and Others and Supplemental - APSC
319
THIS FlUNG IS 1 I . I I 1 I: An Initial {Original) OR 0 Resubmission No. - Su bmisdon Form 1 Approved OMB No.1902-0021 (Expires 12131)2014) Form 1 -F Approved OMB No.1902-0029 (Explres 12131L!014) Form 3-Q Approved OMB No.190243205 (Expires 05131l22014) FERC FINANCIAL REPORT FERC FORM No. I: Annual Report of Major Electric Utilities, Licensees and Others and Supplemental Form 3-Q: Quarterly Financial Report fhtsa regorb ma mandatory under the Federal Pwr Act, Sectlonr 3.4(a). 304 and 309. and 18 CFR f4f.l and 141 400. Fallure to report may result In crImlnal Rnas, chll peneMas end otlmrmandloni as pmuldad by law. The Fadera! Energy Regulatory Commbdon does not consuer these mpvrb to be of wnfidentlal nature I YearlFerlod of Report End of Exact Legal Name of Respondent (Company) Entergy Arkansas, Inc. I I f
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Transcript of and Others and Supplemental - APSC
THIS FlUNG IS 1 I . I
I 1 I: An Initial {Original) OR 0 Resubmission No. - Su bmisdon
Form 1 Approved OMB No.1902-0021 (Expires 12131)2014) Form 1 -F Approved OMB No.1902-0029 (Explres 12131L!014) Form 3-Q Approved OMB No.190243205 (Expires 05131l22014)
FERC FINANCIAL REPORT FERC FORM No. I : Annual Report of
Major Electric Utilities, Licensees and Others and Supplemental
Form 3-Q: Quarterly Financial Report
fhtsa regorb ma mandatory under the Federal P w r Act, Sectlonr 3.4(a). 304 and 309. and 18 CFR f4 f . l and 141 400. Fallure to report may result In crImlnal Rnas, chll peneMas end otlmrmandloni as pmuldad by law. The Fadera! Energy Regulatory Commbdon does not consuer these mpvrb to be of wnfidentlal nature
I
YearlFerlod of Report
End of
Exact Legal Name of Respondent (Company) Entergy Arkansas, Inc. I
I f
Deloitte.
INDEPENDENT AUDITORS' REPORT
Entergy A r b , Inc. Little Rock. Arkansas
We have audited the accompanying iinanciz. statements of Entergy Arkansas, Inc. (the "Companym), which comprise the balance sheet - regulatory basis as of December 3 1,2013, md the dated statements of income -regulatory basis, retained earnings - regulatory basis, and cash flows - regulatory basis fir the year then ended., included on pages 1 10 through 123 of the accompanying Federal Energy Regulatory Commission Form 1, and the related notes to the financia1 statements.
Management's Responsibility for the Flnanda? Statements
Management is responsible for the preparation and fair presentation of these financia1 statements in accordance with the accounting requirements of the Federal Energy Regulatory Commission BS set forth in its applicable Uniform System of Accounts and published accounting releases: this includes the design, implementation, and maintenance of internal control relewnt to the preparation and fair presentation of financial statements that are f K e from material misstatement, whether due to fraud or ermr.
Audfton' Responsibility
Our responsibility is to express ail opinion on thfie financial Statements based on our audit. We conducted our audit in accordance 14hauditing standards generally accepted in !he Unkd States ofAmerica. Those standards require that we plan and perform the audit to obtain reasonable assmce about whether the financial statements are free from material misstatement. *
An audit involves performing procedures to obtain audit evidence about the amounts and discloslues in the financial statements, The procedures seIected depend on the auditor's judgment, including the assessment of the risks of matcrial misstatemcnt of the financial statements, whether due to fmud or error. In making those risk assessments, the auditor considers internal control: relevant to the Company's preparation and fair presentation of the financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Campany's internal contro1. Accordingly, we express no such opinion. An audit a h includes evaluating the appropn'atencss of accounting policies used and the reasonableness of significant aecomting estimafes made by management, as well as evaluating the owralf presentation of the financial statements.
We believe that the audit evidence w have obtained is sufftcient and appropriate to provide a basis for our audit opinion.
Oplnlon
In our opinion, the regulatory-basis financial statements referred to above present fairly, in all material respects, the assets, liabilities, and proprietary capital of Entergy Arkansas, Inc. BS of December 3 1,20 13, and the results of its operations and its cash flaws for the year then ended in accordance with thc accounting requirements of the Federal Energy Regulatory Commission as se! forth in hs applicable Uniform System ofAccounts and published accolmting releases.
Basis of Aecoun ting
As discussed in Note B to the financial statements, these financial statements were prepared in accordance with the accounting requirements of the Federal Energy Regulatory Commission as xt forlh in its applicable Uniform System of Accounts and published accounting reIeases, which i s a h i s of accounting other than accounting principles gcnedy accepted in the United States of Amtrim Our opinion is not modified With respect to this matter.
This re- i s intended solely for the information and use of the board of directors and nwnagoncnt of the Company and for filing with the Federal Energy Regulatory Commission and i s not intended 10 k and should not k used by anyone other than these specified parties.
Febnnry 27.2014
1NSTRUCTlONS FOR FILING FERC FORM NOS. 4 and 3 4
GENERAL INFORMATION
I. Purpose
FERC Form No. 1 (FERC Form 1) Is an annual regulatory requirement for Major electdc utilities, Licensees and others (18 C.F.R. 5 141.1)# FERC Form No. 3-Q ( FERC Farm =)is a quarterfy regulatory requ1rementwMch supplemeoh €he annual financial repoFting requirement (18 C.F.R. 3 141 -400). These reports are designed to collect financial and operagonal Information from electric utilities, licensees and others subject to !he Jurisdiction of he Federal Energy Regulatory C o m m k s h These reports are also consldered to be non-confidential pubnc use forms.
11. Who Must SubmIt
Each Major electric utdity, licensee, or other, as classified in the Commission's Uniform System of Accounts Prescribed for Public Utdities and Licensees Subject To the Provisions of The Federal Power Act (1 8 C.F.R. Part 'I 011, must submit FERC Form 1 (18 C.F.R. 3 141.1), and FERC Form 3 U (18 C.F.R. 9 141.400).
exceeds one of the following: Note: Major means having, in each of the three previous calendar years, sales or transmission service that
(1) one mllion megawatt hours of total annual sales, (2) 1 W megawatt hours of annual sales for resale, (3) 500 megawatt hours of annual power exchanges delivered, or (4) 500 megawatbhours of annual wheeling for others (deliveries plus losses).
Ill. What and Where to Submlt
(a) Submit FERC Forms 1 and 3 4 eleclronicatly through the forms submission saftware. Retain one copy of each report for your files. Any electrontc submission must be created by using the forms submission s o k r e provided free by the Commisslon at its web site: http:lhnrww.ferc.qov/docs-filinalefomrs~f~~-~ lelecsubm-soft.asP. The softwre is used to submit the electronic filing to the Cammisslon via the Internet
(b) The Corporate Officer Cerfificalion must be submitted electronbliy as part of the FERC Forms 1 and 3 4 filings.
(c) Submit Immediately upon pubtication, by either @Filing or mail, two (2) copies to the Secretary of the Commission, the latest Annual Report to Stockholders. Unless eFtling the Annual Report to Stockholders, mail the stockholders report ta the Secretary of the Commission a t
Secretary Federal Energy Regulatory Commission . 888 First Street, NE Washington, OC 20426
I 4 applicable to filers classified as Class C or Class 0 prior to January 1,1984). The CPA Certification Statement cart be either eFiled or mailed to the Secretary of the Cammlsdon at the address above.
For the CPA Certrfication Statement, submit withln 30 days after filing the FERC Farm I , a letter of report (not
FERC FORM 1 3-9 (ED. 03-07] f
The CPA Certification Statement should:
a) ALtest to the conformity, In at1 material aspects, of the below listed (schedules and pages] with the Commission's appkable Uniform System of Accounts (including applicable notes relating thereto and the Chief Acmuntan~s published accounting releases), and
b) Be signed by independent certified public accountants or an independent licensed public accountant certtfied or licensed by a regulatory authority of a State or other political subdivislon of the U. S. (See 18 C.F,R. 55 41 .IC41.12 for specific qualifications.)
Reference Schedules Pases
Comparative Balance Sheet 110-113 Statement of income 114-117 Statement of R e b i n d Earnings 118-119 Statement of Cash Flows 120-121 Notes to Financial Statements 122-1 23
e} The fotlowing format must be used for the CPA Certification Statement unless unusual circumstances or conditions, explained In the letter or report, demand that it be varied. Insert parenthetical phrases onfy when exceptions are reported.
'In connection with our regular examination of the financiat statements of for the year ended on which we have reported separately under date of
conformity In all material respects with the requirements of the Federal Energy Regulatov Commlsslon as set forth in its applicable Uniform System of Accounts and published accounting releases. Our review for thIs purpose Included such tests of the accounting records and such other auditing procedures as we considered necessary In the circumstances.
, we have also reviewed schedules of FERC Form No. 1 for the year filed with the Federal Energy Regulatory Cornrnlsslan, far
Based on our review, In our oplnlon the accompanying schedules Identified in the preceding paragraph (except as noted below) conform In a11 materfal respects with the accounting requlremsnts of the Federa! Energy Regulatory Commission as set forth in Its applicable Uniform System of Accounts and published accounting releases.'
The letter or report must slate which, if any, of the pages above do not conform to the Cornmisston's requirements, +Describe the discrepancies that exist.
(0 Riers are encouraged to file their Annual Report to Stockholders, and the CPA Certification Statement oslng efifing. To further that effort, new selections, 'Annual Report to StockhoJdea,' and "CPA Certmcation Staternenr have been added to the dropdown "plck lisr from whlch companies must choose when eFillng. Further lnstmctions are found on the Cornmlsslon's website at http:/lwww,ferc.dovlhefplhow-to.asp.
(91 FERC Form I and 3-Q free of charge from http:l~.ferc.savIdocs-fiIincrlefom7sIform-.l .pdf and http:l~.ferc.qo~~dfdocs-filinqleforms.asp#JQ-sas .
Federal, State and Local Governments and other authorlred users may obtaln additional blank copies or
IV. When to Subrnlt
FERC Forms 1 and 3-Q must be filed by the follmhg schedule:
FERC FORM 1 t 3 4 (ED. 03-07) I1
a) FERC Form I for each year ending December 31 must be filed by April 1 8fh of the foltowlng year (18 CFR 5 141.1), and
b) FERC Form 3-Q for each calendar quarter must be filed within 60 days after the reporting quarter (18 C.F.R. 3 141.400).
V. Where to Send Comments on PublIc Reportlng Burden.
The public repoFting burden for the FERC Form 1 collection of Information Is estimated to average 1,144 hours per response, including the fime for reviewing Instructions, searching existing data sources, gathering and rnarntainhg the data-needed, and completing and revlewing the cotlection of Information. The public reporting burden for the FERC Form 3-P collection of Infomation Is estimated to average 150 houm per response.
Send comments regarding these burden estimates or any aspect of these cotlecUons of Information, Including suggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 first Street NE, Washington, DC 20426 (AttenGon: Information Clearance Officer); and ta the Office of information and Regulatory Affafrs, Office of Management and Budget, Washington, DC 20503 (Attention: Desk Officer for the Federal Energy Regulatory Commlsslon). No person shall be subject to any penalty If any collection of information dces not display a valid control number (44 U.S.C. 5 3512 (a)).
I
FERC FORM d C 3-Q (ED. 03-07)
GENERAL INSTRUCTIONS
I. all accounting words and phrases In accordance with the USofA.
Prepare this report In conformity with the Uniform System of Accaunb (18 CFR Part 101) (USofA). Interpret
II. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages and figures per unit where cents are important The truncating of cents Is allowed except on the four basic financial statements where roundlng Is required.) The amounts shown on all supporthg pages must agree with the amounts entered on the statements that they support When applying thresholds to determine significance for reporkg purposes, use for balance sheet accounts h e balances at €he end of the current reporting period, and use for sta!ement of income accounts the current year's year to date amounts.
Ill word "None* where it truly and completely states the fact
Complete each question fully and accurately, even If it has been answered In a prevlous report Enter the
IV. Applicable" In column (d) on the Ust of Schedules, pages 2 and 3.
For any page@) that is not applicable to the respondent, omit the page@) and enter 'HA,'' "NONE," or "Not
V. Enter the month, day, and year for alf dates: Use customary abbrevhtions. The "Date of Report" Included In the header of each page Is to be completed onIy for resubmlsdons {see Vtl. below).
VI. Generally, except for certain schedules, all numbers, whether they are expected to be debits or credits, must be reported as positive. Numbers having a sign that 1s different from the expected sign must be reported by enclosing the numbers in parentheses.
VI I the reason for he resubmission in a footnote to the data field.
For any resubmisstons, submit the electronic filing uBng the form submisston software only. Please explain
Vl11. except as specifically authorized.
Do not make references to reports of previous periodslyears or to other reports in Iieu of required entries,
IX, upon-those shown by the report of the previous periodfyear, or an appropriate explanation given as to why the different figures were used.
Wherever (schedule) pages refer to figures from a previous pen'odryear, the figures reported must be based
Definitions for statistical classkations used for completing schedules for transmission system reporting are as follows:
FNS - Ffm Network Transmlsslon Senrice for Self. "Firm" means service that can not be intempted for economic reasons and is intended to remain reliable even under adverse conditions. "Network Service" Is Netmrk Transmisslon Sewice as described In Order No. 888 and the Open Access Transmission Tariff. "Self" means the respondent.
FNO - Firm Network Service for Oulers. "Firm" means that sewice cannot be Intempted for economic reasons and Is Intended to remain rellable even under adverse conditions. "Network Service" 1s Network Transmisslon Sewice as described In Order No. 888 and the Open Access Transmission Tariff.
LFP - for Long-Term Firm Point-to-Poht Transmission Resewations. "Long-Tern" means m e year or longer and" fim" means that service cannot be intempted for economic reasons and Is Intended to remain reliable even under adverse conditions. "Point-to-Point Transmission Resewations" ?re described in Order No. 838 and the Open Access Transmission Tariff. For a
terminatjon date of the contract defined as the earllest date either buyer or seller can unilaterally cancel the contract.
OLF - Other Long-Tern Firm Transmkskn Servlce. Report sewlce provlded under contracts whIch do not conform to the terms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and 'firm" means that senrlce cannot be Intempfed for economic reasons and Is Intended to remain reliable even under adverse conditions. For all transactions Identified as OLF, provide lo a footnote the termination date of the contract defined as the earliest date either buyer or selJer can unilatera!ly get out of the contract
SFP - Short-Tern Firm Point-tc-Point Transmission Resewations. Use this classification for a
EXCERPTS FROM THE lAW
Federat Power Acl, 16 U.S.C. 5 791a425r
Sec. 3. The words defined in this section shall have the following meanings for purposes of this Act, to with:
(3) 'Corporation' means any corporation, joint-stock company, partnership, association, business trust, organizd group of persons, whether Incorporated or not, OF a receiver or receivers, trustee or trustees of any of the foregoing. It shall not include 'municipalities, as hereinafter defined;
(4) 'Person' means an individual or a corporation;
(5) 'Llcensee, means any person, State, or municipalify Licensed under the provisions of section 4 of this Act,
(7) 'munlcipality means a city, county, Irrigation district, drainage district, or other political subdivision or
and any assignee or successor in Interest thereof;
agency of a Slate competent under the Laws thereof to carry and the buslness of developing, bnsrnithng, unihzing, or distributing power; .-..,.
(11) "projecf means. a complete unit of improvement or development, consisting of a power house, all water conduits, all dams and appurtenant works and stntctures (including navlgation structures) which are a part of said unit, and all storage, diverting, or fore bay reservoirs directly connected therewith, the pdrnary line or lines transmitting power there from to the point of junction with the distribution system or with the interconnected primary transmission system, all miscellaneous structures used and useful In connection with said unit or any part thereof, and all water tights, rights-of-way, ditches, dams, reservoirs, Lands, or Interest In Lands the use and occupancy af which are necessary OF appropriate In ihe maintenance and operation of such unit;
"Sec. 4. The Commlssion 1s hereby authorized and empowered
(a) To make Investigations and to cokct and record data concerning the utrtization of the water 'resources of any region to be developed, the water-power industry and its relation to other fndustn'es and to fnferstate or foreign commerce, and concerning the tocation, capacity, development -costs, and relation to markets of power sites; ... to the extent he Commission may deem necessary or useful for the purposes of this Act"
"Sec. 304. (a) Every Licensee and every public utility shall file with the Commission such annual and other periodic or special' reports as the Commission may be rules and regulations or other prescribe a5 necessary or appropriate to asslst the Commission In the -proper administdon of this Act. The Commlssion may prescribe the manner and FERC Form in which such reports salt be made, and require from such persons specific answers to all questions upon which the Commission may need information. The Commission may require that such reports shalt include, among other things, full Information as to assets and Liabilities, capitalization, net Investment, and reduction thereof, gross receipts, interest due and paid, depreciation, and other rdserves, cost of project and other facitities, cost af maintenance and operation of the project and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation, generation, fransmlsslon, distribution, delivery, use, and sale of electric energy. The Cornmissbn may require any such person to make adequate provision for currently determining such costs and other facts. Such reports shall be made under oath unless the Commission othedse specifies*.lO
FERC FORM 1 t 3-Q (ED, 03-07] VI
"Sec. 309. The Commission shall have power to perfom any and all acts, and to prescribe, issue, make, and resdnd such orders, rules and regulations as it may find necessary or appropriate to carry out the provisions of this Act Among other things, such rules and regulations may define accounting, technicat, and trade terms used In this Act; and may prescribe the FERC Form or FERC Forms of all statements, declarations, applications, and reports to b? filed with the Commission, the information which they shall contain, and the time within which they shalt be field ..."
General Penalilles
T h e Commission may assess up to $1 million per day per violation of its rules and regulations. See FPA 9 3 16(a) (2005),16 U.S.C. 9 825o(a).
FERC FORM 1 & 3-Q (ED. 03-07) V I
,
BLANK PAGE
I Exact Legal Name of Respondent Enkergy Arkansas, Inc.
02 YearlPeriod of Report End of 201 31Q4
ANNUAL CORPOWTE OFFICER CERTlFICATlON he undersigned officer c8tlmes that
have axamlned this report and to the best of my knowledge, lnfnrmatron, and belief all statements of fad confatned In this teport BIB correct stalemanis I the buslness afhln of lhe respondent and tha finandat statements. and other financial inronnatlon wntalned In this =port, conform In all mtedal !spects to be Uniform System of Accounts.
5 Name of Contact Person GIna G. Belott
06 Xitle of Contact Person Sr. Lead Accountant
FERC FORM No-4I3-0 fREV. 0 2 - M Pam I
I8 Telephone of Contact Person,lncluding 09 ThIs Report Is h a Coda (I) An Original (2) A Resubmissjon
(504) 5764753
i 0 Date of Report WQ* Da, w I t
D l Name 03 S~gnatum
02 TNs Alyson M. Mount
Sr.W & Chlef Accounting ORicar Afyson M. Maunt
04 Date Slggned (Mu, Da, Vi)
04117t2014
L
23
24
25
26
27
28
29
30
31
32
33
I 12
-
Anowan& 228(ab).229(ab)
Exlraordlnary Properly Lesscs 230
Unremwred Plant end Regulltory S l d y Cosb . 230
Tramrnkdon Sswlcs m d Garwrtron Intarconncdon Study Costs
Other Regulatnrykseb 232
Miscellaneous D e k d h b r b 233
Accumulated Detemd l n m s Taxes 234 CapitalStock 250-251
W a r Pakf-in Capdat 253
231
t
Capita1 Stock Expense 254
Lonu-Term Debt 256.257
__ - Comparative Babnos Sheti 110-113
Slatemsd of In- hrm Year 11 4-1 17
Staleman1 of Rctlhed EimL.7pl tor the Year 1 18-1 19
Statemnt of Cash FI4rJ 120-121
Notes to Rorndd 5tatwnmtl 122-123
35
36
I 17
Taxes Accrued, PrepaM and Charged During the Year 262-263 1 Atcumulated Deterred Inveahent Tax Cradits 266-2S7
Nuckar Fuet Maledab 202-203
Ekctrlc Plant In Swb 204-207
Efedde Flant b a w d b Mh.n 2t3 NA
I 2t8 I I 1
20 1 Acurmulaltd Pmvhh br bmmcrrflon el Ekcttlc WItv Plant t 2t9 I I
227 * I
I 39 I RawnJliaUoon of RenMled Net Income with Taxable Inc lor Fed tncTax I 261
I NA ' 1 NA I NA I
I
FERC FORM NU. 1 [ED. 12-961 Pam 2
UdLU UL ncpu1r (Mo, Da, Yr)
TtB Trtte el Schedule lo.
37 Ottrsr Oefarmd Credits (a)
I 1
LIST O f SCHEDULES ( H e c k UbLty) (contwued)
Refemnw Rema- Page No.
269 @I (4
iter In column (c) the terms 'none," 'not applbble," or "Nv as appmpriate, where no information or amounls have been repoded for !rtain pages. Omit pages where the respondents are 'none," 'not appficable," or"A*.
39
40
41
Acwrnulaled Deterred IncarnaTaxes-r Property 274.215
Ammulated Deferred lnecrme Taxes9thw 276-277
Other Regulatory Uabllilles 278
46 I ElacErk OperaUon and Mafntenanm Expenses I
44 I Salas of Electrluty by Rats Schedules I
47 I Purchased Power I . .
49 Tmnsmbslon of EIacMclty by ISOIRTLb
50 TransmIsshn of Eleetrldty by Qlhen
I
51
52
53
54
55
58
!i7
58
59
60
81
62
63
. .
Mlsdlaneovs General Expenses-EIectrk
DeprechtIon and Amortbatlon Of Elecb.le Plant
Regulatory Commhsbn Expenses Research, DevaQpmant and Demonstration AcMles
DutnbutIon of Salahs and Wages
Common Utility Plant and Expenses Amounb Included In ISOIRTO Settlement Statemenb
Purchase and Sale o?Ane)llary Servlas
Monthly Tranrrnisrlun System Peak Luad Monthly ISORTO Transmlssbn Syskrn Peak Load Ebdrle Energy Amunt
Monihty & a b and Output
Sleam Ekddc GeneraUng Rant Stabstiu
-
.-
338337 35IM5t
352-353
354.355 .
35s 397
398
400
400a
401
401
402403
64 Hydroelaetrte Gsnsratlng Plant StaUstles
65 P m ~ a d Stoma Gantratlnn Plant Statlstiu
NA
NA
66 I Generating Plant Statlatks Pages
3l0-301
302
3w 31 031 1
320323 326-327
328.330
331 I w 1 332 1 1 335 1 1
FERC FORM NO. 1 ED. 12-96) Pacts 3
UBm OTMWpOII i n m n w i a (1) fJAn Ofiglnal (Mo, Da, Ur) maitru UI n m p w i l u o r i b
(2) n A RasubrnIssIon I 1 Entergy Arkansas, I n c
eerfain pages. OmIt pages where the respondknts are 'none: "not applicable," or "A". I
marimrma or n e w
End of 20tm4
Trtte of Schedule
~ubstabtons
rraniactloni with Asswbted (Aptilialed) Companbs ~ _ _ _ _
%atnote Data
Stockholders' Reports Check approprfate box fl Two ap ler will ba aubmttted
No snnuat report to stodrhoklea tS prepared
Referam Page No.
01 422-423
424425
428-427
429
450
Remarks
(4
NA
Paam 4
Name of Respondent Entergy Arkansas, [ne. I This Report Is:
(I) AnOriglnal (2) AResubmission
Dke of Report IMO, 03, YO
YearPericd of Report
I t End of 2013M4
GENERAL INFORMATION 1. Frovlde name and title of officer having custody of the general corporate books of account and address of
office where the genera1 corporate books are kept, and address of office where any h e r curporate books of account are kept, I f different from that where the general corporate books are kept
slyson n. nomat Banior V i m Prmd.dent and Chief Accaunting O f i i w r
639 Loyol& Avenue Hnw Drlaan8, LouLmiana 7Uf13
2. Provide the name of the State under the laws of which respandent Is Incorporated, and date of Incorporation. If Incorporated under a special taw, give reference to such law. If not Incorporated, state that fact and give tho type of organizafion and the date organized.
3. If at any time during the year the propem of respondent was held by a receiver or frustee, give {a) name of receher or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possesslon by receiver or ttustee ceased.
NO-
4. State the dasses or utility and other services furnished by respondent during the year in each State in which the respondent operated.
Wkanma - Zloetrfa U t i l i t y SmEYIca a N 8 Q U X i - f h C k h uttli* 8 O D d e S
Tonno..** - mnctrio U t i l i t y B o d e .
5. Have you engaged as the principat accountant to audit your finandal statements an accountant who Is not the principal accountant for your previous year's certified finandal statements?
(1) Yes ... Enter the date when such Independent accountant was initially engaged: (2) Bl No
t
FERC FORM IJo.1 {EO. 12-87) PAGE 401
-
lame of Respondent htergy Arkansas, Inc.
This Report Is: (1) An Original (2) 13 AResubmissIon
Date of Report (Mo, Da, Yij
Yearperiod of Report
2013M4 I / End of - - _ _ .~ ~-~ .
CONTROL OVER RESPONDENT 1. If any corporalion, bufness trust, or similar organkatim or a wmbllnation of such organkatloos jointfy held
mnbl over the repondent at the end of he year, state name ol contrdlitw corporation or organbtlon, manner In - - Hhich control washeld, and extent of montroj. If eontrot was fn a holding company wgan'aagon, show the chain 3f wlmershlp or control to the rnaln parent company of organiratlon. If wntml was held by a bstee(s), state lame of tnrslee(s), name of benefidary orbeneficieades far whom trust was mafntahed, and purpose of tbe trust
9s of December 31,2013, Entergy Corporation owned 46,980,198 shares of the Respondent's wrnrnon stock whlch represented 100% of !he votlng rights.
.
IUdonn System of Acwuni, regardless of the relalivs voting rig& of each party.
1 I I . I I
CORPORATIONS CONTR6LLEO BY RESPONDENT
1. Report below the names of all wrporations, business trusts, and slmllar organkations, controlled dlredly or Indirectly by respondent at any time durIng tha year. If control ceased prior lo end of year, give partlwlan (details} In a faotnots, 2. If wntrol was by other means than a direct holding of voting rights, stde In a fmtnote the manner In which control was held, namhg any intermedlades Involved. 3. If control was held JoinUywith one or more other Interests, state he fact In a fmtnote and name !he otherhnterests.
Name of Company Controlled
, (4
Entergy Arkansas Reloratton Funding. U C
Tansmlssbn Company Arkansas, U C
Syrtem Fualr, he.
1
5
6
Kmd of Business Parwnt Voling stock owned
@I
100%
100%
I 7 1 I I I
. . . ._ . . . . -. . . . . . . . .
i 251 I I I
Footnote Rat (dl
I * W l f I u 01 nsynnwllr 1 Entergy Arkansas, Inc. .. I OFFICERS
I. Report below h e name, titte and salary for each exeartie offier whose salary is.$50,000 or more. An 'exewtive oRcer" of a respondent includes Its president, sewelary, treasurer, and vice president In charge of a prindpal business unit, dMslon or function {such as sales, admInIstratton OF finance), and any other person who performs similar policy making functions, 2. If a change was made during the year In the incumbent of any position, show name and tofa! remuneration of the prevbus incumbent, snd he dale the d m g e In Incumbency was made.
Lne 1 itle Name of Officer 2 : a e r
NO, (a) (bl {C)
I Pmilddent and Chtef Executive Officer 2 of Entergy Arkansas, he. Hugh T. McDonald 342.79
3
IO 11
Chlef Ereculrve Mficerand Chslrman of the Board of Entem Corporation (1) J. Wayne Leonard
CUef Ezecuhe MAcer and Chabman of the Board t of Entergy Corporation (3) Leo P. Denauk
I
14 of Entergy Corporatrm (3) Andmw S. Man h 15 16 Sr.W and ChleIAecDuntlng Officer d Entergy COT. Alyson M. Mount
17
I
I .-
I I
23 24 25 26 27 2a
EXEC. VP and Genera1 Counsel of Entargy Cow. I Maws V. Brawn I a 1
Group PmMant Wlrty Opmtlons of Entergy Carp.
Exec VP and Chief Nuclear mer ot Entergy Carp. (4}
ExecVP and Chlef Nuclear Oftier of Entergy Cop. (5)
Thacdora H. Buntmg. Jr.
John T. Hermn
Jetltey S, Forbes
Execuhe VP - Human Rasources and Admbistrabon of Entergy Curpocatlon [6} E Renas Conley
Sr. VP- Human Resources and Chiel Dnrenrty OffimrolEntergy Corparabnn (7) Donald W. Wncl
Executive VP B Chlel Adrnlnklrative MIicer of Entergy Corporatton Rodedck K. West
(11 mbmd January 2013
(2) ceased January 2013 (3) etaeted Fehary2013 I(4) restgned January 201 3 I(5) eladed January 201 3 (6) retrred September 2013 g) elected Saplember2013
Officen whose salaries BE! not
presented WBCB mmpensaled by other System companDes and not by Entergy Arkansas, tne.
- I
48
Does the respondent file wilh the hmrrJsslon annvaI (or mom frequent) Rllngs contahhg Ute Inputs to ma tomula fate{s)?
FERC FORM NO. 1 I F I N . 12481
Yes
IJ
Paam t06a
INFORMATION OH FORMULARATES Fonnula Rala Vadanees
17 18 19 20 21
I. If a respond& does not submd such 611ngs than Indbte in a footnote to the appllable Fom 1 schedule whem formula rate Inpub drfler from
2. Tha bohda should provide 8 narrative desetiptlon explalnlng how the 'ratd (or haling) was d e h d Fdillerent fmm the reported amount In the
3. The fmtnofa should explain amounts excluded from the ratebas8 orwhere labor or other alfocaffon facton, operakg expensas, or other Rems
1. Where the ComIsslon has prodded guldance on tmu la rate inputs. the speMc pmceedlng should be noted In the footnote.
amounts reported in tha Form 1.
Form 1.
tnpadlng formula rate Inpub dlffer fmm amounts reported In Form 1 sehedula amounb.
227 Matedals and Suppiles (el 1,2 227 Maledab and Supptres IC) 12.16 234 Accumlated Deferred Inmma Taxes (Account 190) (el 2 262 Taxes Aeuued, Prepaid and Charged During Year [d) 17.18 262 Taxes &Wed. Prepald and Charged Durlng Year la] 17.18
Line Nu. Page No(s). Schedute Column h e No
1 i l l Comparative Balance Sheet
22 23 24 25 26 27
4 118 Statement ot Retatned Eamlngs (4 29 5 f i e Statement of Retaroed Eamlngs (dl 29 6 118 Stalmment of Relalned Earnings (dl 36 7 110 Statement of Relalned Eamlnrrs I
262 1 Taxes A m W , Prepald and Chargad Durlng Year t (d) 18 262 Taxas Accnred. Prepald and Charged Durlng Year td) 17 262 Taxes Acwed. FrepaH and Charged Durlng Year td) 2,9 262 266 Accumulated Dehrred Inveshnenf Tax C r e d k Ir) 8 275 Ammulated Deferred lnmme Taxes (Aewunt282) (k) 2
Taxes Accnrod. Prepald and Charged Dunng Year (d) 3,4 10
91 204.206 1 EbctrIc Plant In Service I ~b)~E14,18-24,27-34,3743 I land 50
28
29 30
m I Accumulated Dehrred Income Taxes (Atmunt283) 1 (k) 3 320 I Ek~lrtc Operations and Malnlenanw IC) 4, E-tl, 1519 320-321 I UeetdcOperations and Mamlenanca ExDanse . I . Ib) 5.25.63
33 IseS6, and 69-72
35 321 Elech~e Operations and Marnlenanee Expwnsa (C)193,107 34 321 EkELrlc Operatlorn and Malntenanca Expense t C ~ ~ l l 2
35 323 Ekctnc Oparabons end Mamlenance Erpense I [c] 1101 4 93 37 323 Uadrle Operations and Mahienan- Expense tc1hB.l-184 and 188193
381 323 I Eledrlc Operabons and Mahtenance Ejrpensa I (c)lras 391 323 1 Electric OPeratlons and Malntenance Expense (e) 1 f 85
931 338 J OapreclaUon Expense I (9110 441 402403 1 SteamElectnc Generating Plant lnstnrctlons All 15
Une
1 2
No. Page No(s). Schedule Footnotes explalnlng the differences are attached
1 I 51
Column b e No
0 I 7 8
42 I 43
44
. .
Name OF Respondent
Entetgy Alkansas, Inc
3 Paqe: 10
Page No 1s). 111
117
I17
This Report is: (1 X An Original (Mot Yrl (2) - A Resubmission I 1
Date of Report
20WQ4
-1 Une No.: 3 Column: b
Schedule
Comparative Balance Sheet Prepayments used In 4th Rev. Rs No. 94, Service Schedule MSS-4, differs from Form 1 amounts because the formula rate reflects an allocation of the balance at: the last day of t h e previous month, allocated using plant ratios Statament of Income for the Y e a r Interest expense used in 4th Rev. RS No. 9 4 , Sexwice Schedules MSS-I and MSS-3, differs f r o m Form 1 amounts because the formula rate reflects the embedded cost of debt a t December 31 of the previous year times the Debt Capitalization ratio a t December 31 of t h e previous year Stmtmment o f Income for the Year Interest expense used in 4th Rev. Rs No. 94, Service Schedule MSS-4, dif fers from Form 1 amounts because the formula rate reflects the embedded cost of debt at the last day of the previous month t imes the Debt Capitalization .ratio at the l a s t day of the previous month Stlrtmaont of Rmtafned Earnings Return on Preferred Stock used in 4th REV. RS No. 94, Service Sehcdules HSS-1 and MSS-2, differs from Form 1 amounts because the formula rate calculates Return on Preferred Stock using the embedded cost of Preferred Stock at December 31 of the previous year times t h e Preferred Stock Capitalization r a t i o at December 31 of the previous year S t a t e m e n t o f Retained E a d n g s Return on Preferred Stock used in 4th Rev. RS No. 94, Service Schedule MSS-4, d i f f e r s from Form 1 amounts because the formula rate calculate Return on Preferred Stock using the embedded cost of Preferred Stock at the last day of the previous month times the Preferred Stock Capitalization ratio at the last day of the previous month Statement of Retained Earnings
fD. q2-871
Page 106 Footnote.1
Line No 57
70
7 0
29
29
36
Responder
hansas. Inc
118
204, 206
204 I 206
206
204, 206
ORM NU.
1 This Report is: (11 XAi Origin; I 121 A Resubr
~
FOOI%OTE DATA
leturn on Common Equity used in EES lo. 94, Service Schedules MSS-1 and ISS-2 , differs from Form 1 amounts >@cause the formula rata calculates 7eturn on Common Equity using a stated Return on Equity of 11.0 3ercent t i m e s t h e Common Stock h p i t a l f z a t i o n ratio at December 31 >€ the previous year 3tatmment: of Retained Earnings Teeturn on Common Equity used in 4th xev. RS No, 94, Service Schedules 4SS-4, differs from Form 1 amounts- 3ecatlse the formula rate calculates Teeturn on Common Equity using a stated Return on Equity of 11.0 *
sercent times the Common Stock Zadtal izat ion r a t io at the last Jay of t h e previous year 2lectric Plant in Semice Plant investment used in 4th Rev, E- No. 94, Service Schedules MSS-1, differs from ??om 1 amaunts because the formula rate only reflects the cost of intermediate gas and oil units, plus the cost of step-up transformers and associated transmission equipment related to the intermediate gas and oil units, less the proportionate share of RDIT In Account 282 E1.ectzj.c Plant zn ServjLco Plant investment used in 4th Rev. RS No. 94, Service Schedules MSS-4, differs from Form 1 amounts because the formula rate anly reflects the cost: of the Designated Generating Unit, plus t h e cost of step-up transformers and associated transmission equipment related to the Designated Generating Unit, at the last day of the previous month E l e c t r i c P l a n t i n S e n i c e Plant: investment used in 4th Rev. RS No. 94, Service Schedule MSS-2, differs from Form I amounts because the formula rate only reflects Inter-Transmission Investment (i.i=.
(1) the cost of transmission lines operated at 115 kV-and above that connect to another company's transmission system, (2 ) a l l other lines operated at 230 kV and above, and (3) certain substation equipment) E l e c t r i c P l a n t in Service Plant investment used I n 4th Rev. RS No. 94, Service Schedule MSS-4,
ED. 124471
ite of Report Mo, Da, Yr)
I I
36
8-14, 50
8-14, 18-24, 27-34, 37-43 and 50
48-57
4 , 86-95
d
Page 106 FooinoteP
Name L
Enfergy
L3
f Responder3 I Arkansas. Inc
- 20 6
I
' 219
219
&ffers from Form 1 amounts because the formula rate reflects an allocation of Misc. Intangible and General Plant investment: at the last day of the previous month using a Labor Ratio E l e c t r i c P l a n t in Service Plant investment used in 4th Rev. RS No. 94, Service Schedule MSS-4, differs from Form 1 amounts because the fonnula rate includes a direct assignment of the cost of any coal mining equipment associated with the Designated Generating Unit at
I I Depredation (nArmn) APD used fn 4th Rev. RS No. 94, I Service Schedule MSS-1, differs
i from Form 1 amounts because t h e , formula rate only reflects the APD 'related to t h e intermediate gas and o i l Units, plus the APD related to
' t h e step-up transformers and associated transmission equipment related to the intermediate gas and 011 units Aceumulated Proviaion f o r Depreciation APD used in 4th R e v . RS No. 9 4 , Service Schedule MSS-2, differs from Form 1 amounts because the
, formula rate only reflects the APD ~ related to the Inter-Transmission ! Investment Accumulated Provirion for Depreciation APD used in 4th Rev. RS' No. 94, Service Schedule MSS-4, dif fers from Form 1 amounts because the formula rate only reflects the APD related to t h e Designated Generating Unit at the last day of t h e previous month Materiala and Supplies Costs used i n 4th Rev. RS No. 94, Service Schedule MSS-4, d i f f er from Form 1 amounts because the formula ,rate only reflects the Fuel 'Inventory related t o t h e Designated Generating Unit at the last day of
1 1 the Last day of t h e previous month 1 L4 1219 1 Accumulated Provision for I (bl'
FERC tORM NO. 1
15
L6
(ED. 12-87) 1
L7 227
. .
Ibl
tbl
I I t h e previous month I 18 1227 1 Materials and Supplies I (d
Costs used in 4th Rev. RS No. 94# Service Schedule MSS-I# dif fer from Form 1 amounts because the formula rate only reflects the Materials and Supplies related to t h e
ite of ReDort Mo, Da, Yr}
I 1
97
1
1
1
1-2
12, 16
Page 106 Footnote.3
I
3
r
5
ERG
iesponder
kansas, Inc.
!34
!62
262
2 62
262
2 62
2 62
3RM NO.
IFhls Report Is: ! (1 y Ar; Origin; (2) - A Resubn
FOOTNOTE DATA
3esignated Generating Unit at: the Last day of the previous month 4ceeumulated De€ezred Income raxes {Account 190) Zests used in 4th Rev. 8s No. 9 4 , Service Schedule MSS-4, differ from Form 1 amounts because the formula r a t e either directly assigns any \DIT related to the Designated Senerating Unit or allocates ADIT msed on a Plant Ratio raxea Accrued, PrapaLd and Charged During Year Costs used in 4th Ret. RS No, 94,’ Service Schedule MSS-1, differ from Form I amounts because the formula rate only reflects the corporate franchise and ad valorem taxes related to the intermediate gas and o i l units laxea Accrued, Prepaid and Charged During Y e a r Costs used in 4th Rev. RS No. 94, Service Schedule MSS-2, differ from Form 1 amounts because the formula rate only reflects the corporate franchise and ad valorem taxes xelated to t h e Inter-Transmission Investment Taxes Accrued, Prepaid and Charged During Year Costs used in 4th Rev. RS No. 94, Service Schedule MSS-4, differ from Form 1 amounts because the formula rate allocates Corporate Franchise Taxes based on a Plant: Ratio T a x e s Accrued, Prepaid and Charged During Year C o s t s used in 4th Rev. RS No. 948 Service SchedukMSS-4, differ from Form 1 amounts because t h e formula rate only reflects t h e ad valorem t a x e s related to t h e Designated Generating Unit Taxes Accrued, Prepaid and Charged During Year Costs used in 4th Rev. RS No. 94, Service Schedules MSS-1, MSS-2 and MSS-48 differ from Form 1 amounts because the formula rates calculate State and Federal income taxes using the incremental statutory rate T a x e s Accrued, Prapaid and Charged D u r i n g Year Costs used in 4th Rev. RS No. 94, Service Schedule MSS-4, differ from Form 1 amounts because the formula ED. 12-87)
slon I te of Report bto, Da, Yr)
I t
?
17, l a
17, 18
18
17
2, 9
3 , 4 , 10
‘earlPerjod of Report
2013Q4
Page 106 Footnote.4 - - _
Responde1
&ansa$, Inc.
266
275
277
320
320-321
DRM NO.
This Report 1s: (1) X An Origin (2) - A Resubi
FOOTNOTE DATA
rate allocates Payroll Taxes based
Accumulated Deferred Xnvestment Icax Credits Costs used In 4th Rev. RS No. 44, Service Schedule MSS-4, differ from Form 1. amounts because the formula r a t e either direct ly assigns any ITC Amortization related to t he Designated Generating Unit or allocates ITC Amortization based on a Plant Ratio Accumulated Deferred Income Taxes (Account 2B2) Costs used in 4th Rev. RS NO. 9 4 r Service Schedule MSS-4, differ from Form 1 amounts because the formula rate either directly assigns any ADIT related to the Designated Generating Unit or allocates ADIT based on a Plant Ratio A c m u l a t e d De€erred Income Taxes (Account 263) Costs u s e d i n 4th Rev. RS No. 94, Service Schedule MSS-4, differ from Form 1 amounts because t h e formula rate either directly assigns any ADIT related to t h e Designated Generating Unit or allocates ADIT based on a Plant Ratio
a Labor Ratio
E l e c k r i e Operakions and Maintsnance Expense Costs used in 4th Rev . RS No, 94, Service Schedule MSS-1, d i f f e r from Form 1 amounts because the formula rate only reflects the Production 06;M Expenses related to intermediate uas and oil u n i t s E l e c t r i c Operations and Maintenance Expense Coats used in 4th Rev. RS No. 9 4 # Service Schedule MSS-3, Paragraphs 30.02 through 30.10, differ from Form 1 amounts because the formula rate: (1) assigns the cost of fuel and purchased power on an hourly basis; (2) develops the cost of fuel for each generating unit by multiplying the average BTWkWh for the previous year times the current estimated coat of fuel per BTUr and (3) includes an adder that is based on: (a) the System cost of fixed Production OhM expenses for the previous 3 years divided by the System net steam generation for those three yearst (b) incremental replacement SO2 costs for each
ED. 12-87)
ite of Report Mo, Da, Yr)
I t
B
2
3
4 , 6-111 15-19
5, 25, 63
Page 106 Footnofe.5 - -
Respond e i
irkansas, Inc.
320-321
321
321
323
323
323
323
ORM NO.
This Report Is: (I) XAn Origtn (2) .AResubi
FOOTNOTE DATA
generating unit, adjusted weekly, and ( c ) incremental replacement NOx costs f o r each generating u n i t , adjusted weekly. Elacbic Operations and Maintenance Expense Costs used in 4th Rev. RS No. 94, Service Schedule MSS-4, differ from Form 1 amounts because the formula rate only reflects the non-fuel Production OhM Expenses related to the Designated Generating Unit
Electric Operations and Maintenance Expenee Costs used in 4th Rev. RS No.- 94, Service Schedule MSS-2, dif fer front Form 1 amounts because the formula rate only reflects t h e Transmission 06M Expenses related to t h e Inter-Transmission Investment Electric O p e a t i o n s and' Maintenance Expanee Costs used in 4th R e v . RS No, 94, Service Schedule MSS-4, differ from Form 3 amounts because the formula r a t e only reflects the Transmission O&M Expenses related to the step-up trans f o m e rs and associated transmission equipment related to the Designated Generating Unit Electric Operations and Maintenance Expensea Costs used in 4th Rev. RS No. 94, Service Schedules MSS-1 and MSS-2, differ Erom Form 1 amounts because the formula rates allocate A&G costs usina a Labor Ratio Electr ic Operation8 and Maintenance Expenses Costs used in 4th Rev. RS No. 94, Service Schedule MSS-4# differ from Form 1 amounts because the formula rate allocate A&G costs using a Labor Ratio E h c t r i c Operations and Maintanance Expense Costs used in 4th Rev. RS No. 94, Service Schedule MSS-1, differ from Form 1 amounts because the formula rate only reflects the Insurance Expense related to the intermediate gas and oil units Eleetzfu Operations and Maintenance Expense Costs used in 4th Rev.'RS No. 9 4 ,
ED. 12-87)
sskn 7 ate of Report :Mo, Da, Ur)
I I
I t 6-11, 15-19, 24, 26-32, 35-39, 44-441 53-57 * 62, 64-66 and 69-72
112
931 107
18 1-193
181-184 and 186-193
185
185
1 * Page 106 Foatnole.6 . -
Service Schedule MSS-4, differ from Form 1 amounts because the formula rate only reflects t he Insurance Expense related to the Designated
Costs used in 4th Rev. RS No. 94, Service Schedule MSS-1, differ from Form 1 amounts because t h e formula rate only reflects the Depreciation Expense related to intermediate gas and o i l units, plus the Depreciation Expense related to the step-up transformers and associated transmission equipment related to I the intermediate gas and oil. units
Costs used in 4th Rev. RS No. 94, . Servfee Schedule MSS-2, differ from Form 1 amounts because the formula rate only reflects t h e Depreciation Expense related to the
I Inter-Transmission Investment ,
Costs used in 4th Rev. RS No. 94, Service Schedule MSS-4, differ from Fom 1 amounts because t h e formula rate only reflects the monthly Depreciation Expense related to the Designated Generating Unit, plus the Depreciation Expense for t h e step-up transformers and associated transmission equipment related to
1 Generating Unit 33 6 1 Depraclation Expense
336 I Depreciation ~xpense
336 IDeprsdation Expnsa
I the Desiunated Generatfna Unit
4 02-403
Costs used i n 4th Rev. RS No. 94, Service Schedule MSS-4, differ from Form 1 amounts because the formula. rate only reflects an allocation of t h e monthly General Plant Depreciation Expense using a Labor Ratio Steam-Electric Genmrating Plank S t a t L S t i C S Costs used in 4th Rev. RS No. 94, Service Schedule MSS-1, d i f f e r from Form I amounts behause t h e formula rate anly reflects the capacity related to intermediate gas and oil u n i t s
ssion I ate of Report :Mo, Da, Yr)
I f
2
7
2-7
1 0
5
IFERC FORM NO. i (ED. 12-87) 1
Page I06 Footnote.7
BLANK PAGE
- - r - - - -. Entergy Arkansas, fnc.
J euirrmiw ui nepon End of 2013144 I I L.." , ,rvv,r I - . UULQ ui nspruri
(1) An Ortginat I (2) A Resubmlsslan I
~
I I
IMPORTANT CHANGES DURING THE QUAREWEAR
G i e partialam (details) conwmlng the matters lndided behw, Make the statemenfs expfldt and predse, and nmber them In accordance with the Inqulrles. Each [nquhy should be answered. Enter 'none," 'not applicable: or NA' where applicable. If Infomation whkh answers an Inquiry 1s given etsewhwe in the report, make a refereme to Ute schedule in which R appears. I, Changes In and hmportant additions to franchise dghts: Describe the actual consideration given therefore and state from whom the franchise rights wer8 acquired. If aqulred without the payment of consideradon, state that fad 2. Aqquisitlon of ownership In otherrxlmpanies by reorganization, merger, of consolidation with ather cornpanles: Give names of cprnpanies InvoIved, parliculan concerning the transactions, name of the Commbsion authowng the transaction, and reference to CumrnfssIon suthorktation 3. Purchase or sate of an operating unit or system: Give a brief descriptlon of the property, and of the transactions re1ahg thereto, and reference lo Comrnisslon authorfration, if any was requlred. Give date Journal enides called for by the Uniform System of Acwunts were submitled to the Commbsion. 4. Important leaseholds (ather than leaseholds for natural gas lands) {hat have been acquired or given, assigned cr surrendered: Glve effective dates, lengths of terms, names of parks, rents, and other condiffon. State name of Cornmisstan authorlzlng lease and glve reference to such authorization. 5. Irnpodaant extendon or reduction of transmisslun or dlstribdon system: State temitmy added of retInquIshed and dale operations began of ceased and give reference to CommIsdon authorhallon, if any was required. Sla!e a h the approximate number of wstomers added or lost and approximate annual revenues of each dass of sedce. Each natural gas company must also state major new continuhg sources of gas made evailabla to it from purchases, development. purchase wntract or otherwise, gMng Iocation and approximate Wa! gas volumes available, period of contracts, and other parties tu any such amngemenls, etc. 6. ObfigatIons Incurred as a result of issuance of securities or assumpuon of BabiliUes or guarantees lndudlng Issuance of short-term debt and cornmedal paper having a maturity of one year or less. Give reference io FERC or Staate Cornmissloo authotkatlon, as appmprtate, and the amount of obfigalion or guaranfee. 7. Changes in artides of Incorporalion or amendments to chartec Expfatn the nature and purpose of such changes oramendrnents. 8. State Ute estimated annual effect and nature of any hiportant wage s d e changes during the year. 9. Stale briefly the status of any materially Important IegaI proceedings pending at the end of !he year, and the results of any such proceedings wlmlnated during the year. IO. Desaibe briefly any materially important transactions of he respondent not disdosed ekewhere In thls report In whIch an ofimr, director, security holder reported on Page 704 or 105 of the Annual Report Form No. I, voting truslee, assodated company or known assoctate of m y of these persons was a party or In whIch any such person had a matedaI Interest 11. (ResenredJ 12. If the important changes durfng the year relating to the respondent company appearing In the annual report to stockholders 8re applicable In every respect and furnish the data requkd by Inslmdons 1 to 11 above, such noles may be lnduded on fils page. 13. Desaibe fully any changes In officers, diredors, rnajbr security hofden and voting powers of the respondant that may have occurred during !ha reporting period. 14. In the event !hat the respondent participates In a cash management prograrn(s) and Its pruprieetary csp'bl ratlo Is less than 30 percent please desaibo the slgnifrcant events or transactions causing the proprietary capItal ratio lo be less than 30 percent, and the exfent lo whlch the respondent has amounts loaned or money advanced to its parent, subddiary, orafilated companies through a msh management progmm(s). Additionally, please desuibe plans, If any to r q a h al least 8 30 percent proprletgry ratio.
PAGE 108 INTEMIONALLY LEFT BLANK SEE PAGE 169 FOR REQUIRED INFORMATION.
Page 108
Name of Respondent TMs Report is: . Date of Report YearlPenod of Report (l)&AnQrigInal (Mo, Da, Yr)
Entatgy Arkansas. lnc. 2Gf3M4 IMPORTM CHANGES DURING THE QVARTERWE4R (Cantinued)
1.
2.
3.
4 .
5.
6.
7.
a.
9.
None
None
I n November 2012, Entergy Arkansas purchased the Hot Spring Energy Fac i l i ty , a 620 MW combined-cycle natural gas turbine' unit located in Malvern, Arkansas, from KGen Hot Spring LLC far approximately $253 million.
entries with the E R C in May 2013 in Docket No. EC11-l13-000.
None. See Entergy Arkansas's 2013 FERC Form 1 Notes to Financial Statements, Note 10 regarding capital leases.
Entergy Arkansas jo ined the Mfdcontinent Independent System Operator, Xnc. t"MfSO'l on December 19, 2013, Provider f o r transmission service over Entergy Arkansas's transmission facilities under t h e MIS0 Tariff.
The FERC approved t h e transaction in Docket No. ER12-1102-000. The APSC approved the acquisit ion in APSC Docket No. 11-069-tl. Entergy Arkansas f i l e d journal
As o f that date , t h e Entergy OATT waz cancel led and MISO is the Transdss ion
See Entergy Arkangas's 2013 E R C Form 1 Notes Eo Financial Statements, Notes 4 , 5 , 6, and 8.
None
Fossil operating and clerical employees are represented by the International Brotherhood of Electrical Workers Am-CIO, meal. Unions 647# 7501 and 1703. The Company and the Union agreed to a contract e f i ec t i ve October I, 2012 through October 1, 2015. Effective October I, 2013, t h e nage increase was 2.0k.
Transmission, distr ibut ion, and u t i l i t y SUppQrt employees are represented by the fntarnafional Brotherhood of Electrical Workers AFL-CIO, Local Unions 647, 750, 1439, and 1703. The Company and the Union agreed to a contract affective October I, 2012 through October 1, 2015. Effective October I, 2013, the wage increase was 2.0%.
Effective April 1, 2013, executive and senior management, middle management, professionals, and nen-represented operating, maintenance, and support s t a f f pay increases averaged approximately 1.9%.
Arkansas Nuclear One
Operating, maintenance, engineering, technical , and administraEive employees are represented by the International Brotherhood o f Electr ica l Workers AFL-CXO, Local Union 647. the Union agreed to a contract effective March I, 2012 through March 1, 2015. I, 2013, the nage increase was 2.0%.
Security employees are represented by the United Government Security officers of America, Local Union 23. The Company and t h e Union agreed to a contract effective June 21, 2009 through March 31, 2013. The Cumpany and the Union agreed to a new contract effective April I, 2013 through March 31, 2016. Effective April lr 2013, the wage increase was 2,OR.
See Entergy Corporation and Subsidiaries 2013 Form 10-K Part I, Legal Proceedings.
The Company and E f f e c t i v e March
10. None
11. Not applicable
12. See Entergy Arkansas's 2013 EERC Form 1 Notes to Financial Statements.
13. Sea EnEcrgy Arkansas's 2013 FERC Form 1 pages 104 and 105 for O F f i e e r and Director changes that occurred in 2013.
1 4 . Not applicable
IFERC FORM NO. I (ED. 12-96} ?&e i 09.1 1
Enkrgy Arkaniaf, Ine.
Ref. Una No. TMs of Accounl Page No.
{I) AnOriginal 121 tl AResubmisston I ! End of 2013M4
Current Year Pdor Year
Baiancs 1201 End of QuarterlYear End Balanca
FERC FORM NO. I (REV. 12031 Page I i O
0 5,395
0 82,298,469 02,205,414
1 50%
(
72,801,91: 42,IO7,01!
( I ) AnOrighal (2) 0 A Resubmisston I 1 Endof 2013M4
COMPARATIVE BAtANCE SHEET (ASSETS AND OTHER DEBITSlConBnued)
Rei. Page Nu
Ibl Balanee
21,043,896) 21.a60.54! 01
227 ;as Stored Undammund -Current fI64.1)
~ .~ _- )eFiratrva Instrumerith3eb - Hdges {1781- Less) Long-Term Portton of Darfvatlve lnstnrment&seb - Hadgas (176 :oQl Cumnt and Accnred Assek (Ltnes 34 through 66)
lnamoltired Debt Expenses (181) 3Raordinaw Prowrtv Lasses (18ZlI
DEFERRED DEBITS
66 67 723,579,924 561 ,%6,80!
* .
