JQ4

I 101

Entergy Arkansas, Inc. (2) n A Resubmission

I

0411 8/2006

I 121

A I#:. 1 ACCOUNT 208: Donations Received from Stockholders - None

2

3 ACCOUNT 209: Reduction in Par or Stated Value of Capital Stock 4

5

6 ACCOUNT 210: Gain on Resale or Cancellation of Reacquired

7 Capital Stock

8

9 ACCOUNT 21 1: Miscellaneous Paid-in-Caoital - None

From $1 2.50 to $0.01

I

'1Vt

586,782,M

981,89

13 I 14 I I 15

16

17

I 181 19

20 I I I

21

22 23 24

25 I I

26 I 27 I

1 I I

28 I I 29

30

31 32

33 34 35

I I

38 I I

I 401TOTAL 587.764.54:


This Re r t IS: Date of Report (1) 8 A n Original (21 n A Resubmission 0411 812006

(Mo, Da, Yr) Entergy Arkansas, Inc.

. I i i i CAPITAL STOCK EXPENSE (Account 214)

1. Report the balance at end of the year of discount on capital stock for each class and series of capital stock. 2. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.

.

Line I Class and Series of Stock i Balance at tnd ot Year

Yeadperiod of Report End of mI5/Q4

No. 1

2

3

4

5

6

8

9

10

11

12

13

14

15

(a) (b) Common Stock - $0.01 par value $1.96 Preferred Stock - $0.01 par value

73,88[

222,62t

17

18 I 1 19

20

21

22 TOTAL 296,50E

This Re oft Is: (1) d A n Original (2) n A Resubmission 0411 812006


Entergy Arkansas, Inc. I I 1

1. Report by balance sheet account the particulars (details) concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other long-Term Debt. 2. In column (a), for new issues, give Commission authorization numbers and dates. 3. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds. 4. For advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received. 5. For receivers, certificates, show in column (a) the name of the court -and date of court order under which such certificates were issued. 6. In column (b) show the principal amount of bonds or other long-term debt originally issued. 7. In column (c) show the expense, premium or discount with respect to the amount of bonds or other long-term debt originally issued. 8. For column (c) the total expenses should be listed first for each issuance, then the amount of premium (in parentheses) or discount. Indicate the premium or discount with a notation, such as (P) or (D). The expenses, premium or discount should not be netted. 9. Furnish in a footnote particulars (details) regarding the treatment of unamortized debt expense, premium or discount associated with issues redeemed during the year. Also, give in a footnote the date of the Commission’s authorization of treatment other than as specified by the Uniform System of Accounts.

YearlPeriod of Report End of 2005lQ4

I

24) ACCOUNT 224 - OTHER LONG-TERM DEBT: 251 POLLUTION CONTROL BONDS:

26 27 28 29 30

Pope County 6.3% Series 19,500,000 126,888

Jefferson County 6.3% Series 9,200,000 52,168

Pope County 6.3% Series 120,000,000 1,032,000

302,250 D

154,100 D

I 1,506,200,O 2931 1,948 33 TOTAL



Vame of Respondent

Entergy Arkansas, Inc. (2) n A Resubmission 04/18/2006 I 1 1 I

LONG-TERM DEBT (Account 221,222,223 and 224) (Continued) .

I 0. Identify separate undisposed amounts applicable to issues which were redeemed in prior years. 11. Explain any debits and credits other than debited to Account 428, Amortization and Expense, or credited to Account 429, Premium In Debt - Credit. 12. In a footnote, give explanatory (details) for Accounts 223 and 224 of net changes during the year. With respect to long-term 3dvances, show for each company: (a) principal advanced during year, (b) interest added to principal amount, and (c) principle repaid juring year. Give Commission authorization numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) in a footnote including name of pledgee and purpose of the pledge. 14. If the respondent has any long-term debt securities which have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. 15. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest sxpense in column (i). Explain in a footnote any difference between the total of column (i) and the total of Account 427, interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. 16. Give particulars (details) concerning any long-term debt authorized by a regulatory commission but not yet issued.

YearIPeriod of Report End of 2005IQ4

s n in Nominal Date Date of , (Total arno!%fo%&n%ing without

AMORTIZATION PERIOD

of Issue Maturity Date From Date To reduction for amounts held by respgh)dent) (d) (e) (f) (9)

33/28/2002 04/01/2032 0312a12002 04/01 12032 100,000,000

Line No. Interest for Year

Amount (i)

6,700,0001 ;

I I I I I I

35/06/2003 I05/01/2018 I05106/2003 I05/01/2018 I 150,000,OOd 8,100,0001

11/12/2002 11/01/2032 1 1 I1 a2002 11/01/2032 100,000,000 6,000,000 I

36/25/2003 I07/01/2018

3611 112003

I 10/12/2004 111/01/2034

06/01/2033 0611 112003 06/01 12033 100,000,000 5,900,000 I <

3111 912005 02/01/2025 ==I== I

35/26/2005 I06/01/2010

I I 1'

1011 a2004 3,828,000 1; 1:

1 1 101 12034 60,000,000

01119/2005 ~

05/26/2005

9,409,750 14 l!

06/01/2010 100,000,000 2,687,500 If

1;

Os01 12025 175,000,000

10/01/1993

0711 712001

1 0101 12023 1,599,306 11 l!

07/01/2005 3,062,500 2(

I

0611 511 994

~~ ~ ~ ~

2' 900,000,000 53,037,056 2:

2: 24 2!

12/01/2016 0611 511 994 12/01 I201 6 19.500.000 1.228.500 2t

06/15/1994

~ ~ ~ ~ ~~ ~

2: 06/01/2018 0611 511 994 06/01 I201 8 9,200,000 579,600 21

2: 11/15/1995

03/23/2005

I

11/01/2020 11/15/1995 11101/2020 120,000,000 7,560,000 3(

3' 01 101 12021 03/23/2005 01 101 12021 45,000,000 1,737,500 3:

This Re ort Is: (1) d A n Original (2) 0 A Resubmission 0411 8/2006


Name of Respondent Entergy Arkansas, lnc. I Yearperiod of Report

Endof 20051Q4

Line Class and Series of Obligation, Coupon Rate Principal Amount No. (For new issue, give commission Authorization numbers and dates) Of Debt issued

(a) (b)

81 Department of Energy (Nuclear Fuel Disposal Cost) I I 91

Total expense, Premium or Discount

(4

10 I Pope County 5.05% Series I 47,000,000( 1,415,722 11 I I

2 3 4 5 6 7

Independence County 6.25% Series 45,000,000 209,943 481,500 D

SOLID WASTE DISPOSAL BONDS: Jefferson County 5.6% Series 45,500,000 458,413

113,750 D

23 24 25

12 13 14 15 16

17

18 19

20

21

I I 28 I

TOTAL ACCOUNT 224 331,200,000 5,522,502

29

30 31 32

33

I

~

TOTAL 1,506,200,000 29,511,948

This Re ort Is: (1) d A n Original (2) I-I A Resubmission 0411 812006




, , I I I LONG-TERM DEBT (Account 221,222,223 and 224) (Continued)

10. Identify separate undisposed amounts applicable to issues which were redeemed in prior years. 11. Explain any debits and credits other than debited to Account 428, Amortization and Expense, or credited to Account 429, Premium on Debt - Credit. 12. In a footnote, give explanatory (details) for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a) principal advanced during year, (b) interest added to principal amount, and (c) principle repaid during year. Give Commission authorization numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) in a footnote including name of pledgee and purpose of the pledge.

Nominal Date Date of ., (Total amo%%%%ng without Interest for Year AMORTIZATION PERIOD

of Issue Maturity Date From Date To Amount 0)

reduction for amounts held by resp dent) ?6 (d) (e) (f) (9)

06/15/1993 01/01/2021 0611 511 993 01 101 12021 914,063

I I I I 161,047,5151 4,715,3591 8

Line No.

