name entergy arkansas, inc. · 2005. 5. 2. · dew orleans, la 701 13 intergy corporation i39...

FERC FORM 1 SUPPLEMENT

NAME ENTERGY ARKANSAS, INC. (Here show in full the exact corporate, firm or individual name of the respondent)

LOCATED AT 425 W. CAPITOL, P.O. BOX 551, LITTLE ROCK, ARKANSAS 72203 (Here give the location, including street and number of the respondent's main business office within the State)

COMPANY # 1 1 (Here give the APSGassigned umpany number)

TO THE

ARKANSAS PUBLIC SERVICE COMMISSION

COVERING ALL OPERATIONS

FOR THE YEAR ENDING DECEMBER 31,2004

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004

In order to satisfy the filing requirements of the Arkansas Public Service Commission, these supplemental schedules will be filed annually with a copy of the Federal Energy Regulatory Commission Form 1. One complete copy will be filed with each, the Utilities Division and the Tax Division of the Arkansas Public Service Commission, on or before March 31 immediately following the year being reported.

To: Arkansas Public Service Commission Post Office Box 400 Little Rock, Arkansas 72203

Submitted herewith is the annual report covering the operation of

of

accordance with Section 51 of Act 324 of the 1935 Acts of Arkansas.

ENTERGY ARKANSAS, INC. (Company)

LITTLE ROCK, ARKANSAS (Location)

for the year encling December 31,2004. This report is submitted in

The following report has been carefully examined by me, anld I have executed the verification given below.

/s/ NATHAN E. LANGSTON (Signature)

SENIOR VICE PRESIDENT & CHIEF ACCOUNTING OFFICER (Title)

*************** VERIFICATION

STATE OF ) LOUISIANA

PARISHOF ) ORLEANS I, the undersigned, NATHAN E. LANGSTON. SENIOR VICE PRESIDENT & CHIEF ACCOUNTING OFFICER

(Name and Title) of the ENTERGY ARKANSAS. INC., on my oath do say that the following report has been prepared under my

direction from the original books, papers, and records of said utility; that I have carefully examined the same, and declare the same a complete and correct statement of thle business and affairs of said utility in respect to each and every matter and thing set forth, to the best of my knowledge, information, and belief; and I further say that no deductions were made beftpre stating the gross revenues, and that accounts and figures contained in the foregoing statements embrace all of the financial transactions for the period in this report.

) ss.

(Company)

Subscribed and sworn to before me this day of April ,2005 MY

25th

Commission Expires

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 General 1

1.

2.

3.

4.

5.

6.

7.

8.

9.

10.

11.

12.

13.

14.

GENERAL INSTRUCTIONS, IDEFINITIONS, ETC.

Two (2) copies of this report, properly filled out and verified, shall be filed with the Utilities Division of the Arkansas Public Service Commission, Little Rock, Arkansas on or before the 31st day of March following the close of the calendar year for which the report is made.

This form of annual report is prepared in conformity with the Uniliorm System of Accounts for Public Utilities prescribed by the Public Service Commission, and all accounting words and phrases are to be interpreted in accordance with the said classification.

The word "respondent" in the following inquiries means the person, firm, association or company in whose behalf the report is made.

Instructions should be carefully observed, and each question should be answered fully and accurately. Where the word "none" truly and completely states the fact, it should be given to any particular inquiry.

If any schedule does not apply to the respondent, such fact should be shown on the schedule by the words "not applicable."

Except in cases where they are especially authorized, cancellatitons, arbitrary check marks, and the like must not be used either as partial or entire answers to inquiries.

Reports should be made out by means which result in a permanent record. The copy in all cases shall be made out in permanent black ink or with permanent black typewriter ribbon. Entries of a contrary or opposite character (such as decreases reported in a column providing for both increases and decreases) should be shown in red ink or enclosed in parentheses.

Each report shall be bound in permanent form before returning to the Commission. Binding with clips is not sufficient.

Answers to inquiries contained in the following forms must be complete. No answer will be accepted as satisfactory which attempts by reference to any paper. document, or return of previous years or other reports, other than the present report, to make the paper or document or portion thereof thus referred to a part of the answer without setting it out. Each report must be complete within itself.

In cases where the schedules provided in this report do not contain sufficient space for the information called for, or if it is otherwise necessaty or desirable, additional statements or schedules may be inserted for the purpose of further explanation of accounts or schedules. They should be legibly made on paper of durable quality and should conform with this form in size of page and width of margin. This also applies to all special or unusual entries not provided for in this form. Where information called for herein is not given, state fully the reason for its omission.

Each respondent is required to send in connection with its report to this Commission's Utilities Division, one (1) copy of its latest annual report to stockholders.

Schedules supporting the revenue accounts and furnishing statistics should be so arranged as to effect a division in the operations as to those inside and outside the state.

Answers to all inquiries may be in even dollar figures, with the cents omitted and with agreeing totals.

Each respondent should make its report in duplicate, retaining one copy for its files for reference, in case correspondence with regard to such report becomes necessary. For this reason, several copies of the accompanying forms are sent to each utilitv company concerned.

Give the name, title, office address, and telephone number of the person to whom any correspondence concerning this report should be addressed:

Name Paul J. Ow

Address Enterw Services, Inc.. P.O. Box 61000, New Orleans LA 70161-1000

Telephone Number /504) 576-4482

E-mail [email protected]

Title Manaaer. External Remrtinq

~~ ~~ ~ ~~

Give the name, address, and telephone number of the resident agent:

Name Janan Honeysuckle

Address Enterqv Arkansas, Inc., P. 0. Box 551, Little Rock AR 72203

E-mail [email protected]

Telephone Number 1501 1 377-5886

mailto:[email protected]

mailto:[email protected]

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 General 2

IDENTITY OF RESPONDENT 1. Give the exact name by which the respondent was known in law at the close of the year. Use the initial

word "The" only when it is part of the name: ENTERGY ARKANSAS, INC.

2. Give the location (including street and number) of (a) the main Arkansas business office of respondent at the close of the year, and (b) if respondent is a foreign Corporation, the main business office if not in this state

(a) 425 W. CAPITOL LITTLE ROCK, ARKANSAS 72201

MAILING ADDRESS: ENTERGY ARKANSAS, INC. P. 0. BOX 551 LITTLE ROCK, ARKANSAS 72203

3. Indicate by an X in the proper space (a) the type of service rendered, and (b) the type of organization under which respondent was operating at the end of the year

(a) ( x ) Electric, ( )Gas, ( ) Water, ( ) Telephone, ( )Other (b) ( ) Proprietorship, ( ) Partnershiip, ( ) Joint Stock Association,

( x ) Corporation, ( ) Other (describe below):

4. If respondent is not a corporation, give (a) date of organization, and (b) name of the proprietor or the names of all partners, and the extent of their respective inteirest at the close of the year:

Not Applicable

5. If a corporation, indicate (a) in which state respondent is incorporated, (b) date of incorporation, and (c) designation of the general law under which respondent was incorporated, or, if under special charter, the date of passage of the act:

(a) Arkansas (b) October 2, 1926 (c) "An Act to authorize the merger of business corporations and to provide for the sale of the

assets and franchises of such corporations" approved March 11, 1925.

6. State whether or not respondent during the year conducted any part of its business within the State of Arkansas under a name or names other than that shown in response to inquiry No. 1 above, and, if so, give full particulars:

None

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 General 3 I

7. State whether respondent is a consolidated or merged company. If so, (a) give date and authority for each consolidation or merger, (b) name all constituent and merged companies, and (c) give like particulars as required of the respondent in inquiry No. 5 above:

Entergy Arkansas, Inc. (previously known as Arkansas Power & Light Company) as it conducted business in 2004 came into existence on October 13, 1926. Technically, the corporation was created on October 2, 1926, when the Articles of Incorporation were filed with the Secretary of State; however, no assets other than the minimum necessary to incorporate were obtained until October 13, 1926. On that date, a consolidation and merger occurred which combined with and into Entergy Arkansas, Inc. the following companies: (1) East Arkansas Power & Light Company, (2) Arkansas Central Power Company, (3) Arkansas Light & Power Company, and (4) The Pine Bluff Company. These four companies were corporations of the State of Arkansas, incorporated under the laws of this State.

Additionally, effective on and as of January 1, 1981, the electric properties of Entergy Arkansas, Inc. and the Arkansas-Missouri Power Compainy were consolidated as authorized under the laws of the State of Arkansas. Prior to its consolidation with Entergy Arkansas, Inc., Arkansas-Missouri Power Company was (a corporation of the State of Arkansas, incorporated under the laws of this State.

8. State whether respondent is a reorganized company. If so, give (a) name of original corporation, (b) date of reorganization, (c) reference to the laws under which it was reorganized, and (d) state the occasion of the reorganization, whether because of foreclosure of mortgage or otherwise, giving full particulars:

Entergy Arkansas, Inc. is not a reorganized company, except to the extent as described in the answer to No. 7.

9. Was respondent subject to a receivership or other trust at any time during the year? NO If so, state:

(a) Name of receiver or trustee:

(b) Name of beneficiary or beneficiaries for whom trust was maintained:

(c) Purpose of the trust:

(d) Give (1) date of creation of receivership or other trust, and (2) date of acquisition of respondent: (1 1 (2)

10. Did the respondent act in any of the capacities listed in Paragraph (a) below during the past year? - NO If so,

(a) Indicate the applicable one by an X in the proper space:

( ) Guarantor, ( ) Surety, ( ) Principal-obligor to a surety contract, ( ) Principal--obligor to a guaranty contract.

(b) Insert a statement showing the character, extent, and terms of the primary agreement or obligation, including (1) names of all parties involved, (2) extent of liability of respondent, whether contingent or actual, (3) extent of liabilities of the other parties, whether contingent or actual, and (4) security taken or offered by respondent.

REPORT TO ARKANSAS PUBLIC SERVlClI COMMISSION -YEAR 2004 General 1

DIRECTORS AND COMPENSATION Give the name and office addresses of all directors at the close! of the year, and dates of beginning and extliration of terms. Chairman(*) and

Item No.

1.

2.

3.

4.

5.

6

Name of Director

lonald C. Hintz

qichard J. Smith

iugh T. McDonald*

.eo P. Denault

dark T. Savoff

2. John Wilder

rhese individuals are em

ecretary (**) marked by asterisks.

Office Address

htergy Corporation i39 Loyola Avenue dew Orleans, LA 701 13

intergy Corporation i39 Loyola Avenue dew Orleans, LA 701 13

Intergy Arkansas, Inc. 125 W. Capitol Avenue 10th Floor .ittle Rock, AR 72201

intergy Corporation i39 Loyola Avenue Jew Orleans. LA 701 13

intergy Corporation i39 Loyola Avenue Jew Orleans, LA 701 13

intergy Corporation i39 Loyola Avenue Jew Orleans, LA 701 13

Date Beginning

911 111 992

12/23/2001

511 I2000

212312004

511 I2004

411 / I 999

oyees of either Entergy Arkansas, Inc. or ither Entergy System Companies and are not separately compensated

f Term End

4/30/2004

212 012 0 04

5 directors.

ComDensation

REPORT TO ARKANSAS PUBLIC !SERVICE COMMISSION -YEAR 2004 General 4A

PRINCIPAL OFFICERS AND KEY MANAGEMENT PERSONNEL Give the title of the principal officers, managers and key personnel, the! names and office addresses of persons I

Item No. 1.

2.

3.

4.

5.

6.

7.

a.

9.

IO.

11.

12.

13.

14.

ilding such positions at the close of the year

Title Vice President and Chief Financial Officer (1)

Executive Vice President and Chief Financial Officer of Entergy Corporation (2)

Executive Vice President, External Affairs of Entergy Corporation

President and Chief Executive Officer

Senior Vice President and Chief Accounting Officer

Chief Executive Officer of Entergy Corporation

Senior Vice President, Human Resources and Administration

Executive Vice President of Entergy Corporation (3)

Senior Vice President, General Counsel and Secretary

Vice President and Treasurer

Group President, Utility Operations

Executive Vice President and Chief Nuclear Officer of Entergy Coporation (4)

Vice President and Ehief Financial Officer of Entergy Corporation (5)

Vice President and Zhief Financial Officer (6)

and the annlual salarv of each. Name of person holding

office at close of year Jay A. Lewims

Leo P. Denault

Curtis Hebert, Jr.

Hugh T. McDonald

Nathan E. Langston

J. Wayne Leonard

JVilliam E, Madison

Mark Savolf

Pobert D. Sloan

Steven C. FJlcNeal

?ichard J. Smith

3ary Taylor

2 . John Wilder

rheodore E3unting

Office Address 639 Loyola Avenue New Orleans, LA 701 13

639 Loyola Avenue New Orleans, LA 701 13


425 W. Capitol Avenue 40th Floor Little Rock, AR 72201








1340 Echelon Parkway Jackson, MS 39213



Annual Salary *

*

*

*

aaa,a47

*

*

*

*

*

*

*

*

*

*

3fficers whose salaries are not listed are compensated by other System companies and not by Entergy Arkansas, Inc. 1 ) Elected effective January 2004 2) Elected effective February 2004 3) Elected effective May 2004

(4) Elected effective May 2004 (5) Resigned effective February 2004 (6) Resigned effective January 2004

I ELECTRIC OPERATING REVENUES (Account 400) - ARKANSAS ONLY 1. Revort below oDeratina revenues for each number of customers means the average of twelve basis of classification is not generally greater than

each group of meters added. The average Industrial) regularly used by the respondent if such OPERATING REVENUES KILOWATT HOURS SOLD AVG. NO, OF CUSTOMERS PER MONTH

Number for Number for Line Title of Account Amount for Amount for No. Amount for Year Previous Year Amount for Year Previous Year Year Previous Year

(a) (b) (C) (d) (e) (0 f d 1 Sales of Electricity I 2 (440) Residential Sales $539,283,207 $525,546,678 7,027,875,150 7,056,948,325 562,475 557,96: 3 (442) Commercial and Industrial Sales 4 Smal l (or Commercial) (See Instr. 4) 304,801,575 291,435,033 5,427,665,194 5,327,938,110 82,128 80,74; 5 Large (or Industrial) (See Instr. 4) 318,438,224 305,331,784 7,004,247,780 6,998,762,525 22,528 22,92( 6 (444) Public Street and Highway Lighting 7,473,757 7,111,229 74,821,301 74,683,634 526 50:

8 (446) Sales to Railroads and Railwavs 9 (448) Interdepartmental Sales

10 TOTAL Sales to Ultimate Consumers 1,178,319,391 1,137,105,937 19,734,288,949 19,649,578,316 667,714 622,18:

12 TOTAL Sales of Electricity 1,614,368,763 1,559,275,346 32,082,981,245 32,084,589,251 667,737 622,20! 13 (Less) (449.1) Provision for Rate Refunds 2,835,196 1,655,331 14 TOTAL Revenue. Net of Prov. for Refunds 1,611,533,567 1,557,620,015 32,082,981,245 32,084,589,251 667,737 622,ZOi

7 (445) Other Sales to Public Authorities 8,322,628 7,681,213 199,679,524 191,245,722 57 44

11 (447) Sales for Resale 436,049,372 422,169,409 12,348,692,296 12,43501 0,935 23 2:

- prescribed account, and manufactured gas reve- figures at the close of each month. nues in total. 3. If previous year (columns (c), (e), and (g)), are

2. Repolt number of customers, columns (q not derived from previously reported figures, explain and (g), on the basis of meters, in addition to the any inconsistencies in a footnote. number of flat rate accounts; except that where 4. Commercial and Industrial Sales, Account separate meter readings are added for billing 442, may be classified according to the basis of purposes, one customer should be counted for classification (Small or Commercial, and Large or

1000 Kwof demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.)

of such sales in a footnote.

rather than by Mwh.