25,420,46 20,282.46 I I
1.340.01 5.30:
____
WOa 23QD 232
hmcovamd Plant and Rmulatow Studv Costi H 8 S 1
)rs!im Survey and tnvestigatlon Charges (ElecMc) (183) 'rdlmhaty Natural Gas Survev and Investmatron Chamer 183 11 Xher Prelirnlnary Sumy snd Imrestlgation Charges 4183.2) :baring Aewunh (194) iamporary F~~dlltl8s I1851 Aiscelanaous Defarmd Deb& (186) lei. Losses from Dtsposdon ot UtilRy Pit (?en Issaarch. hwt. and Demonstration Expand. (188) Inamcrktd Loss on Reaquuid Debt (189) kumulated Deferred lnedma Taxes (190) l n m v e r e d Purchasad Gas Cosb (191) rota1 D e k d Deb& (lines 69 through 83) rOTALASSm films 14-18.32.67. and 841
-15,14 I
18.853.25 14 ,I 49.70 1
233
352-353 28,835.84
581 .sa5sz 234
1.746.tO4.18 6.544,372.39
2.122,667.83. 8,426,612,38:
FERC FORM NO. 1 (REV. 1243) Pane ill
vame ot Kesponoent i lnls Keponls: I uate or Kepon 1 rearrrenoa or Keport
Intergy Arkansas, Inc. (1) An Orlginal (mo, da, uri (2) 0 AResubmission i t end of 201 31Q4
253 3.464,414 3,4644 14
586,782,648 586,782.H f 6
7 8 9
Pternlum on Capnal Stock (207) mer Pakiddn CapaaI (ZO&Zl?) lrutallmenk Ramhad on Capttal Stock (212) (Less) Oiscounfon CambI Stc& E131
254b 118-119 11E-119 250-251
I ,aoz,aal 1,802,832 1.1 31,716,202 991,306.44rt
-938,933 -6a4,47; 0 (
14 15
Noneorpoiate Pmpnetorshlp (Non-majar Dnty] {Zla) Ammutated Mher Cornwehenshe Income- I2191
.
17 18 19
. . .-
LONG-TERM DEBT Bonds(221) (Less) Reaquired Bonds 1222)
22 23 24
Unamorttred Pmrniurn on Long-Tern Debt (225) (Lars) Unamortized Dlswunt on Long-Term DebCD8bR W 6 ) Total Long-Term Debt (lines 18 through 23)
30. 31 32 33
A a r n u l a t e d Mljcellaneow Operatbg PMlonr (224 4) Aaxrmubted Pmvislon br Rats Refunds (229) Long-Tern PMbon of DerWUv8 Instrument Llabrlitles tong-Tern Fortlon of Dehatfve Inrmment UabHHlei - Hedges
35 36 37 38 39 40 41 42
Total Mh#r Nonwrrant LlabUbs (Ilnes 26 thmugh 3) CURREWAND ACCRUED LIABILITIES Moles Payable (231) Accounts Payabie (232) Notes Payable to Arsodated Cornpanles (233) Accounts Payable lo Assodated Companles (234) Customer Deposits (235) Taxes A m e d I2361 I 262-263
86.51 2360 85,198,17! -29.3 83241 144.321.07~ 34,141 ,na 46,700,W
45 Matured tong-Term Debt 4239)
COMPARATIVE BALANCE S H E I 3 ILlABlLITlES AND OTHER CREDITSI Cumnt Year W a r Year
Page No. Batanoe
Llne NO.
1 I PROPRImARY CAPITAL ... . .
469.802- 250-253 I t6.350.000 116,350.00C
I
2 Common Slock Issued (201) 3 Preferred Stock Issued (204) 4 Cauital Stock Subscribed (202.2051 5 I Stock Uabltdv lor Convenhn f203.2061 I E
252 I 01 I 254 1 o! f
11 I ReIalned Eamlngs (215,2151,216) . -. ~-
12 I Unappropriated UndbMbuted Subsdbry Eamlngs (216.1)
I at
ot t 20 I Advances fmm Assoelated Cornnanles I2231 01 21 1 Mher Lana-Term Debt (224)
1,216,972 626.73 2.131.837.87R 1.807.345.024
27 l Aecumutatcd Pmvlslon foorProwrtv Insuranm 1228.11 . .
28 I Accumulated Pmvblon for Inlurles and Damages (228 2) 29 I Ammubled Pmvlslon for Pensbns and Benefits 122831
.
26,399,3351 129.1 15.66t 1,247.OUOI 1,676,W
I 1,7713331 f ,2 14,76i
I d i I 723,770,504 680,712.t5:
8?7,296,454 947,053.141
43 I Interest Acuued l237l t 1,718.3061 I,718,3Ot 1,718.306 I,718,3Ot
FERC FORM NO. 1 h v . 12-031 Paae I12
. 1 1 a 1 1 4 c ub I rcapuiiuwii
Entergy Arkansas. [ne.
' FbRM NU. I frev. 12631
I 1 1 1 5 I V q J U A L 13.
(2) 0 AResubrnission I t end of 2013M4
uatc ui n ~ p u i c I caiireiiuu UL n q w i r (1) AnOriglnat . (mo,da,YrJ
Paas 113
[Name of Reswndent 1 This Report is: I Date of Report IYearlPeriod of Report I
Bchedule Paqe: f70 Une No,: 5 Column: E I Includes xemoval costs accrual of $18,605,769.
bchedule page: une NO.: 5 ~ o ~ u m n : d I Includes removal costs accrual of ($12,245,562).
IFERC FURM NO. f ED. 12-871 I Page 114.1$3 Footkte.1
BLANK PAGE
.e.- - .--., Entergy Arkansas. Inc
FERC FORM NO. 1/34 [REV. 0 2 4 4
ti j- '@i Eiiinal (Mo,Da, Vi] End of 20131411 (2) m A Resubmhslan I I
STA'IEMENT OF INCOME
Quarterly 1. Report ln wlurnn (e) the wrrsn't year to date bafanee. Column (c) equals the total of sddlng the data In cdlumn 19) plus the data In column 0) phrs the data In wlumn 0). Report In column ( d ) sbnilar data for the prevlous year. This tnformatjon Is reported in the annual fillng only. Z Enterb column (e} the balance lor the reportrng quarter and In column (9 the balancm lor the same three month perlod lor the pttor year. 3. RepMt b column (9) b e quarter tu date amounts for eledrie utr7ity fundion; In column (r) the quader to date amounts fur gas utilii, and In cotumn (k) the quarter lo date amountr for other ubtity funclron for the currant year quarter. 4. Report in cotumn (h) me quarter to date amounts for slectdc WlIty fundon; fn mfumn Ei) the quarler to dala amounts fargas utrtity, and In column (0 Lhe quarter to dala amounts tor otherutflib fundon for the prlor year quader. 5 If addrtlonal coktmns am needed, place them In K foolnote
Annual orQuarkrIy ifapplicable 1
5. DO not reputt hum quarter data In columns (e) and {f) 6 Report amounts far amunh 412 and 413, Revenues and Expenses from WMy Plant based to men, In anntherutilw colurnnln a shllar manner to a utility depahenl Spread the amunt(s) aver Ihes 2 thm 28 8s sppmphts. Include these arnounb In columns (e) and (d) toMs. 7. Re id arnounb In acmunt 414. Mer U t i l i Operating Income, In the same manner as acwunb 412 and 413 ebwe
(1) aAn Orlglnal (Mo, Da, Yr) End of 20131634
STATEMENT OF INCOME FOR THE YEAR (Conhnued)
- -- .
n A ResubmIssfn I I Enhrgy Arkansas, !ne.
9. Use page 122 for Important notes regardlng be statement ot Incnrne for any account thereof. IO. Ghre Eonelse explanattons crrneemlng unleHled rata proceedings whera a contingency exlsts such that refunds of a malerlal amount may need to be. made tothe ubhtfs customen orwhlch rnay resuk in matedal refund ta the utihty with resped lo power or gas purchases. State foreath p a r effected the gmss revenues or wsh towhkh the contingency relalas and he tax ere& bgetherwkh an explanatron of the major factors whlch affect the rights of the utiw to riiajn such revenuas or recover mounts paid with respct to p m r or gas purchases. 11 Ghre conch sxptanatlons #mcernlng rlgnlficant arnounb of any refunds mada of recelvad durlng the year msulting h m seltlernent of any rata proceeding affedlng revenues received or costs h a d fbr power or gas puft i~s , and a summary of the adjustments made to balance sheet. Income, and expense sccnunts $2 If any notes appsarhg In t h ~ report io stokholden are apptkable to Iha Statement of Inwms, such nates rnay be hnduded at page 422. 13. Enter on page 122 a cpncIse explanation of only those changes h aceounhg methods made duimg h e yearwhlch had an effed on net fnmme, indudlng h basis af ahations and apportronrnents from those used In the preceding year. Also, &e the spproprIate dottar area of such changes. 14. Explaln In a M a ! e H tho previous yeatdquarteh figures 81-8 dilferent fmm that reported In phr reports t5. If the columns am InsutCicIent for repoNng eddbnal ufllity d e p a m n t s , supply the appmpdate aeepun! Wes report the lnfomatlon In a footnote to thb schedule.
43,050,351 t.W.M6,2?l 2 11,059,745
4 0,4 84,O 5 9 2 1,906.335.280 2
205,392,505 2
1 I I I 1 1 I 1 FERC FORM NO, V3-Q 1RW. 0244) . P a m 111
!
1 1
. .*.
I I
8LANK PAGE
I
I
I
,.-,mw y1 . y # - & b *
Entergy Arkansas, Inc.
I I I 1
9 TOTAL Crcdlls to R t l i l m d E a m v r ( k d 439) I ' 10 11 I 2
14 1 13 t
ii)- . .Odglnal (2) ~AResubmIssIan I I
2013144 End of [ M i Da, Vi)
. - 15 TOTAL Debrb to Rebind E a m m ( A c d 439) 16 Balanee Trandensd hum tnmm (Acmunt 433 keri Account 418.1) 17 Appmpriatlons of ReIalncd Eammpl (M 436)
-162,282755 152,503,X -- - -' I -
;- ? .
'19 20 21
~~
22 TOTALAppropwtions of Retamed Eammgr ( A c d 436) I I k 23 Oividends Declared-Pnremd StDdc (Account 437) ' 9
I I 24 1 238 4873,220
26 27 28 -- I
29 TOTAL Dtvldends Declared-Prcfaened Stcck ( A d 437) 30 Wildends Oedared-Common Stock (Amount 430) 31 238 ( 10,m,w
FERC FORM NO. 1c3-Q tW. 02441 Paw I + R
. . .
ntergj Arkansas, lne.
-- I 1
531 BalanmEod of Year(Tota1 liner 49 thrrr 52) I I
I
-938.933 I ( w.47:
20t 3Q4 I Endol . -, 1 I STATEMENT OF RETAINED EARNINGS
, Do not report Unes 4953 on the quarferly uenIon . Reprt all changes In appmp'ated retained earnlngs, unappprialed retaIned earnings, year to date, and mappropdated 7dislnbuted subsidiary eamhgs for the year. , Each credit and deblt dun'ng !he year should h Identified 3s lo the retahed earnings amuot In whlch remrded (Accounts 433,436 439 Indushe). ShQW the eontra primary account affected In mlumn (b) . State the putpose and amounl of each reservation or appropriation of retained earnings. . Ust 6mf account 439, Adjusfmenls to Retained Eamhgs, reflecling adjustments to the opening balance of retalned earnings. Follow y credit, then debit Items h that order. . Show didends furea& ctass and series of capHal stock. , Shcrw separately the State and Federal Income tax efkd o€ items shpwn In accour;rt 439, Adjustments lo Retalned Eambgs. . I3plaln In a footnote Ihe basis for determining the amount reserved or appropriated. If such reservakn or approphatfon 1s to be zwrrent, stab the number and annual smwnts to be reserved or appmpdalaled as well as the totals eventually lo be accumulated. . If any notes eppeadng In the reporl to stockholden are applcabfe to this statement, Indude !hem on pages 122-123.
Cunant PrSvlOUJ QuartsrrYear QuarterMear Yearto Data Year to Data
Balance Bafanm
.. - . . .
41 I I I 421
431 I i I 4-41
Report only on 8nAnnuaI Bask no Quarterly
(Lass) DMdenda R R ~ M (DebH) 219 4
' . BaIance-Beglnnlng of Year (DebH or Credd) 404,472 ( 465581 Equw In Eambgs for Year ( C d n ) (Aecoun1418.1) -324,242 ( 138.301
I
FERC FORM NO. l l 3 4 [REV. 0244) Paum <In
Name of Respondent This Report Is: Date of Report (I) An Origina! (Mo, Da, Ur)
EntergyArkaruas, Inc (2) - A Resubmisslon i1
behedule Page: f f 8 Line No.: 24 Column: c 1 For the Year Ended December 31, 2013
Yearlferiad of Report
2013144
$100 Preferred Stock: 4.32% Serles, $4 .32 per share 4.72% Series, $4.72 per share 4.56% Series, $4.56 per share 4.56% Series, (1965 Series) $4.56 per share 6.088 Series, $6 .08 per share
$25 Preferred Stock: 6.45% Series
Total Preferred Stock Dividends
$302,400 441,320 342,000 342,000 608,000
4 , 837,500
bchedule Page: i f 8 Uns No.: 24 Column: d 1 For t h e Year Ended December 31, 2012
$100 Preferred Stack: 4.32% Series, $4.32 per share 4.72% Series, $4.72 per share 4.56% Series, $4.56 per share 4.56% Series, (1465 Series) $4.56 per share 6.08% Series, $6.08 per share
$25 Preferred Stock: 6.458 Series
Total Preferred Stock Dividends
I
$302,400 441,320 342,1300 342,000 608,000
FERC FORM NO. 1 (ED. 12-87) I
Page 1lSIi9 Foatnote.1
BLANK PAGE
20'3m4 I End of
Destrtptton (See lnstnrdon ND. 1 fur Explanation of Codes)
(a)
Une NO.
Current Veartp Oate Q u arterNear
Prevmus Year to Data Qua rferrYea r
lld lcl _ _ 46 Iloans Made or Purchased I I I
66 67 63 69
51 \Net (Increase) Decrease In AIlowances Held for SpaurlaUcn 52 INat Increase (Decrease1 In Pavables and Accrued Expanses
I I
Net Increase In Short-Term Debt (e) Other (provide details In footnote):
100 I '42 I 9.326.915
71 72 73
.
55 UtigaUon proceeds for relrnb -spent nuctearfuel slorage costa
57 Total of lines 34 thru 551 -536,516,836 -570,634,633
10,270,697
, . I I ' - * - * .
. I- Payments for Rebrement ot. 1 ' . . ' * . - lia - . - ' , - :-- Lonn-termDeMIb) I' -399.713.420 I
. - 50 I I. .I 59 lCash Flows from nnanclng Aetrullies: a .
80 81 82 83 a4 85 86
* I $ , I I . 60 IPmceeds from Issuance of: - * . . 61 Itong-Term Oebt {b) I 718,595,363 I 192,346.712
Dhklends on Ptekrred Stock S,873,220 I 4073,220 Dhvldends on Common Stack -lS,OW,OOOl -1o,cw,ooo Net Cash Provided by [Used tn) Rnancktg Aarvdles
- r r rh-
* 0 . i * (Total of hnes 70 thnt 81) 295,008,723 175,460,623
Net Increase (Dmea5e] In Cash snd Cash Equhralenls nota! of Irnes 22.57 and 83) I as,z4a,4no l6,453,172
* I :I * + .
64 !Other (prowIda details In fwtnde): 65 1
I
..
88 89
I
Cash and.Cash Equivaknls at Beglnnlng of Penod 34,452,596 1 . , . . . . - - --- -.. -- . . I a
. . 1 70 l a s h Prevlded by OuPSiddo Sources (ToGlGlthnr.6E))- 716,595,3631 192,346,712 I
90 Cash end Cash Equlvalenb at End of p l o d 123,700,996 34,452,598
74 IPrefeewd Stock t I 75 lcornmon stock 76 (Other (provlde detaIIs In foutnote): I I n 10ther -12,869 78 \Net Decreasa In Short-Term Debt [e) I 1 79 I I
I * I I t I FERC FORM NO. 1 LED. i2-961 Pam 924
1 W L I I I r n UI F\mpLUuII I
Entergy Arkansas, In&
FERC FORM NO. I (ED. 12-93)
- _ . r - ' - 1..11 r.rp.ut. ."I --... -. . .- End of 20131Q4 I t (I) Anoriginal
(2) AResubmisston
Page 122
NOTES TO F I W C W STATEMENTS 1. Use the spa- below for Impartant notes regarding he Balance Sheet, Statement of Income forthe year, Statement of RehIned Earnings for the year, and Statement of Cash Ffows, or any acarunt thereof. CIassify the notes acmrding to each baric statement, prwld[ng a subheading far e& statement except where B note Is applicable to m m than one statement. 2. Fumbh partrculan (detalfs) as to any significad contingent assets or liabilities exlsting at end of year, Including a brId expranation of any actionlnitiated by fha internal Revenue Sedca lnvolvlng possible assessment of additional Income taxes of material amount, or OF a claim far refund of income taxes ora matedal amwot Initiated by the Utilify. GJv8 also a brief explanation of any djddends in arrears on cumulative preferred stock. 3. For Account 1161 Utifity Plant Adjustments, explah the origln of such amount, debas and credits durfng the year, and plan of disposition wntemplated, giving references to Cormmisshn orders or other authorkations respedng classification of amounts as plant actjustments and requIrernents as to disposition thereof. 4. Where Acwunts 189, UnamorHred Loss on Reaqdreed Debt, and 257, Unarnorihed Gain on Reacquired Debt, are not used, give Bn explanation, prodding the rate lrealment @en these Items. See General Instruction 17 of the Uniform System of Amounts. 5, Give a condse explanatlan of any retalned earnings restdetlans and slate the emoun!tfretained earnings affected by such resWons. 6. I f the notes to financial statements relating io the respondent company appeadng In the annual report to the stockholders are applibfe and furnish the data required by instrudons a b e and on pages 114.121, such notes may be Included herein. 7. For he 3Q dlsdusures, respondent must provide In the notes suffident disdosures so as to make the interim information not rnkleading. Disdosures which would rrubstantlally duplicate the disdosures mnhabed in the most recent FERC Annual Report may be omltted* 8. For h e 34 disclosures, he disclosures shal be provided where events subsequent to tho end of the most recent year have occurred which have 8 material effect on h e respondent. Respondent must hcluda In the notes slgnifican! changes slnce tfte most recenffy completed year In such Bems as: accounting pn'ndptes and practlces; estlmates Inherent In the preparaUon of the finanda1 statements: status of long-term wnhacts; mpitarmtion Induding slgnificant new b o m h g s or modifications of existing financing agreements; and changes resulting from business wmblnaiions or disposltlons. However were material mntingenetes edst, the disclosure of such matters shall be prwided even though a sfggnificrant change stnce yearend may not have occurred. 9. Flnally, IF the notes to the finandal staternenls relatjng to the respondent appeadng In the annual report to the stockholders we apprtble and furnish the data requked by the above instructions, such notes may be Induded hereh.
PAGE I22 INTENTIONALY LEFT 8lANK SEE PAGE 123 FOR REQUIRED INFORMATlON.
hame of Respondent IThis Report is: 1 Date of Report IYearlPeriod of Repart 1 b l e w Arkamas. tnc
11 1 x Ari Original (Mo, Da, Y r ) (2) - A Resubmission I 1 20t3lQ4
A. CASH FLOW STATEMENT, ADDITIONAL MFORMATION: Cash and Cash Equivalents at December 31,2013
Cash (Account 13 1) $849,278
Temporary Cash Investments (Account 136) 122.762%5 1 $123,700,996
Working Fund (Account 135) s 8,a 67
Total Cash and Cash Equivalents
SUPPLEMENTAL DISCLOSURE OF CASH FLOW STATEMENT (in 000's) Cash paid during the period for:
Interest -net ofamt capitalized $963 I2 Income Taxes S 184,592
B. FERC FORM 1 PRESENTATION COMPARED TO GENEMLLY ACCEPTED ACCOUNTMG PRINCIPLES
The accompanying financia? statements have been prepared in accordance with the accounting requirements of the FERC 11s set forth in the Uniform System of Accounts and accounting releam, which differs from GAAP. Additional comparative data, including the 2012 data for the statement of retained earnings and w h flows, are needed to present the financial position and results of operations in order to satisfy GAAP. In addition, GAAP requires the disdosure of the current and Iong-term portion of assets and liabilities. In accordance with FERC reporting requirements, the aforementioned disclosures were not inciudcd in these financial statements.
As required by the FERC, EntergV Arkansas, inc. classifies certain items in the balance sheet (primarily the classification of thc components of accumulnted deferred income taws, taxes accrued, certain other miscellaneous current and accrued liabilities, maturities of long-term debt, deferred debits, deferred credits, and accumulated depreciation) in a manner different than that required by GAAP.
GAAP requires Enterpy Arkansas to consolidate the company from which it leases nuckar fuel, whereas this company is not consolidated for the FERC Form 1 presentation, The significant difference that results fmm this is the elimination from the GAAP balance sheet of the obligations under capital kasses with the nuclear fuel cornpmies and the addition to the GAAP balance sheet of the nuelem fuel companies' credit facility bornwings, commercid paper, and notes payable.
Finally, GAAP requires that Entergy Arkansas consolidate it majority owned subsidiary, Entergy Arkansas Rcstomtion Funding LLC, whereas the investment in the company is presented in the Form 1 using the equity method. The significant difference that results fmm this is the inclusion on Entew Arkansas's GAAP-basis balance sheet of storm cost regulatory assets that m the property of and securitization bonds that BE the obligations of the subsidiary.
C. The Notes to the Financial Statements included h m i n are adapted from the Entergy Corporation and subsidiaries Form 10-K for the Year Ended December 31, 2013. The Form 10-K Notes to the Financial Statements are prepared in conformity with GAAP, and thus may differ in certain instances from the financial statements contained herein.
"Enter& when used in these No!= means Entergy Corporation and its direct and indirect subsidiaries.
I EERC FORM NO. 1 [ED. 12-88) Page 123.1 I
Name of Respondent This Report k Dale of Report {I) An Original (Mo, Da, Yr)
"Registrant Subsidiaries" when used in these Notes means Enterm Arkansas, hc., Enlergy Gulf States Louisiana, L.L.C., Entergy Louisiana, LLC, Entergy Mississippi, Inc., Entergy New Orleans, Inc., Enterm Tew, Jnc., and System Energy Rcsourccs. Tnc,
Yeadperiod of Report
"Utility" when used in the Notes means Entergy's business segment that generatcs, transmits, distributes, and sells electric power, with a small amount of natural gas distribution.
Entergy Arkansas. I n c (2) - A Resubmission I t 2013m4 L
NOTES TO FINANCIAL STATEMENTS (ConBnW)
"Utility operating companies" when used in these Notes means Entera Arkansas, Enters Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entersy Texw.
NOTE 1, SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Use of Estimates In the Prenaration of Finanrinl Statements
In conformity with generalIy accepted accounting principles in the United States of America, the preparatim of Entern Corporation's consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to makc estirnatcs and assumptions that affect the reported amounts of assets, liabilities, revenues, md expenses and the disclosure of contingent assets and liabilities. Adjustments to thc rcported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results BE different from the estimates used.
Revenues and Fuel C m s -
E n t e w Arkanszs, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entera Texas genente, transmit, and distribute electric power primarily to rchil customers in Arkansas, Louisiana, Louisiana, Misskippi, and Texas, respectively. Enters Gulf States Louisiana also distributes natura1 gas to retail customers in and around Baton Rouge, Louisiana. Entergy New OrIemns sefls both electric power and natural gas to retail customers in the City of New Orleans, except for Algiers, where Entern Louisiana is the electric power supplier.
Entergy recognizes revenue from electric power and natura! gas sales when power or gas is delivered to customers. To thc extcnt that dc?ivcrics have occurred but a bill has not been issued, Entergy's Utility operating companies accrue an estimate of the revenues for energy delivered since the latest billing. The Utility o p a t i n g companies calculate the estimate bascd upon severa1 factors including biIhgs through the I s s t billing cyde in a month, actual genention in the month, historical line Ioss factors, and prices in effect in Entergy's Utility opekting companies' various jurisdictions. Changes are made to !he inputs in the estimate as needed to reflect changes in biIIing practices. Each month the estimated unbilied revenue amounts are recordcd as revenue and unbilIed accounts receivable, and the prior month's estimate is reversed. Therefore, changes in price and voIume differences resulting from factors such as weatficr affect the calculation of unbilied revenues from one period to the next, and may resuIt in vatiabilicy in reported rcvenues from onc period to the next BS prior estimates are reversed and new estimates recorded.
~FERC FORM NO. i (ED. 12-88) Page 123 2 I
hame af Respondent lThrs Report is: I Date of Report IYearlPenod of Report I Entergy Arkansas, Inc.
(1) An Original (Mo, Da, Yr) (2) A Resubmkion I t 20t304
Entergy records revenue from sales under rates implemented subject to refund less estimated amounts accrued for probable refunds when Entergy beliwcs it is probable that revenues will be refunded to customers based upon the status
of the rate proceeding E of the date the financia! statements are prepared.
Entergy's Utility operating companies' rate schedules indude either fuel adjustment clauses or fixed fuel factors, which allow either current recovery in billings to customers or deferral of fuel costs until the costs are billed to customers. Where he he1 component of revenues is billed based on a predetermined fuel cost (fixed fueI factor), the fuel factor remains in effect until changed as part of a general rate case, fuel reconciliation, or fixed fuel factor filing. System Energy's operating revenues are intended to recover from Entergy Arkansas, Entergy touisianq Entergy Mississippi, and Enter# New Orleans operating expenses and capital costs attributable to Gmnd Gulf. The capital costs are computed by allowing a return on System Energy's common equity funds allocable to its net investment in Grand Gulf, plus System Enera's effective interest cost for its debt allocable to its investment in Grand Gulf.
Accounting for MIS0 transactions
In December 2013, Enkrgy joined MISO, a regional transmission organization that maintains functional contml over the combincd transmission systems of its members and manages one of the largest energy markets in the U.S, In the MISO market, EnterH offers its generation and bids its Ioad into the market an an hourly h i s . MISO settles these hourIy offers and bids based on locational marginal prices, which is pricing for energy at B given location based on a market clearing price that takes into account physical limitations on the transmission system, generation, and demand throughout the MISO rcgion. MISO evaluat& the market participnnts' energy offers and demand bids to economicdly
and reliably dispatch the entire MISO system. Entergy accounts for thBe hourly offers and bids, on a net basis, in ' openting rcvcnucs when in a net selling position and in operating expenses when in a net purchasing position.
Propertv, Plant, and Esulprnent -
Property, plant, and equipment is stated at original cost. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service Iives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, i s chargcd to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Substantially all of the Registrant Subsidiaries' plant is subject to mortgage liens.
Details of property, plant, and equipmcnt by functional category are pmented on FERC Form 1 pages 204-207 and details of accumulated depreciation by functional category are. presented on FERC Form I: pge 2 19.
Depreciation rates on average depreciable pmperty fur the Registrant Subsidiaries ax shown below:
Eatergy Entergy Entergy GulfStatw Entergy Entergy New Entergy System
Arkamas Louisiana Louisiana Misshippi Orleans Texas Energy
1 FERC FORM NO, +I (ED. 12-88) '123.3 I
Name of Respondent This Report Is: Date of Report (1) X An Original (.Mom Da, Yr)
As of December 3 1,2013, construction expenditures included in accounts payable are $61.9 million for Entergy Arkansas, $13.1 million for Enter= Gulf States Louisiana, 531.1 million for Entergy Louisiana, $2.8 million for Entergy Mississippi, 51.7 million for Entergy New Orleans, $10.9 million for Entergy Texas, and $6.7 million for System Energy. As of D m m b e r 3€, 2012, consfruction expenditures included in accounts payable arc $563 million for Entergy Arkansas, 59.7 million for Enterm Gulf States Louisiana, %I 10.4 miilion for Entergy Louisiana, $4.8 million for Entergy Mississippi, $1.9 million for Entcrgy New Orleans, $8.6 million for Entergy Texas, and $13.5 million for System Energy,
YearlPeriod of Report
join fly-Ownd Gtncmfinv Stations
Entergy Arkansas, Int. (2) - A Resubmission
Cerhin Enter= subsidiaries jointly bwn electric generating facilities with amliates or third parties. The investments and cxpenscs associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their rcspcctivt undivided ownership interests, As OF December31, 2013, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were 8s follows:
I I 20131Q4
Totd Megawatt
Fuel-Typ Capability Generating Stntions e (a) Ownership
UtiIity buslna: Entergy Arkansas - Independcncc
White Bluff Ouachita (b)
Entcrgy Gulf States Louisiana -
Roy S, Nelson Roy S. Ndson
Big Cajun 2 Omchita (b)
Enterw Louisiana - Acadia
Unit 1 Common Fac iiitics Units I and2 Common Facilitia
Unit 6 Unit 6 C o m m o n Facilities Unit 3 Common Facilities
Common Facilities
Coal Coal
Coal
G S
Coal
Coal - Coal
Gas
Gas
838 3 I S O % 15.75%
1,637 57.00%
66.67%
55 1 40.25%
15.92% 603 24.15%
3333%
50.00%
Accumdafed Tnvestm ent Depreciation
(In Millions)
$229 $97 $33 $ 2 5 .
%SO2 $348
$169 $144
$255 $176
$8 $3 $143 $102
587 $73
$19 $- IFERC FORM NO. 1 (ED. 12-88) 123.4 I
\Name of Respondent IThis Report,is: 1 Date of Repcrt IYearlPeriod of Report I Entergy Arkansas, fnc.
( d ) 11 Ar; OrigtnaI (Mo, Da, Yr) (2) I A Resubmission I I 2013lQ4
Entcrgy Mississippi
NOTES TO FINANCIAL STATEMEME (Contlnued
- Independence
Enkrgy TCW - Roy S. Nelson Roy S. Nelson
Big Cajun 2 System Energy - Grand Gulf
Units S and2 and Common FaciIi tics Coal 1,679 25.00% $250 $144
Unit 6 Coal 55 1 29.75% $183 $1 13 Unit 6 Common Facilities Coal 1 1.77% $6 $2 Unit 3 Coal 603 17.85% $107 $71
Unit 1 Nuclear 1,413 90.00% IC) $4,696 52,699
(a>
(b)
"Total Megawatt Capability" is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fue1 (assuming no curtailments) that each station was designed to utilize. Ouachitit Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Gulf States huisiana. The investment and accumulated depreciation numbers above are on!y for the common facilities and not for the. generating units. Includes a Ieaseho?d interest held by System Energy. System Energy's G m d Gulf lease obligations are discussed in Note 10 to the financial statements.
(c)
Nuclenr Refuelinp Outare Costs
Nuctear refuehg outage costs are deferred during the outage and amortized over the estimated period to the next outage because these refueling outage expenses ate incurred to prepare the units to operate for the next operating cycle without having to be taken off Iinc.
Alfowance far Funds Used During Constructinn (AFUDC)
AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by !he Regktnnt Subsidiaries. AFUDC increases both thc plant balance and earnings and is realized in cash through depreciation provisions incIuded in the rates charged to customers.
income Tmes
Entergy Corporation and thc majority of its subsidiaries file a United States consolidated federal income tau return. Each tim-paying entity records income taxes as if it were a separate tavpqer and consolidating adjustments are allocated to the tau filing entities in accordance with Enterm's intercompany income tax allocation agreement. Deferred income taxes arc rccordcd for all temporary differences between the book and bu basis of asscts and liabilities, and for certain credits availabbb for canyfonvard.
IFERC FORM NO. i (ED. 12-88) Page I23 5 I
3
Name of Respondent This Report Is: Date of Report Yearipenod of Report (1) X An Original {Mo, Da, Yr)
Entergy Arkansas, fne (2) - A Resubmission ! I 2013144 -
N O E S TO FlN4NClAL STATEMEMS (Conllnued) I
Deferrcd tax assets arc reduced by II valuation allowance when, in the opinion of management, it i s more likely than not that some portion ofthe deferred tzu assets will not be realized. Deferred tau assets and IiabiIities fire adjusted for the effects of changes in tau laws and rates in the period in which the tax or rate was enacted.
Investment ~ZK credits are defend and amortized based upon the average useful life ofthe dated property, in accordance with ratemaking treatment.
Accountinp for the Effects of Repulation
Entergy's Utility operating companies and System Enerw are rate-reguIated enterprises whose rates meet three criteria specified in accounting standards. The Utility opemting companies and System Enera have rates that (i) are approved by a body (its regulator) empowered to set mates that bind customers; (ii) are cost-based; and (iii) can be charged to and collected from customers. These criteria may also be applied to separable portions of a utility's businas, such 8s
the generation or transmission functions, or to specific classcs of customers. Because the Utility operating companies and System Energy meet these criteria, each o f them capitalizes costs that would othenvise be charged to expense if the rate actions of its regulator make it probabb that those costs will be recovered in future revenue. Such capitalized costs are reflectcd as regulatory assets in the accompanying financial statements. When an enterprise condudcs that recovery of a regulatory asset is no longer probable, the regulatory asset must be removed from the entity's balance sheet.
An enterprise that ceases to meet the three criteria for all or part of its operations should report that event in its financial statements. In general, the enterprisc no longer meeting the criteria should eliminate from its balance sheet at[ regulatory assets and Iiabilities reJated to the applicable operations. Additionally, if it is determined that a regulated
+ enterprise is no longer recovering all of its.costs, it is possible that an impairment may exist h a t could require further write-offs of plant assets,
Rtpulatow Asset for Income Taws
Accounting standards for income taxes provide that a regulatory asset be recorded if it is probable that the currently determinable future increase in regulatory income tax expense wiII be recovered from customers through future rates. The primary source of Enter@ regulatory asset for income faxes is book depreciation of AFUDC equity that has been capitalized to property, pfang and equipment but for which there is no corresponding h,u basis. AFUDC equity is a component of property, plant, and equipment that is included in rate base when the plant is placed in service.
Cash and Cash Equivalents
Entcrgy comidcrs all unrestrictcd highly liquid debt instruments with an original or rcrnaining maturity of three months or less at date of purchase to be cash equivalents, *
* Atlownnce for Doubtful Accounts
1 1 1 Page 123 6
Name of Respondent
Enlergy Arlranras. Inc
This Report is: (I) X An Original (2) - A Resubmission
The allowance for doubtful accounts reflects Entergy's best estimate of losses on the accounts receivable balances, The allowance is b s e d on accounts receivable aging, historical experience, and other currently available evidence. Utility operating company customer accounts receivable are written off consistent with approved regulatory requirements.
Date of Report YearlPenod of Report (Mo, Da, Yr)
I f 2013Q4
Jnvestmentg
Enter= records decommissioning trust funds on the balance sheet at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning trust funds, the Registrant Subsidiaries record an offsefting amount in other regulatory liabilitiedassets to the unrealized gainsl(1osses) an investment securities. For the portion of River Bend that is not rate-regulated. Entergy Gulf States Louisiana has recorded an offsetting mount in other deferred credits to the unrealized gaind(1osses). The assessment of whether an investment in a debt security has suffered an other-than-temporary impairment is based on whether Entergy has the intent to sell or more likely than not will be required to sell the debt security before recovery of its amortized costs. Further, i f Entergy does not expect to recover the entire amortized cost basis of the dcbt sccurity, an other-than-temporary impairment is considered to have occurred and it is measured by the present vahe of cash flows expected to k collected less the amortized cost bassis (credit toss). The assessment of whether an investment in an equity security hns suffcred an other-than-temporary impairment is based on a numbcr of factors including, first, whether Entergy has the ability and intent to ho?d the investment to recover its value, the duration and severity of any losses, and, then, whether it is expected that the investment will recover its value within a reasonable period of time. Entergy's trusts are managed by hi@ parties who operate in accordance with agreements f iat define investment guidelines and pIace restrictions on the purchasa and sales of investments. See Note i7 to the financia1 statements for details on the decommissioning trust funds.
Derivative Financial Instruments and Cornmddity nerivativm
The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase, normal sales criteria. The changcs in the fair value of recognizcd derivatives are recorded each period in current emings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction.
Contracts for commodities that will be physically deiivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet thk noma1 purchase, normal sales criteria and nre not rccognizcd on the balance sheet. Revenus and expenses from these contncts are reported on a p s s basisis in thc appropriate revenue and expense categories as the commditics are received or delivered.
For other contmcts for commodities in which Entergy is hedging the variability of cash ffows related to a variabIe-rate assct, liability, or forecasted transactions that tpatiQ as cash flaw hedges, the changes in the fair value of
IFERC FORM NO. i (ED. 12-88) Page 123.7 1
Name of Respondent This Report 1s: Date of Report { I ) An On’ginal (Mo, Da, Yr)
Enlergy Arkansas, In& (2) - A Resubmission I 1
such derivative instruments are reported in other comprehensive income. To qualiQ for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the c a h !lows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified tu earnings in the periods when the underIying transactions actually occur. The ineffective portions of all hedges are recognized in current-period earnings.
YearlPenod of Report
2 0 1 ~ ~ 4
Entersy has determined that contracts to purchase uranium do not meet he definition of a derivative under the accounting standards for derivative instruments because they do not provide for net scttlernent and the uranium markcts are not sufficiently liquid to conclude that forward contracts BE readily convertibk to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these confmcts would be accounted for consistent with Entergy’s other derivative instruments.
Fair Values
The estimated fair values of Entern’s financial instruments and derivatives are determined using bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial insttllments heid by regulated businesses may be reflected in future rates and therefore do not accrue to the benefit or detriment of stockhoiders. Entergy considers the cmying Etmounts of most financial instruments classified BS current ass+ and tiabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note I6 to the financial statements for further discussion of fair vatue.
Tmpnhnent of Lonp-Lived Assets
Entergy periodically reviews long-lived assets held in nlI of its business segments whenever events or changes in circumstances indicate that recoverability of Lhcsc assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows dcpcnd on thc future operating costs wssociatcd with the assets, the efficiency and availability of the assets and generating units, and the future markct and price for e n e r a over the remaining life ofthe assets,
Reacquired Debt
T h e prcmiums and costs associated with reacquired debt of Entergy’s Utility openting companies nnd System Enerw (except that portion allocable to the deregulated operations of Entergy Gulf States Louisinna) BE included in regulatory assets and are king amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in nccordoncc with ratemaking treatment.
Taxes Tmnojed on Revenue-Producing Trrtnsacfions
1 FERC FORM NO. 1 (ED. 12-88) Page 123 8 I
Name of Respondent This Report Is: (t) An Original
Entergykkansas. Inc (2) - A Resu#mission
Governmental authorities assass taxes that are both imposed on and concurrent with a specific revenue-producing transaction between B seller and a customer, including, but not limited to, saIes, use, value added, and some excise hies. Entergy presents these ticues on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority.
Date of Report YearlPedod of Report {Mo, Da, Yr)
I I 201 31Q4
New Accountinv Pronouncements
The accounting standardaetting process, including projects between the FASB and thc International Accounting Standards Board (IASB) to converge U.S. GAAP and International Financial Reporting Standards, is ongoing and the FASB and the IASB are each curredy working on several projects that have not yet resulted in final pronouncements. Final pronouncemcnts that result from these projects could have a material effect on Enterpy's fiture net income, financial position, or cash flows.
NOTE 2. RATE A N D REGULATORY MATTERS
Reeulatorv Assets
.. Utber Regulatory Ajsets
Regulatory assets repmcnt probabte future revenues associated with costs that are expected to be recovered from customers through the rcplatory ratemaking process under which the Utility business operates. Details of regulatory assets in FERC account 182.3 are presented on FERC Form 1 page 232. -
File1 and purchased power cost rccovery
Enter= Atkansas, Entergy Gulf States Louisiana, Entergy Lduisiana, Entergy Mississ'ippi, Enterm-New Orleans, and Enfersy Texas me allowed to mover fuel and purchased power costs through fucI mechanisms inchded in electric and gas rates that are recorded as fuel cost recovery revenues. The difference bemeen revenues collected and the current fuel and purchased power costs is generally recorded BS "Deferred fuel costs" on the Utility operating companies' financial statements. The table below shows the amount of deferred fuel costs as of December 31,2013 and 2012 that Entergy expects to recover (or rerum to customers) through fuel mechanisms, subject to subsequent regulatory review.
2013 2012 {In Millions)
Enterm Arkansas $68.7 $973 Entersy Gulf States Louisiana (a) $109.7 $992 Entergy Louisiana (a) $37.6 $94.6 Enterpy Mississippi $38.1 $26.5 Entergy New Orleans (a) ($19.1) $1.9
~FERC FORM NO. I (ED. m s s ) Fags 123.9 I
Name of Respondent
Enlergy Arkanaas. Ine.
This Report Is: (1) X An Original (2) -A Resubmissh
Entew Texas
Date of Report YearlPenod of RepoFt (Mo, Da, Ut)
I t 2OWW
($4.1) ($93 3)
(a) 2013 and 2012 include $100.1 million for Entersy Gulf States Louisiana, $68 million for Enterw Louisiana, and $4.1 million for Entergy New Orleans of fuel, purchased power, and capacity cosfs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be over a period greater than twelve months.
Enterw Arkansas
Production Cost Allocation Rider
The APSC approved a production cost allocation rider for recovery from customers of the retail portion of the costs allocated to Entergy Arkansas as a result of the System Agreement proceedings, which are discussed in the "System Aereement Coat Equalirafion Proceedinps" section below. These costs cause an increase in Entersy Arkansas's deferred fuel cost balance because Entergy Arkansas pays the costs over seven months but collects them from customers over tweive months.
Energy Cost Recovery Ridcr
Entersy Arkansas's rctail ntcs include an encrgy cost recovery rider to recover fuel and purchascd cncrgy costs in monthly customer bills. The rider utilizes the prior calendar-year enera costs and projected energy sales for the twelve-month period commencing on April 1 of each year to develop an e n e w cost rate, which is determined annually and includes B true-ip adjushent reflecting the over-'or under-recovery, including carrying charges, of the enera costs for the prior cdendar year. The energy cost recovery rider tariff also allows nn interim rate request depending upon the level of over- or under-recovery of fuel and purchased energy costs.
In October 2005 the,APSC initiated an investigation into Entergy Arknnsas's interim mew cost movery mte. The investigation focused on Entersy Arkansas's 1) gas contncting, portfolio, and hedging practices; 2) whoIesale purchases during the period; 3) management of the cod inventory at its coal generation plants; nnd 4) response to the contractual failure of the railmads fo provide coa? deliveries. In March 2006 the APSC cxtcnded its investigation to cover the costs included in Entergy Arkansns's March 2006 annual energy cost rate filing, and II hearing was held in the APSC investigntion in October 2006,
In January 2007 the APSC issued an ordcr in its review of the enerw cost mte. Thc APSC found that Entergy Arkansas failcd to maintain En adequate cod inventory level going into the summer of 2005 and that Entergy Arkansas should be responsibfc for any incremental enera costs that resulted from two outages caused by employee and contractor error. The coal plant generation curtailments were caused by railroad delivery problems and Enter= Arkansas has since resolved litigation with the railroad regarding the delivery problems. The APSC staff was dimled to perform an analysis with Entergy Arkansas's assistance io determine the additional fue1 nnd purchased energy costs associated with these findings and fiie the analysis within sixty days of the order. After a final determination of the costs is made by the APSC,
~FERC FORM NO, i (ED. 12-88) Page 123.10 I
Name of Respondent This Report Is: Date of Report (Mo, Da, Yr) (1) 3 An Original
Enfergy Arkansas will be directed to refund that amount with interest to its customers as a credit on the energy cost recovery rider. Entera Arkansas requested rehearing of the order.
YearlPeriod of Report
, In February 2010 the APSC denied Entergy Arkansas’s request for rehearing, and held a hearing in September 2010 to determine the amount of damages, if any, that shouId be assessed against Entergy Arkansas. A decision is pending. Entergy Arkansas expects the amount of damages, if any, to have animmaterial effect on its resuIts of operations, financial position, or cash flows.
Entergy Arkansas. Inc (2) A Resubmission NOTES TO FINANCIAL STATEMENTS (Codbueff
The APSC also established a separate docket to consider the resolved railroad Iitigation, and in February 2010 it wtablished a procedural schedule that concluded with testimony through September 2010. The testimony has been filed, and the APSC will decide the case based on the record in the prwccding.
f l 2 0 t W 4
In January 2014, Entergy Arkansas fi?ed a motion with the APSC relating to its upcoming March 2014 calculation of its revised energy cost rate. In that motion, Entergy Arkansas requested that tho APSC authorize Enteqg Arkansas to exdude $65.9 million of deferred fuh and purchased energy costs incurred in 2013 from the caIcuIation of its 2014 revised enera cost rate. The $65.9 million is an estimate of the incremental fuel and repIatement enera costs that Entergy Arkansas incurred as a result of €he AN0 stator incident. Entcrgy Ar!amas requested that the APSC authorize Entergy Arkansas to retain that amount in its deferred fuel balance, with recovery to bc reviewed in a later period aRec more information is available regarding various claims associated with the AN0 stator incident. The APSC approved Entcrgy Arkansas’s rcquest in February 2014. See the “AN0 Damwe and Outape” section in Note 8 to the financial statements for further discussion of the AN0 stator incident.
Retail Rate Proceedinps
Filings with the APSC (Entergy Arkansas)
Retail Ratcs
2013 Base Rate Filing
In March 2013, Entergy Arkansas filed with the APSC for a general change in rates, charp, and tariffs. Tlte f i h g assumed Entergy Arkansas’s transition to MIS0 in December 2013, and requested a rate increase of%174 rniIlion, including $49 miIlion of revenue being transferred from collection in riders to base rats . Tlte filing also proposed a new transmission rider and a capacity cost recovery rider, The filing requested a 10.4% return on common equity. In September 2013, Entcrgy Arkansas filed testimony reflecting an updated rate increase request of $145 million, with no change to its requested rchm on common equity of 10.4%. Wearing in the procccding began in October 2013, and in December 2013 the APSC issued an order. The order authorizes a base mte increase of $81 million and includes an authorized return on common equity of 9.3%. The order allows Entergy Arkansas to amortize its human capital management costs over a three-and-a-half year period, but aIso orders Entergy Arkansas to fife a dctaikd report of the Arkansas-spccific costs, savings and final payroll chnges upon concIusion of the human capital management initiative.
~FERC FORM NO. I (ED, 12-88) Page 323.1 I I
"-
Name of Respondent This Reportis: (I) XAn Original
Entergy Arkansas. Ine {2) I A Resubmisston
Date of Report Year/Periud of Report (Mo, Da, Yr)
I t 20131114
System Apreement Cost EsunIization Praeedinps
The Utility opcrating companies historically have engaged in the coordinated planning, construction, and operation of generating and bulk transmission facilities under the terms of the System Agecment, which is a rate schedule that has been approved by the FERC. Certain of h e Utility operating companies' retail regulators and other parties are pursuing litisation involving the System Agreement at the FERC. The proceedings include challenges to the allocation of costs as defined by the System Agreement and allegations of imprudence by the Utility openting companies in their execution of their obligations under the System Agreement.
In June 2005, the FERC issued a decision in System Agreement litigation that had been commenced by the LPSC, and essentially affirmed its decision in a December 2005 order on rehearing. The FERC decision concluded, among other things, that:
0
, m
The System Agreement no fonger roughly equalizes total production costs among the Utility operating companies. In order to reach rough production cost equalization, the FERC imposed a bnndwidth remedy by which each company's totd annual production costs will have to be within +I- 1 I% of Entergy System average total annual production costs.
In calculating the production costs for this purpose under the FERC's order, output from the Vidalia hydroelectric power plant will not reflect the actual VidaIia price for the year but is priced at that year's average pricc paid by Entergy Louisiana for the exchange of electric e'nergy under Service Schcdulr: MSS3 of the System Agreement, thereby reducing the amount of VidaIia costs rcfl ected in the cornparkon of the UtiIity operating companies' total production costs. The remedy ordered by FERC in 2005 required no refunds and became effective based on calendar year 2006 production costs and the first reallocation payments were made in 2007.
,
The FERC's dccision reallocates total production costs of the Utility operating companies whose relative total production costs expressed as a percentagc of EnterB System average producfion costs arc outside en upper or Iower bandwidth. Under thc current circumstances, this will be accomplished by payments fmm Utility operating companies whose production costs are more than 11% below Entcrgy System average production costs to Utility operating companies whose production costs are more than the Entergy System average production cost, with payments going first to those Utility operating companies whose tohl production costs arc farthgst above the Enterm System average.
The financial consequcnccs of the FERC's decision are determined by the tohl production cost of each Utility
JFERC FORM NO. 7 (ED. 12-88) Page 123.12 1
I Name af Respondent IThis Report i5: I Date of Repart 1YearlPemd of Report 1
NOTES TO FINANCIAL STATEMENTS {Continued)
operating company, which are affected by the mix of solid fuel and gas-fired generation available to each company and the costs of natural gas and purchased power. Entergy Louisiana, Entergy Gulf States Louisiana, Enterey Texas, and EnterH Mississippi are more dependent upon gas-fired generation sources than Entergy Arkansas or Entergy New Orleans. Of these, Entersy Arkansas is the least dependent upon gas-fired generation sources. Therefore, increases in natural gas prices generally increased the amount by which Enterpy Arkansas’s total production costs were below the Entergy System avcrage production costs,
The LPSC, APSC, MPSC, and the Arkansas Electric Energy Consumers appealed the FERC’s December 2005 decision to the Unired States Court of Appeals for the D.C. Circuit. Entergy and the CiLy of New Orleans intervened in the various nppcals. Thc D.C. Circuit issued its decision in April 2008. The DG. Circuit concluded that the FERC’s orders had failed to rdcquakly explain both its conclusion that it was prohibited from ordering refunds for the 20-month period from September 13,2001 - May 2,2003 and its determination to implement the bandwidth remedy commencing on January I, 2006, rather than June 1,2005. The D.C. Circuit remanded the c a e to the FERC for further proceedings on these issucss.
In U c t o k 201 I, the FERC issued an order addrcssing the D.C. Circuit remand OR these two issues, On the first issue, the FERC conc!dcd that it did have the authority to order refunds, but decided that it would exercise its equitabIe discretion and nd rcquirr: refunds for rhc 20-month period from September 13,2001 - May 2,2003. Because the ruling on refunds relied on finding in the interruptible load proceeding, which is discussed in a separate section below, the FERC canctudcd tht the refund ruling will be held in abeyance pending the outcome of the rchedng requests in that proceeding. On the second issuG the FERC reversed its prior decision and ordered that the prospective bandwidth remedy kgin on June 1, ZOOS (the datc of its initial order in the pmcccding) rather than January 1, 2006, as it had previously ordmd. Fursum to the Octobcr 201 1 order, Entergy was required to calculate the additional bandwidth payments for he period June - Dccemkr 2005 utilizing the bandwidth formuIa tariff prescribed by the FERC that was filcd in a December 2006 compliance filing and accepted by the FERC in an April 2007 order. As is the case with bandwidth remedy payments, these payments and receipts will uItimatcly be paid by Utility operating company customers to other Utility operating company customers.
In Dccembcr 201 I, Entergy fiIcd with the FERC its compliance filing that provides the payments and receipts among the Utility opcrating companies pursuant to the FERC’s October 2011 order, The filing shows the foflowing paymcntshccipts among the Utility opcrating companies:
Payments (Receipts) (In Millions)
E n t e w Arkansas $156 Entcra Gulf States Louisiana ($75) Entew Louisiana Entergy Mississippi Entcrgy New Orleans
1F€RC FORM NO. 1 (ED. 12-88) Page 123.13 I
Name of Respondent This Report Is: Date of Report YearlPerhd of Report (1 ) An Original (Mo, Da, Yr)
N O E S TO FINANCIAL STATEMENTS (Continued)
Entergy Texas ($43)
Enterw Arkansas made its payment in January 2012. In Fcbruary 2012, Entergy Arkansas filed for an interim adjustment io its production cost allocation rider requesting that the $156 million payment be collected from customers over the 22-month period from March 2012 through December 2013. In March 2012 the APSC issued an order stating that thc payment can be recovered from retail customers through the production cosballocation rider, subject to refund. The LPSC and the APSC have requested rehearing of the FERC's October 201 1 order, In December 2013 the LPSC filed a petition for a writ of mandamus at the United States Court of Appeals for the D.C. Circuit. In its petition, the LPSC requested that the D.C. Circuit issue 3n order compelling the FERC to issue a final order on pending rehearing requests. In its rcsponse to the LPSC petition, the FERC committed to rule on the pending rehearing request before the end of February. In January 2014 the D.C. Circuit denied the LPSC's petition. The APSC, the LPSC, the PUm, and other parties intervened in the December 201 1 compliance filing proceeding, and the APSC and !he LPSC also filed pmfests.
I
Cafendar Year 2013 Produdion Costs
The Iiabiiities and assets for the preliminary estimate of the payments and receipts required to implement the FERC's remedy based on cdendar year 2013 production costs were recorded in December 2013, based on certain year-tdate information. T h e preliminary estimate was recorded based on the following estimate of the paymendreceipts among the Utility operating companies for 2014.
2014 Payments (RecciptsJ)
(ln Millions) Entergy Gulf States Louisiana $- Entergy buisiana !F- Entergy Mississippi %- Entergy New Orleans ($16) Enterm Texas $16
The actual paymentslrcccipts for 2014, based on calendar year 2013 production costs, wiIl not be calculated until the Utility operating companies' 2013 FERC Form Is have been filed. Once the calculation is completed, it wi11 be filed at the FERC. The level of any payments and receipts is significantly affected by a number of factors, including, among others, wcather, the price of alternative fuels, the operating characteristics of the Enfergy System generating fleet, and multiple factors affecting the calculation of the non-fuel rclated revenue rcquinment components of the total production costs, such as plant investment. Bntcrw Arkansas is no longer a participant in the System Agreement and is not part of the calendar year 20 13 production costs calculation.
Rough Production Cost Equalkition Rates
[FERC FORM NO. I [ED. 12-88) Page 123.14 I
Name of Respondent This Repart Is: (1) X An Origlnal
Entetgy Arkansas. In& ( 2 ) A Resubmission
Each May since 2007 Entergy has filed with the FERC the rates to implement the FERC's orders in the System Agreement proceeding, These filings show the following paymentslreceipts among the Utility operating companies are necessary to achieve rough production cost equalization as defined by t€~c FERC's orders:
Payments (Receipts)
Date of Report YearlPenod of Report (Mo, Da, Yr)
I 1 2013Q4
2007 zoos 2009 2010 2011 2012 2013 -- (In Miilions)
Entergy Arkansas $252 $252 $390 $41 $77 $41 $- Entergy G d f States Louisiana ($120) ($124) ($I 07) %- ($12) $- %- Entersy Louisiana ($91) ($36) ($140) ($22) $- ($41) 3- Entera Mississippi ($41) (S?O) ($24) ($19) ($40) z- $- Entergy New Orleans $- ($7) %- %- ($25) $- @ 15) Entergv Texas ($30) ($65) ($119) %- $- $- $15
The APSC has approved a prduction cost allocation rider for recovery fmm customers of the retail portion of the costs allocated to Entergy Arkansas. Entergy T e w proposed a rough production cost equalization adjustment rider in its September 2013 rate filing, which is pending. Management believes that any changes in the allocation of production costs resulting from fhe FERC's decision and related retail proceedings should result in similar rate changes for retail customers, subject to specific circumstances that have caused trapped costs, See "2007 Rate Filinn Based on Calendar Year 2006 Production Costs- bclow, however, for B discussion of a FERC decision that could result in tapped costs at Entergy Arkansas related to a contnct with ArnerenUE.
Enterpy Arkansas and, for December 2012 and 2013, Entergy Texas, record accounts payable and Entcrgy Gulf States Louisiana, Entersy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entersy T e w record accounts receivabIe to reflect the rough pmduction cost equalization payments and receipts required to implement the FERC's remedy. Entergy Arkansas and, for December 2012 and 2013, Entergy Texas, record a corresponding reguhtory asset for the right to cokct the payments from customers, and Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas record corresponding regulatory liabilities for their obIigations to p&ss the receipts on to customers. The regulatory 8ssct and IiabiIities art! shown as "System Agreement cost equalization" on the respective balance sheets.