1 2

12/01/1997

C

lOl01/2017 12/01 I1 997 1 0101 I201 7 45,500,000 2,548,000 e 7

I 17 18

la1 812001

19 2c 21

9 09/01/2028 12/1 812001 09/01 12028 1,582,332 1C

1 1

22 23 24 3.5

400,247,515

26 27 28

20,865.354 12 12 14 15 16

FERC FORM NO. 1 IED. 12-96) Dsma 9C7q

Name of Respondent


bchedule Paqe: 256 Line No.: 1 Column: i

Total interest for accounts 221 and 224 is recorded in Account 427, as shown on page 117, line 62.

This Report is: Date of Report Year/Period of Report (1) X An Original (Mo, Da, W .

(2) - A Resubmission 0411 W2006 2005/Q4

IFERC FORM NO. 1 (ED. 12-87)

Page 256-257 Footnote.1

BLANK PAGE

This Re ort Is: (1) $)An Original (2) n A Resubmission 04/18/2006


Entergy Arkansas, Inc. I I I I

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES I

Year/Period of Report End of 2005/Q4

1. Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. 2. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. 3. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete tine 27 and provide the substitute Page in the context of a footnote.

_ _

27 28 29

. . 12 18

Federal Tax Net Income 66,357,253 Show Computation of Tax:

I I

32 33 34

I

23,225,039 Normal and Surtax - 66,357,253 8 35%

Provision for Contingencies 600.000

I

35 36 37

23 I I 24 I

Federal Tax Accrual for the Current Year 23,825,038

44

30 !Federal Net Taxable Income - As estimated on Llne 27 I 66,357,252 31 I

Estimated Consolidated Federal Income Tax

~

39 40 41 42 43

I I I I FERC FORM NO. 1 (ED. 12-96) Page 261

Name of Respondent This Report is: Date of Report Yeadperiod of Report (1) An Original (Mo, Da, Yr)

Entergy Arkansas, Inc. (2) - A Resubmission 0411 a2006 2005lQ4 FOOTNOTE DATA -

~ ~~

ischedule Page: 261 Line No.: 5 Column: a

Taxable Income Not Reported on Books: Net Earnings - Domestic Subs Deferred Contract Revenue Contributions in Aid of Construction Interest Capitalized

Total

ischedule Page: 261 Line No.: 10 Column: a

Deductions on Books Not Deducted for Return: Provision for Deferred Income Tax - Federal Provision for Deferred Income Tax - State Nuclear Fuel Expense Amortization of Intangible Plant Increase in Reserves Deferred Nuclear Shutdown Costs Reserve €or Uncollectible Accounts Non-deductible Meals & Entertainment Deferred Fuel Expense Retail Regulatory Asset Amortization of Bond Reacquisition Losses Maintenance Refueling Reserve Long Term Incentive Plan Deferral of Grand Gulf Cost per Settlement Decontamination & Decommissioning Fund Non-deductible Penalties Non-deductible PAC & Political Expenses Pension Expense Deferred Directors' Fees Research & Experimentation Option Grant Rate Refund Casualty Loss Transition to Competition Low Level RAD Waste Deferred Regulatory Expense Decommissioning - Dry Cask

Total

$87,044,340 16 ,828 ,625 43,579,307

9,696,217 2,974,708

(176 ,549) 4,738,166

479 ,741

526,656 (196 ,814 ,176)

(4 ,632 ,277) (14 ,481 ,877)

( 1 2 9 , 4 9 8 ) 15 ,946 ,786

4,379,229 4,013

723,000 20,974,595

( 1 3 7 , 1 3 4 ) 3,560,506

(304 ,261) 3 ,730 ,640

( 3 , 1 8 5 , 4 7 7 ) 6 , 958,102

16 ,243 ,434 2,426,919 6,220,959

$27,174,694 ------------ ---------_-- --------^---

pchedule Page: 261 Line No.: 15 Column: a

Income Recorded on Books Not Included in Return: Amortization of Gain on Sale of Property Customer/IPP Advances Investment Tax Credit - Federal Allowance for Funds Used During Construction

Total

$275,317 25 ,486 ,100

4,451,040 20 ,096 ,140

$50 ,308 ,597 ------------

------------ ------------

IFERC FORM NO. 1 (ED. 12-87) 1 Page 261 Footnote.1

Name of Respondent


!Schedule Page: 261 Line No.: 20 Column: a 1

This Report is: Date of Report Yeadperiod of Report (1) X An Original (Mo, Da, Yr) (2) - A Resubmission 0411 812006 2005lQ4

Deductions on Return Not Charged Against Book Income: Excess of Tax over Book Depreciation Property Insurance Reserve OPEB & SFAS 112 Medicare Subsidy Removal Costs (Amounts Incurred) Tax Amortization Decontamination & Decommissioning - Tax Regulatory Cagitalized Costs Pension and Hospital R, -serve Severance Accrual Coal Car Lease Payments Deductions for Dividends Paid on Certain Preferred

Total

Stock

$15,368,670 14 ,565 ,912

5 ,443,002 56 ,081,904

872,719 3 ,558 ,227

791,735 1 ,042 ,515 1 , 1 2 6 , 3 0 3 1 ,838 ,995

176 ,532

$100,866,514 --___---_---_ ------------- -------------

lschedule Page: 261 Line No.: 22 Column: a 1 Reconciling Items:

Federal Income Tax Accrual - Current Year Federal Income Tax Accrual - Prior Year State Income Tax Accrual - Prior Year Miscellaneous

Total

ISchedule Paae: 261 Line No.: 44 Column: a

The Respondent intends to join in the filing of a consolidated Federal Income Tax Return by Entergy Corporation and Subsidiary Companies for the year ended 2005. The estimated consolidated tax allocable under the provisions of Securities and Exchange Commission Rule 4 5 ( c ) is as follows:

Entergy Arkansas, Inc. Entergy Gulf States, Inc. & Subsidiaries Entergy Louisiana Holdings, Inc. Entergy Mississippi, Inc. Entergy New Orleans, Inc. System Energy Resources, Inc. Entergy Services, Inc. System Fuels, Inc. Entergy Operations, Inc. Entergy Corporation Entergy Retail Holding Company Entergy Retail Texas Inc. Entergy Retail LA LLC A Entergy Solutions Mngmt Services Entergy Nuclear Generation Comp. Entergy Nuclear Ny Inv Co. I Entergy Nuclear Investment Co. Entergy Nuclear Vermont Inv Co. Entergy Nuclear Finance Hold, Inc.

($16 ,599 ,000) (29 ,804,000) 63 ,748,000 (4 ,177,000) (8 ,183,000) 73,384,000 (2 ,000 ,000)

(72 ,000) (243 ,000)

(1 ,632 ,000) (18 ,000)

(1 ,000 ) (1 ,013 ,000)

(17 ,293,000) (29 ,941 ,000) (28 ,212 , 000) (28 ,086,000)

(2 ,915,000)

-

[FERC FORM NO. 1 (ED. 12-87) 1 . - .Page 26? Footnote.2

Name of Respondent This Report is: (1) X An Original

Entergy Arkansas, Inc. (2) - A Resubmission

Entergy Nuclear Finance, Inc. Entergy Nuclear, Inc. Entergy Nuclear Holding Co #1 TLG Services, Inc. Entergy Nuclear Operations, Inc. Entergy Power Bulgaria Entergy Power Development Corp. EP Edegel, Inc. Entergy Mississippi Turbine Company Entergy Power, Inc. Entergy Enterprises, Inc. Entergy Power E&C Holding Entergy Power Operations U . S . , Inc. Entergy Power Gas Holdings Corp. Entergy Power Gas Operations Cow. Entergy Power Generation Corp. Entergy Commerce, InC. Entergy UK Enterprises, Ltd Entergy Int'l Investments No.2 LTD LLC Entergy Global Investments, Inc. Entergy Resources Inc. Entergy Operations Services, Inc. Entergy Technology Holding Co. Entergy Technologies Co. Entergy Procurement Exchange Holding Corp. Entergy Thermal LLC Entergy Power Warren COrp. Entergy International Holdings LTD Entergy Power Ventures I Corp. EK Holdings 111

TOTAL

Date of Report Yeadperiod of Report (Mo, Da, Yr)

O N 1 812006 2005lQ4

12,649,000 (1,066,000)

(184,000) 21,000

(664,000) 7,000

(939,000) (237,000) (211,000)

7,836,000 (2,051,000)

(226,000) 158,000 (1,000)

(278,000) 11,079,000

(4,000) 13,796,000

(146,000) (7,318,000)

(408,000) (214,000) (48,000)

(230,000)

(14,000) (128,000)

(24,000) (541,000)

(7,000)

2 ,450 ,000

IFERC FORM NO. 1 (ED. 12-87) 1 Page 261 Footnote.3

This Re ort Is: (1) &An Original (2) n A Resubmission Entergy Arkansas, Inc.