5. Include unmetered sales. Provide details

6. This Commission requires reporting by Kwh

ELECTRIC OPERATING REVENUES (Account 400) - ARKANSAS ONLY 1. Report below operating revenues for each number of customers means the average of twelve basis of classification is not generally greater than

prescribed account, and manufactured gas revenues in total.

2. Report number of customers, columns (f) and (g), o n the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each a r o w of meters added. The averaae

Muncipal Street Lighting Traffic Signal Service T.V. Amplifier Service Outdoor Lighting

figures at the close of each month. 3. If previous year (columns (c), (e), and (g)), are

not derived from previously reported figures, explain any inconsistencies in a footnote.

442, may be classified according to the basis of classification (Small or Commercial, and Large or rather than by Mwh. Industrial) regularly used by the respondent if such

1000 K w o f demanq. (See Account 442 of the Uniform System of Accounts. Explain basis of

: classification in a footnote.)

4. Commercial and Industrial Sales, Account of such sales in a footnote. 5. Include unmetered sales. Provide details

6. This Commission requires reporting by Kwh

SUMMARY OF UNMETERED SALES - ARKANSAS ONLY FOR THE YEAR 2004

Avg. NO. Revenues KWH Customers $5,614,110 66,972,850 302

316,686 7,617,542 171 1 1 7,544 172,879,673 2,081

14.208.388 22.098.998 *

$20,256 .?28 369.559. GL? 25S4 -

*Customers are not counted in this sales classification but are counted in applicable schedules of service.

;cJ rn 'II 0 x I -I 0 D F z cn

'0 C m 0 cn

z r rn

rn

3 5 cn 0 z

- z 8 0

I

s D x N 0 0 P

v) C U P P D -L

UTILITY PLANT - SYSTEM Plant in Service (Classified) Property Under Capital Leases Plant Purchased or Sold Experimental Plant Unclassified Plant Leased to Others Plant Held for Future Use Completed Construction not Classified Construction Work in Progress Plant Acquisition Adjustments

Sub-Total

Other Plant Adjustments Other Utility Plant (itemize) Nuclear Fuel (in Process of

Nuclear Fuel Under Capital Lease

Total

Refinement, etc.)

UTiLiTY PLANi ARWNSAS

Plant in Service (Classified) Property Under Capital Leases Plant Purchased or Sold Experimental Plant Unclassified Plant Leased to Others Plant He ld for Future Use Completed Construction not Classified Construction Work in Progress Plant Acquisition Adjustments

Sub-Total

Other Plant Adjustments Other Utility Plant (itemize) Nuclear Fuel (in Process of

Nuclear Fuel Under Capital Lease

Total

Refinement, etc.)

Beginning Balance $5,946,969,819

24,046,589

1,120,117

238,806,745

6,21 O,943,27C

7,465,93€ 102,690,786

$6,321 ,O99,99d

Beginning Baiance $5,914,788,45:

24,046,58!

1,101,631

238,789,141

6.1 78.725.821

7,465,938 102,690,78

$6.288.882.54

Additions $242,055,99'

242,055,99

9,423,91 39,847,12

$291.327.03

Additions $241,97596

241,975,962

9,423,910 39,847,129

Retirements ($65,624,336:

(65.624.336

(4,689,096 (48,682,848

($1 18.996.28C

(38,17(

(65.662.50t

(4,689,09( (48,682,84i

I

$291,247,001 I ($1 19,034,451

Adjustments (162,273)

(6,546,765)

(1 2,634,348:

(1 9,343,386:

($1 9,343,386

Adjustments ($6,709,036

(6,546,765

(4,008,901

(1 7.264.702

($1 7.264.70:

Balance at end of Year

$6,123,239,207 17,499,824

20,117

72,397

6.368.031 545

1,

226,

12,200,752 93,855,067

$6.474.087.364

Balance at end Gf Year

$6,084,431,04: 17,499,82~

1,063,461

234,780,24:

6,337,774,57;

12,200,75 93,85506

$6,443,830,39

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -9- YEAR 2004 SUPP. E 3

DAILY PEAK LOAD CURWES

1. Show total net 60 minute peak demand of Intrastate Energy. 2. If 60 minute peak is not available, give that which is available, specifying period. 3. Include total net power demand including that generated and purchased.

Arkansas Load Hour Maximum Minimum Ava. Max. Ava. Min.

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

4569 4453 4285 4008 3951 3975 4223 4509 4808 51 53 5570 5876 6070 6296 6368 6514 6569 6414 6377 6233 6060 5990 5535 51 17

2656 251 8 2498 2502 2521 2567 2760 2885 2994 3025 3008 2964 2952 2887 2883 2916 3052 2970 31 79 3387 3481 3488 31 83 3235

384 1 3691 356 1 3494 3466 351 9 3677 3836 4062 4343 4570 4768 4943 5097 51 96 5257 5294 5267 51 77 5023 4884 4781 441 7 4095

3047 2990 2961 2984 :3119 3271 :3558 3627 :3570 3565 :3535 3477 :3459 ,3434 ,3408 3392 3430 3467 367 1 3768 3745 363 1 3372 31 75

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -- YEAR 2004 SUPP. E-4 p p - ~ p p --p_p-p---- RAILYPT,AKISBIICUBYES--l

Max, day of yr. (7/13/04), Peak Mw 6569 Peak Hour 500 PM

Min. day of yr. (03/21/04), Peak Mw 3488, Peak Hour 1O:OO PM

Yearly Peak (7/13/04), Historical Max. Day (7/13/04)

Avg. day max month (7/04) I -x- -

- - p . ~ ~ - - ~ ~ - - ~ - - ~ 8000 - r ~ -

lu

7000

I * Avg. day min month (03/04) \ 6000

A R K A N 5000 S A S

4000 0 A D

I 3000 N - -I+--+-- I

I m n Y Y M

W I

2000 4

I 1000 1

0 c t 1--t--t i4-t t f- ++t-+-+--t-t---t----t-+-t--t 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

Hours

- Jnil No.

1

1

2

-

2

2

2

1

2

1

1

2

2

2

4

4

2

3

3

1

1

-

GENERATING UNIT OUTAGES - SCHEDULED COMPLETE OUTAGE

Date out

4/20/2004 21:48

611 112004 22:31

2/6/2004 1 150

2/7/2004 5:29

2/9/2004 529

2/9/2004 5130

9/20/2004 7:OO

5/3/2004 6:09

2/6/2004 23:42

3/30/2004 20:32

1011 512004 22:28

11/16/2004 1540

1/3/2004 0:oo

311 012004 16:OO

311 112004 7:16

2/14/2004 7:22

8/26/2004 8:02

3/1/2004 7:OO

41212004 22:06

On

5/13/2004 1 1 :31

6/20/2004 2: 13

2/7/2004 1150

2/9/2004 5:29

2/9/2004 530

2/9/2004 16: 12

1211 712004 20:28

5/5/2004 19:41

3/29/2004 19:40

4/2/2004 14:24

4/15/2004 23:45

11/16/2004 10:40

1111 812004 2:30

311 012004 13:03

3/14/2004 1458

3112l2004 14:03

5/8/2004 20:46

812612004 9:07

4/5/2004 17:05

5/13/2004 17:lO

I Hrs. Lost I Reason for Outage

541.7 1 R’I 8 Refueling outage

195.7 Plarnned shut down to repair LP Turbine diaphragm gasket leak.

24.0 Off line for planned maintenance for 2P-32C Reactor Coolant Purnp Motor

41.7 Start up scheduled for RCP Outage delayed due to extented emergency dieseal generator overhaul.

0.017 Turbine Generator was tied to the grid following a planned outage extlantion, then tripped on anti motoring.

10.7 Scheduled outage extended due to troubleshooting the Turbine Generator anti-motoring trip.

60.9 Replaced Circuit Breakers

61.53 Replaced Circuit Breakers

1243.97 Installation and upgrade to boiler control and burner management system.

65.87 Damaged done to tubes while removing ash and slag during outagl using explosive blasting.

31 0.12 Boiler Outage with a primary concern of removing ash accumalatio in the finishing superheat, economizer, and air preheater. Repairs were made in various other areas while the unit was offline.

757.20 HF’ turbine upgrade

34.83 While preparing for overspeed test, developed bearing rub

1621.05 Boiler Control Replacement, Air Preheater Drive work, Rebuild 4A, 4B, 4C Condensate Pumps, Stop Valve Inspection

94.97 Bailer control replacement, Air preheater drive work, 4C condensate pumps, stop valve inspection

30.78 An1 additional penetration into the scroll case was made to provide an additional source of Fire Water.

2028.40 TurbinelGenerator Inspection and cleaning of the generator

1.08 Replaced DC Power Supply in Generator Control Cabinet.

849.08 Retube condenser on two waterboxes and burner managment.

978.07 Spring 2004 Planned Outage for Boiler Work and other miscellaneous maintenance activities.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-5A

GENERATING UNIT OUTAGES - SCHEDULED COMPLETE OUTAGE

Plant Name

White Bluff

White Bluff

- Unil No.

1 -

2

-

1 Hrs. Lost Reason for Outage

Outage for Boiler Work and other rrliscellaneous maintenance activities.

OUTAGE

- Jni UO,

2

2

2

1

-

1

2

1

1

1

1

1

1

1

1

1

1

2

2

2

2

_.

Date out On

GENERATING UNIT OUTAGES - UNSCHEDULED COMPLETE OUTAGE

Hrs. 1 Lost

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 Supp. E-6

Plant Name

AN0

Carpenter Dam

Couch

Independence

8/29/2004 10:26 8/29/2004 23:21 12.9 Main Turbiine offline to replace Stator Cooling Strainer.

6/12/2004 3:36

7/23/2004 19: 13

8/29/2004 23:22

Boiler Tubls leak on lower slope of rear furnace wall. Tube number 448 and 449 from right (south) wall.

8/30/2004 0:30

8/30/2004 3:27 4.1 Main Generator tripped off line due to anti-motoring. I I

9/30/2004 19:15/ 10/3/2004 0:05( 52.8 /TUBE LEAK IN LOW TEMPERATURE SUPERHEATER SECTION.

3/28/2004 16:45 3/28/2004 18:OO 1.3 Lightning struck the transmission grid and caused unit to trip. 1 1 8/20/2004 22:29 8/22/2004 0:49 26.3 Tube leak ion the south wall of the boiler on the second from the bottom tube.

The tube is water cooled and is located below water-cooled door to the east about 3 6 from bend.

1/15/2004 19:30

411 912004 4281 411 9/2OO4 6:Oq 1.6 I Lost boiler due to steam drum level swinging while increasing load,

1/16/2004 2:34 7.1 ' B SECTION BOTTOM ASH HOPPER IS FULL. IT IS OUT OF THE WATER UP TO THE LOWER SLOPE TUBES

6/2/2004 11 :39

Reason for Outage

6/2/2004 19:OO 7.3 Bad proxiniitor on #4 turbine bearing vibration caused the unit to trip on faulty reading.

6/1 2/2004 537

7/24/2004 504

2.0 Lose of 1A Boiler Feed Pump at high load caused drum level to swing and tril the boiler and turbine. Indication is that high temperatures in the BFP control cabinet caused 1A BFP to trip.

9.9 Lightening storm in the area struck heat shield on 161 kv transmission line in switchyard. The shield was severed and dropped across phases and tripped the bus and unit. TOC switchyard crew replaced shields and cleared bus.

9/28/2004 1 541 10/2/2004 14:03 108.2 Forced outage to repair Main Feedwater Vent line weld. I I

10/20/2004 650 10/20/2004 1650 Failure occured in the swithyard during a switching operation that cleared the buss and ii relay failed, therefore bringing the unit offline.

4/19/2004 11 :OO( 4/20/2004 13:23l 26.4 I Drum level chart not working, leaving us with no drum level indication.

12/10/2004 2354

8/16/2004 21 :25/ 8/17/2004 5341 8.2 loutboard packing on BFP blew out, and pump could not be isolated.

12/12/2004 14:14 38.3 Hydrogen ,seal leak under the generator at high voltage bushing at the southeast corner.

4/17/2004 0:21

10/20/2004 1650 10/21/2004 There was a tube leak below the South Water Cooled door on the bottom tub6 that was repaired.

4/17/2004 3:29 3.1 Tripped Turbine while conducting weekly tests on control valves. Turbine trip caused drum level to go high and therefore the boiler tripped and a mismatch in metal/stlaam temperature.

4/17/2004 4:27

5/1 1/2004 2:26 5/11/2004 5581 3.5 I High vibration in 1 B PA fan impelled a maintenance derating to clean fan blades andl balance.

4/19/2004 351 47.4 Soot bloww erosion in economizer caused from soot blower not being fully retracted from boiler while still blowing steam. Economizer tube was plugged and adjacent tubes were pad-welded.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 Supp. E6A

~1~12004 1 8 s

~12712004 I 7:08

7/4/2004 11 :02

8/29/2004 10:00

91312aa4 a137

1 1 I2612004 9: 1 9

I ~ 1 2 ~ 2 0 0 4 21 158

~1612004 1 811 5

511 012004 15128

511 312004 15:25

511 312004 17106

5/23/2004 22~48

5/23/2004 23140

8/30/2004 17:07

1 0l25l2004 7:28

z2a12004 8:45

511 312004 13:Ol

7/8/2004 16~29

7/5/2004 5:50

8/7/2004 12:02

2/20/2004 0159

3/26/2004 23159

5/18/2004 0106

1/27/2004 5:06

St1 312004 17:10

1/27/2004 501

Plant Name

idependence

ake :atherine

lemmel Dam

Vhite Bluff

s1512~04 22156 28.3

~12912004 23 9 33.2

7/4/2004 18:04 7.0

8/31/2004 23:# 61.7

9/5/2004 8105 47.5

1 1 /28/2004 0137 39.3

I 2/23/2004 I 011 I I 2.2

a412aa4 6100 41 9.8

511 312004 15125 72.0

511 312004 17:01 1.6

5/26/2004 1 1 :43 306.6

5/23/2004 23105 0.3

512~12004 I :28 I .8

8/30/2004 19:36 2.5

1 0/25/2004 121 3 4.8

~2~12004 I 0140 I .9

St1 512004 23158 58.9

7/8/2004 18:36 2.1

7/7/2004 12135 54.7

8/7/2004 15114 3.2

2/21/2004 1100 24.0

3/27/2004 13130 13.5

5/20/2004 2:16 50.2

1/29/2004 10:55 53.8

St1 412004 950 16.7

1/27/2004 5106 0.1

- Jnil No.

2

2

-

2

2

2

2

2

3

3

3

3

4

4

4

4

1

2

2

3

3

1

1

1

1

1

1 -


Reason for Outage

External tube leak on water wall lower rear tube above A bottom ash hopper.

2 Drum saflety valves did not reseat after stator cooling water runback. Runback was due to a blown fuse in stator cabinet. Lose of steam through safeties has unit limited on steam flow through turbine. Only able to achieve 1450 PSI throttle pressure. Lightening /storm in the area.

Tube leaks on the economizer header inlet nipples. Tube numbers 217 from the right wall on the front and rear header.

Tube Failure at weld in Lower Economizer Assembly.

Malfunction, on 14R sootblower didn't allow it to retract from boiler and steam flow from the blower eroded tube and caused leak.

A 8. B Drum level transmitters had frozen legs to the sensing lines, giving fals drum level indication and tripping the boiler. Heat tracing was found not to be working.