2007 Rate Filinn Based on Calendar Year 2006 Production Costs
Several parties intervened in the 2007 rate proceeding at the FERC, including the AFSC, the MPSC, the Council, and the LPSC, which also filed protests. The PUCT also intervened. Intervenor testimony was fifed in which the intervenors and also the FERC Staff advocated a number of positions on issues that affect the level of production costs the individual Utility operating companies are permitted to reflect in the bandwidth calculation, including the level of depreciation and decommissioning expense for: nuclear facilities. T h e effect of the various positions would be to rcallocatc costs among the Utility operating companies. The Utility operating companies filed rebuttal testimony explaining why the bandwidth payments are properly recoverable under the AmcrenUE contnct, and expIahhg why the positions of FERC Staff nnd intcrvcnors on the other issues should be Ejected. A hearing in this proceeding conctudcd in July 2008, and the AW issued an initial decision in September 2008. The ALJ's initial decision concluded, among IFERC FORM NO. I (ED. m s ) Page j23.15 I
INarne of Respondent ITMs Report 1s: IDale of Report 1YearlPenod of Report1 (1) & An Original (Mo, Da, Yr)
Enlergy Arkansas. Inc. (2) A Resubmisskn - I I 201304 NOTES TO FlNANCfAL STATEMENTS (Continuedl
other things, that: (1) the decisions to riot exercise Entergy Arkansas's option to purchase the Independence plant in 1996 and 1991 were prudent; (2) Entergy Arkansas properly flowed a portion of the bandwidth payments through to AmerenUE in accordance with the wholesale power contract; and (3) the level of nuclear depreciation and decommissioning expense reflected in the bandwidth calculation should be calculated based on NRC-authorized Iicense life, rather than the nuclcar depreciation and decommissioning expense authorized by the retai! reglators for purposes of retail ratemaking. Following briefing by the parties, the matter was submitted to the FERC for decision. On January 1 1, 2010, rhe FERC issued its decision both afTinning and overturning certain of the AM's rulings, including overturning the decision on nuclcar depreciation nnd decommissioning expense. The FERC's conclusion related to the AmerenUE contract docs not permit Entergy Arkansas to recover B portion of its bandwidth payment fmm AmerPnUE. The Utility opcrating cornpanics rtquessted rehearing of that portion of the decision and requested clarification on certain other portions of the decision.
AmcmUE argued that its wholesale power contract with Entergy Arkansas, pursuant to which Entergy Arkansas sells power to hrnmU€, dots not permit Enfergy Arkmsas to flow through to AmerenWE any portian of Entergy Arknnseu's bandwidh payment. The AmerenUE contract expired in August 2009. In April 2008, AmerenUE filed a complaint with the FERC setking refunds, plus interest, in the event the FERC ultirnatcly dctermincs that bandwidth payments are not proprly m o v e d undcr Ihc AmerenUE contract. In rwponse to the FERC's decision discussed in the previous paragraph, Entcra Arkansas rtcorded a regulatorJl provision in !he fourth quarter 2009 for 4 potential refund to AmerenUE.
I n May 20 12, the FERC issucd an order on rehearing in the proceeding. The order may result in the rcdocation of cbsts among the Utility oprating companies, although the= are still FERC decisions pending in other System Agreement proctcding that could a f k t the rough prduction cost equalization payments and receipts. The FERC directed Enkw, within 15 days of the issuance of a pending FERC order on rehearing regarding the functionalintion of costs in Lht 2007 rntc filing to file B comprehensive bandwidth recalculation report showing updated payments and receipts in the 2007 nte filing proceeding. The May 2012 FERC order also denied Enterw's request for rehearing regarding the AmcrcnUE contract and ordered Entergy Arkansas to refund to AmercnUE thc rough production cost equalization pymcnk co!lectcd from AmerenWE, Under the terms of the FERC's order a refund of $30.6 million, including interesl, was made in June 2012. Entern and the LPSC appealed certain aspects of the FERC's decisions to the U.S. Court of Appcnis for the D.C. Circuit. On December 7,2012, the D.C. Circuit dismissed Enterp's petition for review as prematue because Entergy filed a rehearing request of the May 2012 FERC ordcr and that rehearing request is still pending. The court also ordered that the LPSC's appeal be held in abeyance and that the parties file motions to govern further proctxding within 30 days of the FERC's completion ofthc ongoing "Entcrgy bandwidth procecdings." On October 16,2013, ihe FERC issued hvo orders rekited to this pmceeding. The first order provided clarification with regard to the derivation of the d o that should be used to functionalize net operating loss caniyforwnrds for purposes of the annual bandwidth f i l i n g . The second order denied Entergy's request for rehearing of the FERC's prior determination that interest should be inchdcd on recalculated payment and receipt amounts required in this particular proceeding due to the fength of time lhat had passed. Entergy subsequently appeakd certain aspects ofthe FERC's deckions 20 the U.S. Court of Appenls for the D.C. Circuit. On January 23,2014, the D.C. Circuit returned the LPSC's appeal to the active docket and consolidated it with Entergy's petition far appellate review. The appeals are pending.
JFERC FORM NO. I (ED. m 8 ) Page 123.18 I
I
Name of Respondent
Entergy Arkansas. he.
2008 Rate Filing Rased on Calendar Year 2007 Production Costs
Thk Report is: Date of Repoit YearlPenod of Report (1) An Original (Mo, Da, Yr) (2) I A Resubmisslon I I 20131114
Seven1 parties inferoened in the 2008 rate proceeding at the FERC, including the APSC, the LPSC, and AmerenUE, which also filed protests. Several other parties, including thc MPSC and the City Council, intervened in the proceeding without filing a protest. In direct testimony filed in January 2009, certain intervenors and the FERC staff advocated a number of positions on issues that affect the level of production costs the individua! Utility operating companies are permitted to reflect in the bandwidth calculation, including the level of depreciation and decommissioning expense for the nuclear and fossil-fueled generating facilities. The effect of these various positions would be to reallocate costs among the Utility operating companies. In addition, three issues were raised alleging imprudence by the Utility operating companies, including whether the Utility operating companies had properly reflected generating units' minimum operating levels for purposes of making unit commitment md dispatch decisions, whether Entergy Arkansas*s sales to third pmkies from its retained share of the Grand Gulf nuclear facility were reasonable, prudent, and nondiscriminatory, and whether Entergy Louisiana's long-term EvangeIine gas purchase contract was prudent and reasonable.
The parties reached a partial settlement agreement of certain of the issues initially raised in this procecding. Thc partiai settlement ageement was conditioned on the FERC accepting the agreement without modification or condition, which the FERC did in August 2009. A hearing on the remaining issues in the proceeding \vas completed in June 2009, and in September 2009 the AW issued an initial decision. The initial decision affirms Enteru's position in the filing, except for two issues that may result in B reallocation of costs among the Utility operating cornpanis. In October 201 1 the FERC issued an order on the AW's initial decision, The FERC's order resulted in a minor reallocafion of paymentd~ccipts among the Utility operating compania on one issue in the 2008 rate filing. Entergy made a compliance filing in December 2011 showing thc updated paymentlrcceipt amounts, The LFSC filed B protest in rcspnse to the compliance filing, In January 2013 the FERC issued an order accepting Entergy's compliance filing. In the January 2013 order the FERC rcquired Entergy to include interest oq the recaIculated bandwidth payment and receipt nmounts for the period from June I , 2008 untii the date of the Entergy inh-system bill that will reff ect the bandwidth recalculation amounts for calendar year 2007. In February 2013, Enter= filed a request for rehearing of the FERC's ruling requiring interest. In March 2013 the LPSC filed a petition for review with the US. Court ofAppeais for the FiFtb Circuit seeking appellate review of the FERC's earlier orders addressing the AW's initial decision. The Fifth Circuit has scheduled the LFSC petition for oral argument in March 2014.
2009 Rate Filine Based on Calendar Year 2008 Production Costs
Several parlies intervened in the 2009 rate proceeding at the FERC, including the LPSC and Ameren, which nto filed protests. In July 2009 the FERC acceptcd EnterSy's proposed rates for filingl effective June 1, 2009, subject to refund, and set the proceeding for hearing and settIement prucedures. SettIement procedures were terminated and a hearing before the AW wns heid in April 2010. In August 20 t 0 the AW issued an initial decision. Thc initial decision substantially affirms Enteigy's position in the fiIing, except for one issue that may result in some reaIlocation of cos& among the Utility operating companies. The LPSC, the FERC trial staff, and Entergy submitted briefs on exceptions in
~ F E R C FORM NO. 4 (ED. 12-88) Page 123.17 I
r
Name of Respondent This Report Is: Date of Report YearlPeriod of Report (1) X An Original (Mo, Da, Yr)
Entetgy Arkansas, Inc. (2) - A Resubmission I 1 2013Q4 NOTES TO FINANCIAL STATEMENTS (Continued)
the proceeding, In May 2012 the FERC issued an order affirming the AW’s initial decision, or finding certain issues in that decision moot. Rehearing and ctarification of FERC’s order have been requested. In January 2013 the LPSC filed a protest of Entergy’s July 2012 compliance filing submitted in response to the FERC‘s May 2012 order. In October 2013 the FERC issued orders denying the LPSC’s rehearing request with respect to the FERC’s May 2012 order and addressing EnterSy‘s compliance filing implementing the FERC’s directives in the May 2012 order. The compliance filing order referred to guidance provided in a separate order issued on that same day in the 2007 rate proceeding with respect to the ratio used to functionalire net operating loss carryfonvards for bandwidth purposes and directed Entergy to make M additional compliance filing in the 2009 rate proceeding consistent with the guidance provided in that order, In November 2013 the LPSC sought rehearing of the FERC’s October 2013 order and Entergy submitted its complimce filing implementingthe FERC’s directives in the October 2013 order.
Comprehensive Bandwidth Recalculstion for 2OO7,2008. and 2009 Rate Filing Proceedinns
Enterw has committed to file a comprehensive bandwidth recalculation report reflecting the updated paymendreceipt amounts in the 2007,2008, and 2009 rate filing proceedings mentioned above in cornpbnce with the applicable FERC orders. It is probable that these pmccedings will result in a reallocation of paymenidreceipts among the Utility operating companies to achieve production cost equalization as defined by the FERC ordcrs. Based on the progress of the proceedings during the fourth quarter of 2013, Entergy was able to estimate the following range for these payments (receipts) as of Dccember 3 1,20 13:
Payments (Receipts)
Low High (In Millions)
Entergy Arkansas $30 $40 EntergV GuIf States Louisiana (W ‘W4) Enterm Louisiana (% 17) ($251 Entcrgy Mississippi $15 $25 Entergy New Orleans ($1) IW Entergy Texas (W ($15)
The Utility operating companies recorded payables tdreceivables from associated companies based on the low end ofthe estimated range. Any payments required by the Utility operating companies as a result of these rate filings are expected to bc recoverable from customers and any receipts are expected to be credited to customers. Therefore, oflsetting regulatory asscts/liabiIitics were also recorded. There is still significant uncertainty regarding the final outcome of these proceedings. As further progress is made, the estimates of the paymentdrtccipts may changc, As is the case with bandwidth rcmedy, these payments and receipts will ultimately be paid by Utility operating company customers to other Utility operating company customers.
201 0 Rate FiIinc! Based on Cnlendar Year 2009 Production Costs
In May 2010, Entergy filcd with the FERC the 2010 rata in accordancc with the FERC’s ordcrs in the System ~FERC FORM NO. I (ED, 12-8~) Page 123.18 I
Name of Respondent This Report Is: Date of Report (Mo, Da, Yr) (I) &An Original
Entargy Mansas. Ine (2) - A Resubrnissbn I I
Agreement proceeding, and supplemented the filing in September 2010. Several parties intervened in the proceeding at the FERC, including the LPSC and the City Council, which also filed protests. In July 2010 the FERCaccepted Entergy's proposed rates for filing, effective June I, 2010, subject to refund, and set the proceeding for hearing and settlement procedures. Settlement procedures have been terminated, and the A U scheduled hearings to begin in March 201 1. SubsequentIy, in January 201 1 the MJ issued an order directing the parties and FERC Staff to show cause why this proceeding should not be stayed pending the issuance of FERC decisions in the prior production cost proceeding cumnt?y before the FERC on review. ln March 201 1 the AW issued an order placing this proceeding in abeyance. In October 2013 &he FERC issued an order granting clarification and denying rehearing with respect to its October 201 I rehean'ng order in this proceeding. The FERC clarified that in a bandwidth pmeeding parties can challenge erroneous inputs, hpIemcntation errors, or prudence of cost inputs, but chaIlenges to the bandwidth formuta itself must be raised in a FederaI Power Act section 206 complaint or section 205 filing. Subsequently in October 20 13 the presiding AW lifted the stay order hoiding in abeyance the hearing previously ordered by the FERC and directing that the remaining issues proceed to a hearing on the merits. The hearing is scheduIed for March 2014.
YearlPeW of Report
miw4
201 I Rate Filinp Based on Cnlendar Year 2010 Production Costs
In May 201 1, Entergy filed with the FERC the 201 1 rates in accordance with the FERC's orders in the System Agreement proceeding. Seven1 parties intervened in the proceeding at the FERC, including the LPSC, which abo filed B protest. In July201 1 the FERC accepted Enter& proposed rates for filing, effective June I, 2011, subject to refund, set the proceeding for hearing procedures, and then held those pmedures in abeyance pending FERC decisions in the prior production cost proceeding currcntly before the FERC on =view. In January 20 14 ihe LPSC filed a petition for a writ of mandamus at the United States Court of Appeals for the Fifth Circuit, In its petition, the LPSC requested that the FiAh Circuit issue an order compelling the FERC to issue B final order in several proceedings related to the System Ageemcnt, including the 201 1 rate filing based on calendar year 2010 production costs and the 2012 and 2013 rate filings discussed helow.
-
2012 Rate FiIino BAsed on Calendar Year 201 1 Production Costs -
In May 2012, Entera filed with the FERC the 2012 rates in accordance with the FERC's orders in the System Agreement proceeding. Seven1 parties intervened in the proceeding at the FERC, including the LPSC, which also filed a protest. In August 2012 the FERC accepted Enter& propostd rates for fdirg, effective June 2012, subject to refund, set thc procceding for hearing proccdum, and then held those pmedures in nbeymce pending FERC decisions in the prior production cost proceedings currcntly before the FERC on review.
2013 Rate FilinEBased on Calendar Year 2012 Production Costs
In May 2013, Entcrsy filed with the FERC the 2013 rates in accordance with the FERC's orders in the System Agreement proceeding. Several parties intervened in the proceeding at the FERC, including the LPSC, which also filed a protest. The City Council intervened and filed comments related to including the outcome of a related FERC proceeding in the 2013 cost equalization calculation, In August 2013 the FERC issued an order accepting the 2013 rates, e f fcch
IFERC FORM NO. t (ED. l a 8 1 Page 123.1 9 1
Name of Respondent This Report Is: Date of Report (1) An Original (Mo, Da, Yr)
Tnferruptible b a d Proceeding
YearlPehod of Report
In April 2007, the U.S. Court of Appeals for the D,C. Circuit issued its opinion in the LPSC’s appeal of the FERC’s March 2004 and April 2005 orders d a t e d to the treatment under the System Agrccment of the Utility operating companies’ infemptible Ioads. In its opinion the DE, Circuit conchded that the FERC ( I ) acted arbitmriIy and capriciously by allowing the Utility operating companies to phase-in the effects of the elimination of the intemptible load over a IZmonth period of time; (2) failed to adequately explain why refunds could not be ordered under Scction 206(c) of the Federal Power Act; and (3) exercised appropriately its discretion to defer addressing the cost of suIfur dioxide allowances until a later time. The D.C. Circuit remanded the matter to the FERC for a more considered determination on the issue of =funds. The FERC issued its order on remand in Septmbcr 2007, in which i t directed Entergy to make a compliance filing removing all interruptible load from the computation of peak load responsibility commencing April 1,2004 and to issue any necessary refunds to reflect this change. In addition, the order directed the Utility operating companies to make refunds for the period May 1995 through July 1996. In November 2007 the Utility operating companies filed a refund report describing the refunds to be issued pursuant to the FERCs orders. The LPSC filed a protmst to the refund report in December 2007, and the Utility operating companies filed an answer to the protest in January 2008. The refunds were made in October 2008 by the Utility operating companies that owed refunds to the Utility openting companies that were due a refund under the decision. The APSC and the Utility operating companies appealed the FERC decisions to the D.C. Circuit. Because of its refund obligation to its customers FS a result of this pmccding nnd n related LPSC proceeding, Entern Louisiana recorded provisions during 2008 of approximately $I 6 million, including interest, for rate refunds. The refunds were made in the fourth quarter 2009.
Entergy Arkansas, Ine.
Following the filing of pctitioners’ initial briefs, the FERC filed a motion requesting the D.C. Circuit hoId the appeal of the FERC’s decisions ordering refunds in the interruptible load proceeding in abeyance and remand lhc record to the FERC. Tfie D.C. Circuit granted the FERC‘s unopposed motion in June 2009. In December 2009 the E R C established a paper hearing to determine whether the FERC had the authority and, if so, whether it would be appropriate to order refunds resulting from changes in the treatment of interruptible Ioad in the alIwcation of capacity costs by the Utility opcmling companies. In August 2010 the FERC issued an order stating that it has the authority and refinds are appropriate. The APSC, MPSC, and Enteqy requested rehearing of the FERC’s decision. In June 20 1 1 the FERC issued an order granting rehearing in part and denying rehcnring in part, in which the FERC determined to invoke its discretion to deny refunds. The FERC held that in this case where “the Enter# system as a whole collected the proper IeveI of revenue, but, as was later established, incorrectly allocated peak load responsibility among the various Entera operating companies .... the Commission wilt apply here our usual practice in such cases, invoking our equitable discretion to not order refunds, notwithstanding our authority to do so.” The LPSC has requcstcd rehearing of the FERC’s June 2011 decision. In October 201 1 the FERC issued nn ”Order Establishing Paper Hearing” inviting parties that oppose refunds to f i l e briefs within 30 days addressing the LPSC’s argument that FERC precedent supports refunds under the circumstanccs present in this procceding. Parties that favor refunds were then invited to file reply briefs within 21 days oFthe date that the initial briefs are due. Briefs were submitied and the matter is pending.
(2) A Resubmission I t 2013M4
(FERC FORM NO. 1 (ED. 12-88) Page 425 20 I
Name of Respondent This Report Is: (1) &An Original
Entargy Arkansas, Inc. (2) I A Resubmission
In September 2010 the FERC had issued an order setting the refund report filed in the proceeding in November 2007 for hearing and settlement judge procedures. In May 20 I 1, Entergy filed a settlement agreement that resolved 311 issues relating to the refund report set for hearing. In June 201 1 the settlement judge certified the settlement as uncontested and the settlement agreement is currently pending before the FERC. In Jury 201 I , Entcrgy filed 3n amendedlcorrected refund rcpott and a motion to defer action on the settlement agreement until after the FERC rules on the LPSC's rehearing request regarding the lune 201 1 decision denying refunds.
Date of Report YearlPenod of Report {Mo, Da, Yr)
I I 201 3144
Prior to the FERC's June 201 1 order an rehearing, Entergy Arkansas filed an application inNovember 2010 with ihe APSC for recovrry of the refund that it paid. The APSC denied Enteqg Arkansas's app!ifation, and also denied Entergy Arkansas's petition for rehearing. If the: FERC were to order Entergy Arkansas to pay rcfunds on rehearing in the interruptible load proceeding the APSC's decision would trap FERGapproved costs at Entersy Arkansas with no regulatory-opproved mechanism to recover them. In August 201 1, Entergy Arkmsas filed a complaint in the United States District Court for the Eastern District of Arbmas asking for a declaratory judgment that the rejection of Entergy Arkansas's appkation by the APSC is preempted by the Federal Power Act. The APSC filed a motion to dismiss the complaint. In April 2012 the United States district court dismissed Enterw Arkansas's complaint without prejudice stating that Entergy Arkansas's claim i s not ripe for adjudication and that Entergy Arkansas did not have standing to bring suit ot this time.
In March 2013 the FERC issucd an order denying the LPSCs request for rehearing of the FERCs June 201 1 order wherein the FERC concluded it would exercise its discretion and not order refunds in the interruptible toad proceeding. Dased on its review of the LFSC's request for rehearing and the briefs filed as part of the paper hearing established in October 201 1, the FERC affirmed its earlier ruling and declined to order refunds under the circumstances of the case, In May 20 13 the LPSC fiIcd 3 pctition for review with the U.S. Court of Appeals for the D.C. Circuit seeking review of FERC prior orders in the Intermptible Looad Proceeding that concluded that the FERC would exercise its discretion m d not order refunds in the prmeeding. The appeal is pending.
Enterm Arkama.r Opvnrfunity Sales Proceediq
In Junc 2009, the LPSC filed a complaint requesting that the FERC determine that certain of Entergy Arkansas's sales of eIectric energy to third parties: (a) viohted the provisions of the System Agreement that allocate the e n e r a generated by Entergy System resources, (b) imprudently denied the Entergy System md its ultimate consumers the benefits of Iow-cost Entcra System generating capacity, and IC) violated the provision of the System Agreement that prohibits sales to third parties by individud companies absent an offer of a right-of-first-refusal to other Utility operating companies, The LPSC's complaint challcngcs sales made beginning in 2002 and requests refunds. On July 20,2009, the Utility operating companies filed a response to the complaint requesting that the FERC dismiss the complaint on the merits without hearing because the LPSC h x failed to meet its burden of showing any violation of the System Agrement and failed to produce any evidence of imprudent action by the Entera System. I n their response, the UtiIity operating companies explained that the System Agreement clearly contempIates that the Utility opiating companies may make sales to third parties for their own account, subject 'to the requirement that those sales be inciuded in the Ioad (or Ioad
IFERC FORM NO. 1 {ED. 12-88) Page 123.21 I
1
Name of Respondent This Report Is: (1) &An Original
Entargy Arkansas. he, A Resubmisslon
shape) for the applicable Utility operating company. The response further explains that the FERC already has determined that Entergy Arkansas's short-term wholesale sales did not trigger the "right-of-first-refusal" provision of the System Agreement. While the D.C. Circuit recently determined that the "right-of-fmt-refusaI" issue was not properly before the FERC at the time of its earlier decision on the issue, the LPSC has raised no additional claims or facts that would warmnt the FERC reaching a different conclusion.
Date of Report YearlPeriod of Report {Mo, Da, Yr)
I I 20?3tP4
The LPSC filed direct testimony in the proceeding alleging, among other things, (1) that Entergy vio?ated the System Agreement by permitting Entergy Arkansas fo make non-requirements sales to non-affiliated third parties rather than making such energy available to the other Utility operating companies' customers; and (2) that over the period 2000 - 2009, these nm-requirements sales caused harm to the Utility opemting companies' customers and these customers shou?d be compensated for this harm by Entergy. In subsequent testimony, the LPSC modified its original damages claim in favor of quantifying damages by re-mnning intra-system bills, The Utility operating companies believe the LPSC's allegations are without merit. A hearing in thc matter was held in August 20 IO.
In December 2010, thc ALJ issued an initial decision. The AW found that the System Agrcement allowed for Enterm Arkansas to make the sales to third parties but concluded that the sales should be accounted for in the same manner BS joint account sales. The A U concluded that "sharcholdcrs" should make refunds of the damages to the Utility opemting companies, along with interest. Enterpy disagreed with several aspects of the Am's initial decision and in January201 1 filed with the FERC exceptions to the decision.
The FERC issued a decision in June 2012 and held that, while the System Agreement is ambiguous, it does provide authority for individual Utility operating companies to make opportuniq sales for their uwn account and Enterm Arkansas made and priced these sales in good faith. The FERC found, however, that the System Agreement does not provide authority for nn individual Utility opcrating compnny to affoccate the energy associated with such opportunity sales as pa^ of its lond, but provides a different allocation authority. The FERC further found that the after-the-fact accounting ntethodolojg used to allocate thc encrgy used to supply the sales was incansislent with the System Agreement. Quantifjring the effect of the FERC's decision will requife re-running intra-system bills for a ten-year period, and the FERC in its decision established further hearing proccdum to determine the calculation of the effects. In July 2012, Entergy and the LPSC filed requests for rehearing of the FERC's June 2012 decision, which arc pending with the FEW,
As required by the procedural schedufe established in the calculation proceeding, Entergy filed its direct testimony that included ti proposed illustrative re-run, consistent with ibe dircctives in FERC's order, of intra-system bills for 2003,2004, and 2006, the three years with the highest volume of opporhmiv sales. Entergy's proposed illustrative re-run of intra-system bilk shows that the potential cost for Enterm Arkansas would be up to $12 million for the yean 2003, 2004, and 2006, and the potential benefit wodd k significantly less than that for each or the other Utility operating companies. Entergy's proposed illustrativc ~e-mn of the intra-system bills also shows an offsetting potentia! benefit to Entergy Arkansas for the years 2003,2004, and 2006 resulting from the effects ofthe FERC's order on System Agreement Servicc ScheduIes MSS-I, MSS-2, and MSS-3, and the potential offsrtting cost wouId be significantly Iess than that for each of the other Utility operating companies. Entergy provided to the LPSC an illustrative intra-system bill
~FERC FORM NO. I (ED. 12-88) Page 123 22 J
.. Name of Respondent Thls Report is: Date of Report YearlPeriod of Report
(I) An Original (Mo, Da, Yr) Entergy Arkansas, hc (2) - A Resubmission ' I I 20333Q4
NOTES TO FINANCIAL STATEMENTS (Continued)
recaIculation BS specified by the LPSC'for the years 2003,2004, and 2006, and the LPSC then filed answering tstirnony in December 2012. In its testimony the LPSC claims that the damages that should be paid by Entergy Arkamas to the other Utility operating company's customers for 2003,2004, and 2006 are $42 million to Entcrgy Guif States, Inc., $7 million to Entcrgy Louisiana, $23 million to Entergy Mississippi, snd $4 million to Entergy New Orleans. The FERC staff and certain intervenors filed direct and answering testimony in February 2013. In April 2013, Entergy filed its rebuttal testimony in that proceeding, including revised illustrative re-run of the intra-system bills for the years 2003, 2004, and 2006. The revised cakulation determines the repricing of the opportunity sa?= based on consideration of moveable reesourccs only and the remOV81 of exchange energy received by Entergy Arkansas, which increases the potentia! cost for Entergy Arkansas over thc three years 2003,2004, and 2006 by $23 million from the potentia! costs idcntificd in the Utiiity operating companies' prior filing in September and October 2012. A hearing ww held in May 2013 to quantify [he &ect of repricing the opportunity sales in accordance with the FERC's decision.
In August 2013 the presiding judge issued an initial decision. The initial decision concluda that the methdofom proposed by the LPSC, rather thnn the methodoIogies proposed by Entergy or the FERC Staff, should be used to cakulntc thc paymmnts that Entergy Arkansas is to make to the other Utility operating companies. The initid decision abo concludes that the other System Agreement service schedulw should not be adjustcd and that payments by Entersy Arkansas should not bc r c k t c d in h e rough production cost equaht ion bandwidth calmufations for She applicable ycars. The initial decision does- recognize that the LPSC's rnethodoloa would muIt- in an inequitable windfall to thc olhcr UtiIhy qxnting companies and, therefoR, conc?udes that any payments by Entergy Arkansas should be rcduccd by 20%. 7ht Utility opcrating companies are currently analyzing the effects of the initial decision. The LPSC, APSC, City Council, and FERC staff filed briefs on exceptions andor briefs opposing exceptions. Enterw filed a brief on exceptions requesting that FERC reverse the initial decision and R brief opposing certain exceptions taken by the LFSC and FERC staFT. Thc FERC's review of the initial decision is pending. No payments will be made or received by thc Utility o p t i n g cornpanics until the FERC issues an order reviewing-the initial decision and Entergy submits a subsequmt filing to comply with that order.
S f n m Cost Recovrrv Fillnes with Retail Rrpulators
Enterm Arkansas December 2012 WinterStom
In December 2012 a severe winter storm consisting of ice, snow, and high winds caused significant damage to Entersy Arkansas's distribution fines, equipment, poles, and other facilities. Total restoration costs for the repair andlor replacement of Entergy Arkansas's electrical facilities in areas damaged from the wintcr storm were $63 million, including costs recorded as regulatory assets of approximately $22 million. In the Entergy Arkansas 2013 rate case, the APSC approved inclusion ofthe construction spending in rate base and approved an increase in the normal storm cost accrual, which will effectively amortize !he regulatory asset over a five-year period.
NOTE 3. INCOMETAXES
~FEKC FORM NO. i (ED. 12-88) Page 123 23 I
h a m e of ResDondent IThrs Renort Is; 1 Date of Report IYearlPeriod of Repor€ I Erilerqy Arkansas. tnc.
(MO, Da, Y r ) I I 2 0 1 m
Details regarding income byes are presented on FERC Form I pages 261-267 and 272-277.
Carrvovers
The Registrant Subsidiaries' estimated tau attributes carryovers and their expiration dates as of Dccember31, 2013 are as follows:
Entergy Entergy Entergy Gullstates Entergy Entergy New Enttrgy System
Arkansas Louisiana LoulsIana MbsLsIppI Orleans Texas Energy
Federal net operating lossw $ I 3 bilIion $280 million 12 billion $82 million $56 miIlion - $583 miliion Year(s) of expiration 2029-203 1 2029-2032 2028-2033 2029-2032 2030-2032 NIA 2029-2032
State net operating losses $109 million f685 million $2.8 billion I 523 million - I
Ycar(s) of expiration 2024-2026 2025-2027 2024-2027 NIA 2026-2027 NIA N/A
Mkc. federal credits $2 rnilIion $1 million $3 million $I million SI million - 0 million Year(s) of expiration 2024-2032 2024-2032 2026-2032 2024-2032 2024-2032 NIA 2024-2032
State credits - I - $12.4 million - $3.9 million SI 8.8 miltion Ycar(s) of expiration NlA NIA NIA 2014-2018 NIA 2014-2027 20 15-20 t 8
As a result of the accounting for uncertain tau positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operatink loss carryovers and tau credit carryovers.
Unrecopnized tax hcnefiits
Accounting standards establish a "more-likely-th;in-not" recognition threshold that must be met &fore a h~ benefit can be recognized in the financial statements. If a h x deduction is taken on a fax return, but does not meet the more-likeiy-fhan-not recognition thrcshold, an increase in income ta liability, above what is payable OR the tzu return, is required to be recorded.
A reconciliation of the Registrant Subsidiaries' &ginning and ending amount of unrecognized tau benefits for 2013,2012, and 201 1 is as follows:
Entergy Entergy Entergt Gulf States Entergy Eafergy New E n t e w Sysfcm
2013 Arknnsas Loubfana Louisiana Mississippi Orleans Te*as Eaeqg ~FERC FORM NO- i (ED. ir-ss) Page 123.24 1
Name of Respandent Thts Report is: Date of Report (Mo, Da, Yr) (1) z h Oilginat
Entergy Arkansas. f n c (2) - A Rerubmlsslon I I
(In Thousands) Gross balance at Januasy I, 2013 $344,669 $465,721 $536,673 $16,841 $52,018 $13,954 $260,346 Additions based on t ~ . u positions dated to the cumnt year 6,427 7,276 1O,61 1 957 5 83 2,170 4,170 Additions for tax positions of prior
Reductions for tax positions of prior
SettIements (668) (66) (15276) (72) (3,466) 492 (6,755) Gross balance at December 3 I, 20 13 347,7 13 465,075 6 1 1,605 16,186 51,679 13,017 265,185 ORsets to gross unrecognized tau bencfits:
Unrecognized tax bencfits net of unused tau
years 1,228 7,189 1 18,025 401 3,506 587 8291
Ye= (3,943) (15,045) (38,423) 11,941) (962) (4,186) (967)
h s s carryovers (345,674) (136,151) (611,605) (16,186) (22,078) (266) (225,286) b -
YearlPericd of Report
2OIYQ4
attributes and payments $2,039 5328,924 $- $- $29,601 $12,751 $39,899 ------
Entew Entergy Entergy Gulf Statu Eutergy Enteqg New Entergy System
20 12 Arkansas Louisiana Louisiana Mississippi Orleans Texas Encqy
Gross balance at Janumy 1,2012 Additions based on fax positions related to the current year Additions for ~ L K positions of prior Ye= Reductions for tau positions of prior years Settlements Gross balance at December 3 1,2012 Offsets to gross
(In Thoussands)
$335,493 $390,493 $446,187 $II,052 $56,052 $19,225 $281,183
10,409 8,974 67,72 1 8,4O I 497 1,656 8,7 15
429,232 392,548 33 1,432 4,057 445 4,834 271,172
(39,534) (5031: 8) ( I 69,465) (5,703) (2,506) (1 1,649) (20,934) (I 12) (279,790) - (390,93 1) (275,776) (139,202) (966) (2,470)
344,669 465,721 536,673 I6,84 1 52,O 18 13,954 250,346
I FERC FORM NO. i (EO. 12-88) Page j23 25 I
Name of Respondent
Enlergy Arkansas. Ink
unused tax nttributes and payments S2,542 $304,766 $- $- $16,507 $12,361 $ 10,922 -------
This Report Is: Date of Report YearlPeriod of Report (1) X An Original (Mo, Da, Yr) (2) I A Resubmission * I f 2013x14
Entersy Entergy Entergy GuIIStates Entergy Entergy New Entergy System
Arkansas Loutiana Imuisiana Mississippi OrIeans Texas E n e w - 2011 (m T ~ ~ I J S Z U I ~ S )
Gross balance at January 1,20 1 1 $240,239 $353,886 $505,18X $24, I 63 $1 8,176 S 14,229 $2243 1 8 Additions based on t x t pit ions rclattd to the currcnt year 11216 9.3 98 8,748 457 50,212 1,760 44,419 Additions for tax positions orprior years 44,202 50,944 2 f ,052 2 1,902 7,343 7,533 . 14,200 Reductions for t ~ x positions of prior years (335) (21,7193 (27,991) (5,022) ( 12,289) (3,432) (4,942) Settl-menrs 43.091: (2,016) (60,810) (30,448) (7,390) (865) 2,988
Gross balance at December31,20tI 33 5,4 93 390,493 446,187 11,052 56,652 19,225 281,183 Offsets fo gross unrecognized k x benefits:
Loss carryovers ( 146,429) (263 94) - (2 16,720) (5,930) (I,21 I ) (10,645) (10,752) Cash paid to taving authorities (75,977) (45,493) I (7,556) (1,174) (1,376) (41,878)
Unrecognized ILK benefits net of used tax attributes and payments SI 13,087 $3 18,606 $229,467 ($2,434) $53,667 $7,204 $228,553
-----I--
The Registrant Subsidiaries’ balances of unrecognized !ax benefits included amounts which, ifrecagnized, would have reduced income tar expense as follows:
December 31, December 31, December 31, 2013 2012 201 f
(In Millions)
IFERC FURM NO. 1 (ED. 12-88) Page 123.26 1
'Name of Respondent This Report Is: (1) X An Original -
Date of Report YeadPeriod of Report (Mo, Da, Yr)
Entergy Arkansas, fnc. (2) I A Resubmisslon I 1 2013M4 N O E S TO FINANCIAL STATEMENTS (Continued)
Entergy Arkansas $0.6 Entergy Gulf Sat= Louisiana $44.0 Entergy Louisiana $87,9 Entergy Mississippi $3.9 Entergy New Orleans c Entersy Texas $10.1 Sys tern Energy $3 3
$0.6 $7
$44.0 $107.9 $92.4 $28 1.3
$3.9 $3.8 %- %-
$8.6 $73 $35 t
The Registrant Subsidlaits accrue interest and penali,Ls related to unrecognized tax "enefits in income tax expense. Penalties have not been accrued, Accrued balances for the possibIe payment of interest arc as follows:
December 31, December 31; Dccember31, 2013 2012 2011
(In Millions) EntergV Arkansas $1 5 2 $21.8 $1 1.4 Entergy Gulf Smtes Louisiana O? 7.0 $33.1 $14.4 Entergy Louisiana $1.0 $0.9 S0.8
Entergy New Orleans $0.9 $0. I $2.4 Entergy Te.w $O.S $0.7 $0. I
Enterpy Mississippi $2.1 $2.4 $1.7
System Energy !§ 19.0 $333 $18.5
Iacome Tax Wtfpation
2000 Tax Year
In February 2008 the IRS issued a Statutory Notice of Deficiency for the year 2000. The deficiency resulted from a disaftowance of foreign tax credits (the same'issue discussed above) as wcli s the didowance of depreciation deductions on non-utility nuefear plants. Entergy filcd a Tau Court petition in May 2008 chnllenging the I R S treatment of these issues. In June 2010 n trial on the depreciation issue was held in Washington, D.C. fn February 201 1 B joint stipulation of settled issues was filed under which the IRS conceded its position with respect to the depreciation issue, The outcome of the foreign txx credit matter for the year 2000 is tffectiveIy settled in Entergy's favor as determined by the U.S. Supreme Court's unanimous decision in the PPL proceeding in May 2013 as discussed above.
Income Tax Audits
Entcrgy nnd its subsidiarics file U S fcdenl and various state and forcign income tzx returns. IRS cmcaminations are substantially completed for years before 2009. All state taxing authorities' examinations are completed for years before 2005.
200.12005 IRS Audit
~FERC FORM NO. i (ED. 12-88) Pegs 323 27 1
Name of Respondent Thb Report is: Date of Report (1 1 An Original (Mo, Da, Yr)
In Junc 2009, Entergy filed a formal protest with the 1RS Appeab Division indicating disagreement with certain issues contained in the 2004-2005 Revenue Agent's Report (FUR), The most significant issue disputed was the inclusion of nudear decommissioning liabilities in cost of goods sold for the nuclear power plants owncd by the UtiIhy resulting from an Application for Change in Accounting Method for txu purposes (the "2004 CAM).
YeadPeriod of Report
During the fourth quarter 2012, Entergy settled the position refating to the 2004 CAM. Under the settlement Entcrgy conceded its tax position, resulting in an increase in txable income of approximately $2.97 billion for the h~ years 2004 - 2007. The settIemcnt provides !hat Entergy Louisiana is entitled to sdditional ta?r depreciation of approximately $547 million for years 2006 and beyond. T h e defemd tax asset net af interest charges associated with the settlement is $155 million for Entergy. There was a related incrcase to Entcrgy Louisiana's member's equity account.
Enter# Arkansas. Inc (2) A Resubmisslon I t 20t3Q4 NOTES TO FINANClAt STATEMEMS (Contlnud)
200iS2007 IEE Audit
The IRS issued its 2006-2007 RAR in October 201 1. in connection with the 2006-2007 IRS audit and muIting MR, Entern resolved !he significant issues discussed below.
In August 201 1, Enterw entered into a settlement agreement with the IRS relating to the mark-tpmarket income tau treatment of various wholesale electric power purchase and sale agreements, including Entergy htlisiana's contract to purchase electricity from the Vidalia hydroeIectric facility. See Note 8 to thc financial statements for further dctaiIs regarding this contract and a previous LPSGapproved settlement regarding the t i~x treabnent of the confmct.
With respect to income tau accounting for wholesde electric power purchase apements, Entergy recognized income for tau purposes of approximately 31.5 billion, which represents a reversal of previoudy deducted temporary difI'ercnccs on which deferred tax= had been provided. Also in connection with this settlement, Entergy recognized a gain for income tx~ purposes of approximately $1.03 billion on the famation of B whotly-owncd subsidiary in ZOOS with axorresponding step-up in the tax basis of deprcciable assets resulting in additional tax depreciation at Entergy Louisiana. Because Entergy Louisiana is entitlcd to deduct additional tax depreciation of $1.03 billion in the future, Enterw Louisiana recorded a deferred t ~ x asset for this additional tax basis. T h e tar expense associated with the gain is offset by recording the dcfcrred tau asset and by utilization of net operating losscs. With the recording of the dcferrcd tau asset, there was a corresponding increase to Entergy Louisiana's member's equity account, The agreement with the JRS effectively settled rhe hu treatment of varioui wholesale electric power purchase and sale agreements, resdting in the reversnl in third quartcr 201 1 of approximately $422 million of deferred tau liabilities and liabilities for uncertain tax positions at Entergy Louisianq with a corresponding reduction in income tau expense. Under the terms of an LPSGnppmved final settlement, Entergy Louisiana recorded a $199 million regulatory charge and a corresponding regulatory liability.
'
After consideration of the taxable income recognition and the additional depreciation deductions provided for in the settlement, Enter& nct operating toss carryover was reduced by approxhately $2.5 billion.
~FERC FORM NO. i (ED. 12-88) Page i23.28 I
Name of Respondent This Report Is: Date of Report (Mo, Da, Yr) (1) X An Original
EnkrgyAl)tansas, Ine. (2) - A Resubmisslon I t
2008-2009 JR3 Audit
YearlPeriod of Report
20t3iQ4
In the third quarter 2008, Entergy Louisiana and Entergy Gulf States Louisiana received $679 million and $274.7 million, respectively, from the Louisiana Utilities Restoration Corporation ('LURC"). These receipts from LURC were from the proceeds of a Louisiana Act 55 financing of the costs incurred to restore service following Hurricane Katrina and Hurricane Rita, See Note 2 to the financial statemenfs for further details regarding the financings.
In June 2012, Entergy effectively settled the tax treatment of the storm restomation, which resulted in an increase to 2008 ta?iable income of $129 million for Entergy Louisiana and $104 million for Entergy Gu!f States Louisiana and a reduction of income tax expense of $172 million, including $143 million for Entergy Louisiana and $20 million for Entergy Golf States Louisiana. Under the terms of an LPSGapproved settlement related to the Louisiana Act 55 financings, Entergy Louisiana and Entera Gulf States Louisiana recorded, respectively, a $137 million ($84 million net-of-tau) and a $28 million ($17 million net-of-tax) regulatory charge and a corresponding regdatory Siability to reflect their obligations to customers with respect to the settlement.
In the fourth quarter 2009, Entergy filed Applications for Change in Accounting Method (the 'YO09 CAM") for tar purposes with the US for certain costs under Section 263A ofthe Internal Revenue Code. In the Applications, Entergy proposed to treat the nucIcar decommissioning liability associated with the operation of its nuclear power plants as a production cost properly includabIe in cost of goods sold. The effect of the 2009 CAM was 8 $5.7 billion reduction in 2009 taxable income, The 2009 CAM was adjusted to $93 billion in 2012.
Tn the fourth quarter 2012 the IRS disaliowed the reduction to 2009 taxabb income related to the 2009 CAM. In the third quarter 2013, the InternaI Revenue Service issued its RAR for the tax years 2008-2009. A5 a result of the issuance of this RAR, Entergy and the IRS resolved all of the 2008-2009 issues described above except for the 2009 CAM, Entergy disagrees with the 1RS's disallowance of the 2009 CAM and filed a protest with the I R S Appeals Division on October 24,2013. The issuance of the RAR by the IRS effectively settles all othcr issues, which resulted in an adjustment to the provision*for uncertain tau positions.
Other Tax Maftem
Entersy regutarIy negotiates with the IRS to achieve settlements. The results of all pending litigations and audit issues could result in significant changcs to the amounts oFunrecognized bx benefits, as discussed above.
In March 2010, Entergy filed an Application for Change in Accounting Method with the IRS. In the application, Entc ra proposed to change the definition of unit of property for its generation ersscts to determine the appropriate characterization of costs associated with such units as capitat or repair under the Internal Revenue Code and related Treasury Regulations. The effect of this change wns an approximate $13 billion reduction in 201 I taxable income for EntcrD, including reductions of $292 million for Entera Arkansas, $132 million for Entew Gulf States Louisiana, $185 million for Entcrgy Louisiana, $48 million for Enter= Mississippi, $45 million for Entergy Texas, $13 million for Entergy New Odenns, and $1 80 million for System Energy.
JFERC FORM NO. I (ED. 12-38) Page 123.29 I
Name of Respondent Thls Report Is: Date of Report (t)XAn OriginaI (Mo, Da, Yr)
Entargy Arkansas, lnc. (2) - A Resubmission I t
In September 2013 the IRS issued final regulations that provide guidance on the deductibility and capitalization of costs incurred associated with tangible proprty. Although Enterpy continues to snalyze these regulations, which contain numerous complex provisions, Entergy cumntIy estimates that the effect of the regulations woutd resurt in a $348 million reduction of Entergy's 2014 repairs and maintenance tm dcduction, including decreases in the deduction of $1 14 million for Entergy Arkansas, $34 million for Enterjy Gulf States Louisiana, $22 million fur Entergy Louisiana, $43 rniliion for Entergy Mississippi. $137 million for Entcrgy Texas, and an increase of$2 million for Enteqg New Orleans.
YearlPericd of Report
2013M4
During the second quarter 201 1, Enterm filed an Application for Change in Accounting Method with the IRS related to the allocation of overhead costs between production and non-production activities. The accounting method affects the amount of overhead that will be capitaIized or deducted for tax purposes. The accounting method is expected to be impIemented for the 2014 ta?r year,
Tn March 2013, Entergy huisiana distributed to its parent, Enterpy Louisiana Holdings, Inc., Louisiana income txx credits of W . 6 miIlion which resulted in a decrease in Entergy Louisiana's member's equity accuunt.
NOTE 4. R E V O L W G CREDJT FACILITIES, LlNES OF CIZEDIT, AND SHORT-TERM BORROWINGS
Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 3 !, 2013 as foIiows:.
Amount Drawn as oT
ExpIra tion Amount of Intrrcst Rate December 3 I, Company Date Facility (a) 2013 - * 520 million (b) 1.75?0 -
Entergy Arkansas March2018 $150 million (c) 1.67% - Entergy Gulf States Louisiana March 201 8 S 150 million Id) 1.67% c
Entergy Louisiana March2018 $200 million (e) I .67% - Entergy Mississippi May 2014 $35 million (f) I .92% - Entergy Mississippi May 20 14 $20 million ( f ) 1.92% - Enteqg Mississippi May2014 $37.5 million (0 i .92% - Entergy New Orleans November 201 4 $25 million (g) 1 .a% - Entergy Texas Match 201; 8 S t 50 million (h) 1.92% I
Entergy Arkansas A p d 2014
(a)
(b)
The interest rate is the rate DS of December 3 1,2013 that would be applied to outstanding bomowings under the
The credit facility requires Entcrgy Arkansas to maintain a debt ratio of 65% or less of its totat capitalization. Enterw Arkansas is in compliance with this covenant. Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts rcceivabk.
(c) The credit facility allows Enter= Arkansas to issue letters of credit against 50% orthe borrowing capacity of the ~FERC FURM NO. I (EO. w a ) Page 123.30 I
facility.
I
Name of Respondent This Report is: (1) X An Qdghal
Date of Report YearlPeriud of Report (Mo, Da, Yr)
Entern Arkansas. k (2) I A Resubmission I t 20t3m4 NOTES TO FINANCIAL STATEMENTS (Cantmud)
facility. As of December31,2013, $03 million in letters of credit were outstanding. The credit facility requires Entergy Arkansas to maintain a consolidated dcbi ratio of 65% or less of its total capitalization. Entergy Arkansas is in compliance with this covenant. The credit facility aIIows Entergy Gulf Statcs Louisiana to issue Ictters of credit against SO% of the borrowing capacity of the facility. As of December 3 I , 2013, $153 million in letters of credit were outstanding. The credit facility requires Entergy Gulf States Louisiana to maintain a comolidatcd debt ratio of 65% or less of its total capitalization. Entergy Gulf States Louisiana is in compliance with this covenant. The credit facility allows Entergy Louisiana to issue fetters of credit against 50% of the borrowing capacity of the facility. As of December 31,2013, $7.0 million in Iettcrs of cmdit were outstanding. The credit facility requires Entergy Louisiana to maintain a consolidated debt ratio of 65% or icss of its total: capitalization. Entcrsy Louisiana is in compliance with this covenant. The credit facilities require Entergy Mississippi to maintain a debt ratio of 65% or less of its totaI wpitakation. Entergy Mississippi is in compliance with this covenant. Borrowings under h e Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable. The credit facility requires Entergy New Orleans to maintain a debt ratio of 65% or less of its total capitalization. Entersy New Orleans is in compliance with this covenant. The credit facility allows Enterjg Texas to issue Ietters of credit against 50% of the borrowing capacity of the facility. As of December31, 2013, $25 million in letters ofcredit were outstanding. The credit facility ~equires Entergy Texas to maintain ~l consolidated debt ratio of 65% or less of its total capitalization. Entergy Te.w is in compliance with this covenant.
The facility fccs on the crcdit facilities range from 0.125% to 0.275% of the comrnitmcnt amount.
The short-term bornwings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. The current FERC-authorized limits arc effective through October 31, 2015. In addition to bornwings from commercial banks, these companies are authorized under a FERC order to borrow from the Entergy System money pool. T h e money pool is an inter-company borrowing amngement designed to reducc the Utility subsidiaries' dependence on extemai ' short-term bornwings. Borrowing from the money pool and external borrowings combined may not exceed the FERC-authorized limits. The following are the FERGauthorked limits for short-term borrowings and the outstanding short-term borrowings BS of Dcccrnber 3 I, 2013 (aggregating both money pool and external short-term borrowings) for the Registrant Subsidiaries:
Entergy Arkansas Entergy Gulf States Louisiana Entergy Louisiana Entergy Mississippi Entergy New Orleans Entergy Texns System Enera
Authorized B o m w i n p (In Millions) $250 - $200 - $250 - $175 $4 $100 I
$200 I
$200 I
~FERC FORM NO. 1 (ED, 12-8~) Page 123 31 I
[Name of ResDondent Ifhis Report is: 1 Date of Report IYearlPeriod of Report I . . .
. Enlcrgy Arkansas. I n c
(11 x Ar; Original (Mo. Da, vr) (2) I A Resubmlssion t i 2013lQ4
NOTE 5. LONG -TERM DEBT
DctniIs of long-term debt are presented on FERC Form 1 pages 256-257.
Enterm Arkansas has obtained long-term financing authorization from the APSC that extends through December 2015.
NOm 6. PRFXERFED EQUXTY
Details of preferred equity are presented on FERC Form 1 pages 250-251,
NOTE 7. COMMON EQUITY
Details of common equity am prescntcd on FERC Form 1 pages 250-25 1.
Retained Earninaq and Dividend Rcstrictions
Provisions within the articles of incorporation or pertinent indentures and various other agreements relating to the long-term debt and preferred stock of certain OF €%era Corporation’s subsidiaries could restrict the payment of cash dividends or other distributions on their common nnd preferred equity. As of December 3 i , 2013, under provkions in their morfgage indentures, Entcw Arkansu and Entergy Mississippi had retained earnings unzvailable for distribution to EnteFsy Corporation of $3949 million and $68.5 million, respectively. Entcrsy Corporation received dividend payments from subsidiaries totaling 5702 rniNon in 2013, $439 million in 2012, and $595 million in20f 1.
-
NOTE 8. COMMIIMENTS AND CONTZNGENCIES
Entergy and the Registrant Subsidiaries we involved in a nurnkr of Iegal, reytatory, and tax proceedings before various courts, regulatory commissions, and governmental agencies in the ordinary course of business. Mile management is unable to predict the outcome of such proceeding, management does not befieve that the uItimate resolution of these matters will have B material effect on Enter& results of operations, cash flows, or financial condition. Entcrgy distusscs regulatory proceedings in Note 2 to thc financial statements and discusses tax proceedings in Note 3 to the financial statements.
A N 0 Damaee and Outwe
On March 31, 2013, during a scheduled refueling outage at AN0 1, a contmctor-owned and opcnted heavy-lining appmtus collapsed while moving the genemttoistator out of the turbine building. The co! tapsc resulted in the death of an ironworker and injuries to several other contract workers, caused AN0 2 to shut down, and damaged the AN0 turbine bailding. The turbine building semes both A N 0 1 and 2 and is a nun-ndiological area of the plant AN0 2 reconnected to the grid on April 28, 2013 and AN0 1 reconnected to the grid on August 7,2013. The total cost of IFERC FORM NO. (ED. 12-88) Page 123 32 I
]Name of Respondent \This Report is: I Date of Report IYearlPenod of Report I Entergy Arkansas, I n c
(1 x Ar; Original (Mo, Da, Yr) (2) - A Resubmission I t 20131P4
assessmenf restoration of off-site power, site restoration, debris removal, and replacement of damaged property and equipment was $94 million as of December 31,2013. In addition, E n t e w Arkansas incurred replacement power costs for AN0 2 power during its outage and incurred incremental replacement power costs for AN0 1 power because the outage extended beyond the on'ginaliy-planned duration of the reheling outage. Each of the Utility operating companies has recovery mechanisms in place designed to recover its prudently-incurred fuel and purchased power costs.
Entcrgy Arkansas is assessing its options for recovering damages that resulted from the stator drop, induding its insurance coverage and legal action. Enterw is 3 member of Nuclear Electric Insurance Limited WEIL), a mutual insumnce company that providcs property damage coverage to the membcrs' nuclear generating plants, including ANO. NEIL has notifid Entera that it believes that B $50 million coursc of construction sublimit applies to any Ioss associated with the lifting apparatus fdurc and stator drop at ANO. Entern has respondcd that it diragrecs with NEL's position and is evaluating its options for enforcing its rights under the policy. On July 12, 2013, Entergy Arkansas filed a complaint in tbc Circuit Court in Pope County, Arkansas against the owner of the heavy-lifting apparatus that co?lapsed, an engineering firm, a gcneral contractor, and certain individuals asserting claims of breach of contract, negligence, and gross negligence in connection with their responsibility for the stator drop.
In the sccond qusrtcr 2013, Entcrgy Arkansas recorded an insurance receivable of $50 million based on the minimum amount that it e x p ~ ~ t r to receive from NEIL. This $50 million receivable offsct approxima!cly $35 million of capital spending. $13 million of operation and maintenance expense, and $2 million of incremental deferred refueling outage costs inmurrcd Tor the rceovcry through December 31,2013. As of Dccember 31,2013, Entera Arkansas has incumd approximately S34 million in capital spending, $9 million in operation and maintenance expense, and $1 million in incmental d c f c r d refueling outage costs in excess of its recorded insurance receivable, In January 2014, Enterw Arkansaz, collected $20 million of the $SO million receivable that it expects to receive fromNEE.
Nuclent Tnmmnm
ThId Party Liability Insurance
The Price-Anderson Act rcquircs that reactor licensees purchase insurance and participate in a secohdary insurance p I that providcs insurance coverage for the public in the event of a nudear power pIant accident. The costs of this insurance are borne by the nuclear power industry. Congess amended and renewed the Price-Andcrson Act in 2005 for a term through 2025. The Price-Anderson Act requires nuclear power plants fo show evidence of financial protcction in the event of a nuclear eccident. This protection must consist of two layers of coverage:
1. The primary level is private insurance underwritten by American Nuclear Insurers (AN0 end provides public liabiiity insurance coverage of $375 million. IF this amount is not sufficient to cover claims arising from an accident, the second level, Secondary Financial Protection, applies.
2. Within the Secondary Financial'Protection level, each nuclear reactor has a contingent obligation to pay a
retrospective premium, equal to its proportionate share ofthc loss in excess of the primary level, regardless of proximity to the incident or fault, up to a maximum of $127.3 milIion per reactor per incident (Enters's
[FERC FORM NO. i (ED. 12-88) Page 123 33 1
1 Name of Respondent IThis Report Is: I Date of Report lYeadPeriod of Report a
Etltergy Arkansas. Inc. (1 1 Ar; Original (Mo, Da, Yr) (2) - A Resubmission I I 201W4
3.
maximum total contingcnt obliption per incident is $1.4 billion). This consists of a $1213 million ma?rimum retrospective premium plus a five percent surcharge, which equates to %227,3 million, that may be payable, i F needed, at a rate that is currently set at $19.0 million per year per incident per nuclear power reactor. In the event that one or more acts of terrorism cause a nucfear power plant accident, which results in third-party damages - off-site proper& and environmental damage, off-site bodily injury, and on-site third-party bodily injury (Le. contractors); the primary level providcd by ANI combincd with the Secondary Financial Protection would provide $13.6 billion in coverage. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government p r o w that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist event.
Currently, 104 nuclear reactors arc participating in the Secondary Financial Protection program. The product of the maximum rctmspectivc prcrnium assessment to the nuclear power industry and the number of nuclear power reactors provides over $132 billion in secondary layer insurance coverage to compensate the public in the event of a nuclear power reactor accident. The Price-Anderson Act provides that all potential Iiability for a nuclcat accident is limited to the amounts of insunnce coveragc available under the primary and secondary layers.