I Y

TAXES ACCRUED, PREPAID AND CHARGED DURING YEAR



1. Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts ot such taxes are know, show the amounts in a footnote and designate whether estimated or actual amounts. 2. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (d) and (e). The balancing of this page is not affected by the inclusion of these taxes. 3. Include in column (d) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. 4. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained.

Adjust- ments

'fw 3' (f)

axes Ckarged Line Kind of Tax BALANCE AT BEGINNING OF YEAR

No. (See instruction 5) Taxes Accrued Prepaid Taxes p n g %P (Account 236) (Include in Account 165) (a) (b) (c) (d)

1 FEDERAL TAXES:

3 4 5 6

I 2llncome I 127,000,300 I I -2,893,345 I 19,476,000 I FICA -21 7,922 10,068,980 8,771,419 Fed Unemployment 5.81 0 77,774 90,084 Subtotal 126,788,188 7,253,409 28,337,503

37 38 39 40

41

~~ ~~ ~~

TOTAL 221,026,368 1,075,996 47,210,699 80,631,812

271 Entergy Services, Inc. I I I -3,043,2191 -3,043,219 I I I

30 31 32


Name of Respondent This Re rt Is: Date of Report

Entergy Arkansas, Inc. (1) $An Original (Ma, Da, Yr) (2) U A Resubmission 0411 812006


t I ~ ~~ ~~ ~~ ~

1 - 1 1 1 104,630,955 I I -9,693,381 I I 6,800,0361 2

BALANCE AT END OF YEAR DISTRIBUTION OF TAXES CHARGED (Taxes accrued Prepaid Taxes Electric Extraordinary Items Adjustments to Ret. Other Acco nt 236) (Incl. in Account 165) (Account 408.1,409.1) (Account 409.3) Earnings (Account 439)

fh) f i \ f i \ fk\ f I) Y d

Line No.

1,079,639 -6,500

105,704,094

5,918,448 3 27,681 50,093 4

-5,515.1 68 12,768,577 5

4,150,532

49,996,241 481,190 6,500

-820,240 1,417,909 8 63,162 114.271 9 307,467 -95 10

I I -170,988 I I I 170,988) 201

2,574,9861 I

I I I I I I I 211

12,274,1241 12 770

97,248

I I I I I I -

I I I I I 25

22,783 13 254,455 14

-314 15 31 4 26,613,000 2,301,997 82,071,932

29 30 31 32 33 34 35

23,279.1 77 3,741,441 16 23,192 17

1,246,767 25.1 98,718 17,801,791 18 19

36 37 38 39

I 22'

8,984,413 -8,984,413 23 24


-3,043,219

Paw 263

26 27 28

187,776,026

40

1,246,767 25,453,756 21,756,943 41

101 I I I I I 111 I

39 40

12 13 14 15 16 17


33 34 35

I

36 37 38

Name of Respondent Entergy Arkansas, Inc.

ADJUSTMENT EXPLANATION

This Re ort Is: Date of Report Yeadperiod of Report (1) d A n Original End of 20051Q4 (Mo, Da, Yr) (2) n A Resubmission 0411 a12006

I tine 1 I "I 11.1 "-..".I

to Income I

4 12,101,832 29.63 years 5

11 12 13 14

16 17 i a

I Name of Respondent IThis Report is: I Date of Report IYear/Period of Report 1 Entergy Arkansas, Inc.

(1 x A; Original (Mo, Da, Yr) (2) - A Resubmission 041 8/2006 2005lQ4

ISchedule Page: 266 Line No.: 2 Column: i I Average lives are based on estimated composite useful lives of the properties and are subject to reconsideration each year.

IFERC FORM NO. 1 (ED. 12-87) 1 Page 266-267 Footnote.1

BLANK PAGE

Name of Respondent

Entergy Arkansas, Inc. I $.s Re&" Is:

An Original (2) n A Resubmission

Year/Period of Report End of 2005/Q4 I Date of Report

(Mo, Da, Yr) 0411 812006

4

5

6

7 8

Supplemental Pension Plan 1,648,180 Various 521,847 763,060 1,889,393

Deferred incentive Comp. Amt. 1.1 66,992 Various 158,804 1,219,780 2,227,968

17 18 19 20 21 22

Duke (Hot Springs) IPP and Tax 19,599,897 107 17,951,082 3,936,760 5,585,575

Southern Energy IPP and Tax 11,012,454 107 5,120,990 975,014 6,866,478

Cogentrix Sterlington IPP and Tax 12,048,212 Various 1,178,305 10,869,907

~~~ ~

I

34 35

I

231 Wrightsville Power IPP and Tax 32,387,921 I 107

I I I 45 I I I

7,380,1521 5,118,8171 30,126,586


24 I I I I I I

16,419,0391 107 251 City Water & Light IPP and Tax

26 I 1,492,639 14,926,400

27 28 29 30 31 32

~ ~~ ~ ~~~

Other Independent Power Producers -1,221,099 107 4,903,051 2,507,529 -3,616,621

Add? Minimum Pension Liability 81,160,885 66,128,394 147,289,279

Other 1,018,878 Various 1,731,609 15,438,811 14,726,080

Name of Respondent This Report is: Date of Report (Mo, Da, Yr) (1 ) X An Original


ISchedule Page: 269 Line No.: 1 Column: a

Average Amortization Period - 30 years

Schedule Page: 269 Line No.: 9 Column: a 1

Yeadperiod of Report

2005104

Amortization Period - 35 years/term of lease

,Schedule Page: 269 Line No.: 12 Column: a

Amortization Period - 30 years/term of lease

,Schedule Page: 269 Line No.: 29 Column: a

Entergy Arkansas' accumulated benefit obligation at December 31, 2005 exceeded plan assets. As a result, Entergy Arkansas was required to recognize an additional minimum liability as prescribed by SFAS 87. At December 31, 2005, Entergy Arkansas increased the additional minimum pension liability, decreased the intangible asset, and increased the regulatory asset.

IFERC FORM NO. 1 (ED. 12-87) I Page 269 Footnote.1

This Re ort Is: Date of Report YearIPeriod of Report End of xKwQ4 (1) d A n Original

(2) n A Resubmission 0411 W2006 (Mo, Da, Yr)

Entergy Arkansas, Inc. I U I i

ACCUMULATED DEFFERED INCOME TAXES - OTHER PROPERTY (Account 282) 1. Report the information called for below concerning the respondent's accounting for deferred income taxes rating to property not subject to accelerated amortization 2. For other (Specify),include deferrals relating to other income and deductions.

Line No. Beginning of Year Amounts Debited Amounts Credited

to Account 41 1 . 1

CHANGES DURING YEAR Account Balance at

to Account 410.1

2 Electric 674,221,665 64,272,153 37,625,7$ 3 Gas

4

5 TOTAL (Enter Total of lines 2 thru 4) 674,221,665 64,272,153 37,625,72 6

7

8

9 TOTAL Account 282 (Enter Total of lines 5 thru 674,221,665 64,272,153 37,625.7s

12 State Income Tax 96,801,086 7,871,795 4,409,6C 13 Local Income Tax

NOTES

I

'ERC FORM NO. 1 (ED. 12-96) Page 274

This Re ort Is: Date of Report YearJPeriod of Report Endof 2005IQ4 (1) d A n Original (Mo, Da, Yr)

(2) n A Resubmission 0411 812006 Entergy Arkansas, Inc. . . J I I ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282) (Continued)

3. Use footnotes as required.

CHANGES DURING YEAR ADJUSTMENTS

Amounts Debited Amounts Credited Debits Credits to Account 41 0.2 to Account 41 1.2 Account Amount Account Amount

Balance at Line End of Year No.

0) Credited Debited (e) (f) li\

131 28,2 I I I I I I I .

700,839,766 !

t

700,839,766( < I I I I I

NOTES (Continued)

ERC FORM NO. 1 (ED. 12-96) Paae 275

Name of Respondent This Re ort Is: Date of Report YearlPeriod of Report Entergy Arkansas, Inc. End of 2005104 (1) d A n Original

(2) n A Resubmission 0411 812006 (Mo, Da, Yr)

I I ACCUMULATED DEFFERED INCOME TAXES - OTHER (Account 283)

1. Report the information called for below concerning the respondent’s accounting for deferred income taxes relating to amounts recorded in Account 283. 2. For other (Specify),include deferrals relating to other income and deductions.

7

8

9 TOTAL Electric (Total of lines 3 thru 8) 296,615,997 25,535,783 19,533,11

NOTES

I

3 See Footnote Detail 296,615.997 25,535,783 19,533,ll 4 I


This Re ort Is: Date of Report YearIPeriod of Report (1) d A n Original (Mo, Da, Yr) (2) n A Resubmission 04l18f2006

End of 2005lQ4 Entergy Arkansas, Inc.

I I I 40,756,721 I I

I , I I I t ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283) (Continued)

261,861,941 I !

3. Provide in the space below explanations for Page 276 and 277. Include amounts relating to insignificant items listed under Other. 4. Use footnotes as required.

182

182

29,938,782 208,337,765 2'

10,817,939 53,524,176 2:

2:

I I I I t I

I 40,756,721 I I I 261,861,941 I 1s

:car c n a n n &in I r c n ixacb



/Schedule Page: 276 Line No.: 3 Column: a

YearlPeriod of Report

2005/Q4

Bond Reacquisition Loss Maint./Refueling Reserve Section 475 Adjustment Research & Experimental Expense TCBY Tower (CADC) Decontam. & Decommissioning Fund Tax Gain - ISES Sale Ice Storm Disaster Low Level Rad Waste Regulatory Asset - 30 Yr Retail Prepaid Expenses Capitalized Costs Distribution Maintenance SFAS 1 0 9 Adjustment

Total

Bond Reacquisition Loss Maint./Refueling Reserve Section 475 Adjustment Research & Experimental Exp TCBY Tower (CADC) Decontam. & Decommissioning Fund Tax Gain - ISES Sale Ice Storm Disaster Low Level Rad Waste Regulatory Asset - 30 Yr Retail Prepaid Expenses Capitalized Costs Other Regulatory Costs SFAS 1 0 9 Adjustment

Total

Balance at Beg of Year

$14,519,845 6 ,465,796

( 1 , 9 3 6 , 0 0 8 ) ( 1 5 , 9 4 4 , 5 1 5 ) 15 ,505 ,108 11 ,554,140

1 , 0 8 4 , 6 4 4 93 ,176,438

6 ,372,299 5 ,577 ,360

5 ,470 ,545 1 ,207 ,745

153 ,562 ,600

$296,615,997

-

-___________- --------_---- - _ _ _ _ _ _ _ _ _ _ - -

Adjustments Debits

Acct No Amount

Amounts Debited to Account 4 1 0 . 1

$2 ,703 ,098 11 ,420 ,735

316 1 ,198 ,430

427,445

6 ,962,599

5 1 8 1 6 , 5 6 1 986 ,790

1 , 0 1 9 , 7 5 8

-

- -

Credits Acct No Amount

Amounts Credited to Account 4 1 1 . 1

$885,857 5 ,739,495

1 , 986 , 053

749,528 1 2 4 , 8 4 1

2 ,491 ,614 6 ,372 ,299

206 ,667

9 5 2 , 0 8 1 24 ,683

-

-

182 4 0 , 7 5 6 , 7 2 1


$16,337,086 12 ,147,036 (1 ,936 ,008)

(17 ,930 ,252) 16 ,703,538 11 ,232,057

959 , 803 97,647 , 423

5 ,370,744 816 ,561

5 ,505 ,254 2 ,202,820

112 ,805 ,879

$261 ,861 ,941

-

------------- _-----_-_---- -------------

[FERC FORM NO. 1 (ED. 12-87) 1 Page 276-277 Footnote.1

BLANK PAGE

This Re ort Is: (1) 8 A n Original (2) I l A Resubmission 0411 812006

Date of Report Name of Respondent Entergy Arkansas, Inc.

(Mo, Da, Yr) , I I I I

OTHER REGULATORY LIABILITIES [Account 2541


~~~ ~ ____

1. Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if

Balance at Begining DEBITS Credits of Current Line Description and Purpose of

No. Other Regulatory Liabilities QuarterNear Amount

(a) (b) (c) (d) (e) 1 SFAS 1 15 - Non-Qualiied Fund - Valuation Acct 25,761,416 128 18,258,149 22,518,394

2

3 SFAS 1 15 - AN0 1 Qualified Fund - Valuation Acct 20,673,825 128 18,901,528 20,495,541

4

Balance at End of Current

QuarterNear

(f)

30,021,66'

22,268,831

~ ____ ~~ _ _ _ _ ~ ~ - ~~

51 SFAS 115 - AN0 2 Qualified Fund - Valuation Acct 20,926,332 128 17,971,750 21,261,988 24,216,571

7 I SFAS 109 - Accounting for Income Taxes 34,875,978 Various 2,635,146 340,8251 32,581,65'

22

23

24

9 I Grand Gulf Costs Over Recovery

25

26

27

28

29

407 1,275,013 3,502,810 2,227,79:

39

40

101 I I

FERC FORM NO. 1 / 3 4 (REV 02-04) Page 278

I I 11

12

13

14

15

Other 2,916 Various 17 2,89!

BLANK PAGE

This Re ort Is: Date of Report YearIPeriod of Report (1) d A n Original (Mo, Da, Yr) End of 2005lQ4 (2) n A Resubmission 04/18/2006

dame of Respondent

Entergy Arkansas, Inc. . I I I I

ELECTRIC OPERATING REVENUES (Account 400) , The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (9). Unbilled revenues and MWH elated to unbilled revenues need not be reported separately as required in the annual version of these pages. !. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. i. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added 3r billing purposes, one customer should be counted for each group of meters added. The -average number of customers means the average of twelve figures at the Close of !ach month. 1. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote.

.ine Title of Account Operating Revenues Year Operating Revenues

VO. to Date QuarterlylAnnual Previous year (no Quarterly)

I 620,327,2031 539,293,25t ~~

21 (440) Residential Sales

4 smai (or Comm.) (See Instr. 4) 347,640,523' 304,808,60t

5 Large (or Ind.) (See Instr. 4) 361,878,9421 318,439,751

61 (444) Public Street and Highway Lighting I 7,931,041 I 7,473,75;

8,322,62f 7 (445) Other Sales to Public Authorities 9,790,726

8 (446) Sales to Railroads and Railways ~~~ ~ ~~~

(448) lnterdepartmenta6ales

TOTAL Sales to Ultimate Consumers 1,347,568,435 1,178,338,002

(447) Sales for Resale 403,089,758 436,049,372

TOTAL Sales of Electricity 1,750,658,193 1,614,387,381

(Less) (449.1) Provision for Rate Refunds -3,267,912 2,835.19e

14 TOTAL Revenues Net of Prov. for Refunds

15 Other Operating Revenues

16 (450) Forfeited Discounts I 6,684,9091 3,397,01!