Firing aisle problem

Apparent giround on "B" phase ... location unknown at this time

Apparent giround on " B phase ..... location unknown at this time

Insulator bushing grounded and found that leads were reversed on CT's during return to service after maintenance in March causing a differential rela)

ControlValves did not respond when unit was pit on line. Reverse current tripped unit.

Fires went 'out. Had to have an I & C tech comeout and reset Burner Management System

0 corner 31d elevation burned up.

Low BWCF' flow. BFPs did not react quickly enough to a rapid load change md feedwater flow sagged.

Brushes were replaced. Postponed and done on Saturday for minimal impact.

Fuse failure on unit PT

Proportional valve control card failure.

'ewer Supply to the Remote Control cabinet failed.

Sovernor pump motor contactor failed which did not allow pump to start to naintain proper oil pressure. Replaced contactor assembly, rube Leak located at bottom of seal trough.

-AN MOTOR SWAP FOR UNIT 2.

3oiler tube leak in front reheat pendant.

'A FAN WOULD NOT START

-ass of auxiliary steam

iEATER FAILURE ON DRUM LEVEL CONTROL CAUSED GAUGE TO

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 Supp. E-6B

Date out On

Plant Name

Vhite Bluff

Hrs. Lost

- Jnil No.

1

1

1

-

2

2

2

2

2

2

2

2

2

2

2

2

2

2

-

2/12/2004 557 2/12/2#4 1342


7.7

12/17/2004 7:30

si2112004 21 :23

3/5/2004 22: 1 0

1011 312004 22:15

I o12912004 I 43

1/24/2004 1340

1/24/2004 21 :00

3/27/2004 1549

312a12004 S:I a

312a12004 I I :QQ

1 0/20/2004 23:31

1/24/2004 9122

312a12004 I 6:oo

6/4/2004 23:05

7/23/2004 1745

1 0/22/2004 10:45

12/17/2004 17100 9.5

512312004 I 9:24 6.0

3/7/2004 7:45 33.6

1 0/20/2004 23:31 169.3

I oi3112004 20:33 67.8

1/24/2004 21 100 5.3

1/25/2004 2134 5.6

3/28/2004 511 8 13.5

312a12004 I I :oa 5.7

312a12004 I 550 4.8

1 O/22/2OO4 9130 34.0

1/24/2004 15:40 6.3

~12a12004 21 :35 5.6

6/6/2004 2110 27.1

7/24/2004 0:50 7.1

1 O/22/2OO4 1611 0 5.4

Reason for Outage

Boiler tripped - drum level.

Incorrect wire was pulled from DCS, triggering unit trip.

Level indication column had valve packing leak. Apparently, valve was improperly packed by contractor during the spring 2004 outage.

Balance shot applied to generator. Shot was 16.6 oz at 330 degrees for both bearings 9 and 10.

Suspected condenser tube leaks. Subsequent inspection revealed two weeping tuibe leaks in ‘ A box.

BFP 2A Volute Change-out

Turbine Vilbration Trip

Turbine Vilbration Trip

Problem with Oil Guns

Startup failure due to EHC leak

Problem with Oil Guns

28 Air Heater Drive Motor will NOT stay in service. Found bad bearing in pinion shalt assembly for high-speed air drive.

BMS fault ,tolerant control processors failed. First processor failed on 01/21/04, but no action was taken. Second processor failed on 01/24/04 tripping unit. Foxboro is investigating problem.

EHC System Leak

Offline due! to HIGH OPACITY.

Bottom ash plugged over bottom ash hopper - outage taken to blast out

Turbine trip on high vibration on #4 bearing. Turbine put on turning gear - will roll again in 4-hours.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-7

4/20/2004 21 :48

511 612004 8:00

611 1 I2004 22:31

6/20/2004 11 :32

2/6/2004 11 :50

211 012004 1 1 :45

3/30/2#4 16131

3/30/2004 16%

3l30l2004 17:OQ

3/30/2004 20132

4/3/2004 8125

Plant Name

\NO

ndependence

2.9

68.5

3.2

9.3

3.3

19.6

20.8

0.3

0.2

3.5

10.4

-

Init uo.

1

1

1

1

1

-

2

2

1

1

1

1

1

1

2

2

2

2

2

-

3/30/2004 17135

3131 12004 3:43

3/31/2004 10:29

GENERATING UNIT OUTAGES - SCHEDULED PARTIAL OUTAGE

7.9

I 0.1

6.8

Datl out

4/8/2004 223

4/20/2004 18::

511 312004 11 ::

6/11/2004 19:l

6/20/2004 2: 1

Z612004 8::

2/9/2004 1 6: 1

3/29/2004 1 9 : ~

3/30/2004 16::

3/30/2004 16:f

3/30/2004 17:C

4/2/2004 22:C

4/3/2004 8:;

3/30/2004 9:f

3/30/2004 17::

3/31/2004 314

3/31/2004 10:;

3/31/2004 11 :4 3/31/2004 13:09

4- 4/20/2004 18152 284.2

1.4

4/3/2004 9:s 1.5

3/31 I2004 1 1 1.2

Ope Rat1

% 98.8C

35.5:

57.7E

50.96

5 6 5

-

52.91

54.31

59.81

56.9s

71.77

79.55

52.8C

74.76

77.2C

79.57

31.95

79.57

77.20

Reason for Outage

- Core Coastdown into 1 R18 Refueling Outage

Comnienced shutdown for 1 R18 Refueling Outage

Startup from normal refueling

Power reduction for planned shutdown to repair LP Turbine diaphragm gasket leak Power increase after planned shutdown to repair LP Turbine diaphragm gasket leak

Commenced plant shutdown for planned outage to repair 2P-32C Reactor Coolant Pump motor.

Power ascension after planned outage extension.

Control tuning on new boiler controls.




The 14A conveyor motor was replaced during the Spring Outage and the new rriotor was wired up incorrectly. The motor was wired wye instead of

The 14A conveyor motor was replaced during the Spring Outage and the new rriotor was wired up incorrectly. The motor was wired wye instead of

The removal for repairs of 28 Circulating Water Pump motor created less water flow through condenser and therefore less heat transfer and higher back pressure problems difficulties. Arrangements were made with the EM0 lprior to removal of motor.

The removal for repairs of 28 Circulating Water Pump motor created less water flow through condenser and therefore less heat transfer and higher back pressure problems difficulties. Arrangements were made with the EM0 prior to removal of motor.

The removal for repairs of 28 Circulating Water Pump motor created less mter flow through condenser and therefore less heat transfer and higher

The removal for repairs of 28 Circulating Water Pump motor created less Jvater flow through condenser and therefore less heat transfer and higher back pressure problems difficulties.

The removal for repairs of 28 Circulating Water Pump motor created less mter ,flow through condenser and therefore less heat transfer and higher back pressure problems difficulties.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSIOIN - YEAR 2004 SUPP. E-7A

~ ~ ~ _ _ _ ~

Oper. Rate

%

'3.63%

'7.20%

'8.98%

6.60%

3.63%

1.26%

7.20%

4.23%

1.26%

7.70%

0.7

0.5

0.6

5.51 %

Plant Name Reason for Outage

The removal for repairs of 28 Circulating Water Pump motor created less water flow through condenser and therefore less heat transfer and higher back pressure problems difficulties.

The rlemoval for repairs of 28 Circulating Water Pump motor created less water flow through condenser and therefore less heat transfer and higher back lpressure problems difficulties.







The removal for repairs of 28 Circulating Water Pump motor created less water 'flow through condenser and therefore less heat transfer and higher back pressure problems difficulties.

The removal for repairs of 28 Circulating Water Pump motor created less water Iflow through condenser and therefore less heat transfer and higher back pressure problems difficulties.

The removal for repairs of 28 Circulating Water Pump motor created less water ilow through condenser and therefore less heat transfer and higher back pressure problems difficulties.

Safety valves that were maintenanced during outage had to be set to specific pressure.

Safety valves that were maintenanced during outage had to be set to specific pressure.

The reinoval for repairs of 28 Circulating Water Pump motor created less water flow through condenser and therefore less heat transfer and higher back piressure problems difficulties.

id e p e n d e n c e

-

Jnil No. -

2

2

2

2

2

2

2

2

2

2

2

2

2

2

-

GENERATING UNIT OUTAGES - SCHEDULED PARTIAL OUTAGE

Date out

3/31/2004 13:0!

3/31/2004 19:3(

411 I2004 3:3l

411 I2004 9:4!

411 I2004

411 I2004

1 :3(

3:3(

4/2/2004 3:3!

4/2/2004 1 0:0!

4/2/2004

4/2/2004

2:1!

2:4!

4/2/2004 1 8: 1 !

411 512004 2314

411 612004 710:

411 612004 16:OS

On

3/31 I2004 19:3c

4/1/2004 3:3C

4/1/2004 9:4

4/1/2004 1 1 :3c

411 I2004 1313C

4/2/2004 3:3E

4/2/2004

4/2/2004

4/2/2004

4/2/2004

0:QE

2:lE

2:4E

8:lE

4/3/2004 0:3€

4 1 612004 7:05

411 612004 747

4 1 712004 0:21

Hrs. Lost

6.4

8.0

6.3

1.8

2.0

14.1

6.5

2.2

0.5

5.5

6.4

7.3

0.7

8.2

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 Supp. E 4

1 0Ql2004 22:00

Plant Name

,N 0 %

1 0/4/2004 7:59 34.0 96.89% Integrated Control System problems. Power was reduced to perform

- Uni No

1

1

1

1

1

1

1

1

1

1

1

1

1

-

1

2

2

2

2

2

2

2

2

-

I 111 312004 21 151

12/31 I2004 1430

6/20/2004 22:44

12/4/2004 8:59

3/8/2004 10:30

2/24/2004 4139

2/26/2004 3138

3/1/2004 3:38

3/3/2004 5103

4/7/2004 5123

4/8/2004 5138

511 612004 9129

I 2/3/2004 8:05

4/24/2004 19137

2/24/2004 9:QO

31712004 21 130

7BOI2004 141 5

8f3112004 1507

9/27/2004 23159

10/2/2004 1403

311 0/2004 8130

GENERATING UNIT OUTAGES - UNSCHEDULED PARTIAL OUTAGE

1 1 I1 4/2004 1457

12/31 I2004 20:31

6/21 I2004 10:30

12/4/2004 1425

3/8/2004 1 1 147

2/25/2004 15:26

2/27/2004 10132

31112ao4 2 ~ 5

3/4/2004 1104

4/7/2004 18139

4/8/2004 14~50

611 1 I2004 1 9: 1 7

I 2/4/2004 I 5 7

412612004 3147

2/28/2004 16:00

319~004 3:aa

811 2lxx)4 16:20

912l2Q04 1 I :20

9/28/2004 1154

1 0l312004 8:27

311 112004 5100

I I

17.1

6.0

11.8

5.4

1.3

34.8

30.9

19.8

20.0

13.3

9.2

633.8

17.9

32.2

103.0

29.5

314.1

44.2

1.9

18.4

20.5

Date His. Oper. out I On 1 Lost 1 Rate I

99.64% Reduced Power slightly due to Integrated Control System Problems.

98.21 % Plant Computer Multiplexer failure. Power was reduced to -98%.

99.28% Lowered power to perform excore instrumentation calibration.

99.04% Nuclear Insturnentation Calibration required after previous down power

98.92% Power reduction to 99% to allow Plant Computer Multiplexer reset.

99.28% Isolated a Main Condenser water box for planned tube cleaning

99.52% Isolated a Main Condenser water box for planned tube cleaning.

99.64% lsollated E-I 1 B South Condenser waterbox for planned tube cleaning.

99.64% Isolated E-I 1 B North Condenser waterbox for planned tube cleaning.

97.97% Main Steam Safety Valve Testing

97.85% Main Steam Safety Valve Testing

98.44% Power reduction to reduce LP Turbine vibrations, then continued losse! due to LP Turbine diaphragm gasket leak.

48.33% Power reduced to -40% to allow Main Feedwater Pump Controls powe supply replacement.

99.18% Steam Leak on level control valve for 2T-58A (extraction drain tank). Power reduced to 99.7%

99.77% Power was allowed to drift down -0.5% to allow for the replacement of the 2T-366 RCS Letdown Demineralizer.

99.65% Power was allowed to drift down -0.3 % due to Feedwater Regulating Valve Problem.

99.77% Power lowered to 99.8% to allow repairs to 2T58A heater drain tank lev control valve.

96.04% 2P-13B Heater Drain Pump mechanical seal failure. Power reduced initially to 98% to secure 2P-88. Power restored to 100% with plant output reduced by -30 Mw while the seal was being replaced.

45.10% Power decrease for forced outage to repair Main Feedwater Vent line

50.82% Power increase following forced outage to repair Main Feedwater Vent line 'weld.

99.77% Planned derate: Power was allowed to drift down -0.3 % to perform EFVJ pump turbine quarterly testing.

Reason for Outage

- Uni No

2 -

2

2

2

2

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1 -


Datc out

412012004 1 9: 30

5/21/2004 2253

8/29/2004 7: 10

a12912004 23:21

a1301z~o4 3127

1/2/2004 10: 15

1 122004 12:40

11312004 12:33

1/15/2004 3:43

1 I1 512004 6: 19

1 132 12004 1 3: 44

113112oa4 i6:54

2/5/2004 16:40

2/6/2004 1430

4/28/2004 21 :00

4/29/2004 3125

5/6/2004 17: 15

5/8/2004 1125

51a12004 2108

511 712004 9120

5/18/2004 7:50

511 812004 1 1 50

611 Z2004 537

511 32004 16: 10

7/4/2004 18:30

On

4/21/2004 6:OC

5/22/2004 0:08

a12912004 10:2(

a12912004 2 ~ :

8/31/2004 10:5(

1/3/2004 754

112l2004 16: 13

1/3/2004 1540

1 I1 512004 6: 1 9

1 I1 512004 19:3(

1 I31 I2004 1 4: 01

211 12004 9: 15

~612004 3:2a

2/6/2004 23142

4/29/2004 3:25

~IZ~IZQQ~ 8122

5/6/2004 18:09

51a12004 2:oa

51a12004 22138

511 812004 I : I 5

511 8 1 2 ~ ~ 4 9: I a

511 812004 13: 12

31 Z2004 1 1 144

$11 312004 1 8: 10

7/4/2004 20143

Hrs. Oper. Lost I Rate 1 Reason for Outage

% 10.5 99.88% Power allowed to drift down -0.2 % for Planned Emergency

Feedwater Pump Testing.

1.3 93.59% Turbine Control Valve Testing

3.3 41.96% Commenced Main Turbine shutdown to replace Stator Water coolin Strainer.

0.0 2.10% Main Turbine Tied to the Grid after Stator Cooling Strainer

31.5 72.96% Power ascension to 100% following scheduled outage.

21.65 95.69% ID FAN INTERRUPT SWITCH BROKE OVER AT 455 AMPS AT 4



2.6 68.18% 'BI SECTION BOTTOM ASH HOPPER IS FULL. IT IS OUT OF

13.2 35.89% 'B' SECTION BOTTOM ASH HOPPER IS FULL. IT IS OUT OF

0.3 96.29% BLACK THUNDER COAL TRAIN DELIVERY WHICH HAS HIGH

16.4 95.69% ID FAN AMPS HIGH DUE TO PLUGGAGE IN THE APH AND

10.8 95.69% 1 A ID fan interrupt switch alarm comes in at 440 AMPS and 44 degree blade angle.

9.2 95.69% 1A ID fan interrupt switch alarm comes in at 440 AMPS and 44 degree blade angle.