Entergy Arkansas has two licensed reactors and Enterw Gulf States Louisiana, Enterpy Louisiana, and System Eneqg each have one licensed reactor (10% of Grand Gulf is owned by a non-afiiiated company (SMEPA) that would sham on B pro-rata basis in any retrospeciive premium assessment to System Energy undcr the Price-Anderson Act).
Property Insurance
Entcrgy’s nuclear awnerAicensee subsidiaries are members of Nuclear EIectric Insurance Limited (NEIL), a mutual insurance company that providcs property damage coverage, including decontamination and premature decommissioning expense, to the membcrs’ nuclear generating plants. Effective April 1, 2013, Entergy was insured against such losses per the foliowing structures:
UtiIitv Plants ( A N 0 1 and 2. Grand Gulf. River Bend. and Waterford 31
Deductibles:
Primary Layer (per plant) - $500 million ger occurrence Excess Layer (per plant) - $750 million per occurrence Blanket Layer (shared among the Utility plan&) - $350 million per occumnce Total limit - $1.6 billion pcr occurrence
$2.5 million per Occurrence - Turbidgenerator damage $2.5 million per occurrence - Other than turbinelgenerator damage $10 miIIion per occumncc plus 10% of amount abovc $10 milIion - Damage from a windstorm, flood, earthquake, or volcanic eruption
Note: AN0 1 and 2 share in the primary and excess layers with common poIicies because the plicim are issued on a per site basis. Also, flood and earthquake covcrage are excluded from the pn’mary Iayer, which provides the first
[FERC FORM NU. A (ED. mq Page 123 34 I
* Name of Respondent This Report is: Date of Report YearlPeriod of Report
(I) An Orlginal (Mo, Da, Yr) Enlergy Arkansas, he. (2) - A Resu bmisslon I t 2otwQ4
NOTES TU FIWNCIAL STATEMENTS (Continued) L
$500 million in coverage. Enteqy currently purchases primary layer f l d coverage for Waterford 3 and River Bend.
Under the propetty damage and accidental outage insurance programs, all NEIL insured plants could be subject to assessments shouId losses exceed the accumulated funds available from NEIL. Effective April I, 20 13, the rnLxirnum amounts of such possible assessments per occurrence were as folIows:
Ajsessrnents (in Millions)
Utility: Entergy Arkansu Entergy Gulf States Louisiana Entera Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energr
$25.1 $23
$24.2 $0.07 $0.07 ' N/A $18.9
Enterjg maintnins property insurance for its nuclear units in excess of the NRC's minimum requirement of $1.06 billion per site for nucleor power plant licensees. NRC regulations provide that the proceeds of this insurance must be used, first, to render the reactor safe nnd stable, and second, to complete decontamination operations. Only after proceeds are dedicated for such use and regulatory approval is secured would any remaining proceeds be made available for the benefit of plant owners or their creditors.
In the event that one or more acts of terrorism causes property damage under one or more or all nuclear insurance . policics issued by NEIL (inchding, but not.Iirnited to, those described above) within 12 months from the date the first
property damage occufs, the mmimurn recovery under all such nuclear insurance policies shall be an amgate of $324 billion plus the additional amounts recovered foi such Iosses from reillsumce, indemnity, and any other sources appIicable to such losses. The Terrorism Risk Insurance Reauthorization Act of 2007 created a government program that provides for up to $1 00 billion in coveragc in excess of existing coverage for a termrist eve&
Conventional Property Insurance
Entew's conventional property insunncc program provides coverage of up to $400 million on EUI Entergy system-wide basis fur all operational pcriIs (direct physical Ioss or damage due to machinery breakdown, clectricd failure, firc, lightning, hail, or explosion) on an %ach and every loss" basis; up to $400 million in coverage for ccrtain natural peds (direct physical loss or damage due to earthquake, tsunami, and flood) on an annual aggregate basis; up to . $125 million for certain other natural perils (direct physical Ioss or damage due to a named winchtom and associated storm surge) on nn annuai aggregate basis; and up to $400 million in coverage for all other natural perils not previously stated (direct physical Ioss or damage due to a tornado, ice storm, or any ather natural peril except named windstorm and associated storm surge, earthquake, tsunami, nnd flood) on an "each and every Ioss" basis. The conventional property insurance program provides up to $50 million in coverage for the Entergy New Orleans gns distribution system on an
IFERC FORM'NO. I (ED. 12-38) Page 123.35 1
Name of Respondent This Report Is: Date of Report {Mo, Da, Ur) (1) X An Origlnal
"each and every loss" basis, This $50 million limit is subject to: fhe $400 million annual aggregate limit for the natural periIs of earthquake, tsunami, and flood; the $125 million annual aggregate h i t for the natural perils of named windstorm and mssociated storm surge; the $400 miltion per occurrence limit for all other natural perils not previously stared, which includes tornado and ice storm, but excludes named windstorm and associated storm surge, earthquake, tsunami, and flood; and the $400 million per Occurrence limit for operational perils. The coverage is subjcct to a $40 million self-insured retcntion per occurrence for the natural perils of named windstorm and associated storm surge, earthquake, flood, and tsunami; and a $20 million self-insured retention per occurrence for operational perils and all other natural pcrils not previously stated, which includes tornado and ice storm, but exdudes named windstorm and associated storm surge, earthquake, tsunami, and flood,
YearlPenod of Report
Covered pmperry generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded propcrty generally includes above-ground transmission and distribution lines, POI=, and towers for substations valued at S5 million or Icss, coverage for named windstorm and associated storm surge is excluded. This covcragc is in place for Enterm Corpomtion, thc Registrant Subsidiaries, &id certain other Entergy subsidiaries, inchding the o~ners of the nuclear power plants in the Entera Wholesale Commodities segment. Entergy also purchases $300 million in temrhm insurance coverage for its conventional property. The Terrorism Risk Tnsunnce Reauthorization Act or2007 cmtcd n government program that provides for up to $100 billion in coverage in excess of existing coverage for a terrorist went.
In addition 10 the conventional property insurance program, Entergy has purchased additional coverage ($20 million pcr o~cumnce) for some of its non-regulated, non-generation assets. This policy serues to buydown the $20 milIion deductible and is placcd on a scheduled location basis. The applicable dcductibles are $100,000 to $250,000, except for propertics that arc damagcd by flooding and propcrties whose values are greater than $20 miIlion; these propcrties have 8 5500,000 deductible. Four nuclear locations have a $25 million deductible, which coincides with the nuclear propmy insurance deductible at each respective nuclear site.
Ern ploy m e nt n nd L a h r-rtln t cd Pmceed i n ps
The Registrant Subsidiaries and other Entera subsidiaries are responding to various lawsuits in both state and fedcrat courts and to other labor-rekited proceedings filed by current and former employees, recognized bargaining reprcscntativcs, and third parfies not seIected for open positions or pmviding services directly or indirectfy to one or more of the Registnnt Subsidiaries and other Entergy subsidiaries. Generally, the amount of damages being sought is not specified in these proceedings. These nctions include, but are not limited to, allegations ofwrongful employmcnt actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising undcr collective bargaining agreements; unfair labor practice proceedings and other administrative pmeedinp bcfarc thc Nationol Labor Relations Board or conccming the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entcrgy Corporation-sponsoml plans. Entergy and the Registrant Subsidiarks are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue fo be handkd so that the ultimate resolution of these matters will not be material, in the aggregate, to the
IFERC FORM NO. 1 (EO. 12-88) Page 123 36 1
Name of Respondent This Repart is: Oate of Report Yearperiod of Report (1) &An Qdginal (Mo, Da, Yr]
Enlergy Arkansas. Inc. A 2 ) A Resubmission i l 2 0 1 3 ~ 4 NOTES TO FlNANCiAL STATEMENTS (Cuntlnud}
c
financial position, results of operation, or cash flows of Entew or the Utiiity operating companies.
Grand GuIT- Related Agreements
Capital Funds Agrecmcnt (Entergy Corporation and System Energy)
System Energy has entered into agreements with Enterpy Arkansas, Enterfg Louisiana, Entergy ?$issksippi, and Entergy New Orleans whereby they are obligated to purchase their respective entitferncnfs of capacity and e n e r a from Sysfem Energy’s interest in Grand Gulf, and to make payments that, togcther with other available funds, are adequate to cover System Enera’s operating expenses. System Energy would have to secure funds from other sources, including Enterg Corporation’s obligations under the Capital Funds Agreement, to cover any shortfalls from payments received from Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans under these agmements.
Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Eutergy MississlppI, Entergy New Orleans, and System Energy)
System Enerm has agreed to selt all of its share of capacity and energy from Grand Gulf to Enteqy Arkansas, Entersy Louisiana, Eatergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansa-36%, Entergy buisiana-14%, Entergv Mississippi-33%, and Entersy New Orleans-lTO/o) as ordered by the FERC. Charges under this agreement are paid in considcration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered, T h e agreement will remain in effect until terminated by the parties and the termination is approved by the FERC, most likely upon Grand G u l f s retirement from service. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 20i3 under !he agreement are approximately $223 million for Enterw Arkansas, $8.7 million for Enkrgy Louisiana, $192 million for Entergy Mississippi, and $10.8 million for Entergy New Orleans.
AvaiIability Agreement (Entcrgy Arkansas, E n t e w huiaiana, Entergy Mississippi, E n t c w New Orleans, and System Enew)
Entcrgy Arkanszs, Entergy Louisiana, Entcrgy Mississippi, and Enteqry New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas-I’I.l%, Entersy Louisiana-26.9%, Entersy Mississippi-3 1.3%, and Entergy New Orleans-24.7%) in mounts that when added to amounts received under the Unit Power Sales Agreement or ohenvise, Brc adequate to cover all of Systcrn Enera’s operating expenses as defined, including an mount suficient to amortize the cost of Grand Gulf 2 over 27 years (See Reallocation Agreement t e r n below) aid expenses incurred in connection with a permanent shutdown of Grand Gulf. System Enerpy has assigned its rights to payments and ndvances to certain creditors as security for certain obligations. Since commercial operation of G&nd Gulf began, payments under the Unit Power Sales Agreement have exceeded the amounts payable under the Availability Agreement. Accordingiy, no payments under the Availability Agreement have ever been required. If Entergy Arkansas or Enterm Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entcrgy Louisiana and Enfergy
IFERC FORM NO. 1 [ED. 12-88} Page 123 37 I
Name of Respondent This Report Is: (1) X A n Original
Entergy Arkansas, he. (2) I A Resubmission
New Orleans could become subject to claims or demands by System Energy or its creditors for payments or advances under the Availability Agrecrnent (or the assignments thereof) equal to the difference between their required Unit Power Sale Agreement payments and their required Availability Agreement payments.
Date of Report YearlPeriod of Report (Mo, Da, Yr)
I t 2DtJIQ4
ReafIocation Agreement (Entcrgy Arkansas, Entergy buisiaaa, Entergy Miisissippi, Eutergy New Orleans, and System Energy)
System Energy, Entergy Arkansas, Entcrgy Louisiana, Entergy Mississippi, and EntcFsy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and encrgy from Grand Gulf and the related costs, in which Entcrgy Louisiana, Entergy Mississippi, md Entergy New Orleans agreed to assume all of Enterm Arkansas's responsibilities and obligations with respect to Grand Gulf under the Availability Agreement, FERC's decision alIocating a portion of Grand Gulf capacity and energy to Enter= Arkansas supersedes the Reallocation Agreement s it relatcs to Grand Gulf. Responsibility for any Gmnd GuIf 2 amortization amounts has been individually allocated (Entergy Eouisiana-26.23%, Entergy Mississippi43.97%, and Entergy New OrIcm-29.80%) under the tcms of the Reallocation Agreement. However, the Reallocation Agreement does not affect Entergy Arkansas's obligation to System Energy's lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entersy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so Iong 8s amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under thc Availability Agreement, which is expected to be the case for the foreseeable future.
NOTE 9, ASSET RETIREMENT OBLIGATIONS
Accounting standards require companies to record liabilities for all legal obligations associated with the retircrnent of long-lived assets that result from the normat operation of the assets. For Entcrgy, substantinlly all of its &set retirement obligations consist of its Iiability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning line item on the balance sheets.
These liabilities are recorded at their fair values (which me the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the longlived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the timc value of money for this present value obligation. The nccretion will continue through the completion of ihe asset retirement activity. The amounts added to the carrying amounts of the Iong-lived assets will be depreciated over the usefuI Iivcs of the asscts. The application of accounting standards related to asset retirement obligations is earnings neutra1 to the mte-regulated business of the Registrant Subsidiaries,
In accordance with rotemaking treatment and as requircd by regulatory accounting standards, the depreciation provisions for the Registrant Subsidiaries include n component for removal costs that are not asset retirement obligations under accounting standards. In accordance with regulatory accounting principles, the Registrant Subsidiaries have
]FEW FORM NO. I (ED. 12-88) Page 123.3 I
Name of Respondent This Report Is: (1) X An OrigInal
Date of Report YeadPeriod of Report (Mo, Da, Yr)
Enlergy Arkansas, [ne. (2L A Resubmission I t 201304
NOESTO R W C I A L STATEMENTS (ContlnuE4 c
recorded reguhtory assets (liabilities) in the following amounts to reflect their estimates of the diffetrnce between estimated incurred removal costs and estimated removal costs recovered in rates:
December 31, 2013 2012
(In MiI?ions) Entergy Arkansas $18.6 ($122) Enterw Gutf States Louisiana ($35.3) ($22.0)
Entergy Mississippi 354.3 $57.4
Entergy T e , w $15.1 SI15
Entera Louisiana ($37.0) (59.2)
Entergy New OrIeans $34.9 $29.9
System Energy $56,0 $56.8
?he cumulative decommissioning and retirement cost liabilities and expenses recorded in 2013 by Enterjy were BS follows:
Liabilities ns Change in Liabilities as uf December 31, Cash Flow of December 3 I,
2012 Accretion Estimate Spending 2013 (In MilIions)
Utility: Enteqy Arkansas Entcrgy Gulf States Louisiana Entergy Louisiana Entersy Mississippi Enterw New Orleans Entergy Texas System Energy '
$680.7 $43.1 $- $I- $723.8 $380.8 $223 $- $- $403.1 $4 18.1 nf.6 $39.4 s $479.1
$6.0 $0.4 $- %- $6.4 $22 $0.1 $- e $23 $4.1 SO2 T- % $43
$478.4 $35.5 . $1023 $- $6 162
The cumulative dccommissioningand retirement cost liabilities and expenses recorded in 2012 by Entergy were as follows:
Lfabilitk 8s Change In LiabititIes g~ of December 31, Cash n o w of December 31,
(ln Millions) 2011 Accretion Estimate Spending 2012
uti I ity: Enterm A ~ k a n s ~ $64 0.2 $40.5 $- c $680.7 Entcrgy Gulf Sfates Louisiana $359.8 $21.0 % %- $3 80.8
Entergy Louisiana Entcrp Mississippi Entergy New Orleans Enterm Texas
$345.8 $23.4 $448.9 $- $418.1 $5.7 $03 $- % $6.0
$ 3 9 - $03 %- s $4.1 $23 $02 s ($0.9) $ 2 2
~FERC FORM NO. i (ED. m s 8 ) Page 123 39 1
Name of Respondent This Report is: Date of Report (1) An Original (Mot Oa, Yr)
Entergy Arkansas. Inc (2) A Resubmission i t
System Energy $445.4 $33.0 $- s $478.4
YearlPenod of Report
2 0 1 3 m
Entergy periodically reviews and updates estimated decommissioning costs. The actual decommissioning costs may vary from the estimates because of regulatory requirements, changes in technology, and increascd costs of labor, materials, and equipment. As described below, during 2013 and 2012 Entergy updated decommissioning cost estimates for ccrtah nuclear power plants.
Entergy maintains decommissioning trust funds that are committed to meeting its obligations for the costs of dccommissioning the nuclear power plants. The fair values of the decommissioning trust funds and the related asset retirement obligation regulatory assets (liabilities) of Enter= as of December 3 1,2013 are as follows:
Decom rnissionhg Regulatory ' Trust Fair Values Asset aiabitity)
Utility : AN0 1 and AN0 2 River Bend Waterford 3 Grand Gulf
(In Millions)
$710.9 $219.1 $573.7 ($2 8.7) $3473 $128.5 $603.9 $60.8
Entergy maintains decommissioning tmst funds that are committed to meeting its obligations for the costs of decommissioning the nucIcar power plants. The fair values of the decommissioning trust funds and the related asset rctircmcnt obligation regulatory sets (liabilitics) ofEntera as of December 3 I, 2012 areas follows:
Decom missioaing Regulatory Trust Fah Values Asset (LIabiIity)
(In Millions] Utility: AN0 1 and AN0 2 River Bend Waterford 3 Grand Gulf
$600.6 $204.0 $477.4 ($1.7) $287.4 $126.7 $490.5 $58.9
NOTE 10. LEASES
General
As of December 31,2013, the Registrant Subsidiaries had capital leases and non-cancelable operating leases for equipment, buildings, vehicles, and fuel storage facilities (excluding nuclear fuel [eases and the sale and leaseback transactions) with minimum lease payments as follows:
Capi f d Leases
[FERC FORM NO. i (ED. iz-sq Page 123 40 1
Name of Respondent This Report Is: (1) X A n Original
Enlergy Arkansas. Inc (2) -A Resubmission
Enteqy Entergy
(h Thousands) Year Arkansas Musissippf
2014 $237 $1,570 2015 I58 1,570 2016 - I,S70 2017 I 1,570 2018 - 785 Years thereafker I c
Minimum lease paymcnts 3 95 7,065 Less: Amount rcpresenting interest 216 1,081
$59 84 Present value of net minimum lease payments r
7 - $179
Oate of Report YearlPenod of Report (Mo, Da, Yr)
I I 201YM
Entergy Entergy Enteqg GulfStates Enfergy Entergy New Entcqy
Year Arkansas Louhjana Louisiana Mississippi Orleans Texas (In Thousands)
2014 $32,124 $1 9,735 $11,398 $7,155 $2,121 36,442 2015 33,069 10,294 9,825 6,162 2,083 5,620 2016 17,999 9,551 6,574 4379 1,720 4,4 87 2017 11,019 8,547 4,580 2.992 1,300 3,318 2018 6,669 7,753 3,078 2JOO 883 2,68 1 Years thereaner 3,908 34,981 3,706 * 4306 1,988 2,356 Minimum lease payments S 104,788 $90,86 I $39,161 527,294 $10,095 $24,904 ------
Rental Expenses
Entcqy Entergy Entergy Gulf States Entergy Entern New Entergy System
Year Arkansas Louisiana Louisiana Mississippi OrIeans Texas Eae rgy
(ln Millions) 2013 $12.0 $10.9 $10.1 $4.6 $13 $4.1 $2.5 2012 $12.6 $1 1.9 $11.2 $5.5 $1.5 $6.4 $1.5 201J $13.4 $12.2 $12.2 $52 $1.7 58.4 $1.6
In addition to the abovc rental expcnse, railcar opemting lease payments and oil tank facilities lease payments are recorded in fuel expense in accordance with regulatory trcntment. Railcar operating !ease payments were $8.6 million in 2013, $8.5 million in 2012, and $8.3 miIlion in 201 i for Entergy Arkamas and $ 2 2 milIion in 2013, $1.7 million in 2012, and $2.0 miIlion in 201 1 for Entersy Gulf States Louisiana. Oil tank facilities lease payments for Entergy Mississippi were $3.4 million in 20 13, $3.4 million in 20 12, and $3.4 million in 20 1 1.
[FERC FORM NO. I (ED. 12-88) Page 123 41 I
Name of Respondent ThIs Report Is: Date of Report (Mo, Da, Yr) (?I X An Original
EntergyArkansa% Inc. (2) A Resubmission I I
NOTE 11, RF,TIREMENT, OTHER POSTRETmMENT BENEFITS, AND DEFINED C O ~ U T I O I Y PLANS
YearlPenod of Report
201344
Qualified Pension Plans
Entergy has seven qualified pension plans covering substantialIy all employees: “Entergy Corporation Retirement Plan far Non-Bargaining Employees,” “Entergy Corporation Retirement PIan for Bargaining Employees,” “Entergy Corporation Rctiremcnt Plan II for Non-Bargaining Employees,” ”Entergy Corporation Retimrncnt Plan II for Bargaining Employees,” “Entergy Corporation Retirement Plan 111,” “Entersy Corpontion Retirement Plan IV for Non-Bargaining Employees,” and “Entergy Corporation Retirement Plan IV for Bargaining Employees.” The Registnnt Subsidiaries participate in two of these plans: ”Entergy Corporation Retirement Plan for Non-Bargaining Employees" and “Entergy Corporation Retirement Plan for Bargaining Employees.” Except for the Enter= Corporation Retirement Plan 111, the pension plans are noncontributory and provide pension benefits that are based on employees’ credited service and compensation during the final years before retirement. The Entergy Corporation Retirement Plan 111 includes a mandatory emproyee contribution of 3% of earnings during the first 10 years of plan participation, and allows voluntary contributions from 1% to t 0% of earnings for a limited group of employees.
The assets of the seven qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts of the master trust that is maintained by a trwtee. Use afthe master trust permits the commingling of the trust assets of the pension plans of Entcrgy Corporation nnd its Registrant Subsidiariw for investment and administrative purposes. Although assets are commingled in the master tmst, the trustee maintains supporting records for the purpose of allocating the equity in net earnings (loss) and the administrative expenses of the investment accounts to the various participating pension plans. The fair value of the fmst assets is determined by the trustee and certain investment managers. The trustee calculates B daiiy earnings factor, including rea?ired and unrd ized gains or losses, coIJected and accrued income, and administrative expenses, and allmcates earnings to each plan in ihc master trust OR a pro rata bnsis. .
Further, within each pension plan, the record ofeach Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary nnd is updated quarterly. Assets for each Registrant Subsidiary are increased for invcstmcnt income and contributions, and dccrciqcd for bcncfit payments. A plan’s investment nct income/(foss) (Le. interest and dividends, realized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the vahe of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and bcnefit payments made during the quarter.
Entcrgy Corporation and its subsidiaries fund pension costs in accordance with contribution guidelines cstrrblishcd by the Employce Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assefs of the plans include common nnd preferred stocks, fixed-income securities, interest in a money market fund, and insunnce contracts. The Registrant Subsidiaries’ pension costs are recovered from customers FS
a component of cost of service in each of their respective jurisdictions.
1 1 Page 123 42
Name of Respondent This Report Is: Date of Report (Mo, Da, Yr) (l} X A n Original
Entergy Arkansas, Inc. (2) I A Resubmission I I
Components of Oualified Net Pension Cost and Other Amounts Recuenized iw n R e d a t o w Asset andlor Accumulated Other Comprehensive Income {AOW
YearlPenod of Report
2013M4
The Registrant Subsidiaries’ total 2013,2012, and 201 1 quaIified pension costs and mounts recognized as a regulatory asset andlor other comprehensive income, including amounts capitalized, for their emphyees included the following components:
Entergy Entergy
2013 Arkansas Louhiana Louisiana MhsIssippi Orleans Entergy CtlllStates Entergy Entergy New Eatergy System
Texas Energy (h Thousands)
Net periodic pension cosf: Service cost - benefits earned during the period $25,229 $14,258 $17,044 $7,295 $3,264 $6,475 $7,242
Interest cost on projected benefit obIigation 54,473 26,741 34,857 15,802 7,462 16,303 12,170 Expected return on assets (66,951) (34,982) (41,948) (21,139) (9,117) (22,277) (17,249) Amortization of prior
service cost 23 9 83 10 2 6 9 Recognized net loss 49,5 17 23,374 34,107 f3,189 7,878 13,302 9,560 Curtailment loss 493 8 805 3,542 767 343 1,559 I
Special termination benefit 1.784 808 1,631 359 581 855 1,970 -- Net pension cost S69,O 13 $3 1,013 $49,316 $16,283 $10,413 $16,223 $13,702 Oiher changa in plan
assets and benefit obligations recognized as a regulatory asset anflor AOCI (before
Arising this period: tax)
Net gain ($1 77,105) ($98,610) ($123,234) ($52,525) ($25,419) ($55,772) ($35,5 1 1) Amounts reclassified from
reguulatory asset andlor AOCI to net pcriodic pension cost in the current year:
Amortization of prior service cost (23) (9) (83) cw (21 (6) (91
Amortization of net loss
Total
(493 17) , (23,374) (34,107) (13,189) (7,878) (13,302) (9,560)
($226,645) ($12 1,993) ($1 57,424) ($65,724) ($33,299) ($69,080) ($45,080) Total recognized as net periodic pcnsian income
IFERC FORM NU. 1 (ED. 12-88) Page 123 43 I
Name of Respondent This Report is: {I) XAn Original
Entargy Arlcansas. Inc (2) I A Resubmission
regdatory asset, andor AOCl (before tax) ($157,632) ($90,980) (SI 08.1 08) ($49,441) ($22,886) ($52,857) ($3 1378)
---?----
Date of Report YearlPeriod of Report (Mol Da, Vr)
I I 20131Q4
Estimated amorthat ion amounts from rquIatory asset andlor AOCI to net periodic cost in fbe following year
Prior service cost $- c c %- c c $2 Net loss $3 5,904 $1533 5 $ 2 4 ~ 60 $9,421 35,802 $9,363 $9,510
Entcrgy Enfcrgy E n t e w CuIfStates Entergy Entergy New Entergy System
. 2012 Arkansas huhlana LouIsIana Missfssippl: Orleans Teres Energy
(InThousands) Net periodic pension cod: Service cost - bcnefits earned
Interest cost on pmjecfed
Expected return on assets Amortization of prior service
Recognized net loss Net pension cost Other changes in plan assctf
and benefit obligations recognixed as B rqulntory
' asset andlor AOCI (before tar)
Arising this perid:
during the period
benefit obligation
cost
Net loss Amounts reclassified from
regulatory assct andor AOCI to net periodic pension cost in the current year:
service cost Amortization of prior
Amortization af net loss Total
Total recognized as net periodic pension cost, regulatory asset, and/or AUCI (before tax)
Estimated amortization
%22,? 69 !T 12,273 $14,675 $6,4 10 S2,824 $5,684 $5,920
55,686 25,679 35,201 16,279 7,608 16,823 12,987 (65,763) (34,370) (40,836) (20,945) (8,860) (22,325) (I 6,436)
200 19 208 30 7 15 13 40,772 16.173 28,197 10,532 6,878 10,179 9,001 --
$53.064 $19.774 537.445 312306 38.457 $10.376 SI 1.485
$1 05,133 $77,207 576,163 $27,106 $14,282 S28,745 $1 0,266
(200) 1191 (208) (3 0) (71 (15) (13) (40,772) (16,173) (28,197) (10,532) (6,878) (10;179) (9,001)
$64, I 6 1 $6 I ,O 15 547,758 $16,544 $ 7 3 7 S 1 8,55 1 $1,252 --- $ I 17,225 $80,789 $85,203 $28,850 $15,854 $28,927 $12,737 -------
IFERC FORM NO. 1 (ED. 12-88) Page 123 44 I
Name of Respondent This Report is: Date of Report YearlPenod of Report (I) &An Original (Mo, Da, Vr)
Entergy Arkansas, tne. , (2) A Resubmission i t 2013144
NOTES TO FIWCLAL STATEMENTS (Ccntlnued)
amounts from regulatory asset andlor AOCI to net periodic cost ia the following year
Prior service cost $23 $9 %83 SI0 $2 $6 $10 Net loss %50,175 $23,731 $34,906 $13,375 $8,046 $13,494 $9,717
Entergy Enter0 Entergy GulTStates Entcrgy Eutcrgy New Entergy System
Arkansas Louisiana Louhiana Mtssissslppl OrIeans Texas Energy --- 2011 (In Thousands)
Net periodic pension cost: Service cost - benefits earned
Interest cost on projected benefit obligation Expected return on assets Amortization of pior service
Recognized net loss Net pension cost Other changes In plan assets
and benefit obligations recognixed as it regulatory asset and/or AOCI (behw tax)
Arising this period:
Amounts reclassified from regulatory asset nndlor AOCI to net periodic pension cost in the current year:
during the period
C o s t
- Net loss
$18,072 $9,848 $1 1,543 $5,308 $2,242 $4,788 $4,941
51,965 23,713 32,636 15,637 7,050 15,971 11,728 (62,434) (33358) (38,866) (20,152) (8,455) (22,005) (15,138)
459 . 79 280 I52 35 65 16 9,113 17,990 6,717 4,666 5,579 5,204
$5,538 $4,398 56,861 --- 25,68 1
7-
$33,743 $9,400 523,583 $7,662
$21 7,989 $ IOU29 $137,100 $56,714 $29,297 $64,662 $52,876
Arnodization of prior service cost (459) (79) (2801 (152) (35) (65) (16) Amortization of net loss (25,681) (9,118) (17,990) (6,717) (4,666) (5,579) (5284)
'rota? --
$191,849 $93,132 I1 18,830 $49,845 $24,596 $59,013 $47,576 --- Toial rccognbed as net I
periodic pension cost, regulatory asset, and/or AOCI (before tax) $225,592 $102,532 $142,4 13 $57,507 $3 0-13 4 S63,4 1 6 $5443 7
------I-
Estimated amortization amounts from regulatory
Name of Respondent This Repart Is: (I) g An Original
Entargy Arkansas, Inc. (2) A Resubmisslon
asset andlor AOCX to net periodic cost in the following year
Prior sewicc cost $200 $19 $208 $30 $7 $15 $13 Net loss $41,309 $16,295 $28,486 310,667 $6,935 $10,261 $9,135
Date of Report YearIPenod of Report (Mo, Da, Yr) ' I f 20131114
Qualified Pension OhIkations, Plan Assets, Funded Status, and Amounts Recopnizcd in the Barance Sheet far the RePistnnt Suhidiarim aa of December 31,2013 and 2012
Entergy Entergy Enterpy Gulf States Entergy Enfergy New Entergy System
2013 Arkansas Luuhiana Louistana M h l s s l n d Orteam Texas Emrw
Change in Projected Dcncfit Obligation (?'BO) Balance at beginning of gear Service cost Interest cost Curtailment Special termination bcntfit Actuarial gain Benefits pdd Balance at end of year Change in Plmn Euscb Fair value of asssets at beginning of year
Actual return on plan assets Employer contributions Benefits paid Fair value ofnsscts at end of
Funded statulr Amounts recognized in the balance sheet (funded
status) Non-current liabilities Amounts recognized 89
regulatory asset Prior setvice credit Net loss
Year
Amounts recognized as AOCi (bdore tax) Net Ioss
(In Thousands)
$1,274,886 5623,068 $817,745 5369,852 $174,5585 S382,i76 6282,841 25,229 14,258 17,044 7395 3264 6,475 7,242 54,473 26,74 I 34,857 15,802 7,462 16,303 12,170 4,938 805 3,542 767 343 1,559 - 1,784 808 1,63 f 359 581 855 1,970
(1 10,943) (641 19) (80,794) [31,684) (16,2761 (33,792) (23,882) (57,727) (2 1,69 9) (32,675) ( 16,567) (6,252) 17,496) (9,552) .
5 t.192.640 $579,862 $76 1,350 5345.824 $153,707 5356.080 5270.789
$785,527 5409,971 $489,027 s248J72 SJ06.778 S262,f 10 $168,697 133,113 69,473 s4gm 41,980 1SJ59 44,257 28,878 35JE2 11,550 21: ,152 8,152 4,175 6,880 8,305
(57,727) (21,6991 [32,675) (16,567) (6252) (17,496) (9,552) - ~ 6 ~ 9 s s w m s $561,892 $28 1,837 S I Z , ~ ~ $295,751 $ 1 9 6 ~ 2 ~ --- (S296J45) ($110,567) ($199,458) ($63,987) (S40,747) ($60,329) ($74,461)
($296,345) ($1 10,567) ($199,458) ($63,987) ($40,747) (560,329) (S74,461)
P $- {St) c c c (54) 4 5 7,4 85 178,990 299,740 120390 69,856 120,6 19 12 1,327
3 457,485 $ 178,990 $ 299,739 $ I20290 $ 69,856 $ 120,619 S 121,323 - ----.I
Name of Respondent
Entergy Arkansas, he.
This Report is: (I) KAn QrIginal (2L, A Resubmlsslon
Entergy Entergy Entergy GuICStates Entergy Enfergy New Entcrgy System
20 12 Arkansas h u b h a Lorthlana MlssBsippI OrIeaas Texas Energy (In T h o m d s )
Change in ProJecfed Benefit Obligation (PBQ) Balance at beginning of
Yew $1,116,572 $5 12,432 $704,748 $326,377 S15 1,966 5331,669 S258,26% Setvice cost 22,169 12,273 14,675 6,4 10 2,824 5,684 5,920 Interest cost 55,686 25,679 35,201 16,279 7,6 0 8 16,823 12,987 Actuarial loss 13449 1 92,275 93,817 36,329 18,000 38,328 13,691 Benefits paid
S1,274,886 5623,068 $817,745 $369,852 S174,SM $382,176 S282,84I Balance at end of year Change lo Plan Assets Fair value of assets at
beginning of year S707,275 $366,555 $432,418 $223,981 $94,202 $237,438 5147,091 Actual return on plan =sets W,32 1 49,43 S 5 8,489 30,169 12,578 3 1,909 19,860 Employer contributions 37,163 13,569 28,816 9,665 5,Zl I 9,09 1 9,77 I Benefits paid I54 23 2) (19,591) (30,696) (15,543) (5,813) (16,328) (8,025)
Fair vaIue of assets at end of year $785,527 $409,971 S489,027 5248,272 $106,778 S262,I 10 $168,697
P4J32) ( 1939 1) {3 0,696) ( 15,543) (S,8 13) ( 16,328) (8,025) - -
Date of Report YearlPeriod of Report (Mo, Da, Yr}
I I 20131Q4
Funded status Amounts recognized in the ,baIance sheet (funded status) No n-curren t 1 iabi I i ti es Amounts recognized as regulatory asset
Prior service cost Net loss
Amounts recognized BJ
AOCX (before tax) Prior service cost Net Io55
$489,359) ($213,097) ($328,7 18) (S121,580) ($67,807)
(S489359) ($213,097) ($328,718) (Is 121,580). ($67,807)
0 3 $8 $83 $20 $2 683,790 283,847 456,800 1 85,903 103,072 $683.8 13 $283,855 $456,883 $185,913 $103,074 -----
$- 31 $- c s-
5- $42.4 IS s- $- c I - - - 42,414
($120,066) ($114,144)
(5120,066) {$f14,t44)
$7 S6 189,589 166,276
$189,596 $166382
$- $-
Other Postretirement Benefits
EnterH also currently provides health care and life insurance benefits foi retired empIoyees. Substantially all employees may become eligible for these benefits if they reach retirement age and meet certain eligibility requircmcnts while still: working for Entergy. Entersy uses n December 31 measurement date for its postretirement benefit pIms.
JFERC FORM NO. 1 (ED. 12-38] Page 123 47 I
Name of Respondent This Report Is: Date of Report YearlPenod of Report (l} LS. An Origlnal (Mo, Da, Yr)
Enletgy Arkansas. Ine (2) I A Resubmission i t 2013fQ4
Effective Januaty 1,1993, Entern adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. At January I , L993, the actuarially determined accumulated postretirement benefit obligation (APBO) eamed by retirees and active employees \YS estimated to be approximately $241.4 milIion for Enterpy (other than the former Entergy Gulf Stotes) and $128 million for the former Entera GuW States (now split into Entergy Gulf States Louisiana and Entergy Texas). Such obligations were being amortized over ti 20-year period that began in 1993 and ended io 2012. For the mast pa& the Registrant Subsidiaries recover accrued other postrctimnent benefit costs from customers and are required to contribute the other postretirement benefits coIlected in rates to an external trust.
Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Enterm Texas hwe received regulatory approval to recover accrued other postretirement benefit costs through ntes. Entergy Arkansa began recovery in 1998, pursuant to an APSC order. This order also allowed Entergy Arkmas to amortize a ~gutntory asset (rcpresenting the difference between other postretirement bcnefit costs and cmh expenditures for other postretirement benefits incurred from I993 through 1997) over a IS-year period that began in 3anuary I998 and ended in December 2012.
Pursuant to regutatmy directives, Enterw Arkansas, Enterw Mississippi, Entergy New Orhim, Entergy Te,ras, and System Enera contribute the other postretirement benefit costs cokctcd in rates into external tnrsts. System Energy i s funding, on behalf of Enteqg Opcmtions, other postretimnent benefits associated with Grand Gulf.
Trust assets contributed by participating Registrant Subsidiaries are in bank-administered master trusts, established by Entera Corporation and maintained by a trustee. Each participating Registrant Subsidiaty holds a beneficial interest in the trusts' assets. The assets in the master trusts are commingled for investment and administrative
* purposes. Although assets are commingled, supporting records are maintained for the purpose of alIocating the beneficia1 intmst in nct eamingsl(losses) and the administmtive expcnses of the investment accounts to the various participating plans and parficipating Registrant Subsidiarics, Deneficial .inkrest in an investment account's net incomd(1oss) is comprised of intercst and dividends, realized and unrealized Fins and losses, and expenses. Beneficial interest from these investments is allmated to the plans nnd participating Registrant Subsidiary based on their portion of net assets in the poo!ed accounts.
Other postretirement benefit rbanprs
In December 2013, Entergy announced changes to its other postretirement benefits which indude, among other things, elimination of other postretirement benefits for employees hired or rehired after June 30,2014 and setting a d o h limit cap on Enter& contribution to refine medical costs, effective 2019 for those employees who commence their Entergy retirement benefits on or rtRcr January 1,2015. In accordance with accounting stanbrds, ccrtain of the other postretirement bcnefit changes have been rcffmkd in the December 31, 2013 other postretirement obligation. The changes affecting active bargaining unit employees will be negotiated with the unions prior to implementation, where necessary, and to the extcnt required by law.
[FERC FORM NO. {ED. m s s ) Page 323 4a I
Name of Respondent This Report Is: Date of Report YearlPemd of Repod (I) XAn OrigInal (Mo, Da, Yr)
Enterqy&kansar. Ine. (2) - A Resubmission I I 2013a4 r
NOTES TO FlNANClAL STATEMENTS (Conltnued)
Comnonents d Net Other Postretirement l3nenefit Cost and Olher Amounts Recognized IIS B Rwulatow Asset andlor AOCI
Total 2013, 2012, and 2011 other postretirement benefit costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their employees included the following components:
Entergy Entergy Enteru G u l f s t a h Entergy Enteqg New Entergy System
Arhnsas LouIsIana liouisiana MIssLssIppI Orleans Teras E n e r a
(In Thollsands) 7-
2013
0 ther pcstrethement costs:
Service cost - benefits earned during the period S9,6 19 S7,9 IO s 834 I 53,246 161,752 $3,760 53,580
Interest cost on APE0 13345 s , 9 ~ 9 4 1 a 4289 3,135 6,076 2,945 Expected return on assets (16,843) - - (5,335) ( 4 1 01) (9J9 I ) (3,350) Amortization of prior credit (68% I9421 (508) (204) (24) (501) (126) Recognized net loss 7,976 4,598 5,050 2,534 1,509 3,744 1,89 6 Curtailment Ioss 4,5 17 1,546 1,848 596 354 1,436 760 Net other postretirement
benefit cost $18,125 $22,076 $ 2 4 3 I $5,126 $2,625 $5,124' $5,705
0 ther changes in plan
- -7 ------- assets andbeaeht obligations recognized ag a regdatory asset andlor AOCl (before tax) Arising this period:
Prior service credit for theperiod - ($11,611) ($8,705) (118,844)
Net loss ' ($81336) {$40,938) ($43,753) Amounts reclassified from
regulatory m e t andor AOCI to net periodic pension cost in the current year:
service credit 689 942 SO8 Amortization of prior
Acceleration of prior service credit/(cost) due to curtailment 78 91 41
Amortization of net Ioss (7.9761 (4,598) IS.050l
(X714) ($4,469) (SSJSS) (W591) (S30,018) ($18308) ($34,562) (SI7,579)
204 24 50 1 126
20 (4) 62 9 123341 (1,5091 13,743) (1,896) - - - . . . . . . - . - - - - - - . -7-
($100,062) (S53J08) ($67,088) ($37,042) ($24.466) ($43,102) (S23,93 1) -- Total Total recognized BS net
periodic ofher
[ FERC FORM NO. 1 (ED. 12-88) Page 123.49 I
Name of Respondent This Report Is: Date of Report (Mo, Da, Yr) (1) XAn Original
Entergy Arkansas, Ine. (2) A Resubrnlssion I /
postretirement cost, regulatory asset, n n d h AOCI (before fax)
Estimated amortization amounts from reguhtory asset and/or AOCX to net periodic cost in the rolhwiog year
($8 t ,937) ($3 1,132) (S42,747) ($3 1,9 I 6) (S2 t ,84 I) ($37,978) ($18,Z26) -------
Prior service credit ($2,441) (S2,236) (S3,376) ($9 18) (5709) ($1 JO I ) ($824) Net Ioss SI267 $1Jl2 $1311 S 149 $56 $800 $464
Entergy Entergy Entergy GdfSfates Entergy Entergy New Enttrgy System
Arkansas Loublsna Louisiana MlssMppi Orleans Texas Energy (In Thousands)
- 2012
Of her postretirement casts: Servicc cost - benefits earned
during the period $9,089 S7,521 $7,796 $3,093 $1,689 $3,651 53,293 Interest cost on APBO 14,452 9,590 9,78 1 4,716 3,422 6,650 3,028 Expected return on assets (14,029) I - (432 1) (3,7 I 1) (8,4 15) @,60 1) Amortization of transition
obligation 820 238 382 35 1 1,189 187 8 Amortitation of prior
Reeo&ed net lass 8,305 4,737 4,359 2,920 1,559 4,320 1,970
Net othcr poskeetirement benefit cost
Other changes In plan assels and hcnclit obligations recognked as a regulatory asset and/or AOCI (before tax)
costl(crcdit) (530) (824) (247) (139) 35 (4281 163) - $6,420 - $4,186 $5,965 $5,635 --- S 18,107 S2 1 3 2 sZZ,07 I ---
YearlPedod of Report
201 3Q4
Arising this period: Net loss
NOTES TO FINANCIAL STATEMENTS (Continued) 4
$191 E2,043 527 1 52,260 $9,066 $5,818 $16215 Amounts reclassified from
regulatory asset andlor AOCI to net periodic pension cost in the current year:
Amortitation of transision
Amortization of prior service obligation (azo) (238) (382) (351) (f,189) (187) (8)
(cost)lcre d it 530 824 247 I39 I3 8) 428 63 (2,920) ( 1,559) (4,320) ( 1,970) - Amortization of net Ioss ( 8 3 5 ) (4,737) ( 4 3 9 )
~FERC FORM NO. I (ED. m 1 8 ) Page 123 50 I
I Name of Respondent IThls Report Is: I Dab of Report I YearlPeriod of Report I Enlergy mansas. In&
(I) I I Ar; Original (Mo, Da, Yr] (2) - A Resubmission I I 2013144
Total Total recognized BS net
periodtc other postretirement cost, regulatory asset, andlor AOCI (betore tax)
Estlmated amorflration amounts from regulatory asset andlor AOCI to net pertodlc cost In the foIIowtng year.
Prior service rostl(ctcdit) Net loss
(1525) (S3,SW) 5128 -- S47I $1,667 $1 1.721 (n,86 11
SI: 8,578 522,929 S33,792 s3,559 53,660 52,077 $5,763 -------
($530) (SS24) ($247) ($139) $8,163 $4,693 $5,149 $2,650
Entcrgy Enterm Gulf Stalw Entern E n t e w
53 8 $1387
ERtCrgy New
($428) ($621 $3,905 51,915
E n l e w System Arkansas LauhIana h u M & a MIsslssTppI Orleans Texai- Eneqy - 2011
(In Thousands) Other pos tredrem ent costs: Service cost - bcncfits tamed
during the period $8,053 56,158 $6340 $2,632 $1,448 $3,074 52,642 Interest cost on APBO 13,742 8J98 8,767 4,370 3 3 5 5,945 2,666 Expected return on assets C11328) - - (3,906) (3200) (7,496) (2,115) Amorbtion of tmnsition
Amottimtion of prior service costl(crcdit) (530) (824) (247) (139) 38 1428) (589)
Recognized net loss 6,43 6 2,896 2,793 2,160 968 2,803 1,477 Net olher postrctircmnt benefit
SI 6,994 $16,767 $18336 $5,469 $3,669 S4,OSS $4,090 cost Ofher changes in p l a ass&
and benefit obtfgations
ob1 iga! ion 82 1 239 383 352 1,190 187 9
-- - ----- recognktd as a regulatory asset and/or AOCI (before tax)
Arising this period: Net (gainyoss
Amounts rtcl~ssilicd from regulatory asset andlor AOCI to net periodic pension cost in thc current year:
Amortization of m i t i o n
$32,241 528,721 524,837
obligation I W (239) (3 83) (352) (1,190) (187) (9 )
(costycredit 53 0 824 247 139 (38) 42 8 5g9 Amortization of prior service
Amortiption of net toss (643 6) (2,896) (2,793) (2,160) (968) (2,803) (1,477) ~ F E R C FORM NO. i (ED. mn81 Pass 123.51 I
e.
Name of Respondent This Report Is: Date of Report (Mo, Da, Yr) (1) ls. An Oiglnal
Entergy Arkansas. Inc. (2) A Resubmission I I
YearlPerhd of Report
2013M4
Name of Respondent
Amounts recognized in the bnlance sheet
Cumnt liabilities Non-current liabilities Total funded status
Amounts recognized in regulatory m e t
Prior service costl(credit) Net loss
Thls Report is: Date of Report YearlPenod of Report (I) X An Original (Mo, Da, Ur)
Amoua ts recognixed in AOCI (bcforc tax)
Prior service credit Net loss
Entargy Arkansas, Inc (2) A Resubmlsslon
$- ($8,803) ($10,249) $- s- c s- (19,071) (161,499) (158315) I1 ,lo 1) 8,665 16,200 14Jgs0)
(S19,071) ($170,302) ($168,764) ($1,101) $8,665 SM,200 (S4,950) ----'---
! I 2013M4
($12,996) 5- s- W,056) ($4,335) 66,505) ($4,702) 40,272 I I 9,304 6,485 22,772 IO297
0 7 3 7 6 $- s- MJ48 52,150 $16,267 55,595 ---a----
Entergy Entergy Entergy Gulf Stat- Entern Entergy New Entergy System
2012
Change in APBO Balance at beginning of year Service cost Interest cost Plan participant
contributions Actuarial Ioss Benefits paid Medicare Part D subsidy
received Balance at end ofyear Change in Plan Assets Fair value of assets at
beginning of year Actual return OR plan assets EmpIoyer contributions Plan participant
contributions Benefits paid Fair value ofasscts at end of
Funded status year
(in Thousands)
5290,613 $191,877 $196352 $94,570 $69,316 9,089 7,52 1 7,7 9 6 3,093 1,689
14,452 9,590 9,78 1 4,716 3,422
4,440 1,945 2,725 1,269 742' 1 3 3 6 5,818 16,215 1,625 3,240
(17,873) (9,543) (13,760) (5,199) (4,605)
133 t
S3 15308
$133,602 $60,S26 3,651 3,293 6,650 3,028
1,526 820 2,645 2,861
(6,604) (2,764) .
779 . 908 434 396 644 170 5207,987 f220,O 17 S 100,508 $74,200 S 142,114 S67,934 -
S 164,846 s- S- S54,452 $53,418 S?OS,f8l 532,012 18219 - c 5,874 4,691 10,869 3,419 24,386 7,598 11,035 6,555 4,405 4,852 5,987
4,440 1,945 2,725 1,2269 742 1,526 820 (17,873) (9,543) (13,760) (5,199) (4,605) (6,604) (2.764)
S I 94,O I 8 $- 5- $62,95 1 $58,65 1 $1 15,824 $39,474 (S121,290) (5207,987) (S220,017) (S37,557) ($15,549) (526,290) ($28,460)
IFERC FORM NO. I (ED. 12-88) Page 123 53 1
I
Name of Respondent This Report is: Date of RepoFt (Mo, Da, Vr) (1) &An Original
Enlsrgy Arkansas. Inc. (2) - A Resubmission I t
Amounts rccognized in the balance sheet
Current liabilities Non-cumnt liabilities Total funded status
Amounts recognized in rcgdatory asset
Prior service costl{credit) Net loss
YcarlPeriod of Report
201YP4
Amoanb recognhed in AOCI (before tax)
Prior servicc credit Net loss
$- ($7,546) ($9, t52) s c c s-. (12130) (20044 I ) (2110,165) (37,557) (15,549) (26,290) (28,460)
(S 121390) ($207,987) (S220,o 17) ($37,557) (I 15,549) ($26,290) ($28.460) -1
-------:
(62,146) s- $- ($566) $114 ($1,709) (S246) 26,502 6 1,077 29,773 129,4 84 - - 41,855
S 127,338 s- s- MI289 $226,616 S59J68 $29,527 --
pp-7-w-
s- (32,6%7) ($1,095) P r6- $- s-
s- $74,426 582,700 s- s- s- s- I I - I - - 77,113 83,795 -------
Nnn-Ouatifietl Pension Plans
Entcrgy also sponsors nonqualified, non-contributory defined benefit pension- plans that provide bencfits to certain key empIoyees.
The Registrant Subsidiaries (except System Energy) participate in Entew's nonqualified, non-conhiibutory defined benefit pension plans that provide benefits to certain key employees. The nct periodic pension cost for their employees for the nonqudified plans for2013,20!2, and 201 1, was as follows:
Entergy Eatew E n t e w Gulf States Enfcqg Eritergy New Entergy
Arkansas Louisiana huisinna Mississippi Orleans Texas (In Thousands)
2013 $448 $151 $12 $292 $92 $1,001 2012 $4 64 $158 $12 $183 $79 $648 201 1 $498 $157 %I4 $190 - $65 $763
Included in the 2013 net periodic pension cost above are settIemcnt charges of $415 thousand for Entergy Texas related to the lump sum benefits paid out ofthe plan, Included in the 2012 net periodic pension cost above are settIement charges of $38 thousand for Entcrgy Arkmsas related to the lump sum benefits paid out of lhe plan. TncIudcd in the 201 1 net periodic pension cost above are settlemcnt charges of $41 thousand for Entergy Arkansas related to the lump sum benefits paid out of the plan.
The projected benefit obligation for Iheir employees for the nonqwlified plans as of December 31,2013 and 20 12 was as foIiows:
IFERC FORM NO, I (ED. 12-88) Page 123.54 f
Name of Respondent This Report is: (1) X An Original
Date of Report YearlPericd of Report (Mo, Da, Yr]
Entergy Arkansas. l n c (2) - A Resubmission ’ / I 201wQ4
2013 2012
E n t e e Entergy Entetgy Gulf States Entergy Eatergy New Entergy
Arkansas Louisiana Louisiana Mississippi Orleans Texas (In Thousands)
$4,162 $2,5 1 1 $50 $ t ,752 $434 S7,S 10 $4,323 $2,909 $116 $1,841 $457 $9,732
IFERC FORM NO. 1 (ED. 12-881 Page 123 55 1
Name of Respondent This Report Is: Date of Report (1) An Original (Mo, Da, Yr)
EntergyArkansaj, Ine. (2) - A Resubmbslon I I
The accumulated benefit obligation for their employees for the nan-qualified plans as of December 3 1,2013 and 20 12 was Bs folIows:
YearlPeriod of Report
20131P4
E n t c w Entcrgy Entergy Gull States E n t e w Entergy New Enfew
Arkansas huisiana Louhiaaa Mississippi Orleans Texas (In Thousands)
2013 $3,765 $2,510 $50 $1,528 $3 87 $7,496 2012 $3,856 ' $2,899 $116 $1,590 $427 $9,127
The following amounts were recorded on the balance sheet as of December 3 1,2013 and 20 12:
Entergy Entcrgy Entergy Cuff Stat= Entew Entergy New Entergy
(In Thousands) 2013 Arkansas Loulstana hulsiana MMfss?sslppl Orleans Texas
Current liabilities Non-current 1 iabilities Total funded status
Regulatory asset/(liability) Accumulated other
comprehensive income (bcfore taxes)
2012
($367) ($262) ($6) ($118) ($20) ($786) (3,795) (2249) (44) (1,634) (4 14) (7,124)
$1,979 $422 ($871 $637 ($18) (%1,63 13
($4,162) {%2,511) ($50) ($1,752) ($434) ( $ 7 9 I 0) ----I
$- $57 $- c $- c
Enfergy EIlteb-gy Enfergy CullStates Entergy Eatergy New Entcrgy
Arkansas Louishna Louistane MIssIssiml OrIeanr Texas . _ (In Thousands)
Current liabilities ($209) ($257) ($171 ($Its) ($251 ($853) Non-current tiabilities (4,f 14) (2,652) (99) (1,723) (432) (8,879)
($4,323) ($2,909) ($1 16) ($1,841) ($457) ($9,732) To!d funded status
Regulatory assetl(liability) $2359 $674 W 9 ) $800 588 ($465) Accumutated other
--I---
comprehensive income (before taxes) c $102 $- %- 3- $-
Accounfinr for Pension and Other Post retirement Benefits
Accounting standards rcquirc an employer to recognize in its balance sheet the funded status of its benefit plans. This is measured as the diffcrcncc bctwcen plan assets at fair value and the benefit obligation. Enter# uses a Dccember 31 mcasurement date for its pension and other postretirement plans. Employers are fo record previously unrecognized gains. and losses, prior service costs, and any remaining transition asset or obligation (that multed from IFERG FORM NO. 1 (ED. 12-88) Page t23 56 1
Name of Respondent This Report Is: Date of Report YearlPenod of Report (1) An Original (Mo, Da, Yr)
Entergy Arkansas, Inc. (2) - A Resubmisslon I 1 2a131~4 NOESTO FINANCIAL STATEMENTS (ConBnued) -
adopting prior pension and orher postretirement benefits accounting standards) as comprehensive income and/or as a regulatory asset reflective of the recovery mechanism for pension and other postretirtrnent benefit costs in the Registrant Subsidiaries' respective regulatory jurisdictions, For the portion of Enter= Gulf States Louisiana that is not regulated, the unrecognized prior service cost, gains and losses, and transition assetlobligation for its pension and other postretirement benefit obligations nre recorded as other comprehensive income. Entergy Gulf States Louisiana and Entergy Louisiana recover other postretirement benefit costs on 3 pay as you go basis and record the unrecognized prior service cost, gains and losses, and transition obligation for its other postretirement benefit obligation as other comprehensive income. Accounting standards also requires that changes in the funded status be recorded 85 other comprehensive income andlor a regulatory asset in the period in which the changes occur.
With regard to pension nnd other postretirement costs, Entergy calculates the expectcd mtum on pension and other postretirement benefit plan assets by multiplying the long-term expected rate of return on assets by the market-dated value (MRV) of plan assets. Entern determines the MRV of pension plan assets by calculating a value that uses a 20-quarter phase-in of the difference between actual and expected returns. For other postretirement benefit plan assets Enteqy uses fair value when determining MRV.
Qualified Pension and Other Postmfirement Plans' Assets
The Plan Administrator's trust asset investment strategy is to invest the assets in a manner whereby long-term earnings on the assets (plus cash contributions) provide adequate funding for retiree benefit payments, Thc m h of assets
is based on an optimization study that idcntifies asset aliocation targets in order to achieve the maximum return for an acceptable level of risk, while minimizing the expected contributions and pension and postretirement expense.