I 1 I

I I

2f

27 - TOTAL Other Operating Revenues 35,129.395 41,593,03:

TOTAL Electric Operating Revenues 1,789,055,500 1,653,145,211

ERC FORM NO. 1 (ED. 12-96) Page 300

This Re ort Is: Date of Report Name of Respondent (1) d A n Original (Mo, Da, Yr) Entergy Arkansas, hc. (2) n A Resubmission 0411 812006

5,730,359 5,427,760 83,254 82,133 1

7,333,653 7,004,259 22,321 22,532 !

75,406 74,821 592 526 t

212,317 199,679 45 57 ;

Yeadperiod of Report End of 2005lQ4

21,005,055 8,657,656 I 12,348,692) 20 I 24 1'

I

s 19,734,513 672.91 1 667,740 1(

29,662,711 32,083,205 672,931 667,763 1:

1:

29,662,711 32,083,205 672,931 667,763 1 1


!Schedule Page: 300 Line No.: 4 Column: b

Yearperiod of Report

Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - all other business or professional activities of a non-manufacturing nature.

Entergy Arkansas, Inc. (2) - A Resubmission OW1 W2006 2005104

FOOTNOTE DATA ~

!Schedule Page: 300 Line No.: 21 Column: b

Includes ($3,214,632) of unbilled revenue.

bchedule Page: 300 Line No.: 21 Columns c

Includes $6,910,885 of unbilled revenue.


BLANK PAGE

This Re ort Is:

(2) n A Resubmission 0411 812006

Date of Report (1) d A n Original (Mo, Da, Yr)


I ~, I I I

SALES OF ELECTRICITY BY RATE SCHEDULES J 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 31 0-31 1. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in “Electric Operating Revenues,” Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Reoort amount of unbilled revenue as of end of year for each applicable revenue account subheading. I

YearIPeriod of Report End of 2005lQ4

1 RESIDENTIAL 2 R Gen. Purpose Res. 3 RC Gen. Purpose Res. 4 RT Opt. Res. Time-of-Use 5 RW Gen. Pumse Res.

4,386,421 276,248,982 365,730 11,994 0.0630 5,217 314,610 293 17,805 0.0603

500 29,485 36 13,889 0.0590 3,189,535 160.1 50,398 197,705 16,133 0.0502

6 7

8

RX Gen. Purpose Res. 3,254 166,532 168 19,399 0.051 1

L4 All Night Outdoor Lighting 67,780 6,741,003 2,643 25,645 0.0995

D2 Nuclear Decommissioning 12

9 10

11 12

251 I I I 1 I 261 I

M33 Rate Rider 66,193,648

ECR Energy Cost Recovery Rider 107,584,901 TC Transition Cost Rider 2,872,634 Miscellaneous 608) 24,998 124 4,903 0.041 1

131

31 32 33 34

I I I


18 19

20

21 22

27

28 29 30

This Re rt Is: Date of Report (1) $An Original (2) n A Resubmission 04/18/2006

(Mo, Da, Yr) Name of Respondent


YearfPeriod of Report Endof 2o051Q4

121 LG1 Large Gen. Service I 1,092,2441 36,474,9341 9301 1,174,4561 0.033r

6 7 8 9

10 11

13) LG2 Large Gen. Service I 42,842) 1,405,2151 14 3,060,143) 0.0321 ld LG4 brae Gen. Service 50.61 61 1.51 3.1 491 1 al 2.81 2.0001 0.029s

~

SG5 Small Gen. Service 346 12,163 1 346,000 0.035; SG6 Small Gen. Service 51 1 SG7 Small Gen. Service 22,641 1,003,907 1,021 22,175 0.044: GT1 Opt. LGS Time-of-Use 631,365 18,169,575 308 2,049,886 0.028t GT2 Opt. LGS Time-of-Use 23,387 735,511 4 5,846,750 0.031d GT4 Opt. LGS Time-of-Use 16,491 439,616 6 2,748.500 0.026;

I - I I I . . . ,

151 IL1 LGS Interruptible I 2,1831 54,8371 21 1,091,5001 0.025' 16 17 18 19

LP1 Large Power Service 31,716 1,004,520 5 6,343,200 0.031 i LP4 large Power Service 57,296 1,731,044 5 11,459,200 0.030; PT1 Opt. LPS Time-of-Use 102,418 2,794,426 9 11,379,778 0.027: PT2 Opt. LPS Time-of-Use 120,776 3,276,914 7 17,253,714 0.0271

201 PT4 Opt. LPS Time-of-Use 308,6281 7,971,4731 91 34,292,0001 0.025t I 211 SPC Swcial Contract 18.O88i 798.8001 11 18.088.0001 0.044; 22

23 24 25

. ,

CTV Comm. Ant. & TV Amp. 21,890 1,106,902 2,097 10,439 0.05Of L4 All Night Outdoor Lighting 93,456 6,730,356 1,716 54,462 0.072( M33 Rate Rider 35,381,380 ECR Enerav Cost Recovew Rider 81,252,341

I I I ~ ~

261 TC Transition Cost Rider 24 Miscellaneous 101 4,934 151 6671 0.493

1.81 1,0431

40

41 42 43

~~ ~

28

29

30 31

Total 5,730,359 347,640,523 83,254 68,830 0.0607

TOTAL Billed C 0 C C O.OOo( Total Unbilled Rev.(See Instr. 6) C 0 C C O.OOO( TOTAL C 0 C O.OOO( CI

~

33 34 35

36 37 3a


Entergy Arkansas, Inc. (2) n A Resubmission 0411 812006 . . I I

SALES OF ELECTRICITY BY RATE SCHEDULES

1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 31 0-31 1. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,' Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.


5 6 7 8 9

10

SG2 Small Gen. Service 67,511 3,155,862 46 1,467,630 0.0461 SG3 Small Gen. Service 4,465 170,455 26 171,731 0.0382 SG4 Small Gen. Service 33.641 1,635,964 30 1,121,367 0.048C SG5 Small Gen. Service 39,722 1,989,367 6 6,620,333 0.050' SG6 Small Gen. Service 2,039 372,687 2 1,019,500 0.1 82t GT1 ODt. LGS Time-of-Use 313,235 9.1 70,134 124 2,526,089 0.029:

11 12 13 14

GT2 Opt. LGS Time-of-Use 30,784 890,906 8 3,848,000( 0.0281

IG1 LGS TOU Interruptible 48,799 71 6,388 3 16,266,333 0.01 41 GT4 Opt. LGS Time-of-Use 340,941 7,808,777 76 4,486,066 0.0225

IG3 LGS TOU Interruptible 5,458 77,241 1 5,458,000 0.014 15 16 17 18 19 20

IG4 LGS TOU Interruptible 47,770 659,529 3 15,923,333 0.013t LG1 Large Gen. Service 523,864 18,353,935 274 1,911,912 0.035 LG2 Large Gen. Service 48,758 1,734,347 24 2,031,583 0.035C

0.0381 LG4 Large Gen. Service 72,349 2,332,008 15 4,823,267 0.032: LG5 Laroe Gen. Service 17,346, 505,787 5 3.469.200 0.0292

460,000 LG3 Large Gen. Service 920 35,046 2

21 22 23

IL1 LGS Interruptible 11,255 21 7,233 4 2,813,750 0.01 9: 112 LGS Interruptible 11,228 223,122 2 5,614,000 0.01 95 LPl Large Power Service 43,614 1,542,707 6 7,269,000 0.039