6.4 71.77% 15 A CONVEYOR OUT DUE TO BAD MOTOR

4.9 65.79% 15 A, CONVEYOR OUT DUE TO BAD MOTOR. AFTER NEW

0.9 88.52% A mill feeder tripped due to pluggage. Conveyor had to be cleaned

0.7 71.77% Cooling tower level low due to repairs being made on the river intake

20.5 83.73% Cooling tower level low due to repairs being made on the river intake

15.9 96.97% Cordera coal delivery which has high calcium content so to keep fror

1.5 90.91 % Motor bad on 1 F mill feeder. Motor replaced and returned to full load

1.4 90.91 % Wet coal plugging up chutes. Chutes were washed out and unit was

6.1 12.12% Coulol not get 1A PA fan to start due to not being able to open fan

2.0 95.76% 1.D. fan amps high due to increase in ambient temperature and

2.2 96.97% I.D. fain amps high due to increase in ambient teperature and

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 Supp. E-8B

% 96.97%

95.76%

96.97%

35.89%

75.72%

59.81 %

65.79%

83.49%

95.69%

93.30%

26.32%

23.92%

10.77%

3.59%

37.39%

36.79%

51.95%

13.14%

Plant Name

Independence I.D. fan amps high due to increase in ambient temperature and pluggage in the air pre-heater and misc. areas of the boiler.

I.D. fan amps high due to increase in ambient temperature and [pluggage in the air pre-heater and misc. areas of the boiler.

1I.D. fan amps high due to increase in pluggage in the air preheater, economizer, and areas of the boiler backpass.

When bringing the unit back up, an alarm came in for rotor long I rot1 !jhort. Had to hold at 300 MW and soak the rotor until stresses and shell expansion came together.

FD fan A had a discharge pressure transmitter that was bad (BG1001) and was showing air flow problems that were not existent.


F:D fan A had a discharge pressure transmitter that was bad (BG1001) and was showing air flow problems that were not existent.


ID FAN AMPS HIGH due to pluggage in the APH and misc. areas o the boiler.

Downspout plugged and no coal flow.

High vibration in 1 R PA fan impelled a planned maintenance deratin to go through fan bearing.

High vibration in 1 B PA fan impelled a maintenance derating to cleai fan blades and balance.

Hligh vibration in 1 B PA fan impelled a maintenance derating to cleai fan blades and balance.

High vibration in 1 B PA fan impelled a maintenance derating to cleai fan blades and balance.

1.13. FANS AMPS HIGH DUE TO PLUGGAGE IN THE APH AND MIISC. AREAS OF THE BOILER

ID FAN AMPS HIGH DUE TO PLUGGAGE IN THE APH AND MISC. AREAS OF THE BOILER

21: MILL HAD COAL PIPING PLUGGAGE PROBLEMS CAUSING SIPILLAGE, 28 HAD JOURNAL PROBLEMS, AND 2A HAD A GROUND IN THE FEEDER.

2G MILL HAD A FROZEN INERTING STEAM VALVE DUE TO DlRAlN NOT BEING OPEN.

-

Jni UO

1 -

1

1

1

1

1

1

1

1

1

1

1

1

1

2

2

2

2

-


Date out

711 412004 I I :oa

7/30/2004 1601

8/22/2004 19:50

0121 I2004 17:31

0/21/2004 21 :3(

0121 I2004 22: 1

0/21/2004 22:lf

0121 12004 22:3f

0121 12004 23:l'

I 1/8/2004 6105

5/3/2004 15:25

511 Ol2004 19:51

511 012004 22:05

511 1/2004 5158

1/3/2004 1214

1 I1 5/2004 9142

1 I1 6/2004 6:3C

1 130l2004 6:OC

On

711 4/2004 20:36

7/30/2004 22: 14

8/23/2004 3: 1 5

1 0/21 E004 1 9:53

10/21/2004 22: l l

1 0/21 I2004 22: 15

1 O n 1 12004 22:35

10121 12004 22:47

IO12212004 0:55

1 1 1012004 745

5/4/2004 8: 1 1

511 0/2004 2205

511 1 I2004 2:26

511 112004 9:32

1/3/2004 15:lE

1 I1 612004 6:3C

1/16/2004 9:Ol

113012004 22%

Hrs, LOSl

z -

z

I

1

C

C

C

C

1

1

1E

c L

4

3

2

20

2

16 -

Oper. Rate Reason for Outage

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-8C

1/30/2004 2256

Plant Name

ndependencc I % [

1/30/2004 23:28 0.5193.23%12G MILL HAD A FROZEN INERTING STEAM VALVE DUE TO

-

Uni No

2 -

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

-

1 /31 I2004 17:26

2/1 I2004 1 :03

2/1/2004 1 :31


2/1 12004 1 :03

2/1/2004 1 :31

2/1/2004 7:28

Oper. Rate

7.6

0.5

5.9

7.6

18.6

11.9

15.5

Reason for Outage

96.79% BLACK THUNDER COAL TRAIN DELIVERY WHICH HAS HIGH CALCIUM CONTENT, SO TO KEEP FROM PLUGGING UP THE BA.CKPASS OF THE BOILER, 02 IS HELD AT 3% AND LOAD MUS BE DECREASED TO HOLD ID FANS AMPS WITHIN LIMITS

77.20% FD FAN LINKAGE LOOSE. NUTS WERE REPLACED AND

96.79% BLACK THUNDER COAL TRAIN DELIVERY WHICH HAS HIGH CALCIUM CONTENT, SO TO KEEP FROM PLUGGING UP THE BACKPASS OF THE BOILER, 02 IS HELD AT 3% AND LOAD MUS BE DECREASED TO HOLD ID FANS AMPS WITHIN LIMITS

96.79% HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air preheater, and economizer.




2/6/2004 20:21

2/9/2004 9:00

2/11/2OO4 1 1 :20

2 1 2/2004 7:21

2/13/2004 8:22

2/14/2004 1750

2/7/2004 356

2/1 OR004 3:33

2/11 12004 23: 12

2/1 2/2004 2253

Z1412004 0:06

2 1 8/2004 17:16

96.79%

DFlAlN NOT BEING OPEN

HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air preheater, and economizer.

38036.23472 38036.27569 0.98333 I I

15.7

92.64% HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air prelheater, and economizer.

2/19/2004 6:37

2/21/2004 850

3/2/2004 19:lO

3/3/2004 6:25

3/3/2004 18:55

3/4/2004 3:40

HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air preheater, and economizer.

2/21/2004 854 50.3 97.39% HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air prelheater, and economizer.

3/2/2004 19:lO 250.3 95.01 % HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air preheater, and economizer.

3/3/2004 6:25 11.2 92.04% HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air preheater, and economizer.

3/3/2004 18:55 12.5 95.01 % HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air preheater, and economizer.

3/4/2004 3:40 8.8 93.23% HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air preheater, and economizer.

3/4/2004 10:55 7.3 95.01 % HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air preheater, and economizer.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 Supp. E-8D

3/4/2004 1055

3/8/2004 6:25

311 312004 8:20

$11 512004 18:28

311 612004 7100

5/25/2004 1840

3/26/2004 3150

~ ~ 1 2 0 0 4 I 2:45

3/27/2004 3135

1127l2004 12:13

3/28/2004 3155

3/28/2004 9106

V28l2004 1400

5/7/2004 16142

5/7/2004 16148

5/7/2004 18120

~

Plant Name

3/8/2004 6:25

3/13/2004 8120

311 512004 18:28

311 612004 7:00

3/25/2004 18140

3/26/2004 3150

3/26/2004 12145

3/27/2004 3135

3/27/2004 12: 13

3/28/2004 3155

312812004 9106

3/28/2004 14:00

3l3012004 9:42

5/7/2004 16148

5/7/2004 18120

5/8/2004 22139

?dependence 91.5

121.9

58.1

12.5

227.7

9.2

8.9

14.8

8.6

15.7

5.2

4.9

43.7

0.1

1.5

28.3

-

Unil No.

- 2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

-

90.26% HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air prleheater, and economizer.


89.07% HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air prsheater, and economizer.

86.10% HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air pnsheater, and economizer.


86.70% HIGH ID FAN AMPS due to pluggage in rear superheat pendant, air pmheater, and economizer.





89.07% HllGH ID FAN AMPS due to pluggage in rear superheat pendant, air preheater, and economizer.

85.51 % HllSH ID FAN AMPS due to pluggage in rear superheat pendant, air proheater, and economizer.


71.26Oh Caloling tower level low due to repairs being made on the river intake line and surge pond pumps operating at full capacity and not being ablle to keep up.

59.38% Cooling tower level low due to repairs being made on the river intake line and surge pond pumps operating at full capacity and not being able to keep up.

71.26% Cooling tower level low due to repairs being made on the river intake line and surge pond pumps operating at full capacity and not being able to keep up.


Date Hrs. Oper. out I On I Lost I Rate I Reason for Outage

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 Supp. E-8E

511 312004 3:55

511 812004 1 : 13

512712004 9:45

5/27/2004 17108

511 812004 1 : 13

5/27/2004 9145

5/27/2004 1798

5/29/2004 6157

6/8/2004 20138

7/22/2004 21 148

7/23/2004 12:41

1 2/12/2004 21 :42

12/23/2004 1534

Plant Name

98.18?h

ndependence

Cordera coal delivery which has high calcium content so to keep from plugging up the backpass of the boiler, 0 2 is held at 3% and load must be decreased to hold ID fan AMPS within limits.


4.5 56.97%~

-

Jnil No.

2 -

2

2

2

2

2

2

2

2

2

2

2

2

2

-

2 Drum safety valves did not reseat after stator cooling water runback. Runback was due to a blown fuse in stator cabinet. Los of steam through safeties has unit limited on steam flow through turbine. Only able to achieve 1450 PSI throttle pressure.

Date

38.18%

98.18%,

56.97?4

38.18%#

48.48%

out

511 Z2004 4:3E


Cordera coal delivery which has high calcium content so to keep from plugging up the backpass of the boiler, 0 2 is held at 3% and


2 Drum safety valves did not reseat after stator cooling water runback. Runback was due to a blown fuse in stator cabinet. Lost of steam through safeties has unit limited on steam flow through turbine. Only able to achieve 1450 PSI throttle pressure.

The safeties rebuilt during forced outage had to have the pressure settings adjusted before full load could be achieved.

511 Z2004 8157

23.5

9.0

4.2

511 712004 13337

88.48% #3 motor bushing blew out of 2B Circulating Water Pump.

95.76% I.D. fan amps high due to increase in ambient temperature and pluggage in the air pre-heater and misc. areas of the boiler.

54.55% 12D COAL FEEDER GEARBOX LOCKED UP. SWAPPED FAILED GEARBOX WITH AVAllABLE ONE.

5/27/2004 5: 1 E

77.20%

5/27/2004 9:4E

A new potentiometer was put in place during the outage, but when the unit came back online, voltage swings were observed. After troubleshooting the excitation system, a card in the alterex cabinet was found to have bent prongs on it and was repaired.

511 712004 13:07

5/27/2004 5: 1 E

5/27/2004 914:

5/29/2004 2: 1 S

6/7/2004 21 :OS

7/22/2004 12:5C

7/23/2004 a : x

12/12/2004 17:QO

12/23/2004 14133

Reason for Outage

5/12/2004 8:57 4.4 83.14%' Cooling tower level low due to repairs being made on the river -I-+' intake line and surge pond pumps operating at full capacity and nc I I - Cooling tower level low due to repairs being made on the river intake line and surge pond pumps operating at full capacity and nc

12.1

7.4

12.1

4

7.4

4.6

4.

NO INGlTlON PERMIT. 2G bowl mill ignitors 6 & 8 would light off but 2F Bowl mill ignitors 5 & 7 would not light, so 3 out 4 couldn't be met and ignitor permission could not be given.

REPORT TO ARKANSAS PUBLIC SERVICE COMMlSSliON - YEAR 2004 Supp. E-8F

Date out On

12/26/2004 7:53 12/26/2004 8:36

Plant Name

Hrs. Oper. Lost Rate Reason for Outage

% 0.7 83.1 4% 20 A conveyor tripped on Overload due to coallice buildup under belt idependence

.ake Catherin

:ecil Lynch

Yhite Bluff

71 26%

- Jnil No.

2 -

2

4

2

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1 -

Lost control power to conveyors feeding all of the silos on the unit Found grounded wire on 2H silo gate. Cleared ground to restore


4.3

68.4

13.8

14.9

7.6

6.8

3.8

1.8

5.0

46.2

17.7

11.5

1 .I

6.4

9.8

2.2

10.1

12.7

13.0

7.4

7.1

3.0

9.6

9.9

11.2

5/8/2004 15:00

8/2/2004 3:26

8/30/2004 19:36

5/23/2004 12:44

12/31 I2003 1 8: 16

1/8/2004 8:04

1 I1 2/2004 18:19

1/13/2004 17:19

1 I1 412004 18:OO

1/25/2004 17:40

2/16/2004 17:51

3/1/2004 6:09

3/2/2004 18100

3/4/2004 17149

3/9/2004 14: 15

311 ZOO4 0:10

3/17/2004 2105

311 712004 14144

311 9/2004 18:00

3/23/2004 14:53

3/23/2004 22100

3/26/2004 14125

3/27/2004 21 :38

3128l2004 1509

12/29/2004 10:26 12/29/2004 14:45 I I 511 1 I2004 1 1 :27

8/2/2004 17:14

8/31 12004 10:31

5/23/2004 20:22

1 I1 12004 6:47

1/8/2004 11 :51

1 I1 m 0 0 4 20:06

1/13/2004 22117

1 I1 6/2OO4 16:10

1 /26/2004 1 1 124

2/17/2OO4 5:23

3/1/2004 7:16

3/3/2004 0:23

3/5/2004 3134

3/9/2004 16:28

311 212004 10:15

3/17/2004 1444

311 8QQ04 3144

3/20/2004 1 126

3/23/2004 22~00

3/24/2004 1 :00

3/26/2004 23:59

3/28/2004 7134

312912004 2:23

40.22%

48.45%

77.70%

74.32%

414 BOILER FEED PUMP

4r4 BFPT CONTROLS

31iD ELEVATION A & D CORNERS IGNITOR BOXES

Faulty 02 probe gave false reading and prevented unit from reaching maximum capability.

at chute. Wash water Booster pump was lined up to wash around I head pulley and free up conveyor.

90.80%

73.62%

92.02%

93.87%

96.93%

95.71 %

95.09%

79.75%

92.02%

93.25%

85.89%

93.25%

95.09%

92.02%

92.02%

95.09%

92.02%

94.48%

84.05%

94.48%

HI1 OPACITY.

NO COAL TO PLANT

HIGH OPACITY

HIGH OPACITY (per Robert McGough, Prod. Superintendent)

HIGH OPACITY

HIGH OPACITY

HIGH OPACITY

LACK OF BOWL MILLS

OPACITY HIGH

HIGH FAN AMPS & OPAC

5 MILLS AVAILABLE

ID FAN CONTROLS

HIGH OPACITY

HIGH OPACITY

HIGH OPACITY

HIGH OPACITY

HIGH OPACITY

HIGH OPACITY

HIGH OPACITY

FAN AMPS-OPACITY 1

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUDD. E-8G

313012004 8: 00

313012004 1 1 : 10

313012004 18:22

313012004 18:48

3131 12004 1 1 :07

3/31 I2004 13: 12

313112004 15:23

313112004 19:18

313112004 21 :51

313112004 22:OO

4l112004 6.45

41112004 10:44

41112004 11 141

41112004 13128

4/2/2004 6:23

4/2/2004 12:20

4/2/2004 14106

4/2/2004 18:53

4/2/2004 19128

4/2/2004 1945

4/2/2004 20110

4/2/2004 20138

511 412004 16: 10

5l20l2004 5:16

512012004 5:34

512012004 6:24

Plant Name

Vhite Bluff

313012004 1 1 : 1 0

313012004 18:22

313012004 18~48

3/3112004 0:53

3131 12004 13: 12

3/31 I2004 15:23

313112004 19:18

313112004 21:51

313112004 22:OO

4/1/2004 6144

411 12004 10:43

411l2004 11 140

411l2004 13:28

4/2/2004 6123

4/2/2004 12120

4/2/2004 12:49

4/2/2004 18153

4/2/2004 19128

4/2/2004 19145

4/2/2004 20: 10

4/2/2004 20:38

4/2/2004 22106

511 412004 17:52

5f2Ql2004 5133

512012004 6:24

512012004 a:39

- h i No.