In the optimization studies, the Plan Administrator formulates assumptions about characteristics, such as expected asset class investment return, volatility (risk), and CorreIation coefficients among the various asset classes. The futurc market assumptions used in the optimization study we determined by examining historical market characteristics of the various asset ckses, and making adjustments to reflect future conditions expected to prevail over the study pcriod. Target assct allocations adjust dynamicaily based on the funded status of the pension plans. The fotfowing targets and mngcs were established to produce ~n acceptable, economically ehicient plan to manage around the targets. The target assct allocation range below for pension shows the ranges within which the allocation may adjust based on funded status, with the expectation that the allocation to fixed income securities will increase as the pension funded status increases, The target and range asset alhation for postretirement assets reflects changes made in 2012 as recommended in the kcst optimization study
Enters's qual ificd pension and postretirement weighted-average asset allocations by asset category at December 31,2013 and 2012 and the target =set allocation and ranges are as follows:
Pension Acfuat Actual Asset Allocafion Target Range 2013 2012
Domestic Equity Securities 45% 34% to 53% 46% 44%
IFERC FORM NO. t (ED. iz-sal Page 123 57 1
Name of Respondent This Report is: Date of Report YearlPenad of Report (1) X An Original (Mo, Da, Ur)
International Equity Securities 20% 16% to 24% 20% 20% Fixed Income Securities 35% 32% to 41% 33% 35% Other 0% 0% to IoO/P 1% 1%
Entfirgy mansas, Inc.
Postwhment Asset Ahcat ion Non-TaxabIe Taxable
Actual Actual Actual Actual Tatget Range 2013 2012 Target Range 2013 2012
(2) - A Resubmission - I t 2013144
DornesticEquitySccuriti~ 39% 34% to 44% 40% 38% 39% 34% to 44% 39% 39% IntemationaI Equity Securities 26% 21% to 31% 26% 28% 26% 21% to 31% 27% 27% Fixed Income Securities 35% 30% to 40% 34% 34% 35% 30% to 40% 34% 34% Other 0% 0% to 5% 0% 0% 0% 0% to 5% 0% 0%
In dctcnining its exptcttd long-term mte of return on plan assets used in the calculation of benefit plan costs, Entergy r c v i m pltst pcrfomnncc, cumnt and expected future m e t aIIocations, and capital market assumptions of its investment consultant and invcshntnt managers.
The e x F t e d Iong-tenn rate of return for the qualified pension plans' assets is based primnriiy on the gcometn'c avcmge of the historical annual pcrfunnanct of a representative portfolio weighted by the target asset allocation defined in the tabIc above, dong with other indications of expected return on current assets and expected return avaiIabIe for reinvestmenl. The time pcrhl rrflcctcd is a long dated period spanning several decades.
The expected long-tmn rate of rctum for the non-taable postretirrment trust ass& is determined using thesarnc methodology described above for pension assets, but the asset allocation specific to the non-tawbie postre!irement,8ssets is used.
For the taxable postretirement trust assets, the hvestment aIIocation includes ku-cxempt fixed incomc securities. This msct allocation in combination with the same methoddogy employed to determine the expected return for other trust assets (as dcmibcd above), with a modification to reflect 3pplicabIe taxes, is used to produce the expected long-term rare of rcturn for tarable postretirement trust assets.
Concentdons ofcredit Risk
Enter@ investment guidelines mandate the avoidance of risk concentrations, Types of concentrations specified to bc avoided include, but are not limited !o, investment concentntions in a single entity, type of industry, foreign country, gographic area and individual security issuance. As of Decernber31,2013 all investment managers and assets were materially in compliance with the approved investment guidelines, therefore there were no significant concentrations (defined as greater than 10 percent of plan assets) of risk in Entergy's pension and other postretirement
]FERC FORM NO. 1 {ED. 12-88) Page I23 58 1
Name of Respondent
Entern Arkansas. Inc ti21 -A Resubmission 1 I / I 201304 NOTES TO FIMNCW STATEMENTS (Conllnued)
This Report Is: (I) An Origlnal
YearlPenod of Report
benefit plan assets.
Falr Value Mensuremenis
Accounting standards provide the framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highcst priority to unadjusted quoted prices in active markets for identical assets or liabilities (level 1 measurements) and the Iowest priority to unobservable inputs (level 3 measurements),
The three levels of the fair value hiemhy me described below:
Level I -Level 1 inputs are unadjusted quoted prices for identical assets or Iiabilitits in active markets that the Plan has the ability to access at the measurement date. Active markets me those in which transactions for the asset or tiability occur in suffjcient frequency and volume to provide pricing information on an ongoing basis.
Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that arc, eithcr dimtry or indirectly, observable for the m e t or IiabiIity at the memurernent date. Assets artre valued based on prices derived by an independent party that uses inputs such as benchmark yields, reported trades, brokerldealer quotes, and issuer spreads. Prices are reviewed and can be chalIenged with the independent parties and/or ovcmddcn if it is believed such would be more reflective of fair value. Level 2 inputs include the following:
- - - -
quoted prices for simiIar assets or l iabilit i~ in active markets; quoted prices for identical assets or liabilities in inactive markets; inputs other than quoted prices that are observable for tbe asset or liability; or inputs that are derived principaily from or corroborated by observable market data by correlation or other means.
If an asset or liability has a specified (contractual) term, the LeveI 2 input must be observable for substantidy the full term of the asset or liability.
Leve? 3 - Level 3 refers to securities valued based on significant unobservable inputs,
Assets and liabilities are classified in their entirety based on the lowest level of input that i s significant to the fair M I U ~ measurement. The following tables set forth by level within the fair valuc hierarchy, measured at fair value on a recurring basis at December 3 1,20 13, and Decembr 3 1,2012, a summary of the investments held in the master trusts for Entew’s qualified pension and other postrethment plans in which the Registrant Subsidiaries participate.
~ F E R C FORM NO. 1 (ED. iz-sq Page 123 59 I
i
Name of Respondent This Report is: Date of Report (Ma, Da, Yr) { 1 ) &An Origlnal
Qualified Pension Trust
YearlPeiiod of Report
2013 Level 1 Level 2 LRvel3 Total (In Thousands)
Equity securitims:
Preferred Common
Corporate stocks:
Common collective trusts
U.S. Government securities Corporate debt instruments Registered investment companies Other
Insurance company general account
Fixed income securities:
Other:
(unallocated contracts) Total Investments
Cash Other pending transactions
$6,847 (b) 915.996 [b) - 180,718 (b)
316,863 (d) I
5 1 A2O.424
$6,038 (a)
1,753,958 (c) I
132,915 (a) 464,652 (a) 486,748 (e) 129,269 (r)
36,886 (g) $3.030.3 66
$- $12,885 I 915,996 - 1,753,958
- 333,633 464,652
c 803,6 11 - 129,169
-
Less: o tier postretirement assets inctuded in total investments
Toial rair value of qualilied peasion assets
. - .. ~
280 8,081
(29,9 14)
$4,429,237
2012 Iteve1 1 Level 2 . h v d 3 Total (In Thousands)
Equity securitirrs:
Preferred Common
Corporate stocks:
Common collective trusts
U.S. Government securities Corporafe debt instruments Registered investment companies Other
Fixed income secutjties:
Other: Insurance company general account
(unallocated contracts) Total Invntments
Cash
$861 (b) $5,906 (a)
I 1,620315 (c) 787,132 {b) -
161,593 (b) 150,058 (a) I 429,813 (a)
50,029 (d) 483,509 (e) - 111,oo1 (0
%- $6,767 787,132 -
- 1,620,315
- 3 11,661 I 429,s 13 - 533,538 - 11 1,001
- 36,252 S 53,836,479
571
IFERC FORM NO. I (ED. 12-88) Page 123 60 I
Name of Respondent This Report Is: Date of Report (Mo, Da, Yr) (1) &An Original
Enlergy Arkansas, Inc. (2) A Resubmission i t
Other pending transactions Less: Other postretirement assets included in total investments
TotaI fair d u e of qualilicd pension assets
YearlPeiod of Report
20131Q4
0 ther Postretirement Trusts
2013 Level 1
Equity securities:
Fixcd fircome securities: Common collective trust
U.S. Government securitics Corporate debt instruments Registered investment companies Other
Total investmenis Other pending transactions PIUS: Other postretirement assets
included in the investments of the qualified
pension trust Told fairvatue ofofher postretirement assets
2012
40,808
4,163
$44,971
I
I
Level 1
4,594
18,7841
$3,832,860
Level 2 Level 3 Total L
(In Thousands)
$3 56,700
Ib> 43,47 t 50,563
(4 43,458
$494.1 92
-
(4 $- $356,700
84J79 50,563
I 4,163 43,458
$- J $539,163
773
- - (4
(a1
(0 I
29,9 i4
$569.850
Level 2 Level 3 Tofal (In Thousands)
Equity securities:
Fixed income securities: Common collective trust
U.S. Government securities Corporate dcbt instruments Registered investment
Oher companies
$-
36,392 -
3,229 -
$314,478 (c) $- $314,478
43998 (a) - 79,790 42,163 (a) - 42,163
39,846 (0 c 39,846 $439,885 $- $479,506
Other pending transactions I58 - - Total investments $39,621: -
plus: Other postretirement =sets included in the investments of the qualified pension trust Total fair value of other postretirement assets
8,784
[ FERC FOKM NO. 1 (ED. 12-88) Page t23.61 1
Name of Respondent Thts Report is: It 1 An Original
Cerbin preferred stocks and fixed income debt securities (corporate, govemmenf and securitized) are stated at fair value as determined by broker quotes. Common stocks, treasury notes and bunds, and certain preferred stocks and fixed income debt securities are stated at fair value determined by quoted market prices. The common collective trusts hold investments in accordance with stated objectivcs. The investment strategy of the trusts is to capture the gowtb potential of equity markets by replicating the performance ofa specified index. Net asset value per share of the common collective msts estimate fair vntue. The registered investment company is a money market mutual fund with a stable net assct value of one dollar per share. The registered investment company holds investments in domesstic and international bond markets and estimates fair value using net asset value per share. Thc othcr remaining assets are U.S. municipal and foreign government bonds stated at fair value BS determined by broker quotes. The unalIocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made undcr the contract, plus interest, Iess funds used to pay benefits mid contract expensts, and less distributions to the master trust.
Date of Report YeadPend of Report (Mo, Da, Yr)
Accumulated Penslon llnenefit Obligatian
The qualified pension accumu~ated benefit obligation for each of thc Rcgistmnt Subsidiaries for their employees as of December 31,2023 and 2012 was ILS follows:
December 31- 2013 2012
(In Thousands) Entergy Arkansas S I, 1 07,023 $1,16 f ,448
Enter= Louisiana 5697,945 $735,376
Entergy New Orlcans $150,239 $157,233 Entergy Texas S332,4 84 $ 3 5 0 3 1 System Energy $247,807 $25 1,378
Enterw Gulf Stabs Louisiana $53 0,974 $559, I 90
Enterw Mississippi 53 t 8,94 1 $33 6,aw
Esfimated Future ncnefit Payments
Based upon the assumptions used to measurc Entergy's qudified pension and other postretirement benefit obligations at December 31, 2013, and including pension nnd other postretirement benefits' attributable to estimated future employec scrvice, Entergy expects that benefits to be paid and the Medicare Part D subsidies to be received over the next ten years for thc Rcgistmnt Subsidiaries will be BS foIlows:
Esdmated Future Enlergy Qualified Fensfon Entersy Gulf States Entcrgy . E n t c w Entcrgy Entergy System Bcnefiis Payments Arkansas LauIslana Loublana MIssIsslppi New Orleans Texas Energy
~FERC FORM NO. 4 (ED. i2-881 Page 123 62 I
Name of Respondent Thb Repod is: Date of Report (Mo, Da, Yr) (1) XAn Origtnat
EntargyMtanaas. Inc. (2) I A Resubmission I 1
(In Thousands) Year@) 20 14 $60,456 $23,039 $34,740 $26,920 $6,615 S18,583 $10,523 2015 $61,587 $24,260 $35,623 $17,669 $7,008 $19,137 $10,883 2016 $63,083 $25,556 $36,833 $18,515 $7,437 $19,744 $1 1,463 2017 $64,418 $27,111 $38,247 $19,298 $7,94 1 $20,402 $1 485 1 2018 ~ , 2 s 1 $2a,962 $3 9,9 I 4 $20,223 7 $8,582 $21,140 $12,615 2019 - 2023 $375,976 $177,010 $229,821 $1 14,462 $51,610 $118,750 $77,830
YearlPeriod of Report
2013iQ-4
Estimated Future
Pension Benefits Entergy Gulf States Enfergy Entcrgy Eafergy Enfergy Non-Qualilied Enfetgy
Arkansas Lcuhhna Loub!aaa MhsdssIppi New Orleans Texas - Payments (m ~housands)
Yea4s) 2014 $367 $262 $6 $1 19 $20 $786 2015 $345 $240 $6 $I 1s $20 $70 1 2016 5299 $233 $6 $108 $20 $775 2017 $299 $279 $6 $105 $20 $690 201s $279 5212 $5 $99 $19 $657 2019 - 2023 S1;,916 $932 $21 $64 8 $223 $2,95 1
Estimated Future Other
Pos!retlrernent Bencth Payments Entergy (before Medicare Entergy CutlStates Entergy Entergy Entcrgy Enfcrgy System Part D Subsidy) Arkansas buhlana LauIsIana MissLsIppI New Orleans Texas Enerffy
(In Thousands) Year@] 2014 $17,122 $9,3 85 $ I 0,967 $4,814 $5,044 $7,540 $2,85 8 20 15 5 155 13 $8,899 - $10,049 $4,267 $4,475 $6,S 18 $2,783 2016 $15,523 $9,137 $10,162 $4,340 $4,448 $6,934 $2,736 2017 $15,554 $9,403 $10289 $4,447 $4,423 $7,079 $2,875 2018 $15,987 $9,9 12 $1 0,796 $4,767 $4,502 $7-47 1 $2,984 2019 -2023 $82,455 S5S,934 $59,068 $25,8 19 $21,707 $40,067 $16,928
Mimated Future Enter#'
Subsidy Medicare Part D Entergy GulrStates Entergy Eatergy Eutcrgy Entergy System
Arkansas Louisiana Lowlslana MMsJppi New Orleans Texaj Energy (In Thousands)
_.
Year(5) 2014 $i,241 $582 $718 . $462 $387 $563 $t30
~ F E R C FORM NO. I (ED. 12-88) Page 123 63 1
Name of Respondent - TMs Report is: Date of Report YearlPenod of Report ’ {I) An Original (Mo, Da, Yr)
Entergy Arkansas. Inc (2) I A Resubmission I f 201304 NOTESSO FINANCIAL !XAlEMEMS (ConBnuedd)
2015 $68 $32 $3 9 $25 $20 $30 $8 2016 $74 $35 $43 $27 $20 $32 $9 2017 $81 $3 8 $46 $29 $2 1 $34 $10 2018 $354 $165 $299 $123 $85 3141 $5 I 2019 - 2023 $2,252 $1,061 $2,235 $742 $455 $816 $3 79
Canfrlhut ions
The expected 2014 pension and other postretirement plan contributions of the Registrant Subsidiaries for their empioyem are shown be!ow. The required pension contributions wilt not bc known with more certainty until the January 1,2014 valuations are comp?eted by April 1,2014.
The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretiremcnt plans for their employees in 2014:
Entergy Entern Gulf State~ Entcrgy Entergy Entergy Enlergy System
Arkansas toublnna Loubiana MhslssIppI New Orleans Texas Energy (In Thousands)
Pension
Other Contributions $9339 I 53 1,342 $52,885 $21,604 $10,482 $18,482 $21,257
Postretirement Contributions $25,567 $9,385 $1 0,967 s $- 54.6445 $864
Actuarial Aamnptiong
The significnnt actuarial assumptions used in determining the pension PBO and the other postretirement h e f i t APDO as ofDccembcr 3 1,2013, and 2012 were as follows:
2013 2012 Weighted-average discount rate:
Qualified pension S.O4%-526% 4.3 1% - 4.50% Blended 5.14% Blended 436%
Other postretirement 5.05% 4.36%
Weighted-average rate of increase in future compensation levels 4.23% 4.23% . Nonqualified pension 4.29% 337%
The significant actuarial assumptions used in determining the nct pcridic pension and other postretirement benefit costs for2013, 2012, and 201 I were BS follows:
2013 20 12 201 1 Weighted-average discount rate:
Qualified pension 4.31% - 4.50% 5.10?? - 5.20% 5160% 9 5.70% *
1 FERC FORM NO. 1 (ED, 12-88} Paga 123.64 - I
Name of Respondent This Report Is: (I) X An Original
Entergy Arkansas, ioc. (2) - A Resubmission
Other pos tretiremcnt 436% 5.10% 5.50% Nonguali fied pension 337% 4.40% 4.90%
Weighted-avenge rate of increase
Expected long-term rate of in future compensation levels 423% 4.23% 423%
return on plan assets: Pension asscts 8.50% 8.50% 8.50% Other postretirement non-taxable assets 8.50% 8.50% 7.75% Other postretirement taxable assets 6.50% 6.50% 5.50%
Date of Report YearlPenod of Report (Me, Da, Yr)
* I t 201 3Q4
Enter@ othcr postretirement benefit transition obligations were amortized over 2Oyears ending in 2012.
The assumed health care cost trend rate wed in measuring Entergy's December31,2023 APBO was 725% for pre-65 r e t i r m and 7.00% for post-65 retirees for 2013, gradually decreasing each successive year until it reaches 4.75% in 2022 and k y o n d Cor both predS and post-65 retirees. The assumed health care cost trcnd rate used in mcauring Entergy's 2013 Net Other Postretirement Benefit Cost was 7.50% for pre-65 retirees and 7.25% for post45 ret i rm for 2013, gradually decreasing each successive yew until it rcaches 4.75% in 2022 and beyond for bath pre-65 and post-65 re times.
A one pcrcenhgc point change in the assumed hcalth care cost trend mte for 2013 would have the following effects for the Registrant Subsidiaries for their employees:
2013
Enteqg Arkansas Enteqg Gulf States buisiana Entera Louisiana Entergy Mississippi Entergy New Orleans Entergy Texas System Energy
1 PereentaEe Poht Xnerease 1 Percentage Point Decrease Impact on the Impacton the sum of service * sum of serrice
Impact on the costs and Impact ou the - costs and APUQ interest cost APBO interest cost
Xncreasd(Decrease) (In Thousands)
$27,205 $3,275 ($22,4 83) ($2,622) $21,873 $2,792 ($17,958) ($2,2 19)
$8,235 $1,072 ($6,8 19) ($858) $4,995 $562 ($4342) ($461)
$13,439 $1,483 ($1 1,170) ($1, t 89) $7,022 $1,064 ($5,746) ($847)
$1 8,025 $23 I4 ($1 5,0 I 2) ($2,03 1)
Medicnrc Prescription Drue, Jrnnrovemenf and Modernization Act of 2003
In Decernkr 2003, the Medicare Prescription Drug, Improvement and Modernization Act of 2003 became law. The Act introduces a prescription drug benefit cost under Medicare (Part D), which started in 2006, BS well E a federal subsidy to employers who provide B retiree prescription drug benefit that is at Icast actuarially equivalent to
LFERC FORM NO. I (ED. m a ) Page 123.65 1
Name of Respondent This Report Is: (I) ~ A I I Original
Entergy Arkansas. Ine. (2) I A Resu bmission
Medicarc Part D.
Date of Report YearIPeriod of Report (Mo, Da, Yr)
I 1 20131Q4
The actuarially estimated effect of future Medicare subsidies and the actual subsidies received for the Registrant Subsidiaries for their employees was as follows:
En tergy Entergy Gulfstates Enfergy Entergy Entergy Entergy System Arkansas Louisiana Lontsiana Mlsshslppl New OrIeam Texas Energy
Increasd{Decreim) In Thousands Impact on 12/31/2013 APBO Impact on W3112012 APBO Impact on 20 13 other postretirement benefit cost
Impact on 2012 other postretirement benefit cost
Tmpact on 201 1 0th
postretirement benefit cost
Medicare subsidies received in 20 I3
($9,63 9)
($62,8 7 7)
($4,732)
($5,79 I)
($6,309)
$737
Defined Contrihulion Plans
($4,875)
($32,055)
($2,988)
($3,660)
($3,923)
$410
($5,5 SO)
($3 6,O f 5 )
($3,025)
($3,643)
($3,8 8 9 1
$513
($3,060) ($1,769)
($19,507) ($10,902)
($1,503) ($729)
($1,799) ($9953
($2,0 I 6) ($1,170)
$245 $194
($3,324)
[$21,164)
($1,045)
I$1ml
($1,528)
$334
($1,973)
($13,58 6)
($1,093)
($ I ,4 0 0)
($1,403)
$105
Entcrgy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The System Savings Plan is a defined contribution plan covering eligible employees of Eniergy nnd its subsidiaries. The employing Entcrgy subsidiary makes matching contributions for all non-bargaining and certain bargaining employees to the System Savings Plan in an amount equal to 70% of the participants' basic contributions, up to 6% of their eligible earnings per pay period. The 70% match is nllocated to investments as directed by the employee.
Entergy also sponsors the S3vings Plan of Enterw Corporation and Subsidiaries IV (established in 20021, the Savings Plan of Entergy Corporation and Subsidiaries VI (established in April 2007), and the Savings Plan of Entergy Corporation and Subsidiaries VII (established in April 2007) io which matching contributions are also made. The plans arc defined contribitim plans that cover eligible employees, as defined by each plan, of Entergy and its subsidiaries.
IFERC FORM NO. 1 (ED. 12-88) Page I23 66 I
Name of Respondent This Report is: Date of Report (Mo, Da, Yr) {I) XAn Original
Entergy Mamas, he. (2) - A Resubmission I I
The Registrant Subsidiaries' 2013, 2012, and 2011 contributions to dcfined contribution plans for their employees were as folfows:
Entergy Entergr GutrStates Entergy Enfern E n t e w Entergy
(in Thousands) Year Arkansas Loubfana huhlana MksbsIppI New Orleans Texas
2013 $3,351 $1,906 $2,393 $1,954 $769 $1,616 2012 53,223 $1,842 $2,327 $1,875 $740 $1,601 201 I $3,183 $1,804 $2,260 $1,894 $725 $1,613
YearlPeriod of Report
2013tQ4
NOTE 12. STOCK-BASED COMPENSATION
Note 12 to the financial statements is not applicable to the Registrant Subsidiaries.
NOTE 13. BUSINESS SEGMENT INFORMATION
Repistrant Snhsidiatigs
Each of the Registrant Subsidiaries has one reportable segment, which is &I integrated utility business, except for System Energy, which is an electricity generation business. Each of ihe Registrant Subsidiaries' opeations is managed on an integrated basis by that company because of the substantial: eftect of cost-based rates and reguIatov oversight on the business process, COS! structures, and opemting results.
NOTE 14. EQUITY METHOD XNWSMENTS
See FERC Form 1 page I03 (Corporations Controtled by Respondent) and pages 224-225 (Investments in Subsidiary Companies).
NOTE 15. ACQWSl"I0NS AND DTSPUSiTIONS
Acquhitiona
Hot Spring Energy Facility
In November 2012, Entergy Arkansas purchased the Hot Spring E n c w FaciIiQ, a 620 MW combinedcycle natunl gas turbine unit located in Malvem, Arkansas, from KGen Hot Spring LLC for approximately $253 million. Thc FERC and the APSC approved the transaction.
NOTE 16. RISK MANAGEMENT AND FAIRVALUES
~ F E R C FORM NO. A (ED. 12-88) Paqe 123 67 1
Name of Respondent This Report Is: (1) XAn Original
Entttrgy Arkansas. Inc I ( 2 L A Resubmission I 2013144 NOTES TO FINANCIAL STATEMENTS (Continued)
YearlPeriad of Report
Market Wsk
The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To Ihe extent approved by their retail regulators, the Utility operating companies hedge the exposure to price volati!ity inherent in their purchased power, fuel, and gas purchased for resafe costs that are recovered fmm customers.
Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are ctassified t ~ s normal purchasdnormal: sale transactions due to their physical settlement provisions. Normal purchasclnomal sale risk management toofs include power purchase and sales a p m e n t s , fuel purchase agreements, capacity con!mfs, and tolling agrecmcnts. Financiafly-settled cash flow hedges can include natural gas and electricity swaps and op~ims and i n l m s t rate swaps. Enterm may enter into financially scttled swap and option contracts to manage market risk ihat may or may not be designated as hedging instruments.
In connection with joining MISO, Enterm received a direct allocation of FTRs in November 2013. FTRS are derivative instrtlmmts which rcpmcnt economic hedges of future congestion charges that will be incumd in serving Enlergy's Iwd. They ate not designated as hedging instruments. Entcrgy XiaIIy records FTRs at their estimated fair value and subsequently sdjustr the carrying valuc to their estimated fair vaIuc at the end of each ~ccounting period prior to settlement. Unrealid pins or lossts on RRs held by Entergy Wholesale Commodities are included in operating rcvenues, Tfrc Utility operating companies recognize regulatory Iiabilities or asscts for unrealized gains or losses on FIR. The tat31 volume of Frk outstmding us of Dcccmber 31,2013 is 37,647 GWh for Entcrgy, including 8,769 GWh for Entcqy Arbnms, 6,125 GWh for Entersy Gulf States Louisiana, 9202 GWh far Entcra Louisiana, 6,112 GWh for Enterg Mississippi, 1,402 GWh for Entetgy New OrIcans, nnd 6,038 GWh for Enterw Texas- Credit support for FTRs held by the Utility opttatin! companies is covered by cash or letters ofcredit issued by each Entergy Utility openting company as q u i d by MfSO.
Due to regulatory freatment, the natural gas swaps are marked-to-market through fk l , fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously rcverscd and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps we settled are recovered or refunded through fuel cost recovery mechanisms.
Due to regulatory trcatrnent, !he changes in the estimated fair value of FTRs are recorded through purchased power expenses and then such amounts nre simuhneoudy rcvcrscd and rccardcd as an uffsetting regulatory asset or Iiability. The gains or losses recorded ILS purchased power expense when the FTRs are settled arc rtcovcred or refunded through fuel cost recovery rncchankrns.
The fair vaIues of the Registrant Subsidiaries' derivative instmments not designated &i hedging instruments on their balance sheets as of December 3 1,2013 and 2012 are as follows:
~ F E R C FORM NO. I (ED. 12-88] Paga 123 68 1
Name of Respondent This Report Is: (I) An Original (Mo, Da, Ur)
Date of Repart YearlPerrod of Report
Entern Arkansas, Ine (2) - A Resubmisslon I ! 20131Q4
-. NOTES TO FINANCIAL STATEMENTS (Conbnued)
Instrument Balance Sheet Location Fair Value Registrant
2013 Assets: Natural gas swaps Natural gas swaps Natural gas swaps Natural gas swaps
Gas hedge contracts Gas hedge contracts Prepayments and other Prepayments and other
Prepayments and other Prepayments and other Prepayments and other Prepayments and other Prepayments and other
$2.2 milIion ' Enterm GulFStates Louisiana $2.9 million Entergy Louisiana $0.7 million Entergy Mississippi $0.1 million Entergy New Orleans
$6.7 million $5.7 milIion Entergy Louisiana $1.0 million Entergy Mississippi $2.0 mi t I ion $18.4 miltion Entergy Texas
Entergy Gulf Stat= Louisiana
Entergy New Orleans
2012 Liabilities: Natural gas swaps Gas hedge contracts $2.6 million Entergy Gulf States Louisiana Natural gas swaps Gas hedge contracts $3.4 million Entergy Louisiana Natural gas swaps Other currcnt IiabiIitics $22 million Entergy Missksippi
The effects of the Registrant Subsidiaries' derivative instruments not designated as hedging instruments on their income statements for the years ended December 3 1,2013,2012, and 201 1 are as follows:.
Amount ofgain (103s)
recorded Instrument Income Statement Location. in income Registrant
2013 Natural gas swaps Fuel, fuel-relatcd expenses, $4.5 miIIion Entergy Gulf States
Natural gas swaps Fuel, fueldated expenses, $6,O million Enterw Louisiana
Natural gas swaps Fuel, fuel-related expenses, $2.5 million Enterw Mississippi
Natural gas swaps Fuel, firel-related wpenses, - $0.1 million Entergy New OrIeans
and gas purchased for resale
and gas purchased for remale
and gas purchased for resaIe
and gas purchased for resaIe
Louisiana
FrRs Purchased power expense $(O. 1) million Entergy Arkansas FTRS Purchased power expense $0.3 million Enterw GrtlFStates
m Purchased power expense $ 0 2 rniIlion Entergy Louisiana FrRs Purchased power expense $1,0 million Entersy Mississippi
[FERC FORM NO. i (ED. 12-88) Page t U.69 i
Louisiana
Name of Respondent This Report Is: Date of Report YearlPenad of Report (2) X An Original (Mo, Da, Yr)
20 13M4
N O E S TO FlNANCLAt STATEMENTS fConItnued)
m Purchascd power expense $12 million Entergy New Orlc3ns FrRs Purchased power expense $0.8 million Entergy Texns
2012 Natural gas swaps
Natural gas swaps
Natural gas swaps
Natun? gas swaps
Fuel, fuel-related expenses, and gas purchasscd for resale Fuel, fueldated expenses, and gas purchased far resde Fuel, fueI-rclatcd expenses, and gas purchased for resak Fuel, fuel-rclated expenses, and g;ls purchased for resale
2011
($12.9 million)
($16.2 million)
($1 12 million)
($1.5 million)
Entergy Gulf States Lo tl is i an a Entergy Louisiana
Enterw Mississippi
Enterjg New Orleans
~_____
Natural gas swaps
Naturnt gx swaps
Natural gas swaps
Naturnl gas swaps
Fuel, fuel-related expenses, and gas purchased for resale Fuel, fuel-related expenses* and gas purchased for rcsaIe Fuel, fuel-related expenses, and gas purchased for resale Fuel, fuel-related cxpcnses, and gas purchased for resale
($17.9 million)
($25.6 mi!lian)
($15.0 miIIion)
($3.2 million)
Entersy Gulf States Luuisiana Entergy Louisiana
Entergy Mississippi
Enterw New Orleans
The estimated fair values of Entergy's financial instruments and dcrivntives are determined using historical prices, bid priccs, market quotes, and financial modeling. Considerable judgment is required in developing the estimates
' of fair value. ThereFore, estimates are not necessarily indicative of the amounts that Enterw could reaIire in a cumnt market exchange. Gains or Iossa realized OR financial instruments other than those instruments held by the Entersy Whotcsale Commodities business are reflected in future rates' and therefore do not affect net income. Enterm considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because ofthe short maturity of these instruments.
Accounting standards define fair value FS an exit pice, or the price that would bc received to seII an asset or the amount that would be paid to transfcr a liability in an orderly transaction between knowledgeable market parficipants at
the date of measurement. Entergy and thc Registrant Subsidiaries use assumptions or market input data that market pariicipants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobseruable. E n f e w and the Registrant Subsidiaries endeavor to use the bcst available information to determinc fair value.
Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishcs thc highest priority for unadjustcd rnarkct quotcs in an active market for the identical asset or Iinbility and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are:
~FERC FORM NO. I (ED. 12-88) Page t 23.70 I
Name of Respondent Thls Report is: (1) X An Original
Entetgy Arkansas, Ine , (2) A Resubmission
Level 1 -Level I inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurcrnent date. Active rnarkeis are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primariiy consists of individually owned common stocks, cash equivalents (temporary cash investments, securitintion recovery trust account, nnd escrow accounts), debt instruments, and gas hedge contracts. Cash equivalents includes ail unrestricted highly liquid debt instruments with an originat or remaining maturity of three months or Ins at &e date of purchase.
Level 2 - h v e i 2 inputs are inputs other than quoted price included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date, Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, brokerldcalcr quotes, and issuer speads. Prices are reviewed and can be challenged with the independent parties a d o r ovemdden by Entergy if it is beIieved such would be more reflective of fair value. Level 2 inputs include the following:
Date of Report YearlPenud of Report (Mo, Da, Ur)
I t 20131c14
quoted prices forsimilar assets or liabilities in active markets; quoted prices for identical assets or liabilities in inactive markets; inputs other than quoted priccs that are observable for the asset or liability; or inputs that are derived principa?ly from or corroborated by observable market data by cornfation or other means.
Level 2 consists primarily of individaally+rvned debt instruments or shares in common trusts, Common trust funds arc stated at estimated fair value based on the fair market value of the undedying investments.
'0 Levet 3 - LeveI 3 inputs arc pricing inputs that are gcnerally less observabIc or unobservable from objective soumes. Thcse inputs are used with internally developed methodologies to produce management's best estimate of fair value for the asset or liability. Level 3 consists pn'mady of FRs and derivative power contracts used IIS
cash flow hcdges of powcrsales at merchant power plants.
The vnIues of FIRS are based on unobservable inputs, including estimates of future congestion costs in MISO behveen appiicable sink and source pricing nodes based on prices pubIished by MISO. They are classified as Level 3 assets and liabilities. The valuations of thcse assets and Iiabilities were performed by the Entergy WholcsaIe Commodities Back Office for the unregulated business, and by the Risk Control Group within System Planning and Operations for the Utility operating compania. Enterm's Accounting Policy group evaluated thee valuations, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in ~e valuation. The Risk Control Group d t h i n System PIanninS and Operations performed 8 similar rok' for the Utility operating companies that the Entergy Wholesale Commodities Back Off~ce performed for the unregutnted busin~ss. The Risk Control Group within System Planning and Operations reported to the Vice President - System Planning. Thc Accounting Policy group reported to the Vice President, Corponte Controller.
The following table sets forth, by IeveI within the fair value hienrchy, the Registrant Subsidiaries' assets that are
IFERG FORM NO. (EO. 12-88) Page f23 71 t
Name of Respondent ThIs Report Is: YeadPeriod of Report (1 1 X An Original
Entergy Arkansas, Ine. I t 2013144 NOTES TO FtNANClAL STATEMENTS (ContInucd)
accounted for at fair value on a recurring basis as of December34 2013 and December 3 1,2012. The assessment of the significance of a particular input to a fair value mensurement rcquircs judgment and may affect its placement within the fair value hierarchy IweB.
Entergy Arkansas
2023 LeveI 1 Level 2 Level 3 Total (In Millions)
Assetj: Tempornry cash investmcnts $122.8 $- + $122.8 Decommissioning trust funds (a):
Equity securities 13.6 449.7 - 463.3 Debt securities 58.6 189.0 I 247.6 - 3.8
Escrow accounts 26.0 c - 26.0 $224.8 $63 8.7 s- $863.5
Securitization recovery trust account 3.8 3
2012 Level: 1 Level 2 Level: 3 Total (In Millions)
Assets: Temporary cash investments $24,9 s $- $24.9 Decommissioning trust funds (a):
Equity securities 9.5 374.5 - 384.0 Debt securities 943 122.3 3 216.6
4.4 - 38.0
$171.1 $496.8 $- $667.9
Securitization recovery trust account 4.4 - - Escrow accounts 38.0 -
(a) The decommissioning trust funds hold equity and fixed income securities. Equity securities are invested to approximate the rctums of major market indices. Fixed income securities are held in various governmental and corporate securities. See Note 17 for additional information on the investment portfolios.
The following table sets fodh a reconciliation of changes in the net assets (liabilities) for the fair value of derivatives classified as Level 3 in the fair value hierarchy for theyear ended December 3 1,2013.
Eat.ergy Entergy E n f e w GuIfSfates Entcrgy Entergy New Entergy
Arkansas Louisiana Louisiana Mississippi OrIeans Texas (In Miilions)
Balance as of Januay I , s %- $- $- %- !€- Issuances of FTRs - 7.2 6.2 1 .I 2.2 20.0 Unrcalizcd pins (losses) included
~FERC FORM NO. 1 (ED. 12-88) Paga 123.72 1
Name of Respondent ThIs Report is: (1) X An Original
Date of Report YearlPeriad of Report ' (Mo, Da, Yr)
Eptergy Arkansas, he. {2) - A Resubmission 1 : 20t3Q4 N O E S TO FM"ANlAL STATEMENTS (Continued)
NOTE 17. DECOMMISSIONING TRUST FUNDS
Entew holds debt and equity securities, classified as available-for-sale, in nuclear decommissioning trust accounts. The NRC requires Entergy subsidiaries to maintain trusts to fund the costs of decommissioning AN0 1, AN0 2, River Bend, Waterford 3, and Grand Gulf, T h e funds 3re invested primariIy in equity securities, fixed-rate debt securities, and cash and cash equivalents.
Entergy records decommissioning trust funds on the balance shcct at their fair value. Because of the ability of the Registrant Subsidiaries to recover decommissioning costs in rates and in accordance with the regulatory treatment for decommissioning tmst funk, the Registrant Subsidiaries have recorded an offsetting amount of unrealized gains/(losses) OR invcstmcnt securities in other regulatory liabilitiedwsets. For the nonregulated portion of River Bcnd, Entew Guff States Louisiana has recorded an offsetting amount of unrealized gaind(1osses) in other deferred credits. Accordingly, unrealized gains recorded on the assets in thesc trust funds are recognized in the accumulated other comprehensive income component of shareholders' equity because these assets Itre classified as available for sale. Unrealized Iosscs (where. cost exceeds fair market value) on the assets in these trust funds are also recorded in the accumulated other comprehensive income componcnt of sharehoidcrs' equity unless the unrealized loss is other than temporary and therefore recorded in earnings. Generally, Enterw records realized gains and tosses on ib debt and equity securities using the specific identification method to determine the cost basis of its securitis.
Entem Arknnsas
Entersy Arkansas holds debt and equity sccurities, classified as available-for-sale, in nuclear decommissioning trust accounts. The securities held 8s of Dccember 31,2013 and 2012 are summarized 11s follows:
Total Tof al F3ir Unrealized Unrealized
Value Gains Losses (In Millions)
2013 Equity Securities $4633 $214.0 e Dcbt Securities 247.6 53 5.2
$ 5 2 - $7 1 0.9 $2 19.3 - Total 2012
Equity Securities $3 84.0 $116.1 $-
Debt Securities TnfaI
21 6.6 14.5 0 2
$600.6 $130.6 $0.2 *".Y. - 3
IFERC FORM NO. 9 (ED. 12-88) Page 123.73 I
Name of Respondent
Enlergy Arkansas. Inc.
The amortized cost of debt securities was $248.9 million as of December 31,2013 and $2023 million as of December 31, 2012. As of December 3 1,2013, the debt securities have an average coupon rate of approximately 2.73%, an average duration of approximately 4.82 years, and an average maturity of appmximatcIy 5.52 years. The equity securities arc genedy held in funds that nre designed to approximate the return of the Standard & Poor’s 500 Index. A rclativeIy small percentage of the securities are held in funds intended to replicate the return of the Wihhire 4500 Index.
This Report Is: Date of Report YearlPeriod of Report (1) An Original (Mo, Da, Yr} (2) - A Resubmission I t 201WQ4
The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by investment type and length of time that the securities have been in a continuous Ioss position, are as foIIows as of December 31,2013:
Equity Securities Debt Securities Gross Gms
Fair Unreal’ied Fair Unrealized Value lasses Vatue Lasses
(In MiIlions) Less than 12 months $- s $153.2 $4.8 More than 12 months - I 6.9 0.4
Tofal $- $- $160.1 $53 - The fair value and gross unrealized losses of available-for-sale equity and debt securities, summarized by
investment type and length of time that Ihe securii is have been in a continuous loss position, are as foIlows as of December 3 1,20 f 2:
Equity Securities Debt Securities
Fa1 r Unrealized Fair Unrealized Value Losses . VaIue hsSse3 ’
Gross Gross
(In Millions) Less than 12 months $ 0 3 !€- $24.4 $0.2 More than 12 months
$0.2 s $25.4 $0.2 Total
- 1 .O - - -- - The fair value of dcbt securities, summarized by contractual maturities, IIS of Decemkr 31,2013 and 2012 are as
follows:
2013 2012 (In Millions)
less than ? ycar 58.1 $8.8 1 ycar - 5 years 110.9 98.6 5 years - 10 years 1 18.0 93.1 10 years - 15 yeas 3.9 5.1 15 ycars - 20 years I 0.9
- Name of Respondent This RepoFt is: Date af Report YearlPenod of Report
(1) XAn Orighal , (Mo, Da, Ur) Entergy Arkansas, Inc. (2) A Resuhmisslon ‘ i r 2013Ja4
NOTES 70 FlNANClAl STATEMENT3 (Continued)
20years+ - 5.8 11.0 Total $247.6 $216.6
During the years ended Decernber31, 2013, 2012, and 2011, proceeds from the dispositions of securities amounted to 5266.4 million, $1443 million, and $125.4 million, mpectively. During the years ended December31, 2013,2012, and 201 I , gross gains off16.8 million, %3,4 million, and $3.9 million, respectively, and gross losses ofsO.6 million, $0.1 million, and $0.2 million, respectively, were recorded in earnings.
NOTE 18. VARIADLE INTEREST ENTITIES
Note 18 to the financial statements is not appIicable to the presentation in the FERC Form 1.
NOTE 19. TMHSACTIONS WITII AFFILIATES
Each Registrant Subsidiq purchases elcctricity from or seHs eIectricity to the other Registrant Subsidiaries, or both, under n t e schedules fikd with FERC. The Registrant Subsidiaries receive management, iechnical, advisory, opentin& and rdministntiir smicw from Enterm Services; receive management, technical, and operating services from Entergy Opt ions; and unti1 Ihe fiat quarter 201 1 purchased fuel from System FueIs. These transactions are on an “at cast- bask. In addition, Enttrgy Power sells elecbicity to Entergy Arkansas, Enterm Louisian& and Entergy New Orlcans.
As dcscrikd in Note I to the financial statements, aII of System Energy’s operating revenues consist of biflings to Entcrpy Arkansas, Entctgy Louisiana, Entergy Mississippi, and Entergy’New Orleans.
As dtsctikl in N o ~ e 4 to the finzncial statements, the Registrant Subsidiaries participate in Entergy’s money pool and e m jntemt income from the money pool. Entergy Arbma, Entergy Mississippi, and Enter= New Orleans also received intcmt income from System Fuels until the first quarter 201 1, when System Fucls repaid each company’s investment in Systcrn Fuels.
The tables klow contain the various affdiate transactions of the Utility operating compilnim, Systcrn Encrpy, and other Entergy amiIintts.
infcrcnmpany Revenues
Entergy Entergy Enteqy Gulf States Entergy Entergy New Enfergy System
Arkansas LouMann Louisiana Mississippi Orleans Texm E n e w (In Millions)
20 13 $349.9 $383.1 $1 14.9 $1073 $27.0 $369.4 $735.1 20 12 $324.0 $380.6 $1382 $36.1 $43.9 $3132 $622.1 201 I $293.8 5574.5 $139.0 $125.1 $96.9 $264.1 $563.4
Intercompany Onerafinv Exnenses
~FERC FORM NO. i (ED. i z m ) Paga 123.75 1
Name of Respondent This Report Is: Date of Report YearlPeriod of Repofi {l) An Original (Mo, Da, Yr)
NOTES TO FINANCWL STATEM!ENTS (Continued)
Entergy Entergy Entergy Gulf States Entergy Enteqg New Enfergy System
Texas Energy Arkansas Louisiana Louisiana Misshdppi Orleans (In MiIlions)
--- (4 P I @I 09 $656.1 $672.8 $667.6 %399,0 $279.5 $418.1 $1752 $580.7 $5323 , $597.4 $352.7 $247.2 $386.1 $147.4 $752.7 $563.1 $574.0 s3372 $226.6 5486.6 $13 1.5
Indudes $33 rniIIion in 2013, $1.4 mi!lion in 203 2, and $ I 3 million in 20 1 1 for power purchased from Entergy Power, Includes power purchased from RS Cogen of $32 million in 2013, $2.8 million in 2012, and $41J miltion in 201 1. Includes powcr purchased from Enterm Power of $8.1 million in 20i3, $143 million in 201s and $14.5 million in 20 1 1. Includes power purchased from Entersy Power of $8.0 million in 2013, $14.1 rni!lion in 2012, and $142 million i n 201 1. I
L
I n tercarntlany Interest and Investment Tncome
Eatergy Enfergy ,
Eotergy Gulf States Entetgy Entergy N E W Entergy System r Arkansas Louisiana halsiana Mississippi Orleans Texas E n e w
(In Millions) $- $27.5 $78.2 $- %- s- $- s 528.2 $78.2 $- $7 ’ $0.1 $-
SO. 1 $32.5 $78.1 $0.1 $0. I %- $0.6
NOTE 20. QUARTERLY FINANCXAL DATA
Note 20 to the finnncial statements is not appIicable to the presentation of the FERC Form 1.
IFERC FORM NO. I (ED. 12-88) Page $23.76 1
1
BLANK PAGE
N d l l l U U1 nC3pUllUUllk (Ma; . y ~ ~ - . . ._ .
Entsrgy Arkansas, Inc I t Endof 2 m k
S U M M Y OF UTlLrrY P U N T AND ACCUMCLATED PROVISIONS FOR DEPRECIATION. AMOFmZAflON AND DEPLTnON
'
Report In Column (c) the a'mount for elacbicfundion, In coIwnn (d) lhe amount for gas fumb'm, h mlumn (e), (0, and (a) report othor (specify) end In ahmn (h) w m n hunetton.
EleMc Total Company for the CkaSSifimtiOn' Current Yearmuam Endad 8- I
F I (a1 (bl UtiMy PLnt .. In Servlce Piant In Ssrvlw (ClassMed) 8,337,944,974 8337,944,97 Property Undar Capnal Leases 1,064,228 l.W,22
! ' - .
Ptant Purchased Df Sold Cornplated Constnrctlon no! Classffied 541 ,B70,419 543,970,41
Erparlmenta! Plant U n c l l M M Total (3 thru 7) 8,880,979,821 8,B 8 0,9 7 9,62
Leamd to Olkn Held lor Fuhrn Lhs 1,086,764 1,086.76
Cmstructlon Worlt h Pmrsu 217,578,983 217,578,s A c q u d u n Adjustnwna 21,024,442 21 ,824,M
Total Ul~lrty Plant (8 nuu 121 9,321,469,794 9,121,469.79
Net Wltv Plant lt3 kir 14) 5,011,428,912 I 5,Ot 1,428,9l A w m Prw lor Depr. kncrrt Oepl l,ff0.040.882 4.1 1 o,o4o,w
I . . . .
Total In ssrvlcn (18 hnl2 1) 4,148,763,6341 4,108,763,6?
Leased to Olhsn ' . * I 1 t
ITolal Leased to Gthen (24 L 25)
IHtrld for Future Use I I
28 OepradaUon t78,367 1 7 8 3 29 AmPrtjzabon
Total Held for Futum Uia (28 & 29) 178,367 1 7 8 3 Abandonment of L o a m (Natural Gail I Amort of Plant AequlsMon Adj i,oga,aai 1,098,8€
Tola! Aceurn Prov (squats 14) (22.26,30,31,32) 4,110,040,082 4.1 1 O,U40,8€
FERC FORM NO. .f EO- i 2 4 S l PSW 71m
hame of Respondent (This Report Is: )Date of Report IYearlPencd of Report I (1 Arj Original (Mo, Da, Yr) (2) I A Resubmission I ! 2013144 *
- .. . Entern Arkansas.’lnc
bcheduh Page: ZOO Line No.: 4 Cofumn: c 1 Includes general plant assets only.
~chedule Page: 200 Une No-: 21 Column: e 1 Consists of accumulated provision for amortization of intangible assets.
IFERC FORM NO. I (ED. i2-87) I Page 200 Footnoie.1
I. Repart below the casts incurred fur nudear fuel materials In process of fabrication, on hand, in reactor, and In cooling; m e d by the respondent. 2 If the nudear fuel stock k obtalned under kaslng amngemeds, ab& a statement showhg !he amount of nudear fuel leased, the quantily used and quantify WI hand, and the costs I n c w d under such baslng arrangements.
I t Chanses dunng Year E e g l r R y 3 Y a a r Additroni
Lne Description of item NO. w
22 TOTAL Nuclear Malarlafj held for Sate flatat 19.20. and 21) 22 TOTAL Nuclear Malarlafj held for Sate flatat 19.20. and 21)
Entergy Arkansas, Inc (I) @AnOngtnal I (2) n A Resubmlsslan
Batanw hne End $,Year No.
c I
I 1 1 8
Name of Respondent Thls Report is: Date of Report (1) An Original (Mo, Da, Yr)
Entsrgy Arkansas, tne. (2) I A Resubmission I I
Bchedule Page: 202 Una No.: 12 Column: f I FUEL LEASE FOR ARKANSAS NUCLEAR ONE
LESSOR: RIVER FUEL TRUST #I
Yeadperiod of Report
2013Q4
Xnoestment of River Fuel Trust #1 a t December 31, 2013
Investment at December 32, 2012 $229,196,765
Additional investment in fuel 851 652,246
Daily lease charges allocated to and included in capi ta l ized costs
Less: Burn-up charges paid t o lessor
Total Investment at December 31, 2013
2,449,994
Cost Incurred under River Fuel Trust #l Lease f o r the Year Ended December 31, 2013
Daily Lease Charges Fuel Burn-Up Charges
Total
- As o€ December 31, 2013, arrangements to lease nuclear fuel existed in an aggregate amount up to 5270 m i l l i o n for Entergy Arkansas. The lessors Einance the acqui s i t ion and ownership of nuclear fuel thxough loans made under revolving credit agreements, the issuance of commercial paper, and the issuance of intermediate-term notes. The credit agreements for Entergy Arkansas have a termination d a t e of June 26, 2016. The intexmediate-term notes issued pursuant to these fuel lease arrangements have varying ma.turities through December 15, 2017. It is expected that additional ffnaneing under the leases will be arranged as needed to acquire additional fuel, to pay interest, and to pay maturing debt. However, if such additional financing cannot be arranged, the lessee in each case must repurchase s u f f i c i e n t nuclear fuel to allow the lessor to meet its obligations in accordance with the f u e l lease.
IFERC FORM NO. 1 (ED. 12-87) 1 Page 202-203 Footnote.1
BLANK PAGE
(I) WAR unginar
I I I
End of ,w J I w ~ I V W , ua, L L /
I I t
FERC FORM NO. 1 {REV. 42-05] Page 204
a 127,925,266
1.619.335
I ' LLIU UI C" .-.- 1 - .
! I ' - d u- -- - - - Enbrgy Arkansas, Inc
dlstributlmns ofthess bntahve classifications In cokrmnr (c) and (d), induding the reversals of the pdor yean tentalive account distnbuliom of these amwnfs Careful obssnranca af the above InsttuetIons 8nd the texts of Acewnts 101 and ID0 wlfl wold ssdous cmksions of he r@p#rifid amount of respondenh plant &maI!y In s e w b at end of year, 7. Shmv In d u m n (t) r4assffieatlons or transfen wlthtn utitity plant supunb. Include also b mlulumn (9 the addHans or redudlorn of primary aecwnt dasstfkatkns atlslng from dIsMbut!un of amounts InWlly recorded In Amunt 102, Include In whmn (a) the amounts wrth resped tc accumulated pWsIon for depreelaUon, aqulsXlon adjuslments, ek, and shaw In cobm (fl only h a offset to tha deblts or credlls distributed In ealumn (fj to primary account dassificaMns. 8. ForAmunt399, state ha nature and use of plant tnduded In thls aeeount and H substantlat In amouni submita supplernenlary statement bhowlng subaccnunt classification of aueh plant wnbmlng to fie requttement of these pages. 9. For each amount amprlslng the reported balanm and changas In AeePunt fD2, s tah the property purchased or sold, name of vendor or purchase, and date of transactton. If proposedIoumal entdes have bean filed wilh the Commlrwn 85 requlred by the Uniform System olkaxrunts, ghre sbo dale
(2) n A RasubmIsslon ELECTRIC PLANT IN SERVICE {Accaunt 101,102,103 and 106) {Contrnued)
2 3 4 5 6 7
9
11 12 13
a
ip
17.590
8,65 I .76 9 185.a19.495
2.433.932 23.762
3.953.956.836 m m , 8 r 3
I EntargyArkarrsas, Inc I
G NO.
47 48 49 50 51 52 53 54 55 56 57
19 6a 61 62 63 54
-
sa
I 1
ELECTRIC PLANT IN SERVICE (AEcount 101,102,103 and 106) {ConLnuM) Acwunt Addiuons i i
(359 1) Asset Retirement Costs forTransmlsslon Plant
4. I31STRIBmON PLlllJT I .. 1 p60) Land and Land Rights (361) Structures and lmpmsmenh f4.3g1.4g8 1.342.655 (362) Statlon Equlptnent 351,076,814 t 1.846,930 (363) Storage Battary Equlpmont 1 (364) Poles. T m n . and Fbnures 503.104,134) 28,509.027
TOTAtTransmisslon Plant (Entar Total of Unes 48 thru 57) +.4sa.z73.962 85,554,953 - . 4.832.402
74 (374) &sat Ratlrament Costs lor Dkhlbutbn Plant 75 TOTAL Ontnbutfon Plant (Enter Tobl of 1Les 60 lhtu 74) 76 5. REGlONALTRANSMISStON AND MARKET OPERATION PLANT
2.876.953.605 1 -
. ..
97 (399) Other Tangible Properly 98 I399.1) Asset Retmmad Costs for General Plant 99 TOTAL General Ptant {EnterTotat of lines 48.87 end 9E) 175.670.848 23382.263
I lo0 TOTAL (AccounB 101 and 106) a .m.m.026
102 (ta33)4102) Elecbie Plant Sold (See lnstr 8) 103 (103) Experlrnental Plant UndasslfM 1M TOTAL Etectrlc Plan1 In Ssrulca (Entar Tokt of fines 100 thnr $03) 8.678.370.026 427.1 85.4 63
FERC FORM NO. 1 [REV. 12-03 Page 206 .
I --.--.
Idon I f ELECTRIC PtANT IN SERVlCE(Accwnt 101.~02.103 and 106) (Cwrbnued)
Rebmrnenu Adjustments Transfen Balanca at Una. End pf Year No. 1 - (a (8) (fl 9) -
47 4a
4 I I 1
FERC FORM NO. 1 (REV. 1245) Page 207
49 50 51 52 53 54 55 58 57 58 59 60 61 62 63 64 65 66 67 60 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87
89 90 91 92 93 54 95 96 97 98 98
3 0 0 101 102 1 03 104
a8
Name of Respondent
Entergy Arkansas. he.
bcheduje Page: Z P ~ ne NO,: 90 ~olumn: c 1 . The negative project: additions represeht reversal credits from pr ior year additions for unclassified project costs closed to plant in sarvice,
This Rep& is: Date of Report YearlPeFiod of Report (1) An Original (Mo, Da, Yr) (2) I A Resubrnisslon * I I - 2013M4
IFERC FORM NO. (ED. 12-87) I
. Page 204-207 Foofnokf + -.
~~
31 Land and Land RJghb Under 5250.000 Vadous I 582.679 AI i
45 46
47
51 i t 61
~
i
Total 1,086,768 1
25 26
' 27 za 1
42 43 44
Entergy Arkansas, lnc.
arfor Acmunt .f07cr31,000,000, whkheuerts lass) may begmuped.
I t t 1 21?,!38.963
FERC FORM NO. 1 (ED. 12-87) Page 216
3. Murorpro]tctt (5% of the Bafanes End of the YearforAwunllO7 or31.00P.OOD, whlchevsr b t s s ) may b8 grouped.
36 37 38
I I I 35 I w82 CAW SCRUBBER.STAC~8URNERS 1 2,228,911 1 AN02 UNOERGROUNO PIPING REPLACEMENT 1,690.876
AN02 REPLACE 2P-320 MOTOR WITH SPAR 1,598,369
PURCHASE REACTOR VESSEL STUD TENS10 1.41 1,692
40
41 42
~
WB2 MATS COMPLIANCE -CAPITAL 1 ,I 58,393 AN02 EDG EXCTTERIVOLTAGE REG REPL. 1,122,732 IN1 W S COMPLIANCE-CAPITAL 947.I 15
FERC FOFMffO. I (ED, 12-87) Pags 211.1
(1) wm ongaai I (21 r l A ResubmIsdon
40
41 42
~. I CONSTRUCTiON WORK IN PROGRESS -- ELECTRIC (Accuunt 107)
1, ReportbBw descdptmns and balances at end of year of projeds R process of consbvdm (107) 2. Show Items relathg to 'research, bevefupmrrt, and demonsbaUm" proIects bst, undera mptlon R e g e a ~ . Development, and Demnstra!lng (see Amunt io7 oftha Unlform System o l h u n t j ) 3. Minor pmjects (5% of the Balance End of the YearbrAceount IO7 of $1,000,000, whkhwer la less) may be grouped.