FERC FORM NO. 1 (ED. 12-95) Page 304.2

24 25 26

LP2 Large Power Service 260,817 8,661,574 18 14,489,833 0.0332 LP4 Large Power Service 285,741 9,196,679 23 12,423,522 0.03Z IP2 LPS Interruptible 17,511 390,127 1 17.51 1,000 0.022:

27 28 29 30 31 32 33

PT1 Opt. LPS Time-of-Use 257,093 7,340,627 23 11,177,957 0.028C PT2 Opt. LPS Time-of-Use 527.71 0 14,848,757 21 25,129,048 0.0281 PT4 Opt. LPS Time-of-Use 2,262,650 53,621,737 43 52,619,767 0.023;

PT6 Opt. LPS Time-of-Use 85,442 2,211,234 3 28,480,667 0.0256 PT5 Opt. LPS Time-of-Use 71,263 2,097,755 5 14,252,600 0.029

IT4 LPS TOU Interruptible 645,846 11,865,190 3 215,282,000 0.01 gr SPC Special Contract 119,621 3,867,413 2 59.81 0,500 0.032:

34 35 36 37 38 39 4C

APA Irrigation Service 173,355 8,121,627 2,669 64,951 0.046E APE Irrigation Service 30.600 1,841,422 1,157 26,448 0.0602

L4 All Night Outdoor Lighting 14,915 1,068,553 230 64,848 0.071 C SS Standby Service 53,821 4,046,741 0.0752

CGS Cotton Ginning Service 58,506 2,829,462 4 4 1,329,682 0 . o w

C23 Cogeneration 1,200 7 M33 Rate Rider 35,092,685

41 42 43

I TOTAL Billed C 0 c( C O.OOO( Total Unbilled Rev.(See Instr. 6) c, 0 0 O.OOO( TOTAL 0 d O.OOO(

This Re ort Is:

(2) n A Resubmission 04f 18f2006

Date of Report (1) d A n Original (Mo, Da. Yr)

Name of Respondent

Entergy Arkansas, lnc.

' 1. Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per 'customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 310-31 1. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers.

te the estimated evenue billed pursuant thereto.


Date of Report This Re ort Is: (1) d A n Original (2) n A Resubmission 0411 8/2006

(Mo, Da, Yr) Entergy Arkansas, Inc.

I Y I I 1 SALES OF ELECTRICITY BY RATE SCHEDULES i


3

below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per

2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues,' Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported

e in a footnote the estimated additional revenue billed pursuant thereto. ch applicable revenue account subheading.

I 31 I2 Traffic Signal Service I 7,7201 323,5401 2201 35,091 I 0.041 91 41 L4 All Night Outdoor Lighting 2691 21,8401 651 4,1381 0.0812 I 51 M33 Rate Rider I 817,9151 I

I I I I I 141 15

16 17

18 19

I I

41 TOTAL Billed 0 C cl 0.000c 42 Total Unbilled Rev.(See Instr. 6) 0 C 0.0000 43 TOTAL d 0 a d o.oooc,

I I I I I 1 1




Name of Respondent

Entergy Arkansas, Inc. (2) rl A Resubmission 0411 812006


. . I I I J SALES OF ELECTRICITY BY RATE SCHEDULES

1. Report below for each rate schedule in effect during the year the MWH of electriclty sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Pages 31 0-31 1. 2. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300-301. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. 3. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. 4. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). 5. For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. 6. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.

MWn S Line NumDer and I itle ot Hate scheaule ota Hevenue Average Number of Cus omers

No. (a) (b) (c) (4 @t%fLer es ?FgsE%er 1 'T

(f)

181 I I I I I 1 91

10 11

201

ECR Energy Cost Recovery Rider 2,970,100 TC Transition Cost Rider 64,230

I

12

13 14 15 16 17

I

I

33 34

I

I

J

I

39 40

30 31 32

Total 21 2,317 9,790,726 45 4,718,156 0.0461

41 42 43

351 I I I I I 1

I I TOTAL Billed ol 0 0 ol 0.000c Total Unbilled Rev.(See Instr. 6) 0 9 0.000c TOTAL d 0 d 0.000c

This Re rl Is: Date of Report (1) $Onn Original (Mo, Da, Yr)

Name of Respondent

Entergy Arkansas, Inc. (2) 0 A Resubmission 0411 812006

, - - - - - I

vera e Avera e Monthly Billing Demand (MW) IMonthc NC? Demand Monthly CAemanc

o.camnn= V I ""atnpatny V I I "Yll" rl"nIVllry

(Footnote Affiliations) I cation I Tariff Number I Classifi- Schedule or

YearJPeriod of Report End of 20051Q4

2

3

4 I 5 I City of West Memphis I RQ I 99 I 84 741 67

Conway Corporation RQ 98 186 ' 157 145

City of Osceola RQ 101 41 31 25

CiofThayer RQ 104 5 4 4

6

7 Benton Municipal Light &Waterworks I RQ 132 0 50 C

Arkansas Electric Cooperative Corp. (4) RQ 82 1576 1470 149e

8 I Ameren Service Company I RQ 127 1651 1651 165

I Total

City of Prescott

Farmers Electric Cooperative

NoRh Arkansas Electric Cooperative

I

RQ 133 22 19 i a RQ 134 23 15 15

RQ 135 0 0 C

d

Entergy System Power Pool (1) os os System Sales to OU'tm (2,3,5)

0

94 NIA NIA N/A

94 NIA NJA NIA


Subtotal RQ

Subtotal non-RQ

Page 310

0 0 0

0 0 0

This Re ort Is: Date of Report (1) $An Original (Mo, Da, Yr)

Name of Respondent

Entergy Arkansas, Inc. (2) n A Resubmission 04/18/2006 \ , I I

SALES FOR RESALE (Account 447) (Continued)

OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ' in column (a) after this Listing. Enter "Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-sewice involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (9) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (9) through (k) must be subtotaled based on the RWNon-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ' amount in column (9) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (9) must be reported as Non-Requirements Sales For Resale on Page 401 Jne 24. 10. Footnote entries as required and provide explanations following all required data.

Yeadperiod of Report End of 2005lQ4

Megawatt Hours REVENUE Total (9) Demand Charges Energy Charges Other Charges (h+i+j)

6) 6) (9) (h) (i) (i) (k)

($) Sold

22.038 71,281 654,827 726,108

561,801 2,569,572 25,149,824 27,719,396

141,308 579,046 6,194,615 6,773,661

14,176 58,661 854,518 913,179

232,181 I 1,227,3151 10,634,3451 I 11,861,660l 5

Line No.

1

2

3

4

264,743 I I 9,927,8551 I 9,927,854 6

82,422

1,845

3,278,273

68,624

233,345 I 22,391,7261 12,672,9491 I 35,264.67q 7 1,445,469 I 22,275,0001 29,618,421 I 5i.893.4211 a

316,281 3,669,740 3,986,021 11

100,222 100,222 12

139,430,788 139,430,788 13

226,767 5,021,257 256,195 5,504,219 14

45 I

4,569,577

I

84,667.786 136,523,822 0 221,191,608

123,581 I 297,7851 5,606,641 I I 5,904,424 10

- ~

8,657,656 84,894,553 ~ ~ ~~~ ~ ~ ~~

317,939,010 256,195 403,089,758

4,088,079 I 226,767 I 181,415,188 I 256,195 I 181,898,150 I


This Re ort Is: Date of Report Name of Respondent (1) $An Original (Mo, Da, Yr) Entergy Arkansas, Inc. (2) n A Resubmission 04/18/2006

\-I I I

SALES FOR RESALE (Account 447) 1 . Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term' means five years or Longer and "firm' means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years.


jne No.