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

-

-

3.2

7.2

0.4

6.1

2.1

2.2

3.9

2.6

0.2

8.7

4.0

0.9

1.8

16.9

6.0

0.5

4.8

0.6

0.3

0.4

0.5

1.5

1.7

0.3

0.8

2.3


92.02% HIGH OPACITY

85.89% HIGH OPACITY

88.96% HIGH OPACITY

92.02% HIGH OPACITY

94.48% HIGH OPACITY

90.18% HIGH OPACITY

85.89% HIGH OPACITY

88.96% HIGH OPACITY

87.12% HIGH OPACITY

84.66% HIGH OPACITY

87.12% HIGH OPACITY

90.18% HIIGH OPACITY

95.09% HIGH OPACITY

92.02% HIGH OPACITY

93.87% HIGH OPACITY

98.16% HIGH OPACITY

96.32% HIGH OPACITY

90.80% COAL SUPPLY

82.82% COAL SUPPLY

73.62% COAL SUPPLY

67.48% COAL SUPPLY

61.35% COAL SUPPLY

63.80% SIL.ICA HIGH

61.73% CHIEMISTRY

80.25% CHEMISTRY

92.59% 5 MILLS AVAILABLE

5l2112004 12:28[ 512112004 12:29( 0.01

Reason for Outage

& FAN AMPS

100.00%(Thi,s entry entered mistakenly.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSSION - YEAR 2004 Supp. E-8H

5/28/2004 11:49

~

Plant Name

Yhite Bluff %

5/28/2004 12128 0.7 92.59% SOOTBLOWER COMP PROB

-

Unil No.

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

-

-

0.4

8.8

8.3

1.5

3.5

0.8

3.7

6.5

0.8

5.8

3.0

2.1

8.3

14.2

9.9

7.1

10.4

9.6

7.9

28.2

10.0

10.8

2.9

0.1

2.2

11.8


92.59% CONVEYOR PROBLEM

95.06% HIGH BACK PRESSURE



92.59% HIGH OPACITY

96.30% HIGH BACKPRESSURE









92.59% HlGlH BACKPRESSURE






93.83% HlGlH BACKPRESSURE

91.36% BACKPRESSURE

67.90% Drag Conveyor Broken belt.

86.42% Dragi Conveyor Broken



I I

7/4/2004 9:091 7/4/2004 14:021 4.9195.68%1HlGH BACKPRESSURE

Reason for Outage

5/28/2004 14:00

512912004 1511 1

~13012004 9: I I

~13o12004 I 7:31

6/2/2004 1 1125

6/2/2004 14155

6/7/2004 12105

6/7/2004 15145

6/8/2004 13:30

6/8/2004 14120

611 012004 9:50

611 012004 12:50

611 012004 14155

611 112004 9158

611 1 I2004 14: 17

611 2/2004 5: 18

611 2/2QO4 12123

611 312004 1 1 :20

611 412004 14%

611 612004 1 1 :50

611 712004 16:04

611 812004 1 1 :20

6/22/2004 1523

6/22/2004 18: 18

7/2/2004 13:40

7/3/2004 15:00

512812004 14125

5/30/2004 0:01

513012004 I 7:29

513012004 I 9103

6/2/2004 14155

6/2/2004 15146

6/7/2004 1545

6/7/2004 22117

6/8/2004 14120

6/8/2004 20:05

611 012004 12:50

611 012004 14%

611 012004 23: 12

611 2/2004 0: 1 2

611 2/2OO4 0: 1 2

611 2/2004 12123

611 a2004 22:45

611 312004 2057

611 412004 22149

611 712004 16104

611 812004 2:02

611 812004 22108

6/22/2004 18118

6/22/2004 18123

7/2/2004 1550

7/4/2004 2148

REPORT TO ARKANSAS PUBLIC SERVICE COMMlSSllON -YEAR 2004 Supp. E41

7/4/2004 11331

7/4/2004 22: 50

7/5/2004 2140

7/5/2004 9:46

7/5/2004 1 1 : 15

7/5/2004 1 1 : 17

7/6/2004 1 1 :20

7/7/2004 9140

7/7/2004 11 135

7/7/2004 14:20

7/8/2004 8: 1 2

7/8/2004 10: 12

7/8/2004 12:20

7/9/2004 14125

711 012004 I 4145

711 012004 15:25

711 112004 9:25

?/I 112004 13~20

711 112004 22150

7/12/2004 8:26

7ll2/2004 1 1 :45

711 2/2004 17:OO

'11 2/2004 21 : I 0

'I1 Z2004 22:35

7/13/2004 9:21

'I1 312004 1O:lO

Plant Name

Vhite Bluff

7/4/2004 22:50

7/5/2004 2: 40

7/5/2004 352

7/5/2004 1 1 : 15

7/5/2004 23138

7/5/2004 23:38

7/6/2004 22: 14

7/7/2004 11 135

7/7/2004 14:20

7/7/2004 1859

7/8/2004 9:46

7/8/2004 12:20

7/8/2004 21 :46

~1912004 21 :36

711 012004 I 5:25

711 012004 21 :59

711 1 I2004 13:20

711 112004 22:50

7/12/2004 2:00

711 Z2004 1 1 :45

711 2/2004 17100

711 Z2004 21 : 10

711 Z2004 21 135

711 312004 0:05

7/14/2004 11 :05

711 312004 14140

-

Unil No.

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

-

-

6.3

3.8

1.2

1.5

12.4

12.3

10.9

1.9

2.8

4.7

1.6

2.1

9.4

7.2

0.7

6.6

3.9

9.5

3.2

3.3

5.3

4.2

0.4

1.5

25.7

4.5












95.68% SOOTBLOW SYS HIC
















Reason for Outage

BACKPRESSURE

7/13/2004 14:40) 7/13/2004 17:37) 3.0)91.98%)HlGH BACKPRESSURE

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 Supp. E-8J

711312004 17:37

Plant Name

Vhite Bluff %

711312004 23:45 6.1 90.74% HIGH BACKPRESSURE

- Unii No.

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

-

1

1

-

711 312004 23145

711 412004 1 1 :05

7/14/2004 11 :50

711 412004 1455

711 512004 408

711 512004 9157

711 512004 1 1 :58

711 512004 12:36

711 512004 16: 15

711 612004 7:50

711 612004 1 1 :40

711 612004 1540

711 612004 17105

711 712004 0:10

711 712004 1 1 : 15

711 712004 16103

7I20l2004 1440

7/21 12004 10:35

7/22/2004 10105

7/22/2004 12:53

71222004 21 137

712312004 8: 10

712312004 1 1 :37

712312004 13: 10

7/23/2004 15120

7/24/2004 1 1 145

7/24/2004 14: 10


711 412004 1 :56

711 412004 1 1 150

7/14/2004 1455

711 512004 2156

711 512004 9157

711 512004 11 :58

711 512004 12:36

711 512004 16: 15

711 612004 3:36

711 612004 1 1 :40

711 612004 1540

711 612004 17:05

711 712004 0:10

711 712004 2100

711 712004 16:03

711 812004 2100

7l2112004 0:03

7/21 12004 22:51

7/22/2004 12:53

7/22/2004 21 :37

7/23/2004 0: 10

712312004 1 1 :37

7/23/2004 13: 10

7/23/2004 15120

7/23/2004 15~37

7/24/2004 1 4: 1 0

7/24/2004 17:05

2.2

0.8

3.1

12.0

5.8

2.0

0.6

3.7

11.4

3.8

4.0

1.4

7.1

1.8

4.8

9.9

9.4

12.3

2.8

8.7

2.5

3.4

1.5

2.2

0.3

2.4

2.9

Reason for Outage

















95.68% BKKPRESSURE


96.91 % HIGH BACKPRESSURE









REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 Supp. E-8K

7/24/2004 17:05

Plant Name

Vhite Bluff %

7/24/2004 17:24 0.3 96.30% HIGH BACKPRESSURE

-

Jni No.

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

-

-

7/25/2004 16125

7/30/2004 11 :48

7/30/2004 16:00

7/30/2004 21 140

7/31/2004 14131

8/1/2004 12152

811 12004 16:02

8/1/2004 18136

8/2/2004 1545

8/2/2004 20112

8/3/2004 1 1 : 10

8/3/2004 13100

8/4/2004 9:05

8/4/2004 10140

8/4/2004 13: 16

8/9/2004 1 6: 16

8/9/2004 19107

8/9/2004 22149

811 012004 74159

811 812004 12:37

811 a12004 I 4132

811 912004 10:57

8/20/2004 16104

8/22/2004 12:23


7/25/2004 1851

7/30/2004 16:00

7/30/2004 21 140

713012004 22:20

7/31/2004 21 138

8/1/2004 16102

8/1/2004 18136

8/1/2004 21 :24

8/2/2004 20: 12

8/2/2004 21 133

8/3/2004 13:00

8/4/2004 0:00

8/4/2004 10:40

8/4/2004 13: 16

8/5/2004 0:02

8/9/2004 19107

8/9/2004 22149

8/9/2004 23: 19

811 012004 2221

811 812004 14132

ai1 912004 a32

811 9/2OQ4 20:02

8I20lM04 23:28

8/22/2004 13: 15

2.4

4.2

5.7

0.7

7.1

3.2

2.6

2.8

4.5

1.4

1.8

11 .0

1.6

2.6

10.8

2.9

3.7

0.5

7.4

1.9

10.0

9.1

7.4

0.9







92.59% HIGiH BACKPRESSURE

96.91% HIGiH BACKPRESSURE





95.68% BACKPRESSURE

92.59% BACKPRESSURE

90.74% BACKPRESSURE










8/22/2004 13:151 8/22/2004 20:321 7.3193.83%l HIGH BACKPRESSURE



Supp. E-8L

8/22/2004 20:32

Plant Name

Yhite Bluff %

8/23/2004 0:35 4.0 95.68% HIGH BACH PRESSURE

-

Unil No.

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

-

1

1 -

8/23/2004 12:20

8/23/2004 12140

8/23/2004 14150

8/24/2004 12:00

8/24/2004 1545

8/24/2004 16130

8/25/2004 8:48

8/25/2004 10123

8/25/2004 12140

8/25/2004 17: 17

8/25/2004 22102

8/26/2004 7132

8/26/2004 9157

8/26/2004 11 :32

8/27/2004 1 :42

8/27/2004 6: 18

8/27/2004 10:34

8/27/2004 14: 10

8/28/2004 8:42

8/28/2004 1 1 11 4

8/28/2004 13:47

9/3/2004 1529

9/4/2004 13:00

9/5/2004 1 3145

9/6/2004 11 107

9/6/2004 1533

Reason for Outage

8/23/2004 1 2:40

8/23/2004 14150

8/24/2004 0139

8/24/2004 15145

8/24/2004 16130

8/25/2004 1138

8/25/2004 10:23

8/25/2004 12:40

8/25/2004 17: 17

8/25/2004 22:02

8/26/2004 3103

812612004 9157

8/26/2004 11 132

8/27/2004 1142

8/27/2004 3:08

812712004 10134

8/27/2004 14: 10

8l2812004 1 : 19

8/28/2004 1 1 : 14

8/28/2004 13147

8/28/2004 16:31

9/3/2004 1 8: 1 3

9/4/2004 22:32

9/6/2004 I 135

9/6/2004 15:33

91612004 17135

0.3

2.2

9.8

3.8

0.8

9.1

1.6

2.3

4.6

4.7

5.0

2.4

1.6

14.2

1.4

4.3

3.6

11 .I

2.5

2.6

2.7

2.7

9.5

11.8

4.4

2.0

96.30% BACKPRESSURE

93.83% BACKPRESSURE

96.30% BAGKPRESSURE









95.68% BACKPRESSURE

93.83% BACKPRESSURE

91.98% BACKPRESSURE

95.68% BACKPRESSUR

95.68% BACKPRESSURE

91.98% BACKPRESSURE

88.89% BACKPRESSURE




96.30% BACKPRESSURE





9/6/2004 17:35) 9/7/2004 0:18) 6.7)96.30%)HIGH BACKPRESSURE

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 Supp. E-8M

911 312004 12%

911 412004 1407

911 512004 1 1 :40

911 512004 1 8: 18

911 612004 10:59

911 612004 1 1 :52

911 612004 16:25

911 612004 19:00

91~312004 14:m

1011 912004 6155

1011 912004 13: 10

10123l2004 12:20

10l31l2004 12:08

10131l2004 12:46

12/18/2004 20: 1 5

12/19/2004 3140

12/22/2004 5: 1 5

12/22/2004 17:48

12/22/2004 18145

12/26/2004 0:40

12/26/2004 1 :07

12/26/2004 4:00

12/26/2004 455

12/26/2004 12:45

I2/31/2004 1 1 :00

12131 12004 13:59

~~

Plant Name

Yhite Bluff

911 412004 0:42

911 412004 22:46

911 512004 18: 18

911 512004 23: 19

911 612004 1 1 :52

911 612004 16125

911 612004 19:00

911 612004 22:30

912312004 1 w 5

1011 912004 13:lO

1011 912004 19:37

1 0l23l2004 1433

10/31/2004 12:46

10l31l2004 18:38

12/19/2004 3:40

121 912004 339

12/22/2004 1 1 142

12/22/2004 18:45

12/26/2004 0140

12/26/2004 1 107

12/26/2004 4:00

12/26/2004 455

12/26/2004 12:45

12/26/2004 18134

12/31 12004 1359

12131 12004 19: 12

- Jnil No.

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

-

-

11.7

8.6

6.6

5.0

0.9

4.5

2.6

3.5

3.9

6.3

6.4

2.2

0.6

5.9

7.4

2.0

6.4

1 .0

77.9

0.5

2.9

0.9

7.8

5.8

3.0

5.2


95.68%

94.44%

96.93%

95.71 %

96.93%

93.87%

88.96%

93.87%

95.71 %

98.16%

95.09%

73.62%

95.71 ?4

96.93%

36.81 %

73.62%

26.99%

98.16%

92.02%

85.89%

82.82%

92.02%

79.75%

85.89%

92.02%

85.89%

~ I I I

12/31/2004 19:12 12/31/2004 19:49 0.6192.02%11D FAN REJECTING

Reason for Outage

- 9A CONVEYOR PROBLEM

H 113 H BAC KP R ESS U R E

HliGH BACKPRESSURE

HllGH BACKPRESSURE

HIGH BACKPRESSURE

HIGH BACKPRESSURE

HIGH BACKPRESSURE

HIGH BACKPRESSURE

HIGH BACKPRESSURE

HIGH BACKPRESSURE

HIGH ID FAN AMPS

HIGH BACK PRESSURE

16A DRAG CONVEYOR - Broke chain and speed sensor bracket.