ANOC INSTALL PUMPS FOR MANHOLES AN01 PURCHASE GAP SCANNER TOOL
AN02 FUKUSHIMA SPENT FUEL POOL INST
t41.430
140,837 122,486
43 TOTAL 21 7,578,963
FERC FORM NO. I (ED. 12-87) Page 218.2
Entsrgy Arkansas, In& I I I
CONSTRUCTION WORK IN PROGRESS -- ELECTRIC (Account 107) I
. Report babw dexriptrons and balanws at end or year of proJaetr In process of mnstrudlon (107) L Shw Hems rabtlng to "maarch. dsvelopment, and demonsballon' projects last, under a captmn Research, Development, and Demonsttating (see lceaunt 107 of #a Unlfom Syslern o l A a u n t s ) I. Minor projecb (5% of the Babncs End olthe Year for Account 107 or51,000,000, whlcbmr is less) may be grouped.
Descripf~on of Proled
(a) HTI CARD R U D E R SECURTTY ACCESS
AN02 REPL MlSC SOLENOID VALVES
AN02 UPGRADE 2SC15C SITTO RCS VtV OTHER PRODUCTION PLAKF
2
3 -
Cons1nrcbonwork tn progress - Ebdric (Awunt 107)
@I 113,942
106,230
102,888 1 ,79Q,764 4
1
6 lR4NSMISSIONAND DISTRIBUTION SUBSTATtON PLAM: 7 lAWSON RD BUILD SUBSTATION
8 E O M V ; RPLC CONTROLHOUSE d EQUIP
5
5,940,547
3,767,405
9 t O 11
12 13
DRIVER BVlLO NEW SMR30KV SUB 2,2 64,27 9
LR ALEXANDER -AbDTRANSFORMER 2,376,095
HSALBRIGMSUB: PURCHASE PROPERM 1,353.247
W PURCHS SPARE 5OG!3OKVAXFMR 1: ,328,720
CAMDEN N: NEWLINE FAY & BREAKER 1203.635 1 . .
14 1 CAMDEN MAGUIRE: NEW LlNE BAY B BRKR 1 953.740
15
16
! --.- - -
I 664,948 MWSON RD SITE PURCMSE
VlLONLA BUILD 4OMVA DlST SUB 628.249 I
17 1 RTO METERING - RITCHlE 230 KV I 511.m
21 EL DORADO EHV LtFE EXTENSION #2
22 l%l PUCH SPARE 13 8KV VOLTAGE REG 23 LAKE WUAGE: NEWLINE BAY L BRKR
-24 LR PINJNACE, RPLC ma69
25 WOODWARD 230KV RING BUS
26 COFER RD BUILD N E W l6lKV O-SUS
27 WDWRD UPGRADE WATSON CH4PEL BKR BAY
28 EA] PURCH SPARE 3413KV VOLTAGE REG
29 GIFORD, RPLC HS CS BO500
I
20 1 WOODWARD UPGRADE M C W N T LINE M Y I 4W.083 - - -.- - -
397,766 329.437 314,245
292,217
276,768 267,082
. 245.800
202,846
194232 1
CIP4-ED NERC ELDORAOO SUBST CIP4-ED NERC DELLAECC SUBST
W PURCH 20 BUSHINGS FOR AN0 AXFMR CIP4-ED NERC PLEASANT HILL SUBST WOODWARD; R P M 3 RELAY PANELS
PB SOUTH UPGRADE WOWRD LINE PANEL
C1P4-ED NERC WEST MEMPHIS SUBST CiP4-ED NERC MABELVALE SUBST
CIW-ED NERC SHERIDAN SUBST
ClP4-ED NERC WlGKTSVltlE SUBST
CIP4-ED NERC MCNElL SUBST BUILD NEWSUB AT SMACKOVER
LR AWDER- ADD WSFOF~MER
. - t 90,955
188.335
185,156
170,765 160,506
156.604
146,348 145,573
144,110
139,642
t33,750
128,138
124.826
43 - TOTAL 217,578,SW
FERC FORM NO. 1 (ED. 42-87) Page 216.3 '
(1) p p o l l g l n a l Enbrgy Arbnsa9, Ine. (2) n A Resubmlsdon
12
13 14 -
End of Za13U4 (MO, va, 11)
I t
22
38 37 38
23 24
25 26
- -
SKYUNINQ - L966 MBLM- elAKLY DAM ~ 20223! ELAINE- GILLFIT, REPLACE CROSSARhZS 168,49:
SKYUNfNO - L8M KEO - HLWO BOWS 1 150.75:
27
28 29
- -
39
40
41 42
30
LIDAR - L865 HOT SPRNGSEjTA-MCNEIL SKYLINING - L977 WDWRD - P B A R S M KEO-WM EW, INSTAU. BIRD GUARDS
148,941
144,52!
142.03:
SKYtlNlNQ - L644 PLST HILLS - GRNBR 135,aa
TRANSMISSION LINE PLANT: CAMDEH N W O E N MAGUIRE 4,832'32:
WOODWARDIMCCAMANT UPGIWDE 2,6fi2,17t LIDAR-L858 MAYFLWER- PLSNT NlUS i ,m,za( LKVLLG BGSY-MCN LK: NEW 230KV 1,o99*19r KEO - WM EM. RPL mRUCTURES I,016.66[ ELAINE - G I U T T , REPLACE POLES 940,97! NEWPORT- PARKIN, RPL 32 STRUCTURES 933,65r HOT SPRINGS MILTON TO HSALBRlGfIT 813.474
MONTICELLO EASTREED NEW 115W UNE 721,85f CAUCO ROCK-MELBOURNERINE UPGRADE 6.4 5,9x AECC HYDRO-GILEIT 645,511
1 SKYUNINO - L97D WDWARD - iA ST LN 438.063 UOAR- L869 ELDORAW - LA ST UNE 41 1.4b LK U G - M C N Ut 115KV REBUILD 37239: WOODWAROWATSON C W E L REBUILD UNE 319,27;
BENTON WEST CUT IN 299.261
BRINKLEY EAST - MOSES. REPL 9 STRS 287,94! LIDAR -t057 LIABELVAlE - MAYFLOWER 238.33:
1 swLiNtw- ~837 PNGBRN - smsm 226,W COWAY W 1 MRRLTN E. REPL STRS Z16,9@ LYNCH -JACKSONVILLE 115KV T-UNE 207.34'
207.931
1 MINOR ADD TO WO# CSPmLA16f 206.871
NEWPORT - PARKIN, REPL 9 STRS
1 431 TOTAL I 2 17,578 ,s6:
FERC FORM NO. I [EII. f2-87)
Enfergy Arkansas, Inc
I Lrna Oescqtton af Projact NO. (4
1 CAMDEN N-CAMOW MAGUIRE: NEWROW 1 2 UDAR-L852tWBWAL€ -%BE I 3 SKYLINING -LW9 SAGE -MT. VIEW I 4 OTHERTRANSMISSION LINES PLANT I 5 t
. . 1
CONSTRUCTION WORK IN PROGRESS -- ELECTRIC (Amaunt 107) 1. Reaort bOIWd8SCriPthS and balances a t and of year or ~ m b c b In dmcess of eonstrudion (ton
Conslnrctlon wark In pmgress - 135,018
119.039
115,289 146,413
Electric (Account 107) @1
3. Mmorpmjeets (5% of Lhe Salanta End of the Year for h u n t 107 0 f1,000,000,whlchevsrts less) may be grwpd. W u n t 10.7 of !he U&rm System otAcePunts)
I r I f 6 I UNDtSTRI8UTED OVERHEADS 1 i 85.055 1
14 i s ¶5
17
i 1 1
I
29
30 I I
I 1 '
40
41
I 1
24 I I I
I I
1 I I
25 1 I I 26 I I I 27 I 1 r 1
ZB i I I
31 I I
I I
I I I I
38 I 39 I I
I I
I .
I FERC FORM NO. 1 (ED. 12-87) Ppge 2f8.5
Ejqdsf ZUIYU4 (1) pJA" Onglnat \Moa Lla, 8 1 )
Enbrgy Arkamas. fnc. (2) n A Raiubmlsslan I 1 ACCUMULATED PROVISION FOR DEPRECIA'T10N OF ELECTRIC UTIUTY P W T (Account 108)
?. ExplaIn In 8 footnote any irnprtant adjustments during year. 2, =plain In a footnote any difference between the amount for book cost of plant retired, Una 11, mlumn IC), and that reported for !ec!ric plant in sewlee. pages 206207, column Bd), exduding retirements of nondepredabh property. /. The provisions of Aceount IO8 In the Uniform System of amurtts require that retirements nf depredabfs plan! be remrded when udr plant is removed from service. If the respondent has a slggnifiwnt smwnt of plant retired at year end whkh has not been recorded indot dassified to Ula various mewe functional dassificatlons, make preliminary dosing entries to tentatively fundionatire the t m k os1 of the plant retired. ln additlon, Include all casts included In retirement work In progtess at yearend In the appropriate functional iassifmtions. ;. Show separately Interest credits under a slnking fund or stmdar method of depreciation amunfing.
5
6 7
8
8
10
y==-- * -e*-*",-&. --.ll---
(413) G p . of Elec. pft Laas. to Others r - 7 Transporlalton Expenses-Clearing
Other Clearing Accounts Other AEcxlrrnts (Spec@, detalls In hotncle):
TOTAL Deprec Prov for Yaar [Enter Total of 204,866,761 204,868,754 tinas 3 thru 91
I 1 I
i t Net Chams lor Plant RaBFsd. 7 " " " j 7 1 r l 7 1 . 1
12, BookCast orplant Retired 223,640,096 223,640,096
13 Cost of Rnrnoval 4 5,04 5 ,E a 45,045,566
14 Salvaga (Cmdd) 38,020,832 38,020,832
f 5 70TM Net Chrgs. for Plant Ret (Enter Total 230,664,830 23O.W,830
28
29
1 ~~
G%gIonal Tmnsmisrton end MarkatFperabon 103,174 103,174
General 84,833,745 04,744,426 89,3t9
TOTAL (Enter Total of Iner 20 thru 28) 3,80591 8.692 3,805,740,325 t78,361
F€KC FORM NO. I (REV. 1245) Pago 21.19
Name of Respondent This Report is: Date of Report (Mo, Da, Yr)
Enttsrgy Arkansas, Inc (2) - A Resubmksion * ' I t . (1) XAn Original
bchedule Page: 219 Une No,: 3 Cdurnn: c I Excludes service company depreciation allocations of $7,065,531 (included in the depreciation expense shown on page 336), since these allocations do not offset to accumulated depreciation reserves.
pchsdufe Page: 219 Une No.: f 6 Column: c I N e t (Gain)/Loss closed to Accumulated Reserve.
YearlPenod of Report
2013tQ4
, bchedule Page: 219 Une No.: 20 Column: c 1 Includes $922,127 for asset retirement obligations.
behedub Page: 2f 9 Une No.: 2f Column: c I Includes $63,301,902 for asset retirement obligations.
bchedule Page: 21 9 Uns No.: 22 Column: c I Includes $19,114 for asset retirement obligations.
pchedule Page: 219 Unm No.: 24 Column: c I Includes $12,733 for asset retirement obligations.
[FERC FORM NO. 1 (EO. 42-37) I Page 219 Footrrote.1
E n d d 201W4 111 Urn' urryrlrcl ,"W, Y m , a,,
(2) m A Resubmtsslon I I Entergy Arkansas, !ne.
1. Report beQw hveatmenb In Aewunts 123 t . Iwabnents lo SubSMlary Cmpanles. :Z Pmldde 8 subheading for each wrnpany and Usttbere under the Infomallon mild brbelw. Sub -TOTAL by mmpany and girs a TOTAL In 'ccIurnns (e),lf),(d and (h) (a) Invesbwnt In Sewntles -Ut 8nd desuibe each security avned. For bonds g h also prlndpal smount, date of Issue, matunty and lnterast rate. [b) Invmtment Advanm - Report aeparatev the arnounh of loam or bvtstment advan#r which 8re suqed to mpaymsnf but which 8m not subjecl to utmnt settIamant Wlh respect Lo each advance shcwwhclharths advance b a note or open aceount, Ust each note glvlng date of bsuanee, matutQ date, and specfyhg whether note b a renwaf. 3. Report separatety the equity In undistribukd subsldldlary earnings since aqulaitlon. The TOTAL In arlumn {e) should q u a l the amount entered for
I INVESTMWTS IN SIJBSIDLARY COMPANIES (Account 123 1)
Aecount418 1.
Ln0 Descriphon of Investment No. (a)
1 The Arklahorn Corporatlon 2 Common Stock- 238 shares 3 4 Subtofal
Equrty fn farnlngs -47.6% Ownershlp
MU47
15 Transmbshn Company m a n i a s . UC 16 Capital Contrtblltron
W,872 133,827 198,699
I 181
5 5
7 8
9
19 Arkansas Powar L Llght Company 20 Capltal Contnbtrflon 21 Subtotal
22
~
Syslern Fuels, he.
Subtotal Common Stod - 70 shams
23 I
Ofmm
I 241
7,000 7,000
25 26 27 28
29
--
I 361
37
38 39 40
41
* 42 ITotal Cast of Account 123.1 5 %
I I
6 2 0,6 0 0
-1 17,699
i 1,000 I ~~ I
I
FERC FORM NO. I (ED. 1249) Page 224
I Endof 2 o I m (1) "4ungtnai ( N W , U d , L I)
Entergy Arkansas, Inc Q) n A Resubrntsslon I ! INVESTMENTS IN SUBSIDIARY COMPANIES (Aaount 123.1 1 (Continued)
4. For any sewrltles, notes, of amounts that were pledged dcslgnate such seeuI'Hles, nata% 01 amum In a fmtnds, and state the name of p!edgeB and pUpU¶a ol the pI&& 5. If CoRtmfsslon approval was r q u M for any advance made wwttty acquired, d&gnab such fad In a footnote and gh'e nama of & m m i 3 d D r I , date of rubhofitatlon, and case at docket numbsr. 6. Report coIumn (I) lntsmst and d l v b n d mvenues form Irrwstrnents, Indlldlng such revenues k n securities dlspdssd aIduring the year. 7. In mtumn {h) wrt foreach lnvsstmarrt disposed of dudng the year, the gafn or bss represented by the dtlfarenca between cost of the InYesmnt (or the o h t m u n t atwhlch married In Uta books of amunttfdflernncs from cost) and the seltng prim bereof, no1 Indudlng Interest adjustment Incfudlble in column (9. 6. Report on h e 42, column (a) the TOTAL ccst of Account 123.1
*
4 Equi a Subsrdwy Revsnues for Year Amount of investment at Gain or Loss from Inuashant Une
NO.
1 64,072 2
-292 133,535 3 -292 198,407 4
t 5
Olsp ssdof ?h)
End fYear Ib &I
bXr safyear Ye)
1.000
3.000
15
16
17
FERC FORM NO. 9 (ED. f2-89) Page 225
-334,242
41
. -
. 49.301 -194.861 42
8LAMK PAGE
I ' I 1
20
estimates damounb by bction are aeptable In mhmn (d), daslgnate the- deparlmnt ardepadments whtch use he dass of matadal. Inventory adjusbmntr durhq the year (in a tootnote) s h d n g genera! classes of matearlat and ruppnss and tho
GS. clearing 8ccounts. plant sts) affectad debited Of mddd. Sbw sepm!ety debbit or mdnS to stoms expense
TOTAL Matadals and Suppller (Per Balanca Sheet)
- t 6
hductton Plant (Ejbmated)
transrnlsslon Plant (Estimated) Dbtnibuucin Plant ( E i t h t e d ) Regional Transrnlsrlon md Market Opention Plant {Estrrnalad) Asilgned to - Uthsr IpFwWe detalls In footnote)
94,335,718 97,002,432
17,515,012 T 7.1 54,% i 15,768,477 I 722 B,I sa
1
1 TOTALAccount 154 (EnterToLaIoflines5 thru 71) 127,617307 131,385,551 MarthandISR (Account 155)
Mhar Materials and Supplies (Account 156)
Nuclear Matedals Held for Sale (Account 157) (Not : eppnc to Gas Utll)
Stores kpunsa UndlstrIbuted (Atmount 163) 21,064.545 21,043,898
I 97.57 t ,4 1 0 193,823,376
FERC FORM NO. 1 (REV. I 2 4 5 1 Page 227
Endd 2atzQ4 11) WA” unginai ~ M Q , ua, I r j Enbrgy Arkansas. Inc. (2) n A Resubmfssbn I 1
Allowances (Accounts 158.1 and t 5 8 2 )
1. Report beW he particulars (details) d l e d for cmcerning altowances. 2. Report all aqquisitions of atlowances at cost. 3. Report allowances In accordance with a wdghted average cost allocation method and other accounting as prescribed by General Instruction No. 21 In the Uniform System of Accounts. 4. Report the allowances transadions by the pedad they are first dlgibla for use: fhe current yeafs allowances In columns @Kc), allowances for the three sucmedlng years In mtumns @)-mi starling with the foallclwfng year, and albwanees for tha remaining succeeding years In columns (j)-(k). 5. Repor! on line 4 the Environmental Protection Ageney (EPA} Issued allowances. Report withheld portlons Lines 3640.
I I 1 I I FERC FORM NO. 1 [ED. 32-95) Page 228a
Aaowanees (Amounts 158 1 and 1582) (Continued)
6. Report an Unes 5 allwances returned by the EFA Report on Une 39 Ihe EPA's sales of thewithhdd sllowances. Report on Unes 4346 the net sales proweeds and gainsflasses resultrng fmm the EPA's sals or auction of the wilhheld alIowances. 7. Report on Unes 8-14 the names of vendodbansfemn of allowances acqulre and Identify assodaled mompariles (See 'assdated cornpaw undWDeSnlUons' in the Uniform System of Accounts). 8. Report on Unes 22- 27 h e name of purchasers! transferees of allowances disposed of an Identify assodated companies. 9. Report the net costs end benefiis of hedging transadions on a separale line under purdraseshansfers and saleshnsfen. I O . Report on Unes 32-35 and 43-116 the net sales proceeds and galns or losses from allowance sales.
436 DO 143 45 46
,..'", "I, s .I
End of 20t3M4 6 4 1 U l l y l l l m l
(2) n A Resubmlsibn I I Enrtergy Arkansas, he.
Allowances (Acwunts 158.1 and 158 2)
I, Report below the parllculats (detaPs) d e d for concerning ailmances. 2. Report all aquhMons of allowances at cost. 3. Report allowances In accordance with a weIghted average cost sllowtIon method and other amounffng as prescribed by General Instnrction No. 21 in the Uniform System oIAeeounts, 4. Report the allowances transadions by the period they are First eligible for use: the ament year's allowances In colums (b)-(c), allowances for the lhree sumeding years In mlurnns (d)-(T). starling with the folt&ng year, and allowances forthe remalnhg succeeding yean In columns @&).
48 Lossel
FERC FORM NO. I (ED. 12-95) Page 220b
I Enbrgy Arkansas, Inc.
4346 the net sales proceeds and gaindIosses resulting from the WA’s sate or auction of thewllhheld sllowances. 7. Repoit on Unes 8-14 the names of vendorsltransfemn of altowances acquIre and Identify assodaled compades (See ’assdated company‘ under ’Definiticns” In the Uniform System of AEounts). 8. Report on Unes 22 - 27 the name of purchasers! transferees of allowances disposed of an ldsntify assodated companles. 9. Report the net costs and benefits of hedging transadom on a separate Une under pumhasesntansfen and sa1es)transfers. 10. Report on Unes 32-35 and 4-11 the net sales pmceeds and galns or losses from allowance sales.
I U 1
Allawancas [Accounb 158.1 and 158 2) (ConUnued)
FEW FORM NO. j (ED. 12-95) Page 229b ,
Name of Respondent This Report is: (I) XAn Origlnal
EnlergyArkan3as, l n ~ (2) 1 A Resubmission
bchedule Page: 229 Una No.: 4 Colrrmn:J I Reflects issuances for 2017.
bchedule Page: 229 Une NQ.: 8 Column: b 1
Date of Report YearlPeriad of Report {Mo, Da, Yr)
I I 2013fQ4
Counterparty American Electric Power Koch Supply Trading Exelon Generation Company
Grand T o t a l
No. Amount 477 ‘$101971
2,198 53,789 814 17,501 ------ -----1-
3,489 $82,261 - I m p marum-
IFERC FORM NO. 1 (ED. 12-87) I
~ Page 228229 Footnote.1 _ _ . - -*-
BLANK PAGE
NaFe or Respondent
Entergy Arkansas, I r k
FERC FORM NO. 1TJ-Q (RW. 02-04) Page 232
Name 01 Raspondent
Entergy Arkanias, Inc. I
6 7
T ~ I S R ~ ortdr (1) ~ A n O r l p l n a l I (2) mA Rerubml3slon
I
1 I 1 1 1
OTHER REGULATORY ASSETS (Acwunt 182 3) 1. Report beIow lhe partiwlars (details) called krconceylng other regulatory assets, Including rate order dxk$ number, If applicable. 2. Mhor items (5% ofthe Balance In Acmunt I823 at end of pedod, or amounts less tfian $100,000 whIch ever Is less), may be grouped
33 34 35 36 37
by dasses. 3. For Reqdalory Assets behg arnodked. show perfod of amorthallan.
I
1 I
t
I? 48 19
hame of Respondent Ifhls Report Is: I Date of Report IYearlPenod of Report 1
bchedrrle Psqe: 232 Line No.: 24 Column: a I Production C o s t Equalization Proeeedinq
The U t i l i t y operating companies historically have engaged in the coordfnated planning, construction, and operation of generating and bulk transmission f a c i l i t i e s under the terms of the System Agreement, which is a rate schedule that has been approved by the FERC. Certain of t h e Utility operating companies' r e t a i l regulators and other part ies are pursuing litigation involving the System Agreement at the FERC. The proceedings include challenges to the a l l o c a t i o n of costs as defined by t h e System Agreement and allegations of imprudence by the U t i l i t y operating companies in t h e i r execution of their obligations under the System Agreement.
Xn June 2005, the FERC issued a deeislon in the System Agreement l i t i g a t i o n that reallocates t o t a l production costs of t h e U t i l i t y operating companies whose relative total production casts expressed as a percentage of Entergy System average production costs are outside an upper or lower bandwidth. Under the current circumstances, this will be accomplished by payments from Utility operatfng companies whose produetion costs are more than 110 below Entergy System average production costs t o Utility operating companies whose produetion c o s t s a r e more than the Entergy System average production cost, with payments going f irs t to those U t i l i t y operating companies whose total production costs are farthest above t h e Entergy System average,
Management believes that any changes in the allocation of production costs resulting from t h e FERC'a decision and related retall proceedings should result in similar rate changes for reta i l customers. The APSC has approved a production cost allocation rider for recovery from customers of the retail. p o r t i o n of the costs allocated to Entexgy Arkansas. After 8 FERC decis ion on xequests for rehearing, in 2007, Entergy Arkansas recorded accounts payable and Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy Texas recorded accounts receivable to reflect the rough production cos t equalization payments and receipts required to implement t h e FERC's remedy based on calendar year 2006 produetian costs. Entergy Arkansas recorded a corresponding regulatory asset €or its tight to collect the payments f r o m its customers, and Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, and Entergy Texas recorded corresponding regulatory liabilities far t h e i r obligations to pass the receipts on to the ir customers. The utility operating companies have followed t h i s same accounting practice each year since then.
]FEN FORM NO. 4 (ED. 1247) I Page 232 Footncte.1
. . i MISCEWEOUS OEFFERED DEBlTS IAcmunt 186)
1. Report helow the particulars (delails) dted for conyming miscellaneous deferred debits. 2. For any deferred debi! belng amortized, show period of amorbatton In column (a) 3. Minor item (1% of !he Balance at End of Year for h u n t I83 or amounts less Ban $lOO,Om, whichever 1s less) may be grouped by dasses.
Une Descnptlon olMuceltaneous Balanm at Deb& C R E 0 ITS Balanca at End of Year NO. Deferred D e b b Beginnnlng af Year Amount
(e) (a) (b) (e) (0 1 Non-Ewpenrs Acvued Labor 3,1 732.833 3.81 3.46I 2 3 4 5 6
- 7 8 9
11 12 13 14 <5 16
i o
-
2c 21 21 2: 24
Other 67.066 8.918 Varlous 8,569 67.41 :
t I 1
351 38 1 37 38
40 39 1
41 t
Expenses (Ses pagas 350 - 331) I , 1 1 49 TOTAL 14,149,701 t6,853,25 [
FERC FORM NOm 1 (ED, 12-94} Paw 233
Endol maQ4 (1) W M wnginai MU, vi, r i j
ACCUMULATED DEFERRED INCOME TAXES {Aturunt 190) p) n A Rasubmlsslon I f Entergy Arkansas, Ine.
1. Report the Infomation called for bebw concerning the respondenrs accounting for deferred Income taxes. 2. At Other (Specify), fndude deferrals relating to other lneorne and deducltons.
Lne Description and Location No. tal
1 Ebctrlc
Balancea tnd B a l a m o f lning of V e Y of Yai r
@) {Cl - .I ., .. ~ . - . , .
7 8 d
I
~
I ~~~ ~
Othar
TOTAL Electrfc (Enter Total ol Ilnes 2 thru 7) Gas I-:---' I
71 8,793,200 581,685,M
~
I i
15
16 17 18
Uihsr TOTALGas (EnterTotal of tines 10 thru 15
othar(Speeity) TOTAL (Aect 190) (Total of lines 8.16 and In 710,793,200 sst,6a5.02
I FERC FORM NO. 1 (ED. 12-88) Pags 234
Name of Respondent Thls Report Is: (1) XAn Original
Enfergy Arkansas. Inc. (2) - A Resubmission
Interest on Tax Deficiencies AN0 Shutdown Costs Grand Gulf 1 - O v e r h d e r Recovery Taxable Unbilled Revenue Property Insurance Capitalized Repairs Injuries & Damages Reserve Customer Deposits Unfunded Pension Minimum Pension Liability Supplemental Pension Other Retirement Benefits Deferred Fuel Cost Removal Cost Nuclear Decommissioning Accrued Medical. Claims Uncollectible Accounts Regulatory Liab i l i ty Partnership Xncome/Loss Contract Deferred Revenue Environmental Reserve Incentive Compensation AN0 Building SaldLeaseback Tax Gain Employee Stock Investment Plan Long-Term Incentive Compensation Stock Options Restricted Stock Awards Deferred Director's Compensation Rate Refund EPA ALlowanees Severance Accrual Accounts Payable Accrual Income tax Adjustment Net Operating Loss Carryforward Contribution Carryforward Tax Credit Carryforward S t a t e Taxes FIN 48 Adjustment
Date of Report YearlPenod of Report (Mo, Da, Yr)
I I 201m4
Balance at Beg of Year
$387 152 (211,577)
{ 617821823] 27,651,419 (5,316,5461 1,652,686 I, 625,901 1,756,4 68
(77, 654192I) 327, 255,975
666,263 (14,739,098) ( 50, 068,4701
(761,262) 21,379,523 .
3,O28,6OO 51 263,050
(4361 (1?266)
657 563,143
1,455,678 109,963 25 , 808 633,119
It 394, 825 137t 198 (59,2451 416,492 738,943
2,587,413 35, i 4 a t 628
d
440, 952,750 It 147, 343
(5,9501 240) 2,100,187
200, ooo
$716,793, 200 ~ 9 1 7 = e a i = ~ n
Balance at End of Year
$73,352 (446,226)
(9,228,7511 37,824,958 (13,422,947) 1,499,711 1?764,766 I, 191,436
(79,350,997) 190,753,415
(238,140)
(26,94 6,155) (15, 026,856)
16,7461 182 c
2,895,268 5,957,542 - -
657 489,136
4,405,319 77,776
42,561 1,378,527
236,502 218
695,032
1, 067,391 4,028 , 382
423,391,850
I
(11,720)
34,777,222
- 2,315,195
(5,455,582) 200,000
$581,685,024 -----C-~c~31~
m u f l p n ~ ~ R ~ u 9 1 1
IFERC FORM NO. I (ED. 12-87) 1 Page 234 Footnote.1
Enbrgy Arkansas, Inc I I I
CAPl7ALSTOCKS (Aceount 201 and 2041
1. Report below Vle paNculars (details) called for cooneernfng common and preferred stock ai end of year, dislinguishIng separaie series of any general class. Show sepamtc totals for txlmmon and preferred stock If information to meel the stock exchange reporting requirement oullined In column (a) Is available fmm the SEC 10K Report Form fiting, 3 specific reference to report form (Le., year and mmpany litre) may be rqmrled In column {a) provided the fiseal years for boolh the IO-K report and UiIs report are compatible. 2. Enlries In column (b) should represent the number of shares a~lhorked by the artlcles of incorpomtion as amended to end of year.
I
~ 7
9 1c
Class and Saner of SI& snd NlrmbtM Of Sham1 Par or Stated Call Pnce at Name of Stack Series AutharIzad by Charter Value per share End of Year
(a) rn) I b) (d) ACCOUNT 201: Common Stock
Cmmun - pat value 3 2 5.0 00, MI 0 325,000,O W
0 01 Total a n t 201: Common Slo&
ACCOLINTZM: Pmfamd Stodc 4.32% h f e r r e d - CumUhb48 70,m 100.00 103 6!
1 4.72% Pmfermd -Curnulath 1 83.500 100.00 107 o( 1 I I
I 4.56% Pmfarred - CurnJaho 1 75.0001 100 cwl 102 8:
4 56% Pmbmd - 1465 Series Cwnulatbe I 75,000 100 001 102 E4 , 6.08% Prtkmd - Cumulatrva 102 8:
FEAC FORM NO. 1 [ED. 12-91 1 PiQe 250
intergy Arkansas, fnc. . . I I 1
CAPITAL STOCKS (Account 201 and 2&) (Conbnued) . Giie particulars (details) concemlng shares of any dass and series of stock auhorized to be Issued by a regulatory mrnmlssion Fhhtch have not yet been Issued. . The Identifiation of each class of preferred stoek should show the dividend rate and whether the dividends are eurnulaths or onamdative. 1 . State in a footnote if any capilal st& which has been nomlndly Issued Is nomtnally outstanding at end of year. ihe parttculan (details) In column {a) of any nominally Issued capital stuck, reaqqulred stock, or stock in slnking and other funds which 1 pledged, stating name of pledgee and purposes of pledge.
-
0 TSTANDING PER BALANCE SHEET HELD BY RESPONDENT trne AS REACQUIRED STOCK (Aeeoud217) IN SINKING AND OTHER FUNDS No* crab! m o u n t oulstandng without mducbw
for amounts held by respondent)
szaeies I sw 1 %iL sh;Y I Wnt 46,98D,196 469,802 48,980,198 469,802
1
!
FERC FORM NO. 1 (ED. 12-88) Pago 251
Enlergy Arkansas, Inc
Report below the bahanca at Ihe end of the year and the Informallon spsafied below fer fie respedive ohar palddo capltal aecounb. Provide a subheadlng for each account and show a total for the acmnt as wall as total of all accounts for recondllatron Hltttl batanw sheet, Page 112. Add more mbmn~ for any a#ount ifdeemed necessary- ErpfaIn changes made h anyaaunt during the year and give the eeecuoUng antrlss affedlng s u a change. (a) Donathm Recehd from Stockholden { h u n t 208)StatO smounl and glva brief explanatian offhe P a i n and purposs of each donauoon. (b) RedUetlon In Par or SCaM value of Caprlaf Stock (Account 209): State amount and give bdelexplanatron of the capitat change whlch gave rIss to amcunb reported under thb ~apifon Indudkg IdentrfIcaUon with the class and series of stock lo whlch related. (cl Gafn on Resale or Cancellation of Reaquired Capdal Slodr (Account 210): Rapurt balance at beglnnhg of year, credits, debih. snd balance et end of yearwith a derfgnaticn or the natura of each UEdd and dabH Henllffd by the dass and series of stock to which d a t e d . (a] Miscellaneous Pa1d.h Capbtal {Account 2fI)-Cta3slfy a m n b Included In this account according to captions whlch, together with btlef explanations, dlaclosa !he general natura ofthe transacttons whlch gave rIse !o the reporIed amunls.
End of 2013M4 (I) DA" original (MO, ua, T U
(2) n A Resubmlssion 1 I I
I 1 ( ACCOUMZOS Donallans Recalved from Stockholders - None I 2 3 4
ACCOUNT209 Redudion h Patot StatadValua of Capltal Stock
Frnm51250 to $0 01 (1987) saa,m,aa 5 6
7
~~ ~
ACCOUNT 210: Galn on Resale or Caneellatton of Reacquld Capltal Stock- None
I 151
a 9
I O 11
I
ACCOUtiT211' Miacenaneous Pald4Mepttal- Nons
I I
24 I 25 !
I I 31 I 32 33 34 35
36 37
I
38 - 39
I
FERC FPRM NO. 1 (ED. 12-87) P a p 253
End of 4N 1 JIu4 \'/ 111"' u l l y l r r m l \n.'V, "Y. I , ,
Enhrgy Akanrai, he. p) n A Resubmbrton I I CAPlTAlSfOCK EXPENSE (Account 214)
I. Reporl tha balanco at end of the year of discount on capital stock for each dass and series of capital slock. 2. If any change occurred during the year In the balance In resped to any dass or series of stock, attach a statement giving partiadan (details) of the change. State the reason for any chargpoff of capital stock expense and specify the account charged.
hns
1 Capllat Stock &panso -Common Stock
Cbss and Senes of Slwk NW. (4
Balance at knd or Year P I
1,802,833
. .
i i i 1
0
7 8
9 10
1 t 1 1
. - . -. . .. 18 19 20
21
22 TOTAL 7,802,aJ3
FERC FORM NO, I (ED. 12-87) 'Page 254b
End ot 20WQ4 11) urn unginai (MU,Ud, 11)
htergy Arkansas. he. (2) n A Rerubmlsslon I 1 LONG-TERM DEBT (Account at, 222,223 and 224)
NO.
1 2 3 4 5
1. Report by halanca sheet account the partiwIars (details) concerning long-term debt hduded In Accounts 221, Bonds, 222, Reaqulrd Bonds, 223. Advances from Assodated Companies, and 224, Other iong-Tern Debt 2. In column {a), for new Issues, gh8 Commisslan autho&ation numbers and dates. 3. For bonds essumed by ?ha respondent, Include In column {a) the name of !he Issuing mrnpany as well as a desmipfion of the bonds. 4, For advances from Associated CompanIes, repait separately advances on noles and advances on open accounts. Designate demand notes as such. Indude In column (a) names of assodated companies from whkh advances were remhed, 5. For receivers, cerliflcates. show In column (a) the name of the mud -and date of court order under whfch such cehfkates were issued. 6, In column @) show the pindpal amount of bonds or other long-term debt ohglnally Issued. 7, In column (c) show Lhe expense, premium or discount with resped to the amount of bonds or other Iong-term debt origlnally Issued. 8. For column (c) the lotaI expenses should be listed first For each Issuanee, then the amwnt of premium (In parentheses) or diswunt Indimfa the premlum or dlscourtt with a nofation, such 8 s (P) of (0). The expenses, premlum or dlscount should not be netted, 9. Furnish In a footnote parliculan (details) regarding the treatment of unamorhed debt expense, premlum or discount asscclaated Wlh Issues redeemed dudns the year. Atso, give In a foofnote the date of the Commlsslon's authorization of treatment other than as
(For new Issue. ghe commission Authorization numbea and dater) (a1
ACCOUNT221 -BONOS-MORTG9GE BONDS 5n%Serlal
50%Serles 1 15,000,000
6o,oao,ooo
175.000,OOO
6 I 6 38% SerIes 71
939,967
609,720
4.725,¶02
696.900 n
59.4w D
47.250 I 81 5 68% Sedes
I
15 16 37 18 I S
4.0%Sener
3 05% Sedes
20 21
t 24~ACCOUNTZ24-OTHER LONG-TERM OEBT: ~
1
475% Serlas
~,guo,t1oo,ooo
Pnneipal Amount Total expms. MDebt bruad Pmlurn or Disaunt
31,295,906
1,041.860 ~00,000,WO~ 1 319,000 0
29 30 31 32
~~~ . .
Independence Counly 2.375% Serlas 20f3
Jefferson Countv 1.55% S e t h 2013
1
3oo.ooo.ow I 2,19 1'1 31
54,700,000
I 21,000 0 Z25.000.0Wl 7,400,537
493,941
125,000.000( 4,151,566 1
I 45.0W.OOd 586,176
I I
54.700.OW~ 638.559
I 45.0OO.OoO I 508.717
2,099,4CU,tHOl 33;523,29!
FERC FORM 1.10. {EO, 4246) Page 256
tnaor LUlJl- \., u’ *, ,----, --1 ’-,
LONG-TERM DEBT ( A w u n t 221,222.223 and 224) (ContmUedd)
Enlergy Arkansas, !ne. p) n A ResubmIsslon I 1
10. Identify separate undisposed amounts applimble to Issues whlch were redeemed In prior years. 11. Explain any deblts and CTedifs other than debded lo Account 428, Amortization and EKpense, omedited to Account429, Premium on Debt Credit. 12. In a fooinoto, gk’e explanatory (details) for Accounts 223 and 224 of net changes during the year. Wiih respect la long-term advances, s h w for each mnpany: (a) principal advanccd during year, (b) Interest added lo prindpal amount and (e) pn’ndple tepid during year. Gfve Commission aulhorirah’an numbers and dates. 13. If the respondent has pledged any of its long-term debt securities give particulars (details) In a footnote Induding name of pledgee and purpose of the pkdge. 14. If #le respondent has any long-term debt securities whtch have been nominally Issued and are nominally outshanding at end of year, describe such securities rn a footnote. 15 If Interest expense was lncwred during the year on any oblgatlons retired or reaqulred before end of year, Include such Interest expense In column 0- Explain In B footnote any difference between the total of column (7) and the tab1 of Amunt 427, Interest on Long-Term Debt and Account 430, Interest on Deb! to Assoclated Companles. 16. Give paFUculan (delails) concerning any lonptetm debt authorired by a regulatory cnmmisslon but not yet Issued.
01 M9rZOf 3
I
1 OM 1 I20 1 7 o I m gno I 3 1 OIO 1 I20 17 54,700.000 829.009 32
. .
A
A 1 .. -
FERC FORM NO. 1 (ED. 12-96] Page 257
82,282,566 33 2,133,054,842
Entergy Arkansas, hc Endaf &laU4 (2) CIA ResubmIsslun I !
11 1 I 21 SOU0 WASTE DlSWSM BOHDS
Unt, No.
Total expense, Prernlum or Dlscount
Ctrsr and Ssrm of Obtigatton. Coupon Rale (For nsw hwe, g h mmnBilon AuVlorizatlon numbers and dates)
PnnclpaI Amount Of Dabt Issued
(rl m, tCl
I 10 1 TOTALACCOUHT 221 I ~9S.400.000~ 2.227.393
3 Oeparlmcnt of Ensr~y (Nudeat F W Disposal Cost) 4 5 LONG-TERM OBLKiCirlONS 6 Little Rock N r Form Basa dtrtmbuirwl faulrfles 4.2%
.-
13 14 15 16 17 18 19
25 26 27
231 I I 24 I
I
30 31 32
33
28 1 I 1 29 I
TOTAL . 2,099,400,000 33,523,29! ..
FERC FORM NO. t (ED. f 2-96) Page 256.1
Endof L U I J I W I) pJu' u l y l l l ~ r tt-0". "Y, I .,
LONG-TERM DEBT (Account221.222,223 and 224) {Conlrnued) (2) n A Rasubmkslon I 1 Entergy Arkansas, Ine.
10- Identify separate undisposed amounts appflcabIe to issues Which were redeemed in prior years. 11. Explain any debitsand credits other than debiied to Account 428, Amortization and Gpense, or aedrled lo Account.429, Premium on Debt - Credit. 12. In a footnole, glve explanatory (defalfs) for Accounts 223 and 224 of net changes dudng the year. wlth respect to Iong-term advances, show for each company: (a) principal advanmd during year, (b) inlerest added to principal amount, and (c) prlndple repald durfng year. Give Commlssjon authorization numbers and dates. 13. if the respondent has pledged any of its tong-term debt securities give particulars (details) In a footnote Including name of pledgee and purpose of the pledge. 14. I f the respondent has any long-term debt securities whkh have been nomlnally issued and am nominally outstanding at end of year, deseribe such securltres In a footnote. 15. If Interest expense was Incurred during the year on any obhations retired or reacuulred before end of year, Indude such inferest
.
expense In column 0). Eplaln In a footnote anidiEeierencebet&n the total of column 0 and the total ofAmun1427, interest on Long-Term Debt and Amunt 430, Interest on Debt tu Assdated Companies. 16- Give particulars (details) concerning any long-term debt authorized by a regulatory wntmisslon but not yet issued.
Nomlnal Date Date of I Fatal amo%'%%Aing whout Interest Ibr Year AMORTlZATlOEI PERIOD
of Issue M*turity Data From Qate To Amount reductton for amounb held by Wppt) m (d) (e) (0 (gl
1 I I I I 1 &I 253,3241 Se,SM
1
I I I I I I 88.571
250.000,000 iJ07.943
r
533,054,842 3.703.909 I
1
. 2,133,054,842 . a2,2a2550 *
FERC FORM NO. 1 [ED. 12-96) Paga 25T.I
[Name of Resoondent !This ReDad is: I Date of Report I YearlPeriud of Report I Enkrgy Arkansas. I n k
( 1 1 r~ri Original (Mu, Da, Yr) (2) - A Resubmission I t - ' 2013lQ4
bchetfuh Page: 256 Line No.: 7 Column: I 1 T o t a l interest for Accounts 221 and 224 is recorded in Account 427, as shown on page 117, line 62.
Bchedde Paqe: 256 Uno Nu.: f 0 Column: h I Mortgage Bond 5 - 4 3 Series was retired an August I, 2U13.
bcbedule Pags: 256 Une No.: 26 Column: h 1 Independence County 5.0% Series was refunded on February 4 , 2013, with proceeds from Independence County 2.375% issuance.
kchaddo Page: 256 Une No.: 28 Column: h 1 Jefferson County 4.68 Serles was refunded on February 4 , 2013, w i t h proceeds from Yefferson County 1.550 issuance.
bchedul8 Paqe: 258.1 Une No.: 8 Column: I 1 The weighted average rate was 1.13%. The term loan is due 3anuary 2015.
JFERC FORM NO. i (ED. iz-87) . - I Page 256-257 FDotnote.1
I
B U N K PAGE
t
Edergy Arkansas, tnc.
8 9
I O 11
3. A substitute page. deslgnad ta meet a padiwlar need of a company, may be used fa5 Long as the dab b conslstsnt and meets the requkmenb of the above Insbdlans. For slectronlcnponing purposes compkte Uno 27 and provide h e substiMe Page in Ihe context of 8 footnote.
Deducllms Rearcfed on Books Not Oeduded IPrRetum Sae footnota M B I I
12 f 3 14 15
I
Income Recorded on Bwks Not Included In Return Bes Footnote DataIl 13.368,791
b
20 Sea Footnole Wtdl 41 5.660.376
23 Reeondlhg !tam Iortha Year- See Footnote Detal1 29.023,w
27 pederat Tax Net Income 28 Show Cornputatton o l T w 73 30 Est Fedaral Taxable Income 31
(574,255,744) @35%
-74,255,744
-25.969.510
3-41 1 351
32 33
Federal Taw Acenral lor the Current Year I -25.939.510
J 1 1 I FERC FORM NO. 1 {ED. 12-96) Page 261
-~ ~ ~. ~ ~
41 42 43 44 Eathnated ConsolIdalad Fademl lnwma Tax 16,38,0#
Name of Respondent This Report IS: Date of Report (Mo, Da, Yr) (1) X An Original
Enbrgy Mansas. he. (2) - A Resubmissh I 1
behedule Paqe: 261 t h e No.: 5 Column: a I Taxable Income Not Reported on Books:
YearlFemd of Report
20131E14.
Taxable Unbil led Revenue $9,363 , 218 Contributions in A i d of Construction 2,666,438 TCBY Tower I, 481,266 Interest Capitalized 4,170,283
$17,681,205 Total I-----------
P-FF=L=P==
Deductions on Books Not Deducted for Return:
Nuclear Fuel Expense Interest on Tax Deficiency Securit izat ion Property Insurance Reserve Increase in Reserves Deferred Nuclear Shutdown Costs Reserve for Uncollectible Accounts Non-deductible Meals & Entertainment TCA/Ice Storm settlement Amortization of Bond Reacquisition Losses Maintenance Refueling Reserve Long Tern Incentive Plan Deferral of Grand Gulf Cost per Settlement Non-deductible Penalt ies Non-deductible PAC & Pol i t ica l Expenses Pension Expense Restricted Stock Research & Experimentation Reorganization Costs Option Grant Rate Refund Accounts Payable Reversal of AFUDC equity & net-of-tax Depreciation-Reverse prior flow-through Incentive Comp Severance Accrual Decommfsafoning - Dry Cask Total
$81,723,112 ( 8 O 0 , O O O )
(1,144,132) (12,282,159) (2,169,129)
(598,214) 1,770,408 419,621 526,656
7 ,275,550 69,446
21 663,137
(68 235,635) 113,720
1,379,891 178 390,382
253,165 2,471,880 6,966,097 (35,243) 557,146
9,733,653 14,579,929
2, 721,199 2,429,312
$ 1 4 6,118,483
3,737,115 '
1216O18576
------------ m=U-C---
bchedule Page: 261 Una No.: f 5 Column: a 1 Income Recorded on Books N o t Included In Return:
Amoxthat ion of Gain on Sale of Property $82,048 Equity in Domestic Subs (2921 XPP Advances 1,440,489 Allowance for Funds Used During Constructian 11,844,546
$13,366,791 *
rn-p-mrnm~ T o t a l '
IFERC FORM NO. 1 (ED. 12-87) I Page 261 Footnote.1
I Name of Respondent lThis Report is: I Date of Report IYearlPenod of Report 1 Enlergy Arkansas. he.
(1) Ari Original (Mo, Da, Yr) (2) - A Resubmission I f 2013Q4
bchedule Page: 267 Une No.: 20 Column: a I Deductions on Return Not Charged Against Book Income:
Excess of Tax over Book Depreciation Property Book/Tax Diff-PowerTax Daily Lease Charges Early Retiree Reimbursement Vegetation Management Deferred Fuel Expense Regulatory Capitalized Costs Pension and Kospital Reserve Mark to Market-Other Contracts Coal Car Lease Payments System Agreement - Supplier Refund Section 4 8 1 Adjustment-263A Deem Prepaid Expenses Contribution Carryover Units of Property Deduction Reg Asset - Gustav h Ike Tax Gah/Loss Prop Items EPA Allowances License Extension Costs Casualty Loss Abandonment Loss MIS0 Cost Deferral MOARK Cost Deferral HCM Cost Deferral Business Development Costs Depletion ESI Taxes Rev Proc 2000-50 SW Costs DOE Litigation Ded f o r Dividends Paid on Certain Pref Stock
$37,960,564 1991 082, I12
2,449,420 (240,317) 6,6771 111
(58,521,045) 10,416,528
717,421 It 633,000
(7,010,975) 30,000,000 22,422,190
6 7 6 , 4 0 9 3,165,995
(12,274,284 1 143
(2431 332,194
30*564,927 19,295,408 24,769,261
8,665,763 22,485,857
69, 0 ~ 5 , 0 7 7
131 264 46,775
7 ,809,646
176,530
I, 532, I62
(10,270,697}
Total
bchedule Page: 261 Une #a: 23 Column: a I Reconci lhg Items:
Federal Xncome,Tax Accrual - Current Year Federal Income Tax - FIN 40 Federal Income Tax Accrual - Prior Year State Income Tax - Prior Year Provision for Deferred Income Tax - Federal Provision for Deferred Income Tax - S t a t e Investment Tax Credit - Federal NOL Origination/Utilfzation ESI Taxes
Total
($25,989,510) (6,582,409) 27,298,027 1,720,937
6,320,479 011 8651 107
(1, 988,787) (55,153,664)
1,532,162
$29,023,222 =====e=====
Page 261 Foolnote2
Endol 2013FP4 un" unginai (MO, ua, 11)
(2) g A Rasubmtssbn I I Entergy Arkansas, Inc
TAXES ACCRUED, PREPAID AND CHM?GEO DURING YEAR
1. Glve partidan (details) ofthe comblmd prepa?d and a m e d lax accounts and show the lotal taxes cbarged to operahorn and other accounts during Ihe year. Do nut Include gasollne and other sales taxes whtch have been charged to he accuunta to whtch the laxed matedaal was charged. If the actual, or estlmaled amounts of auch taxes am know, 8hW the amounts In B footnote snd desfgnate whether esllrnated or actual amounts. 2. lndudo on this paga, laxes pald during the yaar and charged direct to final amunb, (not charged to pmpald or amued b e e ) Entertha amounts In both columns (d) end (e) The balandng of thls page iS mtaffeded by the lnclushn of these taxes. 3. lnctuda In column (d) taxa3 charged during he year, taxer charged to operations and olharaccounls thmugh (a) accruals wedded to taxes accrued. {b)amounls credited to propcrtIons of ptepald taxes chargeable to current year, and (c) taxes pald and charged dlred to opratlons oraccounls other than xcruecl and prepald !ax BCCOM~S.
4. Llst the aggregate ol each klnd of tax In such manner b a t the total tax fur each Slaals end rruW~tsbn can readily be ascertatned.
31: I Entomy S ~ N I C ~ S , Ine. 32 I
I f I I 1 301 Income Taxes
I 13,659.163 13,659,163
41 TOTAL I44,32 I ,074 I ,ne,as3 134,113,016 307,603.733
FERC FORM NQ. 1 (ED. 42-98) Page 262
5. If any tax (exdude Federal and State income taxes)- wven more then one year, sh& lhe requlred Information separately for each tax year, idenbfylng the yoar In column (a) 6. Enter all adJuitments of ihe a m e d and prepaid tax aecDunts In t ohmn (0 and axplaln each adjushnt b~ a foot- note. Deslgnale debit adjtobtoenb by parentheses 7. Do not hdude on thh page entrles with respect to deferred lneome bxes or taxes ~olleded through payroll dedudiom or olharwlse peodlng m m ~ l ofsuch taxes lo be tawing ~ulfio& 8. Heport In eolumns 0 hhmugh (I) how ihe taxes were distrbuled. Report In d u m n (r) only he arnountr Eharged to Accounts 408.1 and 409.1 perlahing to cbdk opmtions. Rspdrth wlurnn [r) the amounts charged tu Accounts 408 I snd I09 I partaFntng 10 Dthcr UUIity departments and amounts charged to Aewunts 4082 and 409 2. Also shm In column (0 tha laxas charged h3 utrli plant o r a a r balanw sheet acccrunts .9. For any (ax apportioned to morn than one utirty departmarit or account, stab In a fnotnnots ths bash (nacassky) dapporttonlng such tax
BALANCE AT END OF YEAR (Taxes acerued Prepaid Taxes
(Ind. In Account 165) Y!3! (h)
A m n 236)
-55,689,740 1,734,2221
DISTRIBUTION OF TAXES CHARGED
(Acccunt4US.l,409.l) (Atcount 409.3) E:1fi&&?4;9)
. Une Other NO.
1 1,278,900 -713,262 S 3.213.755 0.175.322 2
EleddC Extraordinary Item us en u e
0 ) (r) 0 Ir)
- . . . 1 I
-788,942 I 365 1 I I 120,2271 4 I 1 I 1 -
*54,744,460 1 I 4,500.008 1 I 5,582,2671 E L 1 L -
FERC FORM NO. 1 (ED. 12-96) Fags 283
A Resubmlsslon Enbrgy Arkansas, Inc
FERC FORM NO. 1 (ED. 12-84) Page 286
Eniergy Arkansas. Ine. ACCUMULATED DEFERRED INVESTMENT TAX CREDnS (Account 255) (continu&)
1 I 38.958.373 I 1
FERC FORM NO. 3 Im. 12-89) Page 267
Name of Respondent This Report is: Date of Report YearlPeriod of Report (I) X An Original (Mo, Da, Yr)
Entsrgy Mtansas, Inc. (2) - A Resubmission t I 20 t 3 M 4 I
FOOTNOTE DATA
bchedde Page: 268 Llne No.: 2 Column: I I Average l i v e s are based on the estimated composite useful l i f e of the properties and are subject t o xeconsfderation each year.
1 1 1 , Page 26G267 Footnote.1
\WIY, Y E , 1'4
3. Mlnw kerns (5% of he Balance End of YearforAccPunt 253 or amounts less b a n SIoQ,OOO. wttlchwerk greater) may be grouped by classes.
47
f t 1 Disallowed mstr - 121 Settlement - D d e t 09-844 I I . ~ O , W ~ various 9,OSS,SlS~ 16,473,4551
Rat8 Case I I I t
TOTAL 530,193,834 '- 233,601.947 37,583,742 342,175689 I
13 I 141 KGENPusat
I I I I I
32 33 34 35
I 361 I I I I I I 1
37 38
I
FERC FORM NO. 1 (Efl. 12-94) Paae 269
I. Report the inkmalion called for below concemhg the respondent's acmunting rot deferred Income taxes raling to property not subjed to aderakd arnnrdzation 2. For other (Speclfy),inclode deferrals relating 10 other Income and dedudions.
Uil8 Accaunt Balance st NO. Beglnnlng ofYear
CHANGES DURING YEAR
Amounts Oebded Amounts Credrted to Amunt 410,I toAcwunt41f.l
(4 @) (el (a) . I Account282 . . 2 Ehmc I 1,5%,62l,901 I 425,838,5691 382,356,21(
i ,59~,e21,901 382,356,211
8
B
1
I TOTAL Account 282 (Ei'IFddr Total of lines 5 thru 1,598,621,901 425,638,569) 3az,3sO2i1
10
11 12
ERC FORM N0.1 (ED. 12-88)
~ ~~ ~ ~. . .- . ... . . . . ~ ~~~~
Classlfieatton ofTOTAL I .
Federal. Income Tax I ,372,878,338 I 367,849.t 26 327,473,s State tnwme Tax 223,745,5631 57.709,44 3 54,382,24'
Page 274
End or 2111 31U4 11) vriginai [Mu. Ud, I I )
Enlergy Arkansas, Ine. (2) n A Resubmlsdon I i ACCUMULATED DEFERRED INCOMETAXES - OTHER PROPERTY (Amunt 282) (Cmbnued)
3. Use footnotes as reqdred.
NOTES (Contmued)
I
FERC FORM NO. 1 (ED. 12-98] Page 276
(1) ~ A I I unginai Entergy Arkansas, Inc. (2) nARssubmtsQon
Endof dU1J1w p u , u c , "1
I 1
Une ACCOunt NO.
(a) 1 Account283
CHANGES DURING YEAR Amounts Debited Amounh Cfedlted
toAarru t4ll.1 toAceo t410.1 Balana at
Beglnnlng of Year 0) (8) H +.
1 r - . . 7 . ' I . * : b * .
2
3
4
--.- 65,l i9,9E1 25,026,52. 21 Federal lnmm Tax . 858,257,583
22 State Incame Tax 75,n5,046 I D,MB,l59 3,654.511
r
I - . I 1
L " L ' . ' Electric
SteDotaII 932,032,623 74,968,140 28,6€i1,03f
FERC FORM NO. j (ED. 12-96) Page 278
7
B 9
11
I
TOTAL EhMc Votal of h a s 3 thru 8) 932,032,629 74,968,140 28.681,03!
Gas I' .. . I . . . . C - L(
1 I -f2
13
14
15
I6
17
l a 19
~~ ~~ --
TOTAL Gas flotal ofllnnsr 11 thnr 16) ----- TOTAL (A& 283) (Enter Total hf lines 9,17 snd 161 832,032,629 74,968,140 28,681,03'
ntargy Aficansas, Inc.