1

Avera e Actual Demand (MW) Monthly &ling vera e Avera e Demand (MW)

Name of Company or Public Authority Statistical FERC Rate Classifi- Schedule or I cation I TarflNumber (Footnote Affiliations) Month; NC? Demand Monthly CPgernant

2

10

11

12

13

14

3

Mississippi Delta Energy Agency (6) os OAlT NIA NIA NIP The Energy Authority (6) os WSPP NIA NIA NIP

EWO Marketing os OAlT NIA N/A NIP

Merrill Lynch os OATT N/A N/A NIP

Strategic Energy os O A T NIA NIA NIP

Total

I Subtotal RQ

I 0 a

I I I ol 0

I Subtotal non-RQ I I I d 0


This Re ort Is: Date of Report Name of Respondent (1) $An Original (Mo, Da, Yr) Entergy Arkansas, Inc. (2) n A Resubmission 0411 8/2006

i ~ ' u SALES FOR RESALE (Account 447) (Continued)

OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter 'Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ' in column (a) after this Listing. Enter "Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which sewice, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-sewice involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (9) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column 0). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. 9. The data in column (9) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (9) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (9) must be reported as Non-Requirements Sales For Resale on Page 401 , h e 24. 10. Footnote entries as required and provide explanations following all required data.

YearlPeriod of Report Endof 2005/44

4,088,079

8,657,656


226,767 181,415,188 256,195 181,898,150

84,894,553 317,939,010 256,195 403,089,758

Page 311.1

Name of Respondent This Re ort Is: Date of Report Entergy Arkansas, Inc. (2) 0 A Resubmission 0411 EV2006

(1) $An Original (Mo, Da, Yr)

1. Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326-327). 2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. 3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (Le., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment fur service is one year or less. LU - for Long-term service from a designated generating unit. 'Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that 'intermediate-term" means Longer than one year but Less than five years.


jne No.

Avera e Actual Demand (MW) Avera e Monthly billing vera e

Name of Company or Public Authority Statistical FEW Rate Classifi- Schedule or

(Footnote Affiliations) Cation Tariff Number Demand (MW) Month; NC8 Demani Monthly CPgemanc

5 I Tenaska Power Services Company (6) 10s I WSPP I NIAI N I P

2 3 4

Duke Energy Trading Company (6) os WSPP NIA N/A NIP

Central Louisiana Electric Company (6) os WSPP NIA N/A NIP

Kansas Citv Power & Liaht (6) os WSPP NIA N/A N I P

Subtotal RO


0 0 0

Page 310.2

Subtotal non-RQ

Total

0 0 0

0 0 0

This Re rt Is: Date of Report (1) 8 A n Original (2) II A Resubmission 041 8/2006

(Mo, Da, Yr) Entergy Arkansas, inc. , % * I I

SALES FOR RESALE (Account 447) (Continued) OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. 4. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ' in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total" in column (a) as the Last Line of the schedule. Report subtotals and total for columns (9) through (k) 5. In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. 6. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 7. Report in column (9) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser.

~ 9. The data in column (9) through (k) must be subtotaled based on the RWNon-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (9) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ' amount in column (9) must be reported as Non-Requirements Sales For Resale on Page 401 ,iine 24. 10. Footnote entries as required and provide explanations following all required data.

YearIPeriod of Report End of XItJ5/Q4

Megawatt Hours

(9)

Sold

74.536 77

REVENUE tine Demand Charges Energy Charges Other Charges (h+i+j) No.

4,334,580 4,334,580 1

Total ($)

($1 ($1 (h) 0) U) (k) ($1

3,773 3,773 2

4,263

55

332

212.541 212,541 3

3,236 3,236 4

16,503 16,503 5

4,088,079 I

32

393,319

1,276,218 176

15

553 1,264

13

~~

226,767 I 1 8 1 , 4 1 5 , 1 8 8 1 ~ 256,195 I 181,898.1 507

1,440 1,440 6

18,480,798 18,480,798 7

34,741,139 17,974,262 52,715,401 8

8,096 8,096 9

795 795 10

28,232 28,232 11

54,292 54,292 12

722 722 13

4,569,577


~~

14

84,667,786 136,523,822 0 221,191,608

Page 311.2

8,657,656 84,894,553 31 7,939,010 256,195 403,089,758

Name of Respondent


bchedule Page: 310 Line No.: 7 Column: a 1

This Report is: Date of Report YearIPeriod of Report (1) An Original (Mo, Da, Yr) (2) - A Resubmission 0411 8f2006 2005lQ4

(4) Includes revenue from co-owners of White Bluff, Independence, and Ritchie Steam Electric Stations due to heat rate incentive and supplying entitlement energy from units other than jointly owned units.

bchedule Page: 310 Line No.: 13 Column: a

(1) A contract wherein the parties have combined their power sources and transmission facilities on a pool basis to maximize capability, reliability, and economy.

behedole Page: 310 Line No.: 14 Column: a

(2) SYSTEM SALES TO OTHERS YEAR ENDED DEMAND ENERGY TOTAL 12/31/2005 MWH CHARGES CHARGES Arkansas Electric Cooperative CorD. 4,794 s- $439.822 $439.822 Associated Electric Cboperative, Inc. American Electric Power Air Liquide Alabama Electric Cooperative, Inc. Ameren Services Bayou Cove, LLC BP Energy Co. Calcasieu Power Calpine Energy Service, LP Cargill-Alliant, LLC Carville Energy Cincinnati Gas and Electric Central Louisiana Electric Company Central Mississippi Generating Company Coral Energy Conoco, Inc. Constellation Power Source, Inc. Cottonwood Energy, LP Dow Chemical Company Duke Energy and Trading Duke Hot Springs Duke Energy Hinds, LLC DTE Energy Trading, Inc. Empire District Electric Eagle Energy Partners East Texas Electric Cooperative Exelon Generation Company, LLC Exxon Company U.S.A. Formosa Grand River Dam Authority City of Hodge City of Jonesboro City of Lafayette Hot Spring Power Company, LLC Independence Power & Light Co. J. Aron & Company Kansas City Power c Light Louisiana Energy Power Authority LSP Energy, LP Merrill Lynch Commodities, Inc. MidAmerican Energy Corporation Mississippi Delta Energy Agency Missouri Joint Municipal Elec Utility Corn Missouri Public Service NRG Power Marketing, Inc.

28; 677 22,229

24 148

3,631 8

610 103

1,888 21,217

13 13,477 1,271

513 5,825

648 5,859 I, 383

780 1,191

-

1

9 4

52

898 - 813 - 206 - 603 - 8 68 - 663 - 550 - 85 - 64 7 - 449 4,702,177 422 - 62 -

1,679 - 184 - 358 -

9,975 - 12 -

3,413 - 2,049 - 4,275 -

275 - - 319,680

277 - 14,306 -

2,033; 719 2,349,828

3 , 4 2-3 9,476

151,212 1,074

62,117 14,621

144,859 1,878,043

1,094 1,178,349

116,785 (51)

48,370 538,418 59,703

803,592 175,601 88,554

111,362 202 , 655 52,345 14,208 25,447

489,510 382,777 47,192 9,317

88,690 (36,098) 13,926 3,938

180,512 19,083 32,586 889,008

1,360 366,367 154 , 754 568,425 19,340

28,002 1,037,078

-

2,033; 779 2,349,828

3,423 9,476

151,212 1,074

62,117 14 , 621

144,859 1,878,043

1,094 1,178,349

116,785 (51)

48,370 538,418 59,703

803,592 175,601 88,554

111,362 202,655 52,345 14,208 25,447 489,510 382,777 47,192 9,317

88,690 4 , 666,079

13,926 3,938

180,512 19,083 32,586 889,008

1,360 366,367 154,754 568,425 19,340

319,680 28,002

1,037,078

IFERC FORM NO. 1 (ED. 12-87) T I


Name of Respondent


Oklahoma Gas & Electric Ouachita Power, LLC Occidental Chemical Corporation Pine Bluff Energy Progress Energy Carolina's, Inc. Public Utilities Rainbow Energy Marketing Corp. RS Cogen Sabine Cogen, LP Split Rock Energy, LLC Southwest Power Administration Southwestern Public Service Southwestern Company Services, Inc SRW Cogen Sunflower Electric Company TECO Energy Source The Energy Authority Tenaska Power Services Company Tennessee Valley Authority UBS AG Union Power Warren Power, LLC West Plains Energy Westar Energy Western Farmers

>

This Report is: Date of Report Yeadperiod of Report (1) & An Original (Mo, Da, Yr) (2) - A Resubmission 0411 a12006 2005lQ4

Plus: Net Adjustments to Sales

TOTAL SYSTEM SALES TO OTHERS:

Supplied By: Entergy Arkansas, Inc. Entergy Gulf States, Inc. Entergy Louisiana, LLC Entergy Mississippi, Inc. Entergy New Orleans, Inc.