ID FAN "8" REJECTING

ID FAN "8" REJECTING

COAL FIRE

COAL FIRE

LOST 10A CONV.

ICIA CONVEYOR RIPPED


10A CONVEYOR RIPPED



1C)A CONVEYOR RIPPED

IOA CONVEYOR RIPPED

ID FAN REJECTING

ID FAN REJECTING

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 Supp. E-8N

2/21 I2004 15150

2/21 I2004 16: 1 4

2/21 12004 I 6128

2/21 12004 I a47

2/22/2004 22:30

iiai2004 8104

1/27/2004 4: 17

2/10/2004 5101

3/1/2004 I I :oa

3/3/2004 I I 148

3/3/2004 I 8132

3/4/2004 17:02

3/7/2004 11 :01

3/7/2004 15106

3/8/2004 9120

3/8/2004 I I 1 I 5

31a12004 I I :55

31812004 13:40

3/8/2004 15150

3/9/2004 425

3/9/2004 5150

3/9/2004 6:30

3/9/2004 1445

3/9/2004 15150

311 012004 5145

311 012004 19: 15

Plant Name

Yhite Bluff

2/21 I2004 16: 14

2/21 12004 I 6128

~2112004 ia:47

2/22/2004 22:30

2/23/2004 3:42

I /a12004 I 2126

1/27/2004 5:50

2/10/2004 13:39

3/1/2004 11:41

3/3/2004 17: 19

3/3/2004 21 132

3/4/2004 17127

3/7/2004 15106

31a12004 9:20

31a12004 I I 1 I 5

31a12004 I I :55

31a12004 I 3140

31a12004 I 5150

31912004 425

3/9/2004 5150

3/9/2004 6:30

3/9/2004 14:45

3/9/2004 15150

311 012004 5:45

311 012004 19: 15

311 112004 3128

-

JnE No.

1

1

1

1

1

1

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

-

-

0.4

0.2

2.3

27.7

5.2

4.4

I .5

8.6

0.6

5.5

3.0

0.4

4.1

18.2

1.9

0.7

I .a

2.2

12.6

1.4

0.7

8.3

1.1

I 3.9

13.5

8.2

I 6.0


49.0av

61.35%

67.48%

79.75%

85.89%

71.09%

82.94%

65.17%

88.86%

59.24%

59.24%

97.16%

71.09%

94.79%

53.32%

56.28%

59.24%

61.02%

64.57%

77.01 %

82.94%

85.90%

a7.09%

8 8 . 2 7 ~ ~

91 .a2%

94.79%

88.86% 311 1 I2004 23:301 3/12/2004 15:31 I

Reason for Outage

ZH EAT s P RAY FAILURE

X O S FULL OF WATER

X O S FULL OF WATER

X O S FULL OF WATER

X O S FULL OF WATER

X O S FULL OF WATER

4 0 COAL TO PLANT

ICs PROBLEM

!2A DRAG CONVEYOR

!OA CONV ERG FAILED

!2A CONVEYOR

1IGH ID FAN AMPS

iIGH OPACITY

1IGH OPACITY

1IGH OPACITY

IIGH OPACITY

ilGH OPACITY

iIGH OPACITY

IIGH OPACITY

IlGH OPACITY

IlGH OPACITY

IlGH OPACITY

UGH OPACITY

IlIGH OPACITY

HIGH OPACITY

HIGH OPACITY

INLY 5 FEEDERS

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 Supp. E 4 0

Date out On

Plant Name

Vhite Bluff

Hrs. Oper. Lost Rate

?4a

-

Uni No

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

-

-

3/28/2004 23155


3/29/2004 1 :00 1 . I 47.39% WATER CHEMISTRY

I I I

3/29/2004 1 :00

3/29/2004 2120

3/29/2004 6: 10

3/29/2004 6: 15

3/29/2004 8130

3/29/2004 9130

3/29/2004 12145

312912004 17100

3/29/2004 17:20

3/29/2004 22120

313012004 0120

3/30/2004 16120

3/30/2004 1 8:30

313012004 19: 1 1

3/31/2004 5113

3/31/2004 9144

3/31/2004 9154

3/31 I2004 1 1 157

411 12004 1 2: 15

4/1/2004 13135

4/2/2004 16150

4/2/2004 20100

4/7/2004 7: 10

4/7/2004 16140

41912004 14:26

41912004 22100

411 612004 17105

3/29/2004 2120

3/29/2004 2:33

3/29/2004 6: 15

3/29/2004 8:30

3/29/2004 9130

3/29/2004 10153

3/29/2004 17:00

3/29/2004 17:20

3/29/2004 22120

3l3012004 0:20

3/30/2004 16120

313012004 18130

3/30/2004 19: 1 1

3/31 I2004 5: 1 3

3/31/2004 8138

3/31/2004 9:54

3/31 I2004 1 1 157

411 12004 12: 15

411 12004 13135

4/2/2004 9131

4/2/2004 20:00

4/4/2004 3136

4/7/2004 16140

41812004 1 :00

4/9/2004 16:21

411 012004 5144

4/17/2004 6:59

Reason for Outage

, 13.9197.63%IGAS INLET TEMPS HIGH

1.3

0.2

0.1

2.3

1.0

1.4

4.3

0.3

5.0

2.0

16.0

2.2

0.7

10.0

3.4

0.2

2.0

24.3

1.3

19.9

3.2

30.6

9.5

8.3

1.9

7.7

65.17% WATER CHEMISTRY


88.86% HIGH OPACITY




85.90% LACK OF CONDENSATE





79.98% OPACITY PROBLEMS


85.90% OF’ACITY PROBLEMS


94.79% HIGH OPACITY

59.24% UNABLE TO BLOW SOOT

94.79% OPACITY

95.97% OPACITY

97.16% OPACITY

88.86% ONLY 5 FEEDERS AVAIL

94.79% OPACITY

95.97% HIGH GAS INLET TEMPS

97.16% HIGH GAS INLET TEMPS

47.39% 17.A CONVEYOR

55.69% 17,A CONVEYOR BEARING

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 SUDD. E-8P

5/1/2004 12330

511 12004 1 8150

5/7/2004 17141

6/4/2004 20:00

6/4/2004 22100

611 812004 1425

6/30/2004 9:30

7/4/2004 15:04

7/6/2004 13: 15

7/8/2004 12147

711 312004 19:30

711 412004 11 103

711 412004 I 1 :50

711 412004 12145

711 512004 1343

711 612004 13140

7/23/2004 11 :45

7/23/2004 15120

7/24/2004 8130

7/24/2004 13:50

7/24/2004 1440

7/24/2004 17: 10

8/3/2004 1755

8/4/2004 10:38

a1412004 I 2155

8/4/2004 13:23

Plant Name

Vhite Bluff

511 I2004 15140

511 12004 20: 1 I

5/7/2004 18141

6/4/2004 22: 00

6/4/2004 22:24

6/18/2004 22:41

6/30/2004 23122

7/5/2004 3145

7/6/2004 1 8: 56

7/8/2004 20:58

711 312004 23148

711 412004 11 150

711 42004 1245

711 512004 3156

711 612004 2: 16

711 712004 0: 10

7/23/2004 15120

7/23/2004 17:45

7/24/2004 9: 12

7/24/2004 14:40

7/24/2004 17: 10

7/24/2004 1 7:25

8/3/2004 21 138

8/4/2004 12155

a 1 4 1 m ~ I 3: 23

8/5/2004 2103

-

Jnii No.

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

-

2

2

2

2

2

2

2

2

2 -

3.7

1.4

1 .0

2.0

0.4

8.3

13.9

12.7

5.7

8.2

4.3

0.8

0.9

15.2

12.6

10.5

3.6

2.4

0.7

0.8

2.5

0.3

3.7

2.3

0.5


97.16% WEiT COAL

80.57% LACK OF MILLS

75.24% GEN COLLECTOR AIR HI

24.24% HIGH OPACITY PROBLEM

36.36% HIGH OPACITY PROBLEM


90.91% ONLY HAVE 5 MILLS





94.55% HIGH BACKPRESURE






36.36% BOTTOM ASH PROBLEMS - Bottom ash has bridged the nose arc1 in one furnace - Unit load dropped to attempt deslag

94.55% PFlESSURE UNIT STARTU






94.55% H E H BACKPRESSURE

Reason for Outage

8/22/2004 13:00 8/22/2004 1440 1.7 90.91% COAL PROBLEMS

12.7 92.12% HllSH BACKPRESSURE I I

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSICIN -YEAR 2004 Supp. E-8Q

1.7 96.97% BACKPRESSURE

0.1 97.58% HIGH BACKPRESSURE


8.0 96.97% HIGH BACK PRESSURE


13.6 96.97% HIGH BACK PRESSURE





0.8 70.91 % DA LEVEL CONTROL

1 .I 72.73% 9A FEEDER PLUGGED UP

16.8 95.97% FANS CONTROLS REJECT

7.3 95.97% FANS UNSTABLE

31.2 93.01 % ID FAN DRIVE PROBLEM

64.7 87.09% ID FAN DRIVE PROBLEM

145.5 50.36% 2A BFP HIGH VIBRATION

5.1 35.55% BFP :?A TO BE PLACED ON GEAR 4HRS DUE TO VOLUTE CHANG

3.9 35.55% FEEDPUMP TRIP

8.3 35.55% COAL. FIRE

1.5 71.09% COAL FIRE

1.9 82.94% ONLY FIVE MILLS

0.1 71.09% COAL SUPPLY PROBLEMS

0.8 82.94% COAL SUPPLY PROBLEMS

6.5 26.07% LOST 10A CONV.

0.9 94.79% 10A CONVEYOR

71.3 88.86% 10A CONVEYOR

Plant Name

Vhite Bluff 8/24/2004 13:35

- Uni No

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

-

-

% 8/24/2004 15:35 2.0 98.18% BACKPRESSURE


12/26/2004 3531 12/26/2004 4501

Date Hrs. Oper.

out I On I Lost 1 Rate I

0.9(59.24%(10A CONVEYOR

Reason for Outage

8/24/2004 15:35

8/24/2004 17:37

8/24/2004 17:40

8/25/2004 14122

8/26/2004 0:28

8/26/2004 12:23

8/27/2004 12:25

8/28/2004 1 0:00

8/28/2004 1 1 : I 0

8/28/2004 1340

~ B I I ~ O O ~ 12:58

911 a2004 18:45

1011 I2004 15158

1 O/4/2004 19:00

1 OF12004 3120

011 1 I2004 10:10

10/23/2004 0:12

0~112004 20:33

1 1 I1 512004 6:45

2/18/2004 20:15

12/19/2004 4:32

12/19/2004 6:00

U19/2004 1650

211 912004 I 6:55

I 2/22/2004 5:i 5

U22I2004 17:51

212212004 18:45

8/24/2004 17:17

8/24/2004 17140

8/25/2004 3143

8/25/2004 22121

8/26/2004 3104

812712004 2:00

8/28/2004 1 132

8/28/2004 1 1 : 1 0

8/28/2004 13~40

8/28/2004 1437

8 B i 1 2 m 1 3 ~ 5

911 2I2004 19148

1 0/2/2004 8149

1 0/5/2004 2: 16

10/8/2004 10129

1011 412004 2:54

1 0l2912004 1 :43

I 11112ao4 I :38

1 1 I1 5/2004 10:36

12/19/2004 4132

121 9l2004 6:00

121 9/2004 7157

12/19/2004 16:55

1211 912004 I 740

I 2/22/2004 I I :43

12/22I2W4 18145

12/25/2004 18105

- Uni No

2

2

2

2

2

2

2

2

2

2

-

-

Supp. E-8R REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004


Plant Name

White Bluff

Oper. Rate %

77.01%

38.86%

32.94%

79.98%

59.24%

77.01%

32.94%

38.86%

34.79%

i9.24%

Reason for Outage

IOA CONVEYOR

10A CONVEYOR

10A CONVEYOR

10A CONVEYOR

1019 CONVEYOR

lor\ CONVEYOR

1014 CONVEYOR

IOA CONVEYOR

lob\ CONVEYOR

21A CONV FAILED

out Hrs. Lost

4.

1.

0.

2.

0.

0.

0.’

0.

12:

1 .:

- On

12/25/2004 18:05 1 2/25/2004 22::

12/25/2004 2250

12/26/2004 045

12/26/2004 1 :06

12/26/2004 353

12/26/2004 450

12/26/2004 5: 15

12/26/2004 5152

12/26/2004 6: 10

I22712004 1 1 :30

12/26/2004 O:L

12/26/2004 1 :C

12/26/2004 3::

12/26/2004 4::

12/26/2004 5: 1

12/26/2004 5:E

12/26/2004 6: 1

12/26/2004 1813

12/27/2004 12:4

Unit No.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-9

AVERAGE ANNUAL HEAT RATES, NET KWH OUTPUT AND CAPACITY FACTORS

1. Report on all generating units available for operatiion. 2. Compute heat rates on basis of total fuel burned on each unit including burner lighting,

banking fuel and spinning fuel. 3. Yearly Capacity Factor in percent =

Total Kilowatt Hours Generated x 100 Kilowatt Capacity of Unit (name plate rating) X 8 z 4

Plant Name

Arkansas Nuclear One

Independence S.E.S.*

White Bluff S.E.S.*

Ritchie S.E.S.

Lake Catherine S.E.S.

Couch S.E.S.

Moses S.E.S.

Lynch S.E.S

Mabelvale CTG's

Remmel Dam

Carpenter Dam

* Jointly owned units are report€

* Effective Jan 2000, Entergy implemented seasonal ratings f a r its generating units. Presented I - - I in Independence Unit 1 and 57% in White Bluff.

ratings which are in effect for the majority months of the year.

1 2

1

1 2

1 CTG

1 2 3 4

1 2

1 2

2 3

Dsls

Blk

Blk

Blk

M W *

857 1011

263

465 481

335 16

47 45

100 547

23 125

70 70

68 110

5

64

9

54

at the 100

B.t.u. Per Net Kwh

10,293 10,258

10,447

11,981 12,252

0 19,769

0 13,711 13,041 12,209

16,039 15,977

21,732 20,289

31,541 80,435

0

67,409

NIA

NIA

Net Gen. Kwh X 10A6

6,820.592 8,621.142

5,432.459

5,342.799 5,629.752

(1.362 0.01 3

-0.01' 0.02f

(2.084 140.125

(0.283 22.656

-0.09! -0.10!

O.O€ -0.52t

(

0.02;

50.118

11 1.893

Capacity Factor

92.88% 1 14.39%

73.98%

74.63% 75.94%

-0.04% 0.01 %

0.00% 0.01 %

-0.22% 2.92%

-0.11% 1.97%

-0.02% -0.02%

0.01 ?4 -0.05% 0.00%

0.00%

52.98%

21.66%

level. Entergy Arkansas Inc. ., share is 31.5%

Major Fuel

Uranium Uranium

Coal

Coal Coal

Gas Gas

Gas Gas Gas Gas

Gas Gas

Gas Gas

Gas Gas

Diesel Oil

Gas

Hydro

Hydro

?re are the winter

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 SUPP. E-11

lame o f Company: ENTERGY ARKANSAS, INC. Time Period : 20O5-20Oi

FUTURE SALES, LOADS & RESOURCES PER DOCKET NO. U-2897 - ELECTRIC UTILITIES -

1. Provide the following information relating t o generating plants, both existing and proposed, (and associated fuel supply and other facilities) wi th a capacity o f 50 MW or more t o be used to supply system demands during the next five (5) calendar years:

Name & Location of Plant :ecil Lynch (Unit #2) 1. Little Rock, AR

:ecil Lynch (Unit #3) 1. Little Rock, AR

:ecil Lynch ( IC Unit) I. Little Rock. AR

larvey Couch (Unit # I ) ;tamps, AR

larvey Couch (Unit #2) ;tamps, AR

ake Catherine (Unit #I) lalvern, AR

ake Catherine (Unit #2) lalvern. AR

ake Catherine (Unit #3) lalvern. AR

ake Catherine (Unit #4) lalvern, AR

lamilton Moses (Unit #I) orrest City, AR

'amikon Moses (Unit #2) orrest City, AR

labelvale (Unit # I ) labelvale, AR

labelvale (Unit #2) labelvale, AR

labelvale (Unit #3) labelvale, AR

labelvale (Unit #4) labelvale. AR

arpenter Dam (Unit #1) ot Springs, AR

arpenter Dam (Unit #2) ot Springs, AR

Di (C)

Const. Began/ Begins

?