CHA-BING YFAR ADJUSTMENTS mounb Debtlad Amounts Cradled Debits Credits Balance at
Amount AWuf l mounl End of Year 3 Account 410 2 D e b d
to Account 41 1.2 (k) (e) (h} (I) fJ)
. ,
.. I 1 ACCUMULATED 6ffERRED INCOME TAXES - OTHER (Aearunl283) IContlnued)
P d d e In the space below explanations for Page 276 and 277. lndude amounts rebling to Inslgnilicant items fisted under Other. Use footnotes 8s required.
urw NO.
* 1 . . t 2 .. . .
1 I 1 8 2 x 8 3 I 144.458.4501283 I 18.530.173 1 852393.4531 3 t I I I - . . - . - - .
I 1 I 1 4
I I I I I I I 18
144,458.9501 18,530,1731 852,391,453 I 19 .. . . .
1823283 120,520,147 283 15,459,525 . 791JW,419 2f
182m83 23,9m.303 283 3,070,648 81,101,034 22 23
NOTES (Continued}
FERC FORM NO. I (ED. 12-98) Paw M
Name of Respondent This Report is: (1) XAn Original
Date of Report Yeadperiod of Repat (Mo, Da, Yr)
Entergy Arkansas. Inc. (2) I A Resubmission I I 20131Q4
FOOIWOTE: DATA P
bchadule Page: 276 Una Na: 3 Column: a I Balance at h o u n t s Amounts Beg of Year Debited to Credited to
Account 4 1 0 . 1 Account 411.1
Regulatory Asset: Securitization Regulatory Asset - MIS0 System Equalization Agreement Maint./Refuellng Reserve Minimum Pension Liability Bond Reacquisition Loss Section 475 Adjustment Capitalized Costs Regulatory Rsset - HCM Regulatory Asset - MOARK TCBY T o w e r (CADC) Mise Capitalized Costs Regulatory Asset - 30 Y r Retail Prepaid Expenses 2638 Methad Change-283901 263A Method Change-283F48 Inc tax Adjustment
Regulatory Asset Securitization Regulatory Asset - MISO System Equalization Agreement Maint./Refuelfng Reserve Minimum Pension Liability Bond ReacquisLtion Loss Section 475 Adjustment Capitalized Costs Regulatory Asset - HCM Regulatory Asset - MOARK TCBY Tower (CADCI Mise Capitalized Costs Regulatory Asset - 30 Yr Retail Prepaid Expenses 263A Method Change 263A Method Change Snc. tax Adjustment
$36,852,032 - (1)
15,066,385 313,834, 604 12,355,471
{ 93,682) a, 037,121
c - 13,607,209
31 925,045 2,011,485
.242, 427, 810 332,331,556
45,461,527
6r 136,067
$25,045,505 6 r 150,194
12,450,000 6,383,085
185,152 7,721114 1
- - -
152,099
11,981 296,0S7
3,243,707 7,568,647
5 , 7 60, 572
w
$11,293,597 337,14 9 682,500
9,23 6,920
1,229,768 574 , 660
c
I - - It 404,746 1,785,402 218,563
16,230 S701450
I. 331,054 c
Adjustments Debits Credits
Acct Acct Balance 'at No Amount NO Amount End of Year
$- 283 6,310,950 -
e
c - c
283 8, 8 Z O l 077 283 3,399,146
c
c
$37,121,993 12,123,995 11,767,499
190,753,416
7,052,799
12,212,550
11, 310,ass 8,0371 121 B, 820,077
12,434,562 5, 063,011 3,7181463 2,291,312
3, 399,146
145,101,067 338,569,149 ' 42,614,438 ---1-----1---
$852, 391,453 " = l l P - u m m L l n H
IFERC FORM NU. i (ED. I Z - S ~ I I Page 276277 Footnote.1
1 35 36
, 37 38 39
40 * 41 TOTAL 68,529,159 123,961,644
. Report below the patllwlars (details) called for mnceynlng other regulatory liabllittes, indlrding rate order docket number, if appllabte !. Minor Hems (5% of the BaIanca In Account 254 at end ofpehd, or amounts less than $ 1 0 0 , ~ which everb less), may be grouped ry dasses. 1. For Regulatory Uablities belng amortized, show period of amortization.
Description und Purpose of Other Regulalory Uabltles
in0 NU.
i
I
55H71 553.171
SI
I5
191 20 I 21 1
23 24 25 26
.. -. . . .
271 I
198,714,037 I- Page 278
254,14T,372
FERC FORM NO. 1/34 (REV 02-04)
Entergy Arkansas, Inc
4
5
6
1 Endof Z013lQ4
Small (or Corm.) (See Inslr. 4) 485,3O4,8? I . 4m,m6,ox
Large [or Ind) [Saa Inalr. 4) 429,603,036 438.000,69€
(444) Pubk Sttbat and Hhhwav Lhhtlnn 9.264512 9300.36i
Line T-uo of Amount Rev- Year OpeSam Aevenuef NO. b Dab aUarterty!Annual P m h year (m C a M y )
(a) (b) (C)
1 Sales of Electrictty . ' 2 (440) ResldenUal Sales 764,681,554 I 75a,i 55,930
8
9
(446) Sales to Rallroads and Raihvap
(448) Interdepartmental Sales
7 (445) OthsrSalai to Publt Authorities a.a3z,w 10,472,5lC
t I I (441) Sabs for Resab
f2iTOTALSalei of Electddty
13) (Lass) (449.1) Pfovlslon for Rate Rahmds
18 I (453) Sales of Water end Water Pwsr t I 19 I 1.154) Rent from Elecldc Pm~ertv 5.803.8741 5.a77.5a
429,14 1,267 369,322,242
2,107,828,f39 z,050,827,7a!
576,360 -144,601
14
15
16 17
____ _ _ _ _ ~ ____
TOTAL Revenues Net of Prov. for Rtfuds Mher Opbratlng Revenues * .
(450) Forfeltad Dlsmunts t0,119,926 9,713,931
(4511 Mtscsllansous Sarvfca Rwsnucs 2,721,108 2.864.26[
.- . .
20 21
22
(455) Intcrdeparimenlal Renb
(456) Other Electric Revenues (456 f l Ravenuas hwnTransrnisslon of Efoctrlcftv of Mhen
16,045.899 9,165,971
33.6~waol . 33.1 53.72!
..
24
25
25
27
(4- 2) Mlsctllaneoui Rwenuer
TOTAL Olher OparaUng Revenuci 68,354,245 60,755,47!
TOTAL Ebctdc Oparalng Revenues 2,l~5.608,Ol6 2,111,727,86!
23 (457.t) Reglonal Control Servlw Kcvenues 50,158
I AVG.NO. CUSTOMERS PER M O m MEGAWAIT HOURS SOLD Year b Date QmrlerIylAnnual I Current Year (no ~uartetfy) I Pmvtous Year (mr Quarterty)
179,083
6,768,840
48 49 '
n.166
9,019,385
30,106,255
163,540
13 12 1 699,120 697,206 1
20.859,?62
8,929,794
29,788,956
29,788,950
Una 12, wlurnn (b) Indudes 5 Una t2, wlumn Id) Indudes
I . t - t ' s,w5,sae 90,045 89,371 4
6,925,238 23,001 22,580 :
1
21,088,970~ 69S..t07l 697.194) 1
0 of unbjflrtd tmvmues. 0 MWH reiaUng to unbllietl mvenuef
FERC FORM NO. It3p (REY. 1245) - Paw 301
Name of Respondent This Report is: (1) Ts. An Original
Date of Report =YearlPerlod of Report (Mo, Da, Yr)
Entargyfiansas. - 2 A Resubmission * I I 201YQ4
FOOTNOTE DATA I
bchedule Page: 300 Une No.: 4 Column: b I Basis of classification of commercial and Industrial Sales Account 442: l a ) Industrial - Standard Classification Manual; (b) Commercial - a11 other business or professional activities of a non-manufacturing nature.
bcheduje Page: 300 Une NO.: 4 ca~umn: c 1 Basis of classification of Commercial and Industrial Sales Account 442: (a) Industrial - Standard Classification Manual; (b) Commercial - a l l other business or professional activities of a non-manufacturing nature.
bchsdule Page: 300 Une NO.: ~t ~ o ~ u m n : b I Other Electric Revenue includes:
Unbi l l ed Revenues $9,396,558* Transmission Equalization Revenues 2,965 , 910 AR Gross Receipts T a x 652 , 892 Affiliate Service Fee Revenue 245,000
Miseellanous Revenue 44,829
Distribution Substation Svc. 21413,993
L f t t l e Rock Air Force Base l88i 935
MIS0 Mkt Sch 11 Wholesale Distribution Revenue 87,502
Tota l
+Includes 99,801 KHtl
Other Electric Rcvcnuc includes:
Unbilled Revenues Affiliate Service Fee Revenue Arkansas Gross Receipts Tax Distribution Substation Svc. Transmission Equalization Revenues Little Rock Air Force Base
Total
$2,186,629* 82,500
622,526 2,572,650 3,342,865
358,808 ccc-------
$9,165,978 muma=a=-=a
*Includes 12,963 M’dH
IFERC FORM NO. I (ED. 12-87) J , Page 3W30i Footno1e.t
REGtONALlRANSMlSSION SERVICE REVENUES (AKxKtnt 457.1)
48 TOTAL
1 Enlergy Arkansas, loc
Va%xder (I)
L n e Number ana litte 01 Ham schedule m soid Kevenua Average Number or Cus omem
NO. (a) @I (el (d t COMMERCIAL 2 SG? Small Gen. Servlce 3,t03,485 184,070,709 83.232 37,287 0 052 3 SG2 Small Gsn. Servlo!~ 16.633 a53321 25 665.320 0 051
.. I I
SALES OF ELECTRlClrY BY RATE SCHEDULES
i. Report below breach rate schedule In effed during the yeartha FmryH of eledrlcity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, mxdudlng date for Sales for Resale whlch f reported on Pages 310.311. 2 Provlde R subhaadhg and total for each prescrbed operahng revenue amount h lhe snqmna fitlowed In'EIeetrle Operating Revenues: Page 300-301. ltths sales under any rata schedule m dassltied In mom than one r~venue amunt. at the rate schedule and Sales data under each apptkable rwanua account rubhaadmg 3. Where the same customers am mwed under mom than o m rate schedub In the same revenue- account classilieation (such as E general rasldanllal sehedula and an off peak water haatlng sdredule), h e entrles In d u m n Id) far the #pedal schedub should denole the duplteatlon In nu&r of reported customem 4. The svaragtr number of wstornan should bo the number of bills rendered dudng the yeardhrHed by the number of bflllng p e W s dudng the year(l2 d all bmlngs am made monthly). 5. Fw any rate schedule having 8 fuel squsimnt dause Stat8 fn a hobrote the estimaled addiffmat revenue billed punuant thereto. 6. Report emount of unbltled reYenUQ 8s of end of year for each appllcsbb mmnuei amunt rubheadlng
301 IGf LGS TOU lntarruptrbb I d IGQ LGS TOU IntermaUbfe
9,880 159,388 2 4,940.000) 0 016 196.728 2 . a 6 0 . m 3 65.576.OOd 0 014
I
6 SG7 S~TMI, Gen. Sew183 I 12.79 1 I 661,905 781 18,378 o 052 1 GTf Opt. CGS Tkne-otUsa 6962731 22.604238 354 1.5668.873 0 032
12 13 14 15 16
81 GI2 Dpt LGS Tune-of-Use I 42.3731 1,333.444 61 7,082,167) 0 031 91 GT4 Opt. LGS flmml-tlse 32.3451 970.24d 101 3234.500~ 0 OM
1 . .
LG1 Large Gen. Sarvlcs 1,082.638 41,412.844 1.022 1.059,331 o 038 LG2 Large Gen. Sarvlce 26,719 1,013,493 13 2,055,308 0 037 LG4 Lwga Gen. %rvlce 27.829 i ,003,576 13 2.1 40,692 0 036 tL1 LGS Intemrptble 4,452 89,103 4 1,113,000 0.ozc LP1 targo Power Servfca 29.562 1.031.999 4 7.390.500 a OM
..
27lTCA Tfansltion Cost Adiusmnent RI 21 I I 2dPCA Produdton Costs Alloeallon R 34.837.3511
24 EECR Energy EMclency Cost Rate I I 13,471,301\ I I 3dCA Capam Acquhtllon Rldar 1 8.59e.m!
I - . . . .
3llSDR Storm Damege Rldar -1351 I 1 32tMFA MunlcbaI Franchise Ad1 I 17.044.?481
- .
33lGMES Gorst Mandated Exp Srchg I I 1 ,t07.71 t I I I 341 FLCF Federal L M Consult Fsa I 158.9591 351ANO AN01 lntertm Capauty Cost Re] I 3,974,6891 I 1 361 Mtse I 2.1501 i O5.2361 411 52,4391 0 0489
1 431 TOTAL d d d d E R C FORM NO. I (ED. 12-95) Fags 301,l
I EntergyArkansar, tnc.
5 6 7 8 9
t I SALES OF ELECTRICITY BY RATE SCHEDULES
1. Report batow for each tats sehedute In effect durlng the p a r Vle MWH of elemlchy aokl, revenue. average number of wstomr, average Kwh per customer, and avaraga mvmue per Kwh, axdudhg date for Sales for Resale whlch k reported on Pages 310-311. 2. Pmvlde B subheadlng and total for ea& ptes&ed operating nuenue account k the sequenca follmed In 'EleetrJc OpeaUng Revenues,'Page 3 W O l . lllhs sales under any rate achedlrh am ctasslfied In mom ban one m w n u ~ account, Ust the rata rch~ddule snd sals3 data under each epplkable mvenuo eecount subheadlng. 3. Whare !he same customen are s e d under more than one ate fchedlr!e In the same revenue acarunielassmcatron (such as a ganeral resldential schedule and an off peak waler heating schedule), the enlrhs in column (6) formu spedal schedule should denota the duptcatlon In number of mported customen. 4 The average numbar of eusbmm should k- Ihe number of bnls randered dudng the year dkHed by the number of bllllng pedods durlng the year (12 Hall bIlllngs am made monthly). 5. For any tale schedula havlng B fusf adjusbnent clause stato In a Bolnota the citlmated additional revenue blIled pursuant thereto. 6. Repatt amount of unblnd revenue 85 of end ofyaarfareaeh sppltcabb mvenue account subheading.
SGZ Small Gen. Suwtce 72,666 3,74 B, 21 3 521 1,397,423 0.051 I SG3 Small Gan. Servlw 5.039 215,640 271 186,630 0.042 SG4 Smatl Gen. Servlm 88,675 3,575,599 48 2,847,396 0.040 SG5 Small Gsn. Servla 40,699 ' 3.3410.801 6 0,783,167 0.082 SG6 Small Gen. Servlw I 603 142.592. 1 603,000 0236
L 1
10 IS2 SGS Inbmrpbble 6271 24.a74 11 827,OOOl 0.039 t t IS4 SGS IntemDLble 16.2511 719.0661 d 8.125.500l 0.044 --. - - - . . ... ..
1
12 GTt Opt. LGS TlmtMII-USe 251 ,gas 8,339303 103 2,440.431 0.032
14 GT4 OpL LGS mO-LIf-US8 181,368 5,021,820 48 3,903,500 0 026
13 GT2 Opt. LGS tlme+EUse 25.704 873.819 5 5,140.800 0 037
FERC FORM HO. 1 {EO. 12-95) Page 3M.2
1 LUIJ1U4 I Endo'
1. Report betow for each rate schadub tn ekd dudng the year the MWH of etcbldty sold. mvenue, average number of arsbmr, average Kwh per customer. and average rnv~nua per Kwh, axfluding da!e fw Sales for Resale which b raporlad an Pages 310-311. 2. Pmvlde a subhaadtng and total tor aach presbied opeatrng m e m e acmunt In tha sequenw folIuwed In Xkh-lc Operating bvenu*e's.* page 3MMOI. If the sales under eny rate scheduh are cIasaRed In mrn than one revenue acaunt. Ust fhe rata achedule and sales data under aach
: a p p b b k revanue auxlunt subheading !3. Where the fame customers a18 served under mom then on# rate schedule In the same revenue 8twunt~lassrficatIan (suth 8s a general resldentlal schedule and an o f psak water heating rchduh}), the entrfas In d u m fd) ro; tho special schedule should denote !ha dupfbllon In number of reported customan. 1
I I . . I
31 C23 CogsneraUon I I 1,0061 51 I
I 33l I
. -. . . . .- . . . 321 I I
FERC FORM NO. I (ED. t2-85) gage 304.1
. . I I SALES OF ELECTRIClrY BY RATE SCHEDULES
1. Repod beefow breach rata schedule In effed during the year the MWH of ekdduty sold. revenue, average number of wstomer, average Kwh per customer. and average mwnue per Kwh. exdudding dah lor Sales for Resale which Is reported on Pages 310-311. 2. Proddo a subheading and total for each prasmhd aperating m n u a account In the sequenca foUmed In'EbMc Operating Revenues: Page 300301. I the sale3 under sny rale schedule are cbssiAed In mom than one revenue Iccounk. Ust h e rate schedule and sates data Under each sppTfcable revenue account subheadlng. 3. Whera the same customers am sewed under morn than one rate schedule in the fame rewnue account clarsllffdon (such 8s a general rcddsnM rchedute and an off peakwater heating schedule). the antrles tn mlumn (d) for the spedal rchedule should denole the dupkahon In number of reporfed wstomea. 4. The average number af witomen should be tha number of b W randad dlrrhg the year divHt?d by the numbsr of blnlng perlods dum the year (I2 Hall blflhgs am made monthly). 5 For any rale sehedute having a ha1 adjustment dause stale bt B btnute the estimated eddAional revenue bi!led pursuant themto. 0. Rep& 8moUnt olUnbItlad revenue 89 or end of p a r for aeth spplicabla mvanue sceount subheading.
2
3 Lt Mudclpat Street Llghtinng 70,809 6,W 0,2 7 9 3061 23 1.4 02 I 0 0864 LlSH Munldnal Shtelded Stmat Ll 93 1 1.655 31 31.0WI 0.125:
- . . .- . -~ I tqYOTALPUBUC5REFTfLHWY I 77,1661 9,264,5121 6351 121,IZtt 0 120
1B 19 20
161 I I I I I 171
OTHER SALES TO . . . . . . . . . - . -
- 21 I PUBLIC AUTHORMES I I I 221SG1 Smll Gen. Senrlce I l.ar31 53.2861 171 61.7061 0 050;
251 pT2 Opt. LPS Tlme-ol-Ura I 96.6851 2,854,972l 11 9S.eS5.CQOl 0.029 261 F T ~ opt ws ~ b ~ t e s t ~ s a 30.D791 943.8671 11 3 0,9 7 9,O 0 0 1 0.030.
271L4 AnNight OutdoorLlghtIng I 291 2,7081 51 5,8001 0 093 28lMP Munleipal Pump Sarvlca 7181 35,420( 211 34,1901 0.049
c I I 4 1 ,TOTAL BiIled a 0 c ol Om 42 Tolat Unbilfad Rev {Sea lnslr 6) 0 C m o a 43 TOTAL d 0 I: o.wa
BLANK PACE
blergy Arkansas, Inc
Subtotal RQ ol 0 I
. . ' SALES FOR RESALE Wcmunt 447)
. Report all sales for resale @e., saIes lo purchasers other than lrlffmafe consumers) transacted MI a settlement bash other than wer exchanges during the year. Do not report exchanges of electricity [Le., transadtions involving a balancing of deblts and wedits IF energy, capacity, etc.) and any settlemenls for imbalanced exchanges on hls schedule. Power exchanges must be reported on he 'urehased Power schedule (Page 326-327). . Enter the name of the purchaser In column {a). Do note abbreviate or Imncate the name or use acronyms. Explaln In a foolnote any wnershlp Interest or afiltation the respondent has wflh the purchaser. In cdumn (b), enter B Stalistieal Classifmtion Code based on the original conIradual terms and conditions of the servlce as foltuws:
IQ - for reqdremenls servlce. Reqdrements s e w b Is service which tfie supplier plans to provide on an ongolng basis (La., the upflier indudes prcjeded load far this service in As system resourca plannlng). In addition, the reliabnlty of requirements senrim must te the same as, or second only lo, the supplieh servlce to Hs own ultimata consumers. F - for tong-term service. 'Longlem' means five years or Longer and "firm' means hat servlca cannot be intemptad for economic easons and Is blended to remaln rellable even under adverse conditions {e.g., !ha supplier must atlempt to buy emergency energy wm thfrd parlies to maintaln deliveries of LF service). This ategory should not be used for bng-term firm servlce whkh meets the lefiniffon of RQ senrlce. For an transadions Identified as E, pmvlda In a footnob the fermlnatlon date of the cantract defined as the !adlest dale that either buyer or setter can unilaterally get out of the conbct IF - for Inlennedlatel-ierm firm sedca. The same as tF servlce except that "lntermedfate-term" means Ionger than one year but Less han five years. ;F - for short-fern firm sedce. Use h i s category ror sll firm sewices where the duration of each period of commtiment for sewlee is ne year or Iess. U - for Long-term sewlce from a deslgnated generalng unit. mLnng-tem" means five years or Longer. The availabWy and reliability uf 8edee, aslde from Emnsmisslon constraints, must match lhhe availability and reliabLly of designated unit. U -for lntemeddiat&!em sewice from 8 designated generating mil. The same 3s LU senrice except that 'btennediate-Ierm' means anger than one year but Less than five years.
Subtotal non-RQ
Tab1
0 0 1
0 0 4
FERC FORM NO. t (a. 12-80)
3s - for olher sewica. m e this category only for those sewlcees which cannot be placed In Uta ahvedefined categories, such as all ion-fin sewIce regardless of the Length of the conbad and sedce from desfgnaled units of LESS than one year. Desaibs the nature 3f the service In a fmhote, 4D - lor Out-of-period adjuslment Use tbls code for any accounting adjustmenfs or "trueups' for senrice provlded In prior reporting (ears. Provide an explanatlon In a footnote for each adjustment. L Group requirements RQ sales together and report them slarting a! line number one. AAer ilsffng all RQ sales, enter "Subtotal - RC1' n column (a). The remalnlng sales may then be llsled In any order. Eder 'Sublolal-Non-RQ" In column (a> aller thls UsBng. Enter Total* In column (a) as fhe Lsst Une of the schedule. Repott subtotals and totat for mlurnns (9) through (k) 5. In Column (c), ldentify the FERC Rate Schedule orT8riff Number. On separate tines, Ust all FERC rate schedules or fariffs under &I& sewicB, as identjfied IR c o h n (b), Is provided. 5. For requirements RQ sales and any type of-servlce InvoIving demand charges Imposed an a monthly (or Longer) bash enkr &e average monthly billing demand In column (a), h a average monthly non-cohcjdent peak (NCP) demand In wlumn (e). and the merage monthly tolncklent peak (CP) demand In column (fj. For all other types of servke, enter NA In columns (d), (e) and (0- Monthly NCP demand Is the maximum metered hourly (60-mlnute Integdon) demand In a month. Monthly CP demand Is the metered demand during the hour (60-rnlnute Integration) In whlch the suppilets system reaches Its monthly peak Oemand reported In columns (e) and ( f ) must be In megawatts. Footnote any demand not stated on a megawatl bask and explain. 7. Report In wlumn (9) the megawatt hours shown on bills rendered to the purchaser. 8. Report demand charges In d u m n (h). energy charges in wlumn (i). and the lofa1 of any other types of charges, Including outsf-ped& adjustments, tn culumn (I). kcplain In a footnote all oclmponents of the amount shown In column 0. Report In column (k) the total charge shown on bills rendered to the purchaser. 9. The data In cdumn (g) through (k) must be suhtotaled based on the RQINon-RQ grouping (see InstruetIon 4). and then totaIed on the Last -line of the schedule. The "Sub!otaI - RW amount In column {g) must be reporled as Requtremenls Sales For Resale on Page 401, l he 23. The 'Subtotat - NokRQ'amount In column (g) must be repodd as Non-Requirements Sales For Resale on Page 401 ,fine 24. 10. FmLno18 entries 8s requlred and pm'de explanations follwdng all requlred dah.
*
FERC FORM NO. I (ED. 12.90) Page 311
Entsrgy Arkansas, fnc.
1. Report all sales for resale (I.@., sates to purchasers other than ultimate consumers) twnsaded ~1 a aeltlement basis other than h e r exdhanges during tha year, Do not report exchanges of e M a € y ( Le., transactions lnvoh1ng.a baIandng of debits and CreSds for energy, capacity, etc.) and sny SetUements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326327). 2. Enter the name of the purchaser In column (a). Do note abbreviate at truncate the name or use acronyms. Explain In a foolnote any wmetzjhlp Interest or affiliation the respondent has with the purchaser. 3. In coIurnn @}, enter 8 Statistical Classifidon Code based on the odglnal contractual terms and conditions of the servlce 8s follows: RQ -for requtements sewIee. Requlternents service Is servlca whlch the supplier plans to p d d e on an ongoing bash (Le., the supptier Includes projected load for this sentice In Hs system resource planning). In sddiion, the rellablity of requirements servica must be the sama as, or seoond onIy to, the suppliefs senrice to Its own ulttrnata consumers. LF -for tmg-term service. 'Longterm" means five years or Longer and 'firm" means !hat sewlee mnnat be Intempted for emnomic reasons and is intended to remain reliable even under adverse canfitions (e g., the suppler must atlempt Io buy emergency energy from ihhird parties to mainlain deliven'es of LF servlce). This category should not be used for bnplerm firm servlce whlch meets h e definIUon of RP servlce. For all transadions Identified 8s LF, provide In a footnote the termlnatjon date of the contract defined as the earftest date that either buyer or setter can unllateralty get out of the conlrad. iF- for Inlermsdlatelm firm service. The same as LF seMm exwpt that "Intermedlaktetm" means longer than one year bu! Less than five yean. SF - lor short-term firm servloa. Use thls mlegory for all firm sem'ces where the duration of each perfod of w m m h e n t lor servlce Is one year M less. LU - for Long-term aenricet fmn a designated generating unit. 'tong-term" means five yean or Longer. The avaflability and reHabIlity of service, aside from transmissim constraints, mud match the availability and reliability of designated unit. IU - for Intermdiate-term rtrvlca from a designated genemting unit. The same as LU senrice except that "Intermediatetemm means Longer than one year bu! Less than Sue years.
IMO, tla, TI) End of 2033194 I t
Sublolal RQ I Srtbloiirion-RQ
0 0 I
1 rota1 1 I
FERC FORM NO. (ED. 12-90]
Endol 201m4 \MU, Yd, L 1)
Entergy Arkansas. l n c I t SALES FOR RESNE (Account 447) (Conlmued)
Fwtnota any demand not slated on a megawall basis and explain. 7. Report In column (g) !he megawatt hours 6hm-n on bills rendered to the purdtaser. 8. Report demand charges In wolomn (h), energy charges in column li), and the total orany other types of charges, including oulol-period adjustments, in column Q). fiplain In a fwtnnde all components of !he amount shown In column 0. Report in column 6) the total charge shown on bills rendered la the purchaser. 8. The dala In column (g) lhrough (k) must be subtotaled based on the RaMnn-RQ gmuplng (see lnstntction 4). and then totajed on Ihe Last -line of the schedule. The "Subtotal - RP" amount In column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The 'Subtotal - Non-RQ' amount In column @) must bn reporled as Non-Requirements Sales For Resale on Page
FERC FORM NO. f (ED. 12-90) Pa39 311.1
- Name of Respondent This Report Is: Oate of Report
(1) An Original IPno$a, yo
bchedule Page: 310 Une No.: 7 Column: B 1
YearlPenod of Report
A contract wherein the parties have combined their power sources and transmission f a c i l i t i e s on a pool basis to maximize overall capability, reliability, and economy.
Entergy Arlranras. he. (2) A Resubmission
System Sales to Others Year Ended 12/31/2013
I I' ' 201 3M4
Ameren Energy Marketing Company American Electric Power Arkansas Electric Cooperative Corp, Associated Electric Cooperative, Inc. Board of Public Utilities Cargill Power Markets LLC Carroll St, Park Central Louisiana Electric Company Citigroup Energy, fnc. City of Caldwell City of Lafayette City of Thayer City U t i l i t i e s of Springfield Constellation Energy Corn Group, Inc. Empire District Electric ETC Endure Energy L.L.C. EWOM Exelon Generation Company LLC Exxon ENCO Grand River Dam Authority Independence Power and Light Co. Kansas C i t y Power & Light
Louisiana Energy Power Authority Magnet Cove Mississippi Delta Energy Agency Nebraska Public Power District NRG Power Marketing LLC Occidental C h e d c a l Corp. Oklahoma Gas & Electric Omaha Public Power District Pine Bluff Energy RS Cogen8 LLC Sabine Cogen, L.P. Southern Company Services, Inc. Southern Miss Electric P o w e r Assoe Southwestern P u b l i c Service SRW Cogen, L. F. Sunflower Electric Company Tenaska Tenaska Frontier Tennessee Vallcy,Authority The Energy Authority Union Carbide Corp. Union Electric D/B/A Ameren Missouri Union Power Partners8 L.P. Hestar Energy
. Lincoln
MWH 702
1,919 1,608 5, 262 352
1,955 I
2,185 3,524
17 123 158 108 748 218
5,947 1,632 I, 109
11 1,108
18 2,544
428 38
605 3 r 571
4 08 802 190
I, 927 5 68 61 32 9 21
911 585 494 306 34 4 375
41 453 2,77U
32,352 2,037
6 3,523
150 8,406
Charges $22,380 107 , 3 67 69, 155 138,190
221 307 751 818
77 125,597 113,842
I, 177 s, 914 10,251 6,042
28,867 13,568 165,299 123,182 42r 341
931 67 230 l t 404
I4Or 690 24 t 037
31,166 2501 092 26,036 22,393 9,161
114,267 27,264
4 , 4 2 1 17,805 1,102
1,756,363
16,235
2,028
38,821
19,853 20 ,885 113,560 15 6,7 20
1,211,093 59,930
4 12 55,172
4 * 950 301, 897 _ _
IFERG FORM NO. I {ED. 12-87) . . 1 Page 310-3 t 1 Footnole.1
Name of Respondent This Report Is: Date of Report { 1) An Original (Ma, Da, Yr)
A Resubmisston I I
Western Area Power Administration Western Fanners Electric Coop. Wrightsville Power
YearlPemd of Report
2013lQ4
Flus: Net Adjustments to Sales
TOTAL SYSTEM SALES TO OTHERS:
Supplied By: Entergy Arkansas, Inc. Entergy Gulf States Louisiana, Entergy Texas, fnc. Entergy Louisiana, LLC Entergy Mississippi, Inc . Entergy New Orleans, Inc.
mn 22,020
LLC 19,227 76,341 4 6,803 14,782
4,799
183,972 --L-__-Id
ma--mamw=
REVENUE $447,435
386,567 3,456,627 1,102,899 293,241
96,000
Note:
The Entergy Companies jo int ly supply energy for sales to non-associated utilities. Due t o the format of purchased power accounting records, it is impractical to identify precisely how much each system company supplied t o any given sale.
( a ) Amount in other charges represents imputed t r k n i s s i o n .
{b) Generator Imbalance Agreement (GXA) Sales are sales made pursuant to t h e GXA for under delivery of energy.
bChedUl8 Page: 310 Line NO.: 3 Column: a I (1) Energy and capacfty sales associated with the Resource Plan.
)Schedule Page: 310 Une No.: 8 Column: 8 I ( 2 ) Includes revenue from co-owners of White Bluff , Independence, and Etitchie Steam Electric Stations due to heat rpte incentive and supplying entitlement energy from u n i t s other than jo in t ly owned u n i t s ,
bchedufe Paga: 310.f Une No.: 2 Column: 3 I Sales provided under a letter agreement: effective March 1992.
bchdufe ~ a g e : ~ ~ . f Line NO.: 4 CaIumn: a I Amounts shown in column (h) are Production Demand related revenues. Amounts in column ( j l axe Transmission Demand, Distribution Demand, or other charges related to revenues.
Page 31P3tI Footnote2
Endof 2oWQ4 (1) ~AnOrOginal (MO, ua, TI)
ELECTRIC OPERATION AND MhINTENANCE EXPENSES
htergyhkansas, Inc (2) mA Raaubmlsshn I t
3l0 Acwunt rn*!€V% the amount for previous year Is not derived from previously repoded figures. explaln In fooho!e.
Anwuntf r Prewour f i a r
(a 40. tal 0) 1 1. P M R PRODUCTION D(PENSES 2 A Steam PowstGenetabon a:.
7
t i
- 20 21 I
33
36
I 50
53
TOTAL Power Pmduction Ex
FERC FORM NO. I (ED. 12-93) Page 320
78 l(557) Mherl3penrer 79 ITOTAL Other PowerSupply Exp [EnterTotal of lines 76 Vlru 78) I
1 80 ITOTAL Power Prrxfudlon Expenses (Total of Unss 21.41.53.74 & 79) 81 12 TR4NSMtSSlON EXPENSES
29.221.664 50 3.5 9 4 . N 2
82 1 Operation 83 I(560) Oparatlon Supervkion and Englneedng 1
1 13.710.381 548,648,527
1.163.792.124
85 (581.1) Load Onpatch-ReIIabllrQ 86 (561 2) Load Dlspatch-Monllor and Operate Transmbsbn SyJlem 87 (561.3) toad Dispatch-Transrnlssbn Service end Schadullng
1
FERC FORM NO. 1 (ED. t2-93) Page 329
473,324374 I 1 MQ DEdI
. . 1 ?.9527811 8,927.4M)'
I 301.999 303.523
2,123.182 2202.986 744.652 646.325 142.124 . a 3 7 a 440.7a4 50.206 59.563
~- .. ~
381 ,I 59 373,204 594.041 497,614
6.1 8.1 41 3,481.953 1.1 52.29
18.902.805 f 8.623.M - . 5.423.363 5.W.461
2 13.809 166.0% 54,325 137,261
2.438.353 2.532.965 3.0 5 5, !M i ,352.53
..I
30
mdof ZOlJIU4 1'1 p J n t Ullyl1A-l \ IWU# I I )
Entergy Arkansas, Inc. (2) n A Resubmiision I t ELECTRIC OPERATION AND MAINTENANCE EkPENSES (Conhnued)
If the amount for previaw year 1s not derlved from previously reported figures, explain In footnote. Account
(a) - .. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
07) Supenrblon . . 243.566 457.292 108) Customer Asibtance Expenses 39.279.9Q2 24.791.292 OS) Infomabenal snd lnstruchonat Expenses i . is2 .8a 1 .1 07.317 110) Mnmllaneaus Customer Sentice and Inbma!tonal Expenses DTAL Customer S e m and fnlomation Expanses (kttal167 thru 170) 41.852.986 27.323.61 0 ,SALES EXPENSES : - '. * I - ,
peratron . . . .
I 967.709 1.178.665
p e r a h , . -
t13) Advettising Expsnws 75.621 73.987 116) Miscellaneous Saki Expense3 454.568 am.43~
I1 I) Supervlsston 33,898 20.317 112) Dernonstfatlng and Salllng Expenses 30,965 89,446
OTAL S a M Expenses (Enter ToLal at llnes ?74 thru 177) ADMINISTFUTIVE AND GENERAL EXPENSES
FERC FORM NO. f (ED. 12-93) Page 323
12 CityofNewton(t) os OAIT INIA NIA NI 13 Clry of Thayer (1) os OATT NIA NfA NI ------- 14
Total
FERC FORM NO. t (ED. 12-90) Page 320
End of 2U131U4 Entergy Arkansas, hc.
AD -for outof-period adjustment, Use thIs code for any smunting adjustments or "tnte-ups" for sewlee provlded In prior repohg years. Provlde an explanation In a footnote for each adjustment.
4. In column (c), Identify the FERC Rate Schedule Number orTariff, or, for non-FERC]urisdictional sellers, Indude an appropdate designation for the eontract. On separate lines, llst all FERC rate schedules, tariffs or contract deslgnations under which senrlce, as ldentrlied in eofumn @), Is provlded. 5, For requirements RQ purchases and any type of s e d c e Involvhg demand charges Imposed on a monnthly (or longer) basls, enter h e monthly average billing demand In column (4, the average monthly non-wlnddent peak (NCP) demand In column (e), and the average monthly cdnddent peak (CP) demand In cdumn (0. For all other types of sewice, enter NA In mlumns (d), (e) and (0. Monthly NCP demand Is !he maxImum melered hourly (6bmInute Integration) demand In a month. Monthly CP demand Is the metered demand during h e hour (6O-mmuts Integration) In whkh the suppllets system reaches Hs monthly peak. Demand reported In columns (e) and (9 must be bl megawatts. Footnofe sny demand not stated on a megawatt hasis and expjaln. 6. Report In column (g) the megawatthours shown on bills rendered to the respondent Report In columns (h} and fl the megawtlhours of power exchanges recehed and delivered, used 8s the bash for setilement. Do not report net exchange. 7. Report demand charges In wtornn 0, energy charges In calumn (k), and the total OF any other tVpes of charges, including ouMf.period adjustments, in column [I). Explain in a fuotnote all components of the amount shown In mturnn 0. Repatt In column (m) the t o M charge shown on bills received as settlement by the respondent. For power exchanges, repoft In mlumn (m) the sewement amount for tho net receipt of energy. If more energy was deiiiered #an received, enter a negative amount. If the settlement amount 0 Indude eredits or charges other than Inaemental generatlon expenses, or (2) excludes ce:ertaIn credits or charges mered by the agreement, pmvlde an explanatory footnote. 8. fhe dab In column (9) through (m) must be totalled on the bst h e of the schedule. The tala1 am& In column (9) must be reported as Purchases on Page 401, line I O . The totaI amount in column (b} must be repurled as Echange Receked on Page 401, line 12. The total amount in mlurnn (r) must be r~porled 8s Exchange Delivered on Page 401, line 13. B. Footmrte entrfes as required and pravlde explanations foltowfng all required data.
LIne qurcfiased Megawatt Houo MegaWalt Hours Demand Chargas . Energj Charges Mher Charges Total Q+k+l) N ~ .
POWER EKCHANGES COSTISEITLEMENT OF POWER MegaWatl Houn of ScHlembnt {S) (8 Ittl ((7 Im)
Received Dernrered (91 (h) 0)
6,153,373 3,952,922
I
74,044,486 24,526 2,92 1.07 9
92,431
1,171,957 1 1,197,798 1
1,242,190 1 214,441 I
1
FERC FORM NO. t (ED. .tZ-90) Page 327
E n d d 2013U4 ~MO, ua, 1 ti Eniergy Arkansas, Inc. I f
ED POWER A m u t 555) pu83%ng power ex&angesI
1. Report all power purchases made during the year. Also report exchanges of eleddclty (I B., iransadons Involvhg 3 balana'ng of JebHs and credits for energy, capacity, efc.) and any senlements for Imbalanced exchanges. 2. Enter the name of the seller or other party In an exchange transaction In uAurnn (a). Do not abbrevlate ortr~n~ate the name or use acronyms. Explaln In a footnote any ownenhlp interest or affiliation the respondent has with the seller. 3. In co!umn (b), enter a Statistical Classmcation Coda based on the orfginal contradual terms and condhions oflhe sewice as fooltom:
RQ - lor requlrements senrlce. Requlremenls senrlco Is 6ervIce whlch he supplkt plans lo provlde on an ongohg basis 0.e , the supplier Includes projects hat! for thls s e w b In Its system resource planning). In addition, the reliabllity of requirement senrlce must be the same as, or sewnd only to, the suppllets service to it9 own ultimate mnsumers,
LF - for tong-term 6rm servica. *Long-term" means five years or longer and 'firm* means that servtce wnnct be Intempted for emnomfc reasons and Is Intended !o remain reliable even under adverse mondions (e.@, the suppller must attempt to buy emergency energy fmm third parties to maintaln deliveries of lF sewice]. THs ategory should not be used for Iang-term firm senrice firm senrlce which meets the definillon of RQ servlce. For all transaction Identified as LF, provlde in a footnote he lermhatron date of the wntrad defined IS !he earliest dale hat either buyer or seller can unitaterallly get out of !he conbet .
1F- for Inlsmediale-term firm sendee. The same PS LF sewlce expect that 'Intermediatetterm" means Ionger than one year but less than five years.
SF - for shorl-!em strvica. Use this category for all firm services, whem the duration of each period of mrnrnitment for sewice Is ane year or less.
LU -for long-lm smlcs hun 8 deslgnated gcneratlng unit 'Long-term" means five years or longer. The availability and reliabllty of sarvke, 8dde fmm h n r m h s h constnlnts, must match Ihe availabllity and reliablbty of Ihhe deslgnated unit.
IU -lor intermediate-term rtdw frvm a tkslgnakd generating unit, The same as LU senrice expect that lintermedlate-tern" means Ionger than one year bul kss Um h a yean.
EX - For exchanges of eltctrkjty. Use this alewry for transactions Invoklng a balandng of debits and credits for energy, mpaeity, elc. and any aettlementr for Lmbabnced exchanges.
OS -for other servlce. U r s this categwy bnly for those services whlch eannot be placed In the abwdefined otegcries, such as all non-firm swvice regardless of the LmgVl of the mntract and service fmm desfgnated unils of Less than one year. Desdbe the nature of the service In a fodnols fw tach mdptmtnl.
6
Name or Company or RtbPc h - w m y (Footnola Mdhtrons)
CW Water L Q h t
CGWY ~ Cross Oil (2) 10s ,East Texas Eledrle Coopanttvs (os 'North ma Rock Electric DeDt 10s ~
LHUe Rock Wastewaler os Oswota OS IPlne Bluff Energy (2) os Poffatch Forest os West Mamphls OS
West F m e r OS
AVamgS Aduat Demand (Mw) Monthly Billin veraga verage
Tariff Number 1 Demand (d Man$ NCP Darnand Month CP mman FEkC Rate
ScheduIs or
0 tUA NIA Wl
47 MA NIA w NIA NIA NI,
123 NIA WA NA 01 WA . NIA Nli
NIA NfA NIi
. . . .--_ 123 NIA NfA NI,
NIA NIA
FERC FORM NO. 1 (EO. 42-90) Page 326.1
nIergy Arkansas, hc
8,624.a~a
D -for wl-of-perlod adjustment, Use this wda for any accounting adjustments or 'tntwps* for service provided In prior reporting aan. Provfde an explanatIoon In a footnote for each adjustment,
. In cnlumn (c), Identify ?he FERC Rate Schedule Number o r T d f , or, fornon-FfRCjurisdi~onaI sellers, Indude an appmprlata eslgnation for the contra& On eeparale fines, list all FERC rate schedules, tariffs at conkad deslgnations under which sewlca, as lentified In column (b), Is provided. . For requirements RQ purchases and any type of sewlee Involving demand charges Imposed on a monnthly (or longer) bash, enter re monthly average bllllng demand In column (d), ihe average monthly non-crrhcldent peak (NCP) demand h column (e), and the verage monthly cojneiden! peak {CP) demand In d u m n (0. For all othertypes of service. enter NA In dumna (4, (e) and (9. Monthly ICP demand Is the mm-murn metered hourly (6Omhule Intec@on) demand In a month. Monthly CP demand Is the metered demand un'ng the hour (6O-rnlnufe Integration) In wfijch the supplier's aystem reaches Hs monthly peak. Demand reporled In columns (e} end (f) lust be In megawatts. Footnote any demand not stated on a megawatt bask and explaln. , Report h column (g) the megawatthours shown on bllls rendered to the respondent. Report In w!urnns (h) and (i) the megawaHhours f p e r exchanges recehred and delivered, used as the bask for settlement. Do not report net exchange. : Report demand charges In column 0, energy charges In column (k), and the total of any other types of charges, Including ut-of-period adjustments, In column 0). Explain In a footnote all components of the amount shown In wlumn 0. Reprt in column (m) i e total charge shown on bills receIved as settlement by the respondent. For powerexchanges, report In wiumn (m) the aeltlement mount for the net receipt of energy. If mora energy was delivered than recehred, enter a negattve amount. If the settiemen! amount (r) ?dude aedds or charges other than Incremental generatlan expenses, or (2) exdudes certain credits or charges covered by !he greement, provide an explanatory footnote. The data In column {g} through (m) must be loblled on the last line of the schedule. The total amount In mbmn [SI must be
eported 8s Purchases on Page 401, llne I O . The total amount In wlomn (h) must be repried as Exchange Received on Page 401, ne 12. The total amount In co!umn (i) must be reporled as Exchange Delivered on Page 401, fine 33. 1. Foolnote entries as required and pmvlde explanallons fotlowhg all requIted dab. .
323,443 225,052 255,833,984 229,639.541 -?2,349,351 473,324,174
'ERC FORM NO. I (ED, t2-90) Page 327.1
Name of Respondent This Report is: Date of Report (Mo, Da, Yr) (I 1 2( An Original .
bchedule Page: 326 Une No.: 2 Column: a I Represents charges from other member companies of the Entergy S y s t e m under an interconnect ion agreement and contract, wherein the par t i e s have combined t h e i r power sources and transmission facil it ies for maximum overall capacity, reliability, and economy.
~chedulfi Page: 328 Une No.: 3 Column: a I Energy and capacity charges from Grand Gulf Nuclear Power Plant,
bchedule Page: 326 U n e No.: 3 Column: I 1 Represents ($6,235,635) for deferral on ovezhnder recovery under the Grand Gulf Rider and the turnaround of the Grand Gulf Accelerated Recovery Tariff approved by the FERC that provided for the acceleratlon of Entergy Arkansas be ' s and Entexgy Mississippi Xnc's Grand Gulf purchased power obligations with System Energy ResourcesI Inc. and ($5,938,242) r e l a t e d t o GGART.
~Chedule Page: 326 Une No.: 4 Column: 8 I Purchase of entitlement energy i n excess of co-owner requirements in accordance with the respective Purchased Power Agreements.
bcbedrrie Page: 328 Une No.: 5 Column: a 1 (1) Generator Load Imbalance made pursuant t o the Open Access Transmission Tariff (OATT).
FcheduIe Page: 326 Une NU.: 7 column: 3 1
YearlPerbd of Report
JOINT ACCOUNT PURCHASES ARKANSAS ELECTRIC COO'P CORP ASSOCIATED ELECTRIC COOP XNC AEP SERVICE CORP BOARD OF PUBLIC UTILITIES 'CALPTNE ENERGY SERVICES CARGXLL ENG CAG CITY UTILITXES OF SPRINGFIELD CITY WATER & LIGHT CLARKSDALE CLECO CONUCO PHILLIPS COMPANY CONSTELLATION ENERGY EMPIRE DISTRICT ELECTRIC COMFANY EXELON GENERATION COMPANY GRAND RZVER DAM AUTHORITY INDEPENDENCE POWER AND LIGHT KANSAS CITY POWER & LIGHT LAFAYETTE ENERGY LOUISIANA ENERGY AND POWER AUTHORITY MAGNET COVE ENEKGY MERRILL LYNCH COMMODITIES XNC NEBRASKA PUBILC POWER DISTRICT ENERGY NRG POWER MARKETING OCCIDENTAL POWER SERVICES INC UKLAHOHA GAS & ELECTRTC OMAHA PUBLIC POWER DTSTRCIT ENERGY
CHARGES MWH $82,228 1,361
1,601; 799
504
4,677,612 360
4,000
1 9 7 , g w
14,238
It 765 I
6,209 9,265
696 162,138
I, 559 124
303,990 76 106
20,736 111947,696
2, 588 26,978,309
866# 633 4,039 21 001
42,260 I16
8 5,371
ll0,410 9
274 1
37 124
16 4,153
16 2
4,397 1 2
747 476,421
4 6 604,615 24,515
1 0 4 4 1
i i a
IFERC FOAM NU. f (ED. 12-81) *I Page 326327 Foofnote.1
Name of Respondent
Entergy Arkansas, In&
This RepoFt Is: (I An Odginal (2) - A Resubmlsslon
1 FOOTNOTE DATA I
Date of Report YearlPeriod of Report (Mo, Da, Yr)
/ I 2 ~ 1 3 1 ~ 4
RAINBOW ENERGY MARKETING C O W SOUTH MISSISSIPPI ELECTRIC POWER ASSOC SOUTHERN COMPAHY SERVICES INC SOUTHWEST POWER POOL SOUTHWESTERN POWER ADMINISTRATION SOUTHWESTERN PUBLIC SERVICE SUNFLOWER ELECTRIC POWER CORPORATION TENASKA POWER SERVICES CO TENNESSEE VALLEY AUTHORITY UNION ELECTRIC UNION POWER PARTNERS WESTAR ENERGY INC WESTERN AREA POWER ADMXNSTRATX WESTERN FARHERS ELEC CORP WRIGHTSVILLE POWER JOINT ACCOUNT PURCHASES
Total System Purchases From Others (a)
97 9 636,017 324,565
14,234 97 4
3 , 4 8 3 a 57
i r 278,318 62,893
4,715,622 14r 446,366
3r 6 4 1 I* 218
15,550 6,813
151, 244
50 8,426 5,176 I, 361
19 91 15
29,696 3,, 158 159 , 251
4,421 87 20 541 147
375, 831.
(alIncludes purchases made pursuant to the Generator Imbalance Agreement (GfA) for over delivery of energy.
bchedule Page: 326 LIne No.: 8 Column: k I
M I S O MISO MISO MISO MISO
Ancillary Congestion Energy Purchases Losses Uplift
Total Energy Purchases From MISO
behedule Page: 326 Une No.: 8 Column: I 1
MISO Sch 24 Admin CHARGES $24,526
bchedule Page: 326.f Llne No.: 5 Column: c I (2) ** FERC rate schedules are c l a s s i f i e d as special contract PPA's.
1 FERC FORM NO. 4 (ED. 12-87) 1 Page 326327 Footnote2
(Including transacttons referred to 8s Weeling') :. Report all transmission of electricity, Le., wheelng, provided for other electric ulillties, cooperatives, alher public aulhodges, IualiQIng fadliaes, non-traditional utility suppliers and ultimate custwnets for !he quarter. !. Use a separate line of data for each distinct type of tmnsmlsston service lnvdving the entitles fisted in coIurnn (a), @) and (c). 1. Report In column (a) the company or public authority that paid for the transmlsslon sed-. Report In column @) the company or iubllc authorfly that the energywas recelved from and In column (c) tha company or public authority that he energy was deliwered to. 'mvlde the full name of each mmpany or publtc aulhority. Do not abbreviate or truncate name or us% acronyms. bplaln In a fwtnote m y ownership Interest in or afiliatton the respondent has with the enlitles listed In columns (a), @) DT {c) 1. In column (d) enter a Statistical Classifidon code based on #e original: contractual t e r n and conditions of the s e w b as follows: 'NO - Firm Network S e w h for Others, FNS - Firm Network Transmission Sewice for Self, LFP - 'Long-Term FIm Point to Point rransmIsslon Service, O W - Other Long-Tern Ffrm TransmIsslon Service, SFP - Short-Term F~rm Point io PoinlTransrnlssion 3eservalion, NE - non-firm hnsrnission GBM'CB, OS - Other TransmIsslon Senrice and AD - Ovt-of-Period Adjustments. Use this d a or any accounting adjustments or ' t n r ~ p s " for service provided in prior repurling pertods. Pmlde an explanation In a footnote for :ach adjustment See General Instrudon for definitjons of codes.
3 4 5 6 7 8
9
10 11 12 13
Payment By Enargy Recehed Fmm Energy Delivered To Statlstlcal (Company of PublIc Aulhorky) (Company of Publle Authority} (Company of Publlc Aulhorfty) Class& Ine
NO. (Footnote Aftillation) (Footnote AfmlaUon) (Footnofa Amrialion) d o n IC)
h r e n Energy Markettng Peotoa I Amethn Electk P o w t (1) Arkansas Eledrlc Coopenhe Cow. (12) Assodated EleelrIc Cmparatlva, [ne. os M S F Corporabon (2)
H w o s Electtlc Power Coop~atrve, Inc, (1,Z) 1 Buffalo Dunes Wlnd
OS
os
Calpjns Energy SeMws. LP os CargiIEAntant, U C OS
Carthage Waler and Electric Pbnt Centrat Loulslana EbdrlcComnanv tt.21 os
If?
t
14
15 i 0
17 i s III
I
ChIsholrn Vlew Wind Cn Carbon. U C (2)
CQoC Benton (1)
CihrnlHnnu f f P
CItlgmup Energy Inc. os
cw or cam11 (t)
20 21 22 23 24 25
Cl!y or Independence P a t os City or Ktrbyville (1)
Clty of Newlon ( I ) Chy ol lhceola (1) t CItY or Presartt (1)
City of Maldsn Board of Public Works t LFP
City Wabr & Llght Conom, lnc Conslattauon Power Swm c m y CPrporatIon (i] Dow CharnIcaI Company (2) Eagle US (2)
1 U P OS
OS
t
TOTAL I 1 I t
Earl Texas Electric Cooperative (L2)
FERC F O W NO. 1 (ED. 72-90) Page 328
LFP
Entergy Arkansas, Ine.
~ e h e d u t of Tariff Number
(e) SIA
. . . . -I r I
b n s I tY mffered F O r n t H S ta 85 G v L g Ac wu$QSFnc; 1 onhnued)
j, In column (e), Identify the FERC Rate Schedule or Tariff Number, On separafa fines, list all FERC rate schedules or conkad jedgnations ucderwhlch seruke, 8s ldenhfied In 4 u m n (a), is pmvlded. 3. Report redp t and delivery bmttons for a!! Angle conkad path, 'poht lo pdnr transmlsJon servlce. In column (0, report the 5eslgnatIon for the substation, or other appropriate identifieation for where energy was reeded as specified In the wntract. In column [g) report the deslgnatlon for the substation, or other apprnpriale tdentification for where energy was delivered as spedfied In he mntract. 7. Repart In column (h) the number of megawatts of billing demand that Is specilied In the fim transmissh se&e contract Demand reported In column (h) must be fn megmatts. Footnole any demand not stated on a megawatts bash and explaln. E. Report In column (i) and 0 the total megawatthours received and deliverd.
.
U l l U . . .. . -. -. . - . . . . . . .
MegaWatt Houn Megawatt H a m No.
1
(Subsatatton or h e r (Subst& O r d e r Demand Deslgnatron) Destgnathn) mw ReeaIvad DeInrered
0) - (0 (Ql m 0 )
FERCRate I Polnt of Remiat I Pohl ol Qefrvew 1 Ellha I TRANSFER OF ENERGY 1 I*-.
.. -. I OATT I 1 I I I 1:
1
OAIT 11 0A-l-f (3) (3) 17,453 -16.929 I ! OATT I31 (3) 8 a 21
OAIT 1 t 2
1
OAIT 11 0A-l-f (3) (3) 17,453 -16.929 I ! OATT I31 (3) 8 a 21
OAIT 1 t 2 I
OAIT PI (3) 0,727 8,464 z OAIT I 2:
I 1 1 1 1 1
OAl7 I I I I 1
FERC FORM NO. 1 (ED. t2-90} Pago 329
Fnhrgy Arkansas, t n c
-8
3.537 1,024,349
761 .SO8 278,685
I x ~n ungmai I :;; w A ResubmksIan
222,235 222,255 : - a !
135,829 139.366 4
17,sn 1,041,926 !
3,040,293 I
. . T m OF t L Accou9t 456) (C onbnued)
I
(Inchding m k e u h n g )
I - .
2,086 2,086
. In column (k) through (n], report the wvenue amounts as shown on hilts or vouchers. In eohrnn (It}, provide revenues from demand harges related 'to the billing demand reported In column (h). In column [I), prodde revenues hrn energy charges relaIed to the mount of energy transferred. In column (m)* pmvlde the total revenues from all other charges on bills or vouchers rendered, lnduding tvt of period sdjustments. Explain fn B loafnote all wmponents of the amount shown In column (m). Report In column (0) the totd harp shown on bills rendered to tha entity Listed In column (a). If no monetary settlement was'mada, enter rem (1101 1) In column n). Prwide B footnote explalntng the nature of the nonmonetary settlement, Including the amount and type of energy or servlce endered. 0. fhe total amounts h cuIumns (i) and 0 must be reported as Transmissbn Received and Transmlsdon Delivered for annual report iurposes only an Page 401, Unes 16 and 17, respecheiy. I. Footnote entries and provlde exphnations following all required d a h
*
REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS Demand Chatgos Energy Charges (Other Charges) Total Revenues (S) Ltno
No. I
85.626
394.926 362,m 757,699 1
65,626 !