825 1,553 341 48

2,334 156 666

31 2,639

87 64 5

47,145 108 925 50

10,335 3,932

53,273 15,026 1,618

429 122

48,035 1,228

-

- - - - - - - - - 414,909

MWK 68,624

165,675 106,318 54,466 21,302

416,385 ------- ------- - - - - - - -

58,931 158,677 31,101 4,214

129,986 17,468 51,903 10,016 4,686

172,792 8,700

70,827 3,041,793

12,519 93,340 2,900

682,949 255,993

4,583,914 1,125,953

113,002 35,414 14,901

2,926,351 133,564 -----------

29,148,953

58,937 158,677 37 , 701 4,214

129,986 17,468 51,903 10,016 4,686

172,792 8,700

70,827 3,041,793

12,519 93,340 2,900

682 , 94 9 255,993

4,583,914 1,725,953

113,002 35,414 14,901

2,926,351 133,564 ------------

34,170,810

REVENUE $5,504,219

Note : The Entergy Companies jointly supply energy for sales to non-associated utilities. Due to the format of purchased power accounting records it is impractical to identify precisely how much each system company supplied to any given sale.

(3) Amount in other charges represents imputed transmission.

(5) Generator Imbalance Agreement (GIA) Sales are sales made pursuant to the GIA for under delivery of energy.

Fchedule Page: 370.7 Line No.: 6 Column: a

(6) Sales provided under a letter agreement effective March 1992.

Page 310-31 1 Footnote.2

Name of Respondent


bchedule Page: 310.1 Line No.: 7 Column: a

( 7 ) Opportunity sales are sales made in order to market excess capacity resulting from the loss of a contract with City of North Little Rock.

This Report is: Date of Report YearIPeriod of Report (1) X An Original (Mo, Da, Yr) (2) - A Resubmission 0411 812006 2005lQ4

pchedule Page: 370.2 Line No.: 8 Column: a

r

(8) Energy and Capacity Sales associated with the Resource Plan.

(FERC FORM NO. 1 (ED. 12-87) I Page 310-31 1 Footnote.3

BLANK PAGE

Name of Respondent This Re ort Is: Date of Report Year/Period of Report

Entergy Arkansas, Inc. End of 2005/a4 (1) d A n Original (2) n A Resubmission 0411 El2006

(Mo, Da, Yr)

ELECTRIC OPERATION AND MAINTENANCE EXPENSES If the amount for previous year is not derived from previously reported figures, explain in footnote. Line Account &mounpr Amount for

urrent ear Previous Year No. l d

5 (501) Fuel 141,689,852 127,569,958 6 (502) Steam Expenses 1,896,179 2,333,892 7 (503) Steam from Other Sources 8 (Less) (504) Steam Transferred-Cr. 9 (505) Electric Expenses 1,192,792 1,563,934

10 (506) Miscellaneous Steam Power Expenses 6,515,559 3,973,129 11 (507) Rents 4,579,905 4,884,914 12 1509) Allowances

24 (51 7) Operation Supervision and Engineering 18,691,459 19,282,226 25 (518) Fuel 74,275,482 79,677,662 26 (519) Coolants and Water 5,265,466 5,227,466 27 (520) Steam Expenses 22,984,6 1 6 24,583,439 28 (521) Steam from Other Sources 29 (Less) (522) Steam Transferred-Cr.


Name of Respondent

Name of Respondent This Re ort Is: Date of Report YearIPeriod of Report

Entergy Arkansas, Inc. End of 2005JQ4 (1) d A n Original (2) n A Resubmission 0411 812006

(Mo, Da, Yr)

- ELECTRIC OPERATION AND MAINTENANCE EXPENSES (Continued)

If th Line No. 101 101 1 Of 10; 1 ot 10: 11( I l l 11; 11:

-

- - - - - - - - - - - 1 1 E 1 1 € 117 1 1 E 115 12c 121 122 12: 124 125 12E 12i 12f 12s 13C 131 1 32 13: 134 135 136 137 1% 139 140 141 142 143 144 145 146 147 148 149 150 151 152 153

- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -

TOTAL Ooeration (Enter Total of

(590) Maintenance Supervision and Engineering 2,200,059 (591) Maintenance of Structures 44,123 27,226

2.71 4,059 1,159,307 (592) Maintenance of Station Equipment 21,102,118 21,754,071 (593) Maintenance of Overhead Lines

(594) Maintenance of Underground Lines 1,262,163 1,5OO,110 (595) Maintenance of Line Transformers 14,859 3.01 1 (596) Maintenance of Street Lighting and Signal Systems 1,138,641 1,382,438

316,038 (597) Maintenance of Meters 141,712 ieous Distribution Plant 1,121,940


Name of Respondent This Re rt Is: Entergy Arkansas, Inc.

(1) $An Original (2) n A Resubmission


Yeartperiod of Report End of 2005/Q4

I

167 168 169

I

2,822,936 (935) Maintenance of General Plant TOTAL Admtn & General Expenses (Total of lines 165 thru 167) 121,581,827 101,223,452 TOTAL Elec Op and Maint Expn (Tot 80,100,126,134,141,148,168) 1,198,535,316 1,104,410,227

3,185,258

I

Name of Respondent This Re ort Is: Date of Report

Entergy Arkansas, Inc. (1) $An Original (2) OA Resubmission 0411 812006

(Mo, Da, Yr)

Name of Company or Public Authority Rate Average Actual Demand (MW) Classifi- Schedule or Monthly Billing Average Average I cation I Tariff Number Demand (MW) Monthlv NCP Deman Monthlv CP Demanc (Footnote Affiliations)

YearIPeriod of Report End of m05/Q4

I I I 1 I 1 I Total


This Re ort Is: (1) $An Original 12) l l A Resubmission

Name of Respondent


AD - tor out-of-period adjustment. Use this code for any accounting adjustments or "true-ups' for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment.


YearIPeriod of Report End of 2005104

4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. 5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. 6. Report in column (9) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. 7. Report demand charges in column (j), energy charges in column (k), and the total of any other types of charges, including out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column ( I ) . Report in column (m) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. 8. The data in column (9) through (m) must be totalled on the last line of the schedule. The total amount in column (9) must be reported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401, line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13. 9. Footnote entries as required and provide explanations following all required data.

Megawatt Hours Purchased

(9)

Line Megawatt Hours Megawatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l) N ~ .

POWER EXCHANGES COSTISETLEMENT OF POWER .

6) of Settlement ($) (1) (m)

($) (h) 0) (i)

Received Delivered

1 I

1,447,35q 3,265,083

I

194,756,394 194,756,395 2

184,936,014 13,557,4923 198,494,306 2

11,601 2,927 18,086

1,234

422,879 422,873 4

101,990 101,990 E

298,726) 298,726 e

I

2,6361

4,421,Olq 190,446

I

1 12,244 112,244 7 E

224,912 5,871,568 289,485,353 295,356,921

45,34d

784,945 72,109 4,958

10,588,533

1 11

32,728,675( 32,728.675 12 2,620,564 2,620,564 12

116,918 116,918 14

190,446 224,912 190,808,382 1 564,460,537 755,276,919

45,34r- 1C

(b) · ano-c fire protection improvement 1,065,514 1,057,072 ano-1 pressurizer/hotlegs ......

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