0 Plant

WasMlil l Be In

Sewice 1949 --

1954

1967

1943

1954

1 950

1950

1953

970

951

95 1

1970

1970

1970

1970

1932

1932

:e) Plant Ownership

% Owned 100

100

100

100

100

100

100

100

100

100

100

100

100

100

100

100

100

Others Owners (If Applicable)

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 SUDD. E-IOA

lame of ComDanv: ENTERGY ARKANSAS, INC. Time Period: 2005-200!

FUTURE SALES, LOADS & RESOURCES PER DOCKET NO. U-2897 - ELECTRIC UTII-ITIES -

1. Provide the fol lowing information relating to generating plants, both existing and proposed, (and associated fuel supply and other facilities) wi th a capacity of 50 MW or more to be used to supply system demands during the next five (5) calendar years:

Name 8 Location of Plant lemmel (Unit #I) lalvern. AR

:emme1 (Unit #2) lalvern. AR

:emmel (Unit #3) lalvern, AR

.obert Ritchie (Unit #I) lelena, AR

obert Ritchie (Unit #3) elena, AR

rk. Nuclear One (Unit # I ) ussellville, AR

rk. Nuclear One (Unit #2) ussellville, AR

Jhite Bluff (Unit #I) edfield, AR

lhite Bluff (Unit #2) edfield. AR

idependence (Unit #I) ewark, AR

D; (C)

Const. Began1 Begins

-0 IPlant

WasMi l l Be In

Service 1925

1925

1925

1961

1970

1974

1980

'1 980

'I981

'I 983

(e) Plant Ownership

% Owned 100

100

100

100

100

100

100

57

57

31.5

Others Owners (If Applicable)

AR Elec. Coop. Corp. City of: Jonesboro Conway West Memphis

AR Elec. Coop. Corp. City of: Jonesboro Conway West Memphis

AR Elec. Coop. Corp. Entergy Mississippi, Inc. City of: Jonesboro Conway West Memphis Osceola

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 SUPP. E-I1

FUTURE SALES, LOADS & RESOURCES PER DOCKET NO. U-2897 I - ELECTRIC UTILITIES - 1. (Continued)

See Footnotes

(9

Plant Capacity (3)

(MW) 68

110

5

23

125

47

45

96

547

68

70

14

14

14

14

29

30

on E-I 1A

(9) % Plant

Capacity Avail. To Meet Firm Demands

100

100

100

100

100

100

100

100

100

100

100

100

100

100

100

100

100

(h)

Plant Type

Steam

Steam

Gas Turbine

Steam

Steam

Steam

Steam

Steam

Steam

Steam

Steam

Gas Turbine

Gas Turbine

Gas Turbine

Gas Turbine

Hydro - Storage

Hydro - Storage

(i)

Fuel Type -

Nat. Gas

Nat. Gas

Fuel Oil

Nat. Gas

Nat. Gas

Nat. Gas

Nat. Gas

Nat. Gas

Nat. Gas

Nat. Gas

Nat. Gas

Nat. Gas

Nat. Gas

Nat. Gas

Nat. Gas

Hydro

Hydro

U)

Net Heat Rate

21,028

18,599

11,273

26,972

15,108

14,823

14,233

1 1,492

10,759

17,773

15,421

NIA

N/A

(4 cost Of Plant (1) ($OOOs)

9,856

22,899

478

3,694

18,228

6,824

6,458

11,606

49,398

8,356

7,826

2,979

2,920

1,834

2,817

5,469

4,511

(1) Plant Cost

Per KW Capacity (2)

($) 14:

20E

9t

161

14E

145

144

121

9a

123

112

213

209

131

201

189

150

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 SUPP. E-141

'ability (owned percentage of cost & cap

FUTURE SALES, LOADS & RESOURCES PER DOCKET NO. U-2897

lity for jointly

- ELECTRIC UTILITIES - 1. (Continued)

(9

Plant Capacity (3)

(MW) 4

3

4

325

14

842

1,001

462 (4)

470 (4)

257 (4)

(9) % Plant Capacity

Avail. To Meet Firm Demands

100

100

100

100

100

100

100

100

100

100

FOOTNOTES: (If Applicable) (1) Jointly owned unit costs are for E (2) Cost of Unit divided by Rated Ci

owned units). (3) Based on summer 2004 ratings. (4) EA1 share only.

Plant Type

Hydro - Storage

Hydro - Storage

Hydro - Storage

Steam

Gas Turbine

Steam

Steam

Steam

Steam

Steam

I share only.

Fuel Type -

Hydro

Hydro

Hydro

Nat. Gas

Nat. Gas or Fuel Oil

Uranium

Uranium

Low Sulfur Coal

Low Sulfur Coal

Low Sulfur Coal

Net Heat Rate NIA

NIA

NIA

13,029

23,824

10,268

10,258

10,491

11.066

10,675

(k)

cost Of Plant (1) ($OOOs)

1,455

801

768

46,164

1,749

660,406

1,007,046

21 9,671

186,551

117,174

(1) Plant Cost

Per KW Capacity (2)

($1 3 6 ~

26;

19;

14;

125

784

1 ,OOE

834

696

1,447

REPORT TO ARKANSAS PUBLIC SERVICE COMhAlSSlON -YEAR 2004 SUPP. E-12

Uame of Company: ENTERGY ARKANSAS, INC. Time Period: 2005-2006


2. Provide the following information relating to electric transmissilon lines (and associated facilities including substations) of a design voltage of 100 KV or more extending more than 10 miles andlor of 170 KV or more extending 1 mile to be used to supply systeim demands during the next two (2) calendar years:

~~~

(a) Line Size

61kV (159C

161 kV

161 kV

954 kcmil I phase)

500 kV

666 kcmil / phase)

115 kV (1- 1590 kcrnils

I phase)

( b) Line

Distance 12 miles

5

1.5

2

(4 Route of

Line SES - Newport (3rd Line

iilltop (New Ring Bus)

;randview New line and substation

SanSouci Tap Dell - Shelby Line) ;an Souci Substation New Ring Bus)

(uhn Road Substation

Jlaumelle (alternate ubstation feed)

( 4 P ui r pose

011 Line Jonesboro Trans. Service Agree

Support Northwest under contin!

Support Northwest under contin!

New IPP

New IPP

Uew Load cus1:omer

4lternate Feed for Substation -

(e) cost of

Line 1.9 M

3.5 M

1.6 M

5.0 M

12.0 M

3.0 M

3.1 M

Sub- (f)

Number

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUDD. E-13

Name of Companv: ENTERGY ARKANSAS, INC. Time Period 2005-200


(h) Date Const.

BeganlBegins

Dec-04

Jan-05

Dec-06

Jan-06

Feb-05

Aug-06

0) Date To Be

Placed In Servici

J u n-05

Jun-06

Jun-07

Jul-07

Sep-O!j

Aug-0;'

Line OwnershiD fi)

% Owned

100%

100%

100%

100%

100%

100%

. _ I

Other Owners (If Applicable)

;PA will own 1 breaker

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-I4

Jame of Companv: ENTERGY ARKANSAS, INC. Time Period 2005-2001


3. Provide by consumer classes (include residential or domestic sales, commercial sales, industrial sales, public street and highway lighting sales, other sales to public authorities, sales for resale, interdepartmental sales) forecasts of the following for the next two (2) calendar years:

Year

2005

2006

NOTES:

(a) Customer

Class

RESIDENTIAL

COMMERCIAL

INDUSTRIAL

LIGHTING & PUBLIC AUTH

RESALE

COMPANY USE

RESIDENTIAL

COMMERCIAL

INDUSTRIAL

LIGHTING & PUBLIC AUTH

RESALE

COMPANY USE

(b) Avg. No. of Customers

567,530

84,058

22,416

61 1

10

570,882

85,811

22,482

623

5

7,380,987,925

5,627,510,528

7,178,856,983

280,265,344

3,661,356,000

49,674,200

24,178,650,978

7,535,257,815

5,754,429,893

7,269,872,511

286,740,209

2,51~6,192,000

49,723,874

23,412,216,301

FORECAST DOES NOT INCLUDE THE DEMAND SIDE PROGRAMS. COINCIDENT AND NON-COINCIDENT PEAK DEMANDS DO NOT INCLUDE I WHOLESALE (RESALE) EXCLUDES AECC AND JONESBORO I

(d) System Peak Demand (KW)

1,949,858

1,304,871

1,040,887

64,986

562,633

11,518

4,934,753

1,994,941

1,345,992

1,058,793

67,070

328,035

11,631

4,806,463

SSES

(e) Non-Coincidental

Peak Demand lKWl

2,198,940

1,331,557

1,077,484

66,315

572,808

11,754

4,984,007

2,205,467

1,366,755

1,092,431

68,105

333,706

11,810

4,806,463

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUDD. E-15

I

0.4321

0.4923

0.7873

0.4923

0.7429

0.4923

0.431 2

0.4880

0.7838

0.4880

0.8756

0.4880

(9) Avg. Annual Lalad Factor (Based on

Non-Coincidental Peak Demand)

0.3832

0.4825

0.7606

0.4824

0.7297

0.4825

0.3900

0.4806

0.7597

0.4806

Cl.8607

01.4806

Time Period: 2005-200

(h) % Line Losses

8.351 0

8.1842

6.81 05

7.3026

1 S464

8.1842

8.351 8

8.1842

6.81 05

7.3026

1.5464

8.1842

REPORT TO ARKANSAS PUBLIC SERVICE CONlMlSSlON -YEAR 2004 SUDD. E-16 ~

Jame of Company: ENTERGY ARKANSAS, INC. Time Period: 200


4. Provide forecasts of the following for the next two (2) calendar years in kilowatts (beginning January 1):

Year

2005

2005

(a) System Peak

Demand

5,343 MW

** Total capability is equal to owned capabili

(b) Power Sources to

Meet System Peak Demand (1)

Owned Capabiility:

4rk. Nuclear Olne Sarpenter Souch ndependence -ake Catherine -ynch blabelvale Moses ?emme1 ?itchie Nhite Bluff

'urchases W/O Reserves:

;rand Gulf Ixelon :oral 2onoco Phillips

Sales W/O Reserves:

imeren

-0TAL CAPAB;ILITY**

1,837 59 148 257 735 183 56 138 1 1 339 932

4,695

41 1 34 21 8 23 687

165 165

521 7

(c) Reserves (Avg. Sys. & at System Peak)

(1 26) MW***

plus purchases w/o reserves minus sales w/o reserves,

I *** Capability margin at Entergy system peak.

1) To include self-owned generating capability identified by plant, firm and non-firm purchases identified by contract.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 SUPP. E-16A

Uame of Companv: ENTERGY ARKANSAS, INC. Time Period: 200

FUTURE SALES, LOADS & RESOURCES PER DOCKET NO. U-2897 - ELECTRIC U’I’ILITIES -

4. Provide forecasts of the following for the next two (2) calendar years in kilowatts (beginning January 1):

Year

2006

2006

(a) System Peak

Demand

5,165 MW

** Total capability is equal to owned capabil

(b) Power Sources to

Meet Svstem Peak Demand (1)

Owned Capabiility:

Ark. Nuclear Olne Carpenter Couch Independence Lake Catherine Lynch Ma belvale Moses Remmel Ritchie White Bluff

Purchases W/O Reserves:

Grand Gulf Exelon Coral Conoco Phillip:;

Sales WIO Reserves:

4meren

rOTAL CAPAB;ILITY**

1,837 59 148 257 735 183 56 138 1 1 339 932

4,695

41 1 34 21 8 23 687

165 165

5,217

(c) Reserves (Avg. Sys. & at Svstem Peak)

52 MW***

plus purchases wlo reserves minus sales wlo reserves, I *** Capability margin at Entergy system peak. I

I I (1) To include self-owned generating capability identified by plant, firm and non-firm purchases identified by contract.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-17 Name of Company: ENTERGY ARKANSAS, INC. Time Period 2005-2006

FUTURE SALES, LOADS, & RESOURCES PER DOCKET NO. U-2897 - ELECTRIC UTILJTIES -

5. Describe methodology used in forecasts in sufficient detail to allow replication by a third party. Include graphs and formulae if appropriate. I

1 Use of Econometric Models for Sales Forecastinn:

~ Entergy uses econometric equations to forecast sales and customters for all of its jurisdictions. These models are built using standard statistical techniques, e.g. ordinary least squares regression, autoregressive and moving average terms. Using monthly historical data, statistical relationships between sales and their economic drivers are estimated

1 using dynamic regression equations, combining ordinary least squares regression (OLS) with the Box-Jenkins method.

, Sales are estimated as a function of the number of customers, economic drivers, heating and cooling degree days (where applicable), and error correction terms, such as AR(n) and MA(n).

Customers are estimated as a function of economic drivers, a binary (dummy) variable where applicable, and error 1 correction terms. The binary variables are included in situationis where known significant shifts in the number of customers took place.

The inclusion of the autoregressive, AR(n), and moving average, IblA(n), terms has the added advantage of extracting the maximum amount of information from the residual terms, thus quantifying the impact of some subtle long term trends, like income and housing starts.

Econometric equations are used to generate annual sales and customer forecasts based on the criteria listed above. Five-year annual growth rates are produced for the years 2005-2009. Growth projections are then applied to the most recent Present Estimate (in this case 4‘h quarter 2004). In some cases, where the estimated equation results were judged to be untenable, historical growth rates were applied insteald. Qualitative variables (Dummies) were used in cases where known shifts or drastic losses in customers took place. Weather conditions for the projected period are assumed to be “normal” and are based on historical 1995-04 data. Most drivers used are based on county level data, aggregated to the EA1 service area. The source of the driver projections is Economy.com.

Due to the fact that the Commercial and Industrial revenue classes; are both forecasted using multiple segments, a representative model for one segment has been included below for each.

The software package used in the estimation is MetrixND ver. 4.0 ltron, Inc. San Diego, CA

I

http://Economy.com

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-17A Name of ComDany: ENTERGY ARKANSAS, INC. Time Period 2005-2006

1 1 142 127

0.922 0.914 1.994 #NA

-5.057 -4.745

107.599 0.0000 172.55

9 1

0.01 0.08 0.05

5.52%

23.27 0.5038

3 143 139

0.997 0.997 2.008 #NA

13.798 13.881

15366.156 0.0000 '

-1177.19 44074573998 132897381 956096.26

977.80 683.75 0.13%

71.49 n

5. Describe methodology used in forecasts in sufficient detail to allow replication by a third party. Include graphs and formulae if appropriate.

Modeling Equations: Results and Diagnostics EA1

UPRCOEAI

>ONST 0.429 0.129 3.325 0.12% ?ealPersonal I ncorne 0.000 0.000 5.51 6 0.00%

WI) -0.076 0.181 -0.420 67.55%

W 1 ) 0.549 0.152 3.606 0.04%

Forecast

2002

2003

2004 2005 2006

CRBEAI

12.78 12.56 12.69 12.68 12.66 12.73

13.03 13.24

iouseholds 667.600 45.043 14.821 0.00% W ) 0.976 0.023 41 543 0.00% A M I ) -0.069 0.089 -0.770 44.28%

Forecast

551,351 550,822 556,005 555,890 562,455 562,237

566,166 570,098

2002

2003

2004

2005

2006

Iterations

Adjusted Observations

Deg. of Freedom for Error

R-Squared

Adjusted R-Squared

Durbin-Watson Statistic

Durbin-H Statistic

AIC

BIC

F-Statistic

Prob (F-Statistic)

Log-Likeli hood

Model Sum of Squares

Sum of Squared Errors

Mean Squared Error

Std. Error of Regression

Mean Abs. Dev. (MAD)

Mean Abs. % Err. (MAPE) Ljung-Box Statistic

Prob (Ljung-Box)

Iterations



R-Squared

Adjusted R-Squared Durbin-Watson Statistic

Durbin-H Statistic

AIC

BIC

F-Statistic

Rob (F-Statistic)

Log-Likelihood



Mean Squared Error Std. Error of Regression


Mean Abs. % Err. (MAPE) Ljung-Box Statistic Prob (Ljung-Box)

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUpp. E-17B Name of Companv: ENTERGY ARKANSAS, INC. Time Period 2005-2006


General merchandise stores

386889.475 47815.786 8.091 0.00% !mRetail idd 2499.919 1715.096 1.458 14.80%

2409.034 2576.829 0.935 35.21 % 2dd

Forecast

238,261,906 232,657,949 236,243,979 235,185,229

236,891,467 232,364,421

234,941,332

241,040,916

2002

2003

2004

2005

2006

‘otal EA1 Commercial Customers

:ONST 3571261.781 176338532945 0.020 98.39% tetailSales -0.343 0.324 -1.060 29.09%

1.000 0.002 408.430 0.00% W1) -0.325 0.084 -3.872 0.02% w 1

iMA(1) 0.331 0.090 3.655 0.04% Forecast

78,990 79,079 80,526 80,463 82,075 82,131

83,937 85,588

2002

2003

2004

2005

2006

Iterations



R-Squared

Adjusted R-Squared


Durbin-H Statistic

AIC

BIC

F-Statistic

Prob (F-Statistic)

Log-Likelihood



Mean Squared Error



Mean Abs. % Err. (MAPE)

Ljung-Box Statistic

Prob (Ljung-Box)

Iterations


Deg. of Freedom for Error R-Squared

Adjusted R-Squared

Durbin-Watson Statistic Durbin-H Statistic

AIC

BIC

F-Statistic

Prob (F-Statistic)

Log-Li keli hood


Sum of Squared Errors Mean Squared Error




Ljung-Box Statistic

Prob (Ljung-Box)

1 11s 104

0.897 0.883 1.698 #NA

28.025 28.376 64.379 0.0000

-1806.06 118901107127

3930 137198799350

648 131921922452

5.46 1148572.69 719649.98

3.62% 40.40 0.0194

99 142 137

0.998 0.998 2.044 #NA

11.009 11.113

2201 3.076 0.0000 -978.15

5140658387 799831 7 58381.87

241.62

174.12 0.24% 1 10.00

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-17C Name of Company: ENTERGY ARKANSAS, INC. Time Period 2005-2006

20438801 1 622 1 2.71

402.76 261.66 1.17%

25.35

0.3870,


Industrial Other

-112.813 460.586 -0.245 80.74% -250.175 99.945 -2.503 1.54%

0.558 0.139 4.031 0.02% 0.475 0.145 3.277 0.18%

Forecast

413,315 424,695 519,729 504,190 453,506 457,713

461,699 460,724

2002

2003

2004 2005

2006

Total EA1 Industrial Customers

:ONST 17887.182 6d9.752 25.562 0.00% ;sP 0.000 0.000 -1.163 24.72%

0.376 0.148 2.547 1.21% 0.265 0.153 1.737 8.49%

W1) ANI)

Forecast

21,742 22,012 22,261 22,234 22,677 22,487

22,495 22,542

2002

2003

2004

2005

2006

Iterations



R-Squared

Adjusted R-Squared


Durbin-H Statistic

AIC

B IC

F-Statistic

Prob (F-Statistic)

Log-Li keli hood

Model Sum of Squares Sum of Squared Errors

Mean Squared Error



Mean Abs. YO Err. (MAPE)

Ljung-Box Statistic

Prob (Ljung-Box)

Iterations



R-Squared

Adjusted R-Squared


Durbin-H Statistic

AIC

BIC

F-Statistic Prob (F-Statistic)

Log-Likelihood



Mean Squared Error


Mean Abs. Dev. (MAD) Mean Abs. % Err. (MAPE)

Ljung-Box Statistic

Rob (Ljung-Box)

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-17D Name of Companv: ENTERGY ARKANSAS, INC. Time Period 2004-2006


MG@EAI

CONST -87493.389 46896.525 -1.866 6.75% EmGov 301.053 149.976 2.007 4.97% Population 31.467 34.380 0.915 36.41 % Hdd -0.816 0.823 -0.992 32.56% Cdd -1.780 3.239 -0.550 58.49%

Forecast

255,225 256,701 265,929 262,668 277,52 1 273,314

284,106

2002

2003

2004

2005

2006 293,884

CG@EAI

'opulation 3SP

W 1 ) SMA(1)

Forecast

1.317 0.540 2.438 1.61% 0.000 0.000 -0.037 97.06% 0.957 0.024 39.122 0.00% 0.190 0.116 1.637 1O.4O0h

51 5 51 5 549 546 581 580

589 599

2002

2003

2004 2005 2006

Iterations



R-Squared

Adjusted R-Squared


Durbin-H Statistic

AIC

B IC

F-Statistic

Prob (F-Statistic)

Log-Li keli hood



Mean Squared Error



Mean Abs. % Err. (MAPE) Ljung-Box Statistic

Prob (Ljung-Box)

Iterations


Deg. of Freedom for Error R-Squared

Adjusted R-Squared Durbin-Watson Statistic

Durbin-H Statistic

AIC

B IC

F-Statistic

Prob (F-Statistic)

Log-Likelihood



Mean Squared Error Std. Error of Regression



Ljung-Box Statistic

Prob (Ljung-Box)

7'

5(

0.901 0.88(

2.08: #Nl

13.70! 14.18: 37.62;

O.OOO(

-564.2: 39195199i 4167211: 744144.87

862.64 602.9s 2.89% 30.14

0.1802

15 142 137

0.975 0.975 2.435 #NA

3.866

3.970 1361.079

0.0000 -470.97 251129

6319 46.13 6.79 3.65

0.71% 71.78

0.0000

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUpp. E-17E

lame of Comoanv: ENTERGY ARKANSAS, INC. Time Period 2005-2006

. Describe methodology used in forecasts in sufficient detail to allow replication by a third party. Include graphs and formulae if appropriate.

ef i n i t ions

ales and customers R@EAI C@EAI I@EAI G@EAI R@EAI C@EAI I@EAI G@EAI

conomic drivers mManu mRetail mGov 'MF ISP

leather DD :DD

lodeling modifiers ,R !A

'ransformation Identities IPRC@EAI =

esidential customer sales ommercial customer sales dustrial customer sales overnment customer sales esidential customers ommercial customers idustrial customers ,overnment customers

lanufacturing Employment .etail Employment iovernmental Employment idustrial production index - Manufacturing (US) ;ross State Product

leating degree days, Little Rock weather station :ooling degree days, Little Rock weather station

utoregressive correction term doving averages term

MR@EAI/CR@EAI

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-17F Name of Company: ENTERGY ARKANSAS, INC. Time Period 2005-2006


Model Input Data Sales and Customers

1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004

5,680,148 5,521,796 5,867,480 6,022,827 5,988,297 6,613,558 6,492,924 6,791,425 6,917,580 7,049,515 7,057,090 7,118,148

4,067,291 4,147,157 4,267,288 4,390,358 4,445,068 4,773,306 4,880,194 5,063,402 5,161,729 5,221,108 5,328,042 5,487,955

5,689,752 5,940,651 6,314,099 6,487,151 6,646,562 6,836,749 7,053,935 7,239,730 7,051,755 7,027,284 6,998,808 7,020,210

229,620 231,544 242,889 234,148 239,077 232,804 236,618 238,764 245,382 255,225 265,929 277,521

505,347 51 1,074 51 8,135 523,847 527,757 533,863 541,543 546,060 547,938 551,351 556,005 562,455

63,535 64,819 66,382 68,023 69,329 70,973 72,843 75,193 77,496 78,990 80,526 82,075

21,275 21,423 21,890 22,170 22,259 22,522 22,350 22,244 22,240 21,742 22,261 22,677

440 442 448 453 461 467 469 482 502 51 5 549 58 1

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION - YEAR 2004 SUPP. E-17G Name of Company: ENTERGY ARKANSAS, INC. Time Period 2005-2006


1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006

2482 2080 21 52 2334 2023 181 1 1781 2357 21 22 2332 2261 1983 2116 21 16

1283 1060 1350 1198 1194 1814 1252 1424 1178 1204 1059 101 1 1268 1268

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUP^. E-17H Name of Company: ENTERGY ARKANSAS, INC. Time Period 2005-2006


iconornic Drivers

1994

1995

1996

1997

1998

1999

2000

2001

2002

2003

2004

2005

2006

365

375

382

390

398

407

41 5

42 1

429

438

446

456

467

1,019 18,116 7,410

1,047 18,751 8,030

1,065 19,387 8,578

1,089 20,954 9,673

1,113 22,549 10,102

1,140 22,944 11,103

1,161 24,399 11,565

1,180 24,952 12,251

1,202 25,277 12,903

1,225 25,683 13,367

1,247 26,590 14,359

1,269 27,735 15,075

1,295 28,947 16,006

42

41

43

45

48

47

47

45

43

41

41

41

41

44

47

48

49

50

52

52

52

53

52

53

53

54

82 19,653

84 20,345

85 20,637

87 22,384

88 23,149

91 23,751

93 24,255

100 24,333

102 24,649

103 25,076

104 25,806

105 26,648

106 27,551

85

89

93

100

106

111

115

112

111

111

116

120

123

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-I71 Name of Companv: ENTERGY ARKANSAS, INC. Time Period 2005 - 2006

FUTURE SALES, LOADS, & RESOURCES PER DOCKET NO. U-2897 - ELECTRIC UTILITIES - 5. Describe methodology used in forecasts in sufficient detail to allow replication by a third party.

Include graphs and formulae if appropriate.

Reference No. 3 a-h

WHOLESALE MODEL

Sales to the wholesale sector were determined by forecasting sales for each of the following wholesale customers:

Wholesale C u s t o m

Benton Campbell, MO Conway Farmers' Electric Cooperative North Arkansas Electric Cooperatives Osceola Prescott Thayer, MO West Mem p his Ameren * (Union Electric)

I The following factors were considered for each wholesale cus1:omer:

KWHWS = Function of KWH Residential KWH Commercial KWH Industrial Weather

The factors which historically would explain the wholesale growth were considered to be the same factors that explained EAl's residential, commercial, and industrial energy growth. That is to say that the model will predict the wholesale energy growth in the future based ulpon EAl's residential, commercial and industrial energy forecasts and how wholesale energy has grown relative to residential, commercial, and industrial energy growth in the past.

0 Entergy Arkansas Incorporated has a contract for wholes#ale sales without reserves to Union Electric. The forecast is modeled as defined by the contract.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-17J Name of Company: ENTERGY ARKANSAS, INC. Time Period 2005 - 2006

FUTURE SALES, LOADS, & RESOURCES PER DOCKET NO. U-2897 - ELECTRIC UTILITIES - 5. Describe methodology used in forecasts in sufficient detail to allow replication by a third party.

Include graphs and formulae if appropriate.

Reference No. 3a-h

The next step in the forecasting process is the forecasting of customer loads by revenue class with Wholesale included in the EA1 system. EAl's current forecast was produced using ITRON's MetrixLT forecasting model.

PEAK DEMAND MODEL

The MetrixLT model is a traditional forecasting tool (An econometric sales forecast using historical load shapes and scenario-based weather patterns). MetrixLT requires specification of several parameters in order to produce a forecast. Key parameter assumptions are as follows:

Forecast input: KWh Sales(adjusted for co-generation losses) drawn from the 2005 Business Plan sales projections, plus wholesale and company use.

Load Shape Development: A load shape was developed using actual EA1 revenue class loads for 2002. The actual loads were adjusted to add back an assumed level of actual interruptible loads by an assumed level of actual interruptible loads for the industrial revenue class, i.e. to reflect an assumed load as If there were no interruptions. Actual 2002 ADT (average daily temperatures) from Little Rock Weather Station.

Weather input: Little Rock Weather Station - 10-Year Typical Weather (1 994-2003) Developed from 10 years of actual ADT (average daily temperatures).

MetrixLT produces results at the meter level. The meter level results are adjusted by Transmission and Distribution loss factors to produce results at the generation level.

REPORT TO ARKANSAS PUBLIC SERVICE COMMISSION -YEAR 2004 SUPP. E-17K Name of ComPany: ENTERGY ARKANSAS. INC. Time Period 2005 - 2006

FUTURE SALES, LOADS, & RESOURCES PER DOCKET NO. U-2897 - ELECTRIC UTILITIES -


Reference No. 3 a-h

Reference No. 4a i3 4c

4a: See Description for 3a-h

4c: Capability Margin is Determined by the Following Computations:

0 Total Capability = Owned Capability + Purchases w/o Reserves - Capacity Sales w/o Reserves - Sales from Reserves

0 Load Responsibility = System Peak Demand - Demanld Side Resources

0 Capability Margin = Total Capability - Load Responsibility


CHECK Ll!ST

COMPANY NAME ENTERGY ARKANSAS, INC.

Instructions: In the space provided, please enter the appropriate amounts from the Annual Report to the APSC and the FERC Form 1. Any differences should be fully explained. Any differences between ending figures from last year's annual report and beginning balances in this year's annual report should be fully explained.

Description I Total Electric Plant-in-Service

Beginning Balance

Ending Balance

Annual Report

Amount

$ 5,946,969,819

$ 6,123,239,209

FERC Form 1 Amount

$ 5,946,969,819

$ 6,123,239,209

Difference


STATEMENT OF ACCURACY

I do hereby state that the amounts contained in this report are true and accurate, schedules have been cross-referenced by use of the attached check list, and the accuracy of all totals has been verified by me or under my supervision. Should I or anyone under my supervision become aware of any error in or omission from this report, I will take steps to notify the Arkansas Public Service Commission of such error or omission and provide corrected schedules as soon as possible.

Senior Vice President & C,hief Accounting Officer

OFFICIAL MAILING ADDRESS

I

Engineering

Finance

lncome Taxes

Property Taxes

Gas Supply

Legal

Data Processing

P.O. BOX 551 LITTLE ROCK, ARKANSAS 72203

AREA

Annual Report

Fuel Adjustment Report

I I1

PERSON TO CONTACT PHONE NO. / Mr. Steven K. Strickland * Vice President, Regulaitory A€fairs 50 1-377-4457

Facsimile Number 501-377-4415

Cost of Debt Report

Tariffs

Accounting

Rates

Please list the number of utility employees located in Arkansas 1.494

* Initial contact for all areas.

name entergy arkansas, inc. · 2005. 5. 2. · dew orleans, la 701 13 intergy corporation i39...

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