831,903
3,520 3,520 11 151.390 983.353 1
I I
32,570 1,851 34,421
56,566 2,360.074 2,418,640 -1 2 f 0 -1.270
1: 1: 1*
1 I I I
I I 231,7851 231,7851 I'
8.065
r I
50.280 50,2811 1,
35,945 . 35,945 I' 2E 28 2
18,834 18,934 2
18.094 1.239 19.333 2
1 I
2.104 2.1041 1.
s.oS5l 11
I r 1 I
I t 21,4411 21,4411 2
FERC FORM NO. I {ED. 32-90] Pag8 530
Enlergy Arkansas, Inc
Payineni BY (Company of Publt Authorfty)
(Footnote Affilation) (a)
Une NO.
- - - S [xwSkk-,lnk? t s Account456.1)
1. Report all transrnlsslon of eleciddty, Le., heeling, provided for other electric utiIitIes, cooperatives, ather publlc authorities, qualifyhg facilitles, non-traditional ulility aupplien and ultimate customers for the quarter. 2. Use a'sepamte h e of data for each dislinct type of transmksion servlce lnvdving the enfrlies listed In wlumn (a), (b) and (c). 3. Repmt In mlumn (a) the ampany or public suthority hat paid for the transmission senrice. Report in eolumn (b) the company or public authority that the energy was received hum and in column (c) the company or public authority that Ula energy was delivered to. Pmvlde !ha fun name of each company or publlc 8Ulh01ity. Do not abbreviate or truncate name or use acronyms. Expraln fn a foolnole any ownership Interest In or afiliallon the respondent has with the entibes listed In columns {a), (b) or (c) 4. In column (d) enter 8 Statistical Classifidon mode based on the original contractual terms and conddons of the sedc-e as lollows: FNO - Firm Network Sewlce for Ohhers, FNS - firm Network Transmission Senrlce for Self, LFP - 'Long-Term Ern Point to Polnt Transmission Serulce, OLF- Other Long-TEfTrI Firm Tmnsmissbn S e M m SFP - Short-Term Flrm Point to Point Tramrnissbn Resewatlon, NF - nonfirm ImnsmlssIon senrlce, OS - Other Transmlssion Service and AD - Outsf-Period Adjustments. Use thls code far any accounting adjustmenls or "true-ups" for sewlce provfded in prior reporting pedods. Pmvlde an explanation In B footnote for each adjustment. See General Instruclion for definbns of codes.
. -. - - - . . . - - .. .- . . - . . . . . . . . Emqy Racatved From Enorgy Oslhrered To Stahrllal
(Footnote Aflillatlon) (Footnote AfEllaBon) catlon (Company of Public Auvlonty) (Company of Public Authority) ClassM
m) IC1 td)
ETC Endure Ensrgy U C M Marketing. L M (1) Exelon Generation Co 5 z o n Mobit Oil Corporation (2) Formosa Flastlu Corporation (2) Georgla Gulf Corporabon (2) IGrand Rlvar Dam Authontv
. . . . . . I I
1 1 EDFTrading North Amerlca, LLC I I 10s
OS
os os
os
2 1 Emolra Dcltrld EledrIc Ca. I I 10s
34 Pvre BtufTEnargy(2)
TOTAL I
I 10 I Hunbman Corporallon E) I I I - - . . . . -.
I 11 tJ.Amn & Company I I I 12 JP Morgan Venturns Energy 13 Kansas Clty Board of Public Utlldlsi 14 Kansas Ctty P m r f L!ght 15 Kansas Enemy U C I
OS os
5. In mlumn {e). Identify !be FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which servlce, as Identified In column (d), Is provlded. 6. ReportreceIpt and delivery locahns for all single contract path, 'point to p i n r transmisdon sedce. In column (0. reporl the deslgnation for the substation, or other appmpdats Identification for where energy was rer;ehed as specified In the wnb-ad In mhnn (g) report U I ~ deslgnatlon for lhhe substatlon. or other appropiate IdentificaUon forwhere energy was delivered as specified In the contract. 7. Report In coturnn (h) the number of megawatls of bitling demand that Is specified In the firm fransmlssh semIce contract. Demand repded In column (h) must be In megawaKs. Footnote any demand not stated on a megawatts bash and explain. I8. Reprt in wlurnn (i) end (j) the lob1 megawatthours received and delhred.
0 8,220,096 6,033,493
Endof 2013M4
9. In column &I fhrough (nl, report h e revenue amounts as shown on bills or vouchers. In column fil, Drovide revenues from demand
Demand Charges ($1 01
359,490
charges related to thekllhg demand reported in column (h). In column (I), provide revenues from ene& charges related to he amount of energy transferred. tn column (m), pmvlde h e total revenues tiam all olher charges on bltts or vouchers rendered, Including wt of period adjustments. Expldn in a footnote all mmponents ofthe amount shown In column (m). Report In column (n) the fotaI charge shown on bills rendered lo the entlly Usted In column (a). If no monetary settlement was made, enfer zero (1 101 1) In column (n). Provide B fwtnota exphlnlng the nature of the non-monetary settlement, including the arnounk and type of energy or sewice rendered. 10. The total amounts In cdumns (i) and (J) must be reported as Tmnsrnlssion Received and Transmtsslon Delivered for annual report purposes only on Page 401, Lines 16 and 11. Footnote entries and provide explanations foltowlng all requfred data.
respediuely.
Energy Charges (Other Charges) Total Revenues ($) Line ($1 (5) (k+I+m) NO. (1) (m) (nl
19,970 19.970 21,557 381.W7 6.684 6.6M :
287,249 2,736
1.922
352.498 639,747 A
2,738 !
0,573 8.573 I
2.086 2,068 '
2.1 04 z104 1
1,922 ' 2,086
-1911
. .
8,953,851 &472,i39 18,l87,69D 33,6¶3,480
2,088 11 -191 1
FERC FORM NO. I (ED. t2-90) * Page 330.1
-29
505
I
-291 1: and 1
intergy Arkansas, he,
1 ne No.
1 2 3 4 5 0
7
I
1
P a v n t By Energy Rwhred From Energy Deltverd To StattStlrnl (Company ol PubIic Avthortty} (Company of Publlc Authority) (Company of Publlc Avlhoriiy) Classifi-
(a Ibl (el (d) (Footnote Mdutron) (Foolnpta ARnIatbn) (Footnote Affilfatlon) c a m
Plum Point Energy hsocalcr os Poplar Bluff Munrdprl os Ralnbm Energy Marketing Coq
RS Cogen, U C (2) Rurht(1) SaMne Copan. Lp (2)
Shell Chemlul. LP m
I, Report all transrnisslon of electricity, Le., wheeling, provided for other eledn'e dlitles, cmoperathres, other public authoritks!s, lualifyhg facitities, non-traditional u l t i soppllers and ultimate customers for the quarter. L Use a separate llne of data for each distinet type of transmisslon service Involving the entitles listed In dumn (a)l (b) and (c}. !. Report In column (a) !he company OF pubic authority that paid for the hnsmission sewice. Report In column (b) the company or iubllc authority that the energy was received from and In column (e) the company or public authorily hat the energy was deIivered to. VovId8 the full name of each company or public aulhority. Do not abbrevlate or truncale name or use acronyms. Expfaln In a footnote m y ownership Interest In or afKliaIbn the respondent has with #e enlttres listed In columns (a)* @) or (c) I, In coIumn (d) enter a SLatisticaI Ciassificalion code based on the odglnal contradual terns and conditions of !he sed= as follows: :NO - Firm Nehvork Service for Others, FNS -Finn Network Transmission Servlce fur Self, LFP - 'Long-Term arm Point to Poht rransmisdon ServIce, OW - Olher Long-Tern Firm Transmisslon Senrle, SFP - Short-Term Rmr Polnl to Point TransmIssIon qesentation, NF - nonfinn transmlsslon senrice, OS - Other Transmission Sewice and AD - OutsPPedod Adjushenfs, Use thls d e 'or any accounting adjustments or "true-ups9 for senrice pmIded In ptior reporting pehds. ProvIda an expIanaIIon In B footnota for sach adjustment. See General Instruetion for definkons of codes.
Unlon Pawsr Parlnsn. LP Vlnlon Publlc Pdwsr Authorrty (1)
Weslar Ensrgy Western Fermen Eledrlc
os
os os '
f 0
Wdghtsvllle Powor (2)
ENTERGYEMO Oklahoma Energy Resourcts. tnc
MIS0
~-
Southam Cmprny slrvlas . Inc LFP Southwestern E l a m coop LFP Soulhwestam Pmer-mtsn Soultwostam Publi Scrvra Co os SRW Cngensmtlon. LP (2)
Suer Energy M a h e w Tcnaska P m r S m k t s -my (1.2) os TennesseeVahyhiUmty (1) OS Tha Enam Author#. Inc os
os OS
Vadous Vadous
19 20 -
21 22 23 24 25
26 -
TOTAL
FEERC FORM NO. I (ED. 32-90) Page 3283
5. In column (e), Identifir the FERC Rate Schedule or Tariff Number, On separate lines, lis! all FERC rale schedules M eontract designations underwhkh service, as identified kr column (d), 1s prodded. 6. Repd receipt m d delivery lowlions for all single conbad path, 'polnt to pdnr transmission service. In column (0, report the dedgnation for the substatton, or other apprapriah Identification for where energy was received as specified In the contract. In column (g) report the designation for the subdation, or other appropiate idenlifmth far where energy was delivered as specified In the wntrad 7. Report in mhmn (h) the number of megawatls of billing demand that Is speciFied In the firm transmisston senrIce con!raet Demand reported In column (h) must be In megawatts. Footncte any demand not stated on 8 megawatts hasls and explain. 8. Report In column (i) and 67 the lotal megawatthours recelved and deltvered.
OAIT O A T
GIA OAYT
OATT
Une FERC Rate Polnt ot Recaipt Poht of Delrvary Billing Schedule of (Subsatatlon or Mher (Subrlalton or Other Demand Megawatt Houn Megawatt Houn No.
TRANSER OF EN€RGY
Tarlff Number Deslgnetron) Deslgnathn) (W Received Delhrered (el (0 (a m1 01 0)
OATT 81,568 59,721
8,034 1 . 62,300 60,431 1
1 . 252,709 245.127 1
2
(3) [5) 8,263
(3) (3)
(3) (3)
I
GtA QATT I I
GIA . .
2
(31 (3) 35,430 34.076 2 (3) IrJ, 858 a33 2
Various 1Vadous 2
ERC FORM NO. I (ED. iz-ga) Paue 3233
~~ ~~~~
9. In column (k) through (n), report the revenue amounts as Shawn on bills orvowhers. In column (k), provide revenue^ from demand ’
charges related to the billing demand repoded in column 0). In cofumn (1)’ provide revenues from enemy charges related Io the amount of energy transferred. In colmn (m), prwlda tfie iota1 revenues fmm all other charges on bills or vouchers rendered. lnduding out of period adjustments. Explain In a footnote all components of the amount shown In column {m). Report in column (n) the total charge shown on bills rendered ta the entity Usted In column (a). If MI monetary settlementwas made, enter zeta ( i l O 1 1 ) in column (n). Provide a footnote explaining the nabre of the nomonetary settlement, lnduding the amount and type oF energy or sed- rendered. 10. The total amounts In columns cr) and CI) must be ceporled as Tmnsmission Re&d and TransmIssh Delivered for annual repad purposes only on Page 401, Unes 16 and 17, respediiely. 1 I. Foohote entn’es and prwlde explanatrons folIawIng all required dala.
R M N U E FROM TRANSMISSION OF ELECTRlCrrY FOR OTHERS Total Revenues Q)
In1
Oemand Charges Enargy Charges ’ (Other Charges) . (k+l+m) ($1 fml
($1 (I\
($1 tk)
R M N U E FROM TRANSMISSION OF ELECTRlCrrY FOR OTHERS Total Revenues Q) Oemand Charges Enargy Charges ’ (Other Charges)
($1 ($1 . ($1 (k+l+m) (k) (1) m) (n)
33,tif 3,480 I
FERC FORM NO. 1 (ED. 12-90) Fags 3302
Name of Respondent This Report IS: Date of Report (Mo, Da, Yr) (1) XAn Original
Entsrgy Arkansas. Inc (2) --A Resubmission I I
bchedde Page: 328 t h e Nu.: f Column: a I (2) Other charges include annual billing fees, t a r i f f penal t ies , and prior period adjustments fo r the Generator Imbalance Agreement (GIAI . pcheduh Page: 328 Une No.: 2 Column: B 1 (I.] Other charges include network transmission aremice revenue as w e l l as an ancillary service charges related to the Open Access Transmission Tariff (OATTI. kchedule Page: 328 LIne No.: 2 Column: m I
YearlPeriod of Report
20131Q4
Other Charges
customer Ameren Energy Ine. American Electric Power Brazos Electric Power Coop, Inc Central Louisiana E l e c Company City of Bentan City of Caldwell C i t y of Kirbyville city of Newton C i ty Of Osceola C i t y of Prescott City of West Memphis Conuay Corporation East Texas Electric Cooperative EWO Marketing, LLC Louisiana Energy & Pawer Ruth Louisiana Generating, LLC Miss Delta Energy Agency (a) Missouri Joint Mun EUC - Thayer North Little Rock Elec Dept Ruston Tennessee Valley Authority Vinton Publ i c Power Authority
Custom@ r C i t y of Caldwell City of Kirbyville C i t y of Newton En0 Marketing, LLC Miss Delta Energy Rgency {a) Missouri Joint Mun EUC - Thayer Vinton Public Power Authority
Other
Total Other Charges
{a) Includes $14,700 in Other
Scheduling Network
Transmission Revenue $210,578 128,614 345, BO4
2 p 24 9r 001 220,861
45,029 16, 976 19,284
n e , 028
2ag8 242 53,516
717, 310 I, 622, 214
314,862 450, 075
7*533,414 214,687 33,465
743r 263 216,680 82,911'
I, 430, 322
$17,036,636
Regulation 6 !+equenc y Response
$700 261 293.
4,863 2,587 199
20,972
----------- nm-----s---
System Contxol&
$6,014 Dispatch
3,717 8,741
57,210 5,627
4 60 499
3# 542 1,750 E I , O ~ B
20r 640 4Zr224 9,153 12,774 190,374
5,876 396
19, 901 S I 549 2, 189 55,910
$4 614 825
I8 231
m - 1 - 1 1 - 1
C L R C I . I I I
RTO 6 XCT Operations
Reeov $5,663
3 8 4 9 8 8,228
53,863 5, 297 I, 159
433 4 69
3,331 1,649 7,577
19,437 39,762
8,619 11,956
179,247 5,531
373 16,736
5,223
52,861. 2,061
Totel $222,255 135, a29 362, 773
2,360,074 231,785
47,419 17t869 20,252
124,907 56, 915
304,867 757,387
1,704,200 332,634 474,805
7, 903,035 226,094
14,734 781,900 227 , 452
871161 I , 53g1 093
Spinning Supplemental Reserve Reserve
$ i , o e 3 $1,078 4 03 401 450 4 4 8
7,518 78 483 4,000 3,981
32# 424 32,275 307 306
---111- c1---3-
$46,165 $45,972 -lllll 11-1-19
Total $2*861
1,065 I, 184
19,864 10,568
8 12 85,671
$122,030
132, 220
$18,107; 690
----_------
-"llllllll
pchedule Page: 328 Une No,: 4 Column: f I ( 3 ) Multiple points of del ivery and recciat under the Open Access Transmission T a r i f f (OATTJ; therefore; specific points of &livery and r e c e i p t can not be reported.
IFERG FORM NO. 1 (ED. 12-87) I Page 32&330 Foutnote.1
Entergy Arkansas, lnc. TRANSL
I S I
E n d d *01m4 (1) mA" Onglnal (MO, ua. Tr)
ISSION OF ELECTRETTY BY OTHERS (AecDunt 565) (2) n A R'esubmlsslon I t
TRANSEER OF ENERGY1 EXPENSES FORTRANSMlSSION OF ELECTRfClTY BY OWEF
249392
I I 48.675 I I I 48.67 I
24339
250.597
10,764
250.55
10.71
t 463,151 1 463,l:
FERC FORM NO, 1 M (REV. 0244)
I 497.910
1,520,489
Page 332
I 497.91
1320,48
Name of Respondent This Report Is: (1) XAn Original
Enlergyhkansas. tnc. (2) - A Resubrnlsslon
Bcheduh Page: 332 Une No.: f Column: a I The agreement between Entergy Arkansas, Inc, and Arkansas Electric Cooperative Corpora t ion was amended in February 1995. Eased on the new agreement, Entergy Arkansas, Ine. pays a monthly demand charge f o r the use of the wheeling services.
Date of Report YearlPeriod of Report (Mo, Da, Yr)
I 1 2013Q4
bchedule Paqe: 332 Une No,: 4 Calumn: a I These expenses represent the charges incurred from a third party for t h e u t i l i z a t i o n o f theix transmission system by Entergy Arkansas, fnc. associated with either a sale of bulk power t o an external company or a purchase of bulk power from an external company.
These transmission expenses are
bchedule Page: 332 Line No.: 7 Column: P I Respondent delivers energy to Water Valley, Arkansas, and SPA wheels energy to Respondent's customers at Ash F l a t , Arkansas,
bcheduie Page: 332 LIne No.: 9 Column: a I These expenses represent the charges incurred from a third party for the utilization of t h e i r transmission system by Entergy Arkansas, Ine, assoc iated with either a sale of Bulk power to an external company or a purchase of bulk power from an external company.
BcheduIs Page: 332 Une No.: f2 Column: a I These expenses represent the charges incurred from a third party for t h e utilization of their transmission system by Entergy Arkansas, Xne. These transmission expenses are associated with either a sale of bulk power to an external company or a purchase of bulk power from an external company.
These transmission expenses are
- pchedrrle Page: 332 LIne No.: 15 Column: a 1 These expenses represent t h e charges incurred from a third party f o r the u t i l i z a t i o n of their transmission system by Entergy Arkansas, Inc. associated wit.h either a sale o f bulk power to an external company 0r.a purchase of bulk power from an external company.
These transmission expenses are
IFERG FORM NO. I (ED. 92-87)
Page 332 Footnote.t
BLANK PAGE
I tntsrgy mansas, me.
14 1.5
16 17 t8
1 Endal 2013/Q4 \ 1, u ,v 1 w1 r y l l r u l ,'.". "U. 1 4 ,
(2) n A Resubdsshn I t tntsrgy mansas, me.
bne I Descnptron 1 Amount MISCEUANEOUS GENERAL EXPENSES {Account 930.2) {ELECTRIC)
~ ~~
~ommuntfy mlZons 15.418 Purchasing and contram support 300,249
Trans#, lmpfementatlon 19,454 lce Storm secuntkauon amrttratlon 20,728 Other -67.132
I
Ibne I
25 26
1 Endal 2013/Q4 \ 1, u ,v 1 w1 r y l l r u l ,'.". "U. 1 4 ,
(2) n A Resubdsshn I t MISCEUANEOUS GENERAL EXPENSES {Account 930.2) {ELECTRIC)
Descnptron 1 Amount
~ _ _
I
1 13 I Public relations expense I 0,4401
44 45
48 TOTAL 523,186
19 1 20
21 22
I 29 I 30 3t
I 35 I
~
39 40
FERC FORM NO. 1 (ED. 12-94) Paga 335
1 - . .
Entergy Arkansas, Inc
11
I 2
1 . , , I
DEPRECIATION AND AMORTEATION OF ELECTRIC PLANT (Account 403,404,405) (Except amorMzatlnn of aqulsillon adjustments)
f . Report In section A for the year tha amounts for : (b) DepFeclaUon Expense (Accounl403; (c) Depredation Expense for Asset Retirement Costs (Accwnt403.1; (d) Amortiration of Umlled-Term El&'c PIant (Account 404); and (e) Amorttzatton of Other Electric PIant { h u n t 405). 2. Report In Sectlon 8 the rales used to compute amortization charges for eteddc plan! (Aecpunts 404 end 405). Stale the basis used to mmpute charges and whether m y changes have been made In the basis or fates used from the preceding report year. 3. Report at1 svallable Information called for In Sedbn C evetyfim year beginning with report year 1971, reporling annually only changes to columns (e) lhrough (g) from the complete report or h e preceding year. Unless cornpsife depredation accounting for total depredable plant 1s followed, Ist numerically In mlumn (a) ea& plant subaccount, amunt or functional dassifiation, as appmprtak, to whlch a rate Is applied. IdenfjFy at the bottom of Sedlon C Ihe type of plant included In any subaccount used. In coIumn (b) report all depredable plant balances lo which rates are applied showing subtotals by functional Clasdfmtlons and shwlng composite total. Indicate at the bottom or section C the manner In whfcb column balances are obtained. If average balances, slate the method or avemghg used. For columns {e), (d), and (e} report available Infomatlon for each plant subaccount. accounl or functional dassifidon Usled fn column {a). If plant mortality studies are prepared to asslst In estimating werage servke Lhes, shw In eoltrmn (9 the type mortality cuwei sdected as most appropriate for the account and In column (g), if available, the welghted average remahing life of sunriving plant If composite depredation acccunflng Is used, report aveilab!e Informatloon calkd for In columns @) through (g) on Ihls bask 4. If provIsjons fordepredatjon were made dudng lhhe year In addithn to depdalton pmvlded by application of reported rates, state Bt the boflom of section C the amounts and nature of the provislons and the plant Hems to which relaled.
Common PIan!*Eleclrlc
TOTAL 212,094,281 -t01,9B0 l7,571,825 229,504.12
I A. Summaw of Demclallon and Amortrzatlon Charges 1
I I I Demctalton
I ' - . 2 Sham Prduction Plant 316,560,270 -159.774 18,400.49,
3 Nuclear Pmduetlon Plant * 53,645,959 53,645.9s
4 Hydmulk Produdion PIantConventlonal 574.609 -2,103 512,42
610Lhar Produdon Ptanl -24 I 15,855,80 I I t 71Transmkslon Plant 30.224.38d I 30,224,38
- 8 DIstrlbubon Plant 79,345,469 79.345,46
9 Keglonaf Tranmlsrlon and Markct Opsmtion 21,390 i,tag,a93 1,211J8
10 General Plant msss65l 1 15,866,38
8. Baals forAmorttzaUan Charger
FERC FORM NO. I {REV. 12-03] Pass 336
I intargy Arkansas, I n c
ma YO.
12
. - , UepfEClable t 5 1 una t e a Net APP'red MoMhty m e ra g e Aecount No Plant Base Avg. Servles SaIvage De r.rates Curve Re rn a ! n I n g
(In Thousands) Ma (Percent) rppClFent) T#a Ufe Ia) (b) (C) (d) (el 9)
Production Steam:
R3 I R3
15
16 17
lndependanea Common 11,006 l o a oo -1 7. w El
Independerne Und I 31 t 916 108 00 47.0 001 R3 Lake Calhsdne Common 1,932 108 00 4 0 00 R3
19
20
21
t 1.092 108 00 -34 00 0 02 23 lynch Unh t 31 1
24 Lynch UnR 3 31 1 2,052 toa ca -34 00 0 01 25 Rdcha Common 31 1 2,528 loa w -25 00 0.01
. . . . . . . .. .
lake Cathndns Unn 2 3 1.t3B I08 00 -40 00 oat ~3 Lake Catharim, Unlt 3 3 1.342 10800 40.00 002 R3 Laka Catherlna Unt 4 3 4.825 i 00.00 -io 00 002 R3
26 Rnchla Unt 1 31 1 108.00 -2500 0.03 27 WhRa Bluff Sknb Cant 34D I08 00 -18 00 0.01 28 Whlta Bluff Common 31 1 4 2 H 10000 -18 00 0.02
R3
R3
R3 I R3 R3 I R3 I
R3
R3 I
R3 I
46 While Bluff Una 2 31 2 130.674 75 OD -18 00 0.02 R3 47 Couch Common 3 14 51 75.00 3 2 00 0.18 K4 48 Couch Unit 2 314 5.516 75 00 -32 00 DO7 R4 49 lndopendenca Common as7 75 00 47.00 0.0
50 lndependew Unit 1 314 33,289 75.00 -17 011 0 0
FERC FORM NO. $ (REV. 1243) Page 337
akdCathadoe Una 3 3 006 R3 aka Catharine UnR 4 3 533 73q -40 00 004 R3 .yndr Common 31 6 78 73 00 -34 00 mi0 Fu .ynch Unit 1 316 124 73 00 -34 00 OM tu
-
FERC FORM NO. I (REV. 12-05) Page 337.1
1 i I OEPRECUSTION AND AMORTEATION OF ELECTRIC PLANT (Conbnuadl i
47
48
49
I C. Facton Used In Estimating Depmdallon Charges
~~
Remrnef Und 2 331 .f 74 109 01 Remrnel Unrt 3 331.1 n 109 ai
Carpenter Common 331.2 * 30 109.0
une mprecrable BtJmaled
NO. Account No. Plant Base Avg &dca (In Thousands) ltFa
{a) {b) (C)
12 Lynch UnL3 316 625 73.00
~
-5.00 -5 [x1
-5.00
73 00 2,968 73 MI
53 001 53 002 s3
29 AND Common 323 $652 58 M 30 AN0 Unit I 323 164,731 56M
31 ANU Una 2 323 368,347 56 QC 27.717 55 O[
I 33lANO Unlt 1 324 i 1 16.61 61 55 o[ ~ _ _ ~ ~
34 ANOUnR2324 126,740 55.M: 35 AN0 Common 325 119,330 57.0( 36 ANOUnH 1 325 77,998 57 M 37 AN0 Unrl2 325 34,320 57.m
38 TotaI P d u d o n Nudea 2Pa4.923 39
40
41 Camnter Common 330.2 267 75 01
109.01
109.01
I09 Ill 109.01
. . . 1 .
-2w 0.03 R1.5 -2 00 0.04 RI.5
-2 001 OIMR15 -2.00 003 R2 -2 Iw 0 0 2 R2 -2,OO 002 R2 -1.00 0.02 R2
-5 00 001 R3
-5 00 DO2 53 -5 00 53
-5 00 53
4.00 002 s3 -5.00 0011s3
002 53 LLu FERC FORM NO. 1 (REV. t2-03)
C. Facton Used In EstImattng Pepredallon Charges
21 IRsmmeI Unit 5 331.3 I ?09 001 -5 001 0 01 -. .. . . . .
22 Carpenter Common 3321 2,383 105 W -10 00 0.02 23 Carpenter Untt 1 332.1 1,356 105.00 -1aoo 0.01
24 Carpenter UnH 2 332.1 1,376 105 00 -10 00 0.0 1
25 Rtrnmsl Common 332.1 8.297' 105 00 0 a2
27 Rammil Unit 2 332.1 513 I05 00 -1 o.ool 0 01
26 Remmal UnR 1 332.1 513 105 00 -10.00~ 0 01
29 Remmal Cwnmdn 332.2 36 10500 -1 0.w 0 02
30 Carpenter C m m 332.3 40 105 00 .io00 0.02
31 Carpontor Cornmm 353 909 T I 0 0 4 5 00 0.Oi 32 Carpenter UnR 1 333 4 d l t 77 00 4 5 OD 0 Oi 33 Carpcnler Unit 2 333 5.499 ncQ -15.00 0 0:
35 R a m 1 ttnd 1 333 i 1,472 n.ao -15 00 0.0:
34 Remmal Common 333 899 n.00 -15.00 I] Oi
36 Remmel UnA 2 333 1.438 77 00 -1500 0.0:
37 Rarnm~l UnB 3 333 ' 131 77.W 1 5 0 0 0 01
38 Carpenler Comnen 3M 92 7300 -5.00 0.0:
33 CarpenkrUnrt 1 3H 116 73.00 -500 u 01 40 CarpenterUnlt 2 334 3031 73.K 6 001 0.01
42 R e k l UnB 1 3M 123 7.303 -5 00 0 0:
43 R a m e l Unlt 2 334 32 73 00 -5 00 0.0:
4-4 R a m 1 tlnk 3 334 32 7300 -500 00'
46 Carpenter Und 1 335 I 99 77.00 47 Carpenler Und 2 335.1 101 77.m 48 Remmel common 335.1 356 77-00 0 0:
49 Remmel Unit 1 335 1 14 n.oo 50 Remmel Unit 2 335 f 14 77.00
Remalnlng
I
i3
i3
;3 15
I
25
15
75
15
I I
I I
FERC FORM NO. 1 (REV. 42-03) Page 3373
I I I I I I
FERC FORM HO. 1 (REV. 12-03) Page 337A
49
50 DIslnbuUon Plant 360. 3.543 65 00 001 R4
FEFlC FORM NO. 1 (REV. 12-03] Page 337.5
FERC FORM NO. t (REV. 12-03) * P a w 337.6
FERC FORM HO. 1 (REV. 1243)
\Name of ResDondent \This Report Is: I Date of Report IYearlPenod of Report 1 . . . . . . .
Entergy Arkansas, Ine (1 1 xk Original (Mo, Da, Yr) (2) - A Resubmission I t 2013M4
1- FOOTNOTE DATA I
bchedule P a w 338 Une No.: 7 Column: d I Includes $11,237 of service company amortization b i l l i n g allocations.
bcheduie Page: 338 Une No.: I O Cohumn: b I Includes $7,065,531 of service company depreciation billing-allocations,
1 FERC FORM NO. I {ED. A2-87) I
I. Repod particulars (details) of regulatory wmmlssion expenses incurred during b e wrrent year (or Incuurred In previous years, if being amortized) relating to format cases before a regulatory body, or Mses In whlch such a body was a party. 2. Report in mlumns (b) and (c), only the atrent year's expenses hat are not deferred and the current yeah arnodzation of arnounls
Ltna DascrIpllon No. J Fmlsh name of regulatow commIsslon or body tfib
oclcst of cas8 number and 8 derdplton O f the case) tal
t FEDERAL ENERGY REGULATORY COMMISSlON
Assessed by Erpenser Regtilalory ' of
@I (el Commissbn utility
2
91 varlous 61hgs befoom FERC I I 7,67: ~~
101
Docket No. RM67-3400 I
* I I
11 I Docket No. 07-138-TF I I
~~
3 4
I 121 APSC wnsuhantfees Incumd h federal I 1
Annual Charges 1 ,O20,5OB
I 1 1
131 casea I I 587.87,
5 Docket Nos. ER07-682000 t ER07-95WOI 6 I SWem Agreement Remedy Tmk It Schedule 15.w
._
1 l g h R W S A S PUBUC SERVICE COMMlSSlON I 1
I
14 15 16 17
~~ ~~
DockttNo 09QB4-u 2009 W Rats Cars (42 month arno&allon perlod) 529.93
20 21
Docket No. t2-03B-U t Wholasale Baseload CaoactM L Camertv
1 I
30 I €A! Energy Eficlancy . ! I 3936
~~
22 23 24 25
27 - 26
. .- ~
Cost Recovery Rtdar 5.55
Docket No. 1245BU Act 310 Flling 5,83
Docket No. 12-09W 1
2 B f . Eh! RlderAFCRG FIllng 29 I
391 Expanses Incurred h connedon wtth varhous I I 401 fillnos bsfom the APSC and FERC 767,37
6.64
31 32 33
Total Expense for In Account Current Year t82 3 a] Bsglnning u Year
I Docket No. 13428-u 2013 EA1 Rate Case I 802.43
1,020,5081 I
35
I 15.0441
Other expenses Incurred In connection WIVI
5 2 9,9 3 t 528.871
5,559
36 v a r l m 6tlngs beifore the APSC
38 I OTHER 37 1
I
5.8391
117,56
99.568
767.371
I
902.4301
1
I
~~
41 42 MtSO Tranfttion Costs 43 44 45
I 13
I
1341 zo,a5
Entergy Arkansas, Inc Endof L U l a U 4 pJ"4 u r l y r l r = l ,'.'", --. I"
(2) n A RsmbrnMoon I t
t 41 UeclrtC 928 134 36 20,949 42
43 44 45
1 3,986,150 621,339 * 5 2 8.8 7 8 1.17f,192 46
_. . . ..,- - -
Entergy Arkansas. Im
5p( l ) -
6 8(11 7 8(4) 8 8(4) 9
I O Tnbl I t 12 753.408.1.426 5,560,568,592.928 13 107,568.592
I
RESEARCH, OEVELOPMENT, AND DEMONS'TRATION ACTIVITIES
. Dercrbe and show below eosb Incurred and accounts charged during the year far techno!glcal research, deoelspmnt and demnahatron (R. 0 1) projed InhIaled, mntinued orconduded durtng the par. Report PISO support g h n 10 othen during the year for JOoInUy-sponsmd pmfecls (Idenbfy sdpbnl tcgardbss of affillatlon,) For any R. 0 L D w o h ~arrIed with others, show sepaately the responderih a t for the year and m t drsrgsable to rthso (Sea d6tinKion of research. dauelopmant and demonstfatlon In Uniform System af Amunts), !, Indieate In column (a) the appllwble elassfidon, as shown below
:lasslflcatIonr I Eledrle R. D & D Petformed tnlemally: (1) Generation b. Underground
8. -thead
8. hydmelectrlc (3) Dbtribution
b. Fo'pssE-trret steam e. Internal combustion or gas turblne d. Nuclear E. HactrIe, R, D D Peffomsd Extamally: e. Unconvenffonal genedon f. Sitlng and heat rejecbon Power Research Institute
1. Rematton fish and wddllfe I f m e r hydroeIecMc
(4) ReglonalTransmlsslon and Market Operatton (5) Endmnrnsnt (other UWII equlpmenl) (6) mer (CIassHy and include Items In exwss of $50,000) (7) Total Cost l n w d
(1) Research Support to the sbddcai Research Council ur the Hectrlc
@) Transrnhsion Jne CIasrfimUm Description NO tal thl
EPRrDis EPRl researdr MfT Carbon SequastraEron lnllrabve m e t
~
. . 1
28 1 29 I
I
21 I I 221
1
I
_ _ I
30 31. 32 33
34 35 36 37 3 8 .
FERC FORM NO. 1 (ED. 12-87} Pam 352
.. I I 1
RESEARCH, DEVELOPMEM, AND DEMONSTRATION ACTIVITIES (Contrnued]
(2) Research Support to Eddison Eledrlc fnstrtub [3) Research Supportto Nuclear Powsr Groups (4 ) Research Support to Others (Classlly) (5) Total Cost lnwmd
3. lnduda in column (e) all R, D L 0 Hams p&orned Inlamally and in column (d) those hems performed olrlslde he ampany co5llng $50,000 or mom, brielly descfibhg he spscMc area of R, 0 & D {such as safeb, COKBSIDII control, pollution, sulomaUon, measummftt, Insulatlnn. type 01 applanW, E k ) . Gmup hems under 550,000 by tlasrHkattons and Indicate tha number of Item grouped. Under Other, (A (6) and 6 (4)) Crass@ ttems by trpe 01 R, D &
4. S h w In column (e) the account number charged wlhh expanses duhg the p a r nr tho amunt to whkh amounts were apltaked durfng !he year. nsUng AceDunt 107, Coashdlon Work h Progress, first Shpw In cufumn if) the amounts related to the account chargad In column (e) 5. Show In cofmn &I) the total unamudhed acwmubting ot msts Or pmjecb Thb tolal must equal the balance In Amunt 188, Research, Oevelopmant, and Demonstration Expendturns, Oulstandlng at the and oltha year. '8. If msh have not bean segregated for R, D &D ad'des orprojecb, submit estimatas for colvmns (e), {d), snd (0 with such amunh iddenbfied by
7. Report saparalely refaarch end mlalad teathg facllltles opsratad by the respondent
D E W .
I
FERC FORM NO. I ED. 11-87) Pane 353
Enlergy kkansas. Inc
Classrlicallon Dlmct Payroll
@I Distnbuuon
Ufle NO.
Total
(d)
oca Ion 0 ~ a % l cAgd for Cleann Awunts
Realanal Market I 1
(a} I EIedrtc 2 oparauwr 3 PrOducUan 4 Transrnlsrlon
30 OperaLon 31 PducUoManufadumd G a s 32 P m d i l d r ~ ~ N a t Gas Ifncludtnp Erpl. and W.) 33 Ofher Gas Suppty c 34 Storage. LNG Tcrmhaling and Promsing
I * .
* . ‘ - 4
I C 1 . 1 . I ..
7.842,266) 2.604.3246
FERC FORM NO. IED. 92-881 P a m 354
End ot ~IWIQ~ (1) MA" unginai (MO, ua, i r ) (2} n A Re~ubmlsslon I I Enbrgy Arkansas, Inc
DISTRIBUTION OF SALARIESANO WAGES (Conlmuedd)
. . . . .
Name of Respondent This Repbrt is: Date of Report (Mo, Da, Yr) (I) rS. An Original
Entargy Arkansas. Inc. (2) A Resubmission I I
!Schedule Page: 354 f /ne No.; 96 Column: d 1 The following payroll charges from Non-Nuclear A f f i l i a t e are n o t included in this schedule. These charges are included in the Electric O&M schedule (pages 320-3231 only:
YearlPeriod of Report
2013M4
Production: Transrnlssion: Regional Market: Distribution: Customer Accts: Customer Service: Sales: Administrative & General:
$11,107,496 $6,547,086 $123,598 $2, O l a , 372 $6,331,538
$224 * 160 $25, 389,047
$926,299
In addition, Nuclear AEPllfate production payroll charges of $103,041,396 and administrative and general charges of $4,364,361 are not included in t h i s schedule, These charges are included in the Electric ObM schedu1eIpages 320-323)only.
. . IFERC FORM NO. 4 {ED. 12-87) I Page 354-355 Foatnote.1
I I
AMOUNTS INCLUDED IN ISOIRfO SEi7EMENT STATEMENTS
1.The respondent shall report below the detalis malted br armrnlng amounb it rewrded In Awxunt 555, Purchase Power. and Amunt 447, Sates for Resale, for Items shown on ISOIRTO Settlement Statemenh Transactions should be separately netted foraach ISDIRT0 adminktarad energy market forpurpo3es ordatemlnlng whelhar 8n entity b a ne! seller or purchaser In a ghan hour. Net megawatt hours am Lo ba used as the basis fordetemLln! whalhsra net purchase or sale has o m m d In each mnthIy rsportIng perlod. the hourly sale and purthaqa nul amounts am ta be aggregated 8nd aaparately mported In AcEolmt447, Sales for Resale, or Account 555, Purchased Powar, rnspectively,
Una D e m b o n of hemp) Balance 81 End of Balanca a1 End of Batance at End of Balanw at End of NO. Quarter 1 Quarter 2 Quarter 3 Year
0) (b) lCl (dl (0)
46
20 21 22 23 24 25
T o m ( 2.658.074)
-_. .--r . Entergy Arkansas, Inc.
In cdums for usage, report usagerelated billing determhant and the unit o? measure.
(1) On line I columns (b), (c), (4, (e), (f) snd (g) report the amount of ancillary sedces purchased and sold dudng the year,
(2) On line 2 columns @) (c), (4, (e), If). and (g) report the amount of reaetiva supply and voltage mnlrol semkes purchased and sold during !he year.
(3} On llne 3 columns (b) (c), (d). (e), (9, and (9) report the mount of regulation and frequwq response aervkes purchased and sold during the year.
(4) On tlna 4 columns @}, (ell {d), (e), (0, and (9) report the amount of energy imbalance services purchased and sold during the year.
(5) On lines 5 and 6, mlumns (b), (e), (d), (e). (9, and (g) report the amount OS operating resew@ splnning and supplement services purchased and sold during tha pedal.
(6) On line 7 wIumns (b), (c}, (4, (e), (f). and @) report lhe tdal amount of all other types andnary services purchased or sold dm'ng the year. Include fn a Imtnote and specify the amount for each lypa of other anciltaty senrice pmvlded.
Amount Purchased for ths Year
Uraaa - Related Btlllns Detemlnant 1 Amount Sold for the Year
Usasa -Relatad Btlllne Detetmlnant ..
Number of Unltr 03)
336.51
136,51
FERC FORM NO. 1 (Hew 2-04] Page 398
29-87;
719
46,tB
4547.
1.020,90
Name of Respondent This Repart Is: Date of Report (1 ) An Original (Mo, Da, Yr)
Entergy Arkansas. tnc (2) - A Resubmission t i
b b 1 Units of W H reported are related to tranmissfon services and ancillary services sold through December 18, 2013. Effective December 19, 2013, Entergy Arkansas, Inc. became a transmission owning member of Midwest Independent Transmission System Operator (MISO). Entergy Arkansas is no longer a transmission provider and no longer sells transmission services and ancillary services directly. from transmission services and ancillary services sold by MISO. revenue that it receives to t h e transmission owners.
kchedula Paue: 398 U n e No.: 3 Ca1umn.t e I
Instead, Entergy Arkansas now receives revenues M I S O distributes the
YearlPenod of Report
2013104
Dollars for Regulation and Frequency Response, Operating Reserve - Spinning and Operating Reserve - Supplement are derived from t he same MWhrs.
bchedole Page: 398 Une No.: 5 Column: 8 1 Dollars for Regulation and Frequency Response, Uperating Reserve - Spinning and Operating Reserve - Supplement are derived from the same MWhrs.
Fchedule Paqe: 398 U n o No.: 6 Column: e 1 Dollars for Regulation and Frequency Response, Operating Reserve - Spinning and Operating Reserve - Supplement are derived from the same MWhrs.
IFERC FORM NO. 1 (ED. 12-87) I Page 398 Footnote.1
hnbrgy Arkansas, Inc 1 I
MONTHLY TRANSMISSION SYSTEM PEAK LOA0 1) Repod the monthly peak load on !ha raspandsnh transmlsslon system If Uta respondent has two or mom power syftemf whkh am not p h y d d y ilegated, fumlsh the requlred lnfarmatbn for each non-lnkgraled system. 2) Report on Cotumn @)by monlh the tansmisskn syst8m's psak bad. 3) Report on Columns (e 1 snd (d) tha sptcliled lnfwmatlon for aach monthly mnsdsslon - syslem peak b a d reported on Column @I. 4) Repoft on Columns (e) ttiralrgh IJ) by month tho sFttam' monthly maxlmum megawatt bad by stabtlca! classlfieatlons. See General lndruetron for he deflnttbn of each statrstlcal ctasslficatlon.
FERCPORM NO, 1B-Q (HEW. 07-04) Page 4 Q U
]Name of Respondent I This Report Is: 1 Date of Report IYearlPeriod of Report 1 Entaqy Arkansas, Inc.
(1) I I An Original (Mo, Da, Yr> (2) I A Resubrnisslon * I I 20131Q4
bchedukt Page: 400 Line No.: 1 Column: a I The monthly transmission system peak load information represents a l l Entergy companies. Peak load by Entergy business uni t s can be determined, but due to the format of transmission accounting, it is impractical to ident i fy the monthly megawatt peak load by t h e statistical c l a s s i f i c a t i o n s requested.
bchedde Page: 400 Llne Na.: 17 Coiumn: b 1 Due to t h e Entergy operating companies' transit ion t o MISO market participation, and as discussed in Entergy's FERC f i l i n g , Docket ERl.3-948, data f o r t h e monthly transmission pr ic ing zone peak laads are reflected below.
Honth Day 1 14 2 I4 3 27 4 17 S 20 6 27 7 IO
9 3 10 3 11 28 12 16
8 a
Hour 1900
aoo aoo
1700 1600 1700 1600 1700 I600 1€00
900 000
Entergy New Orleans
760,703 697,659 733,805 769,168
I, 003,637 941,500
8631712
1,0221 946 9961 720 890,079 7 7 4 , 037 785,943
Ente rgy Texas
3,790,175 3,558,067 3,526,155 2, 4 5 1 3#701# 789 4,523,932 4 8 387, 654 4,694,692
31 7B3, 023 3,700,368 4 , 0 9 1 , 4 1 1
4,280,143
~ F E R C FORM NO. I {ED. .rz-87) I Page 400 Footnote.1
- I I - - I in! ..
ELECTRIC ENERGY ACCOUHT
Reportbelwtfre Informallan called for wneemng the dtsposfibn af elecbfe energy generaid, purchased, exchanged and wheehd during the year.
Megawatt Houn (61
. ... . .
3 Steam
4 Nudeat t 1.946,22(3 5 Hydm43nvcnttonal I3 0.60s
6 HydrPPumped Storage
7 Olher
. .. . . .-
I 3 5eIbemd 14 Net Exchanges (the 12 mlnus the 13)
15 Transmnslon For Other (Wheting)
2 2 5,O 5 i
98,391 - h f
3embd
Ine 17) 19]Tranimlsdon By Othen Losse~ 20 TOTAL (Enter Total of tlnes 8, IO, 14. l a I and 19)
31,668,311
No. (4 @I
21 DISPOSITION OF ENERGY € ..- F . . .
22 Sales to Ulllmab Conwmen (Indudlng 20,859,162
Inkdepsrtmsnfal Sales) 23 Requlmments Sales for Resale (See 261
instruction 4, page 31 1,)
InshdIon 4, page 31 1.) 24 Nan-Rcquimmenb SaLs for Resale {See 8,929,533
25 Ensm Furntshed Wahout Charpa 25 Energy Used by the Company (Eledrtc
Dept Only, &ducting Station Use) 27 Total Energy Losses 28 TOTAL (Enter Totat of tfnes 22 Through
34,091
1.845.264
31,668,311 21) (MUST EQUAL LlNE 20)
FERC FORM NO. 1 (m. 12-90) Page 401a
'ntargy Arkansas, Inc.
MONTHLY PEAKS AND OUTPLIT , Report the monthly peak load and energy output If the respondent has !wo or mom pawer whkh ara not physically Integrated. furnish the requlred *
,lotmaUon for each non- Integrated system. . Report h column (b} by month ths system's output In Megawatt hours for sa& month , Report b column (e) by mnth the nm-mqulrements sales for marale. lndude h the monthly mounts any energy loss- associated wtlh tho sale% . Report In column (d) by month the system's monthly maxlrnwm megawan load (60 mhute Integration) assodated with tha system. . Repad In cotumn (e) and (f) Ihe spsufied krfomraljon for each monlhlypaek toad reported In column (d).
I
Monthly Nan-Rfquimnts MOFUl-lLY PEAK Sales for Resale &
(a) 01 (cl (dl (9)
In8
10- Monlh Total Monkhly Enargy Assodated Losses Megawatts (See Instr. 4} Day of Month Hour
29 January 2.91 4,575 9 7 5,6 7 5 5,050 15 8W
30 February 2,627.293 940,410 4,976 1 800
31 March 959,287 1 4,753 25 800
41 TOTAL 31,668,311 8,929,533 1
.
FERC FORM NO. 1 (ED. T2-W) Pane 4Oib
Enlergy Arkansas, I n k
3 4 5 6 7 8
U . . I
STWJ-ELECTRIC GENERATING PLANT STATlsnCS (Large Planfs) I . Report data for plan1 In Sarvica onty 2. Large planb 8m steam plants mlh Installed wpauty (name plate ratlng) ol25.MH) Kwormore. Report In thIs page gas-turbtne and Internal mbuslion planb of l0,WO Kw or mom, and nudear planb. 3. lndtcale by a footnote any plant has& or opemted as a jolnt faalrty. 4. If netpaak demand For 80 minutes Is not avallabb, ghra data which h avallabh, spceifylng peW. 5. If any ernptoyws attend mom than o m pjant. report on llna 11 the approximate average numbsrofsmpkyees assignable to each plant. 6. I gas b usad and purchased on a Warm bash repod the Btu content arthe gas end tha quanlny oftual burned cunverted to M c t 7. Quantrlles of hat burned [Une 38) snd avefage cost per una of fuel bumad (Una 41) must be consisknt with-chargas to expense accounts 501 and 9 7 [Une 42) as shw on Une 20. 8. If more than one fuel Is burned In a plant fumlsh only the composile heat rate hralt fuels burned
Year Originally ConstmudEd I974 1981 Year Last Undwai Instaned 3980 198, Total tnslalled Cap ( M a x Gso N a m Phte R a b n g M 1978 DO 102604 Net Peak Demand on Plant - MW (60 minutes) 1878 16T Plant Hwn Connsdsd to Load 12951 875’ Net CwllffWOUi Pkm CaDJbdW tMwawatts) 0 I
1 Khd of Plan! (tntamal Comb. Gas Tuh, Nuclear Nudear . SEean 2 T m of Constr Iconventionel. Ouldoor. BoIler. atcl WA Full Outdo0
10 1 I 12 I3
When Umnad by Condensor Wabr i am 165 Anrags Number of Emprovtcr 986 141 Net Gsnslahon. Excbsnrs ot Wnl UM - K W 601 936229 Cost ot Plant‘ Llnd and land Rmhts 2648089 1 1 0 S
1 134 62200 00
15 16 17 I8
.
Equlpmant Cmb 2029316577 451 28973 Asset Rettmmant Coats 63301 902 I
TotalCost 2572028291 49838039 1300.3176 405.750 Cost wr Kw or Irtstatbd C w a w mu 17151 Indudma
19 IPmductlon ~ x w n r a r k r . sum. E m t I 258326971 251 855
37 Unit (Coa~tonsK)ICbamUGas-mcllEluclear-bdlcal8) MWH TON 8BL
I 39 Avg Heat Cont - Fuel Burned (bluflndIeate H nuelear) 0 3413800 0 8560 0 14or163 ’ 38 Puantrty (Unlls) of Fuel Burned 0 36172787 0 3645078 o 9(150
40 Avg Cost of Fuelhrnt as Dew f o b during p a r 0 MI0 O W 0 0 000 0 000 0.000 0 000 41 1 Averaga Cost of Fuel par Vnd Burned 0 000 2 097 O W C 43.120 0000 120 a0
201 Fuel I . 757572791 1582!i632
, 42 Average Cost or Fuel Burned per Mrnion BTU Io000 0 614 0 MI0 2 520 0 000 20 450 i 43 Average Cost of Fuel Burned per Kwh Net Gen f 0.000 Oo[fB 0.000 0.030 0.w10 0 000 I 44 Avarags BTLI per Kwll Net Generation 10.000 I0336950 0000 OOOO 10576000 0 MI0
21 I Cwhnn md Witar tN&rr Punn On&>- - - - - - - I - - - - - - - 53587581 I
22 I Staam Exnenssi I 33353747 t 130940 . .
23 1 Steam Fmm Other S o m i I 01. I - . - -. -. . . -. . . .
24 S t a m Transfeerrtd (0) 01 - I
25 Ebctrlc Expansas 0 65463
27 Rents 43547ao 14106 0 6301
26 Mist Steam (or Nutkar) PPmr Emnwtl 30234246 322685
, 35 I Exrrsnsaswr Net KWh 1 002291 0 030
FERC FORM NO. 1 (REV. 12-03) Paw 402
I Entergy Arkansas, tnc . .
I STEAWELECTRIC GENERAnNG PLAM STATISTICS (large Plants)(ContfnuedJ
9 Items under Cost of Plant 8m based on U. S. of A Accounb Production expensas do not Include Purchased Power, System Control end Load Otspatchlng. and Othar Expenses Classliltfed 1s Mher Power Supply Expenses, 10. For IC and GT ptants, mport Operatlng bpenses, Amunt Nos. 547 and 549 on Lhe 25 'Electfic Expensas: and Maintenance A a u n t Nos 553 and 554 on Une 32, Walnbnanm of E W c Plant" Indicate planb dedgned lor peaktoad sarvIca. Deslgnats automatidy opsated phnts. 11. Fora plant equlppsd with combinations of fossll mal steam, nuclear steam, hydrn, Internal ccmbustim nrgasturblne aqulpmant, report each 3s a separate ptant However. Ha gas-lurblne unit fundons In 8 wmblned cyde OpsratIOn with B conventtonal m a m mi?, include the gas-tuhhe with the steam plant 12. Ha nuclearpwer gonefatlng pknt. brie!ly axplah by footnote (a) scurunthg method for wst of power generated lnctudhg any excess cwts attributed to research and development; @) types of cost unlts used tor the varlour wmponents of bat cost; and (c} any othsrktamathra data Eoneemlng plant type fuel used, fuel enrichment type and quantity for !he
Swam I Steam Gas turblna FutlOutdwr I Full Outdwr Outdoof
1903 I 1950 I970 1983 I970 I 1970
284 00 752 00 20.00 1746 525 0 8412 4188 0
1 1678 1651 758 I 16
1461736974 477684697 I]
773576 33725 16583 119azao 6877639 514914
m z ~ w a a 51 833873 308059
125 ; 0
1 0 1 322593 I 4455 . . ._
159035984 59067830 84401 1 559 9859 76 5a78 42.2OOB
a o n m 2384264 0 40808146 2933351 0 0
0 0 0 366456 944054 0
0 0 0 0 0 0
493596 571920 0 -225648 2075602 0
35022 93814 0 t3481 8U52 0 94534 349869 0
280181 163461 0 I 2567630 I 3408070 f I 544803 I 3007469 1
1 Entergy Arkansas, lnc.
STEAWELECTRIC GENERATING P M STAllSTICS (Large Plants) (COt'flinmd) f
1. Report data for plant In S8rvIce onty. 2. Large plants am steam plankwh Installed wpaw (name plats rabng) of 25,oM) Kw or mom Report In ttrIs page gar-tufbine and internal cambustton plants of W,WO Kw of m m , and nuclear plants. 3. Indieate by a Ioolnote any plant leased or opemtd as 8 Iolnt hdllty 4. i f net peakdernand for 60 mlnuter h not amllable, give data whlch Is wallable, spec@!ng pe~-Icd. 5. If any empbyees anend mom khan nna plant. report on llne f I the appmrlmata avemgo number ofernpfoyees asslgnabfe tu aadI plant 6. If gas Is used and pttrchaiad on a tharm basts report the Etu mnlent ortho gas and the quanlliy of fuel burned ccoverled to Mct 7. QuanUtIas otfual burned (Une 38) and avaraga cost per unit of fuel burned (une 41) mud be anststent with charges to expense acerrunh 501 and 547 (Line 42) 8s show on Une 20. 8. If mors than one luel Is burned In a plant hrnhh only the cornposh8 heat rate for all bela bumd.
I
1 IKhd of Ptant (Intarnal Comb, Gas Turb. Nuclear 2 lTme of Constr (Convantionat. Outdoor. Boller. @id
. __ - llem
Steam steam Full OuMoor Full Outdoor
4 5 6 7 8
.. _ _ Y8ar Last Unn was Installad 1951 1954 Total Installed Cap ( M a x Gen Name Plala R a U n g m 138 00 225 CQ Net Peak Demand on Plant - M W (60 mlnutes) 0 0 Plant Hours Connadad to Load 0 I)
Net Contlnuous PIant Cauabllltv IMeaawarlsl 0 0 1 9 I When Not Umded bv Condenser Water I 1441 1301
t 0 11 12 13 14
When Urnted by Condenser Water 135 130 Awraga Number of Employees 0 0 Nat Gancratlon. Exclustva 01 Plant Use - Kwh 0 -1MMx)
Structures and trnamvsmn& 0 3060767 Cost of Plant land and Land Righh t 30709 89504
I 15 I EPubment Costs I 63321 4W918l
17 18 19
t 16 i &sat Rcthmant Costs I 86051 I 1284621 -. . ._ .. . .~
3680151 Totalcost 123092 Cost per KW of lnstalted Capauty (line 1715) Including 0 8920 16.3562 Produdon Expenses' Oper. Supv, & Engr 0 224049
37 36 39 40 41 12
1 201 Fuel 1 01 7868% I
Una (Coa~tonslOtCbaFteUGa~-m~uc~ear-~dIcata) MCF BBL
Avg Heat Cont - Fuel Bumad (btuTtndtcate If nuclear) 0 0 0 9449w 0 140462
Average Cost of Fuel par UnH Burn& 0 MI0 0 000 0 000 271.187 OOOQ 767.408 Aveaoe Cost of Fuel Burned wr M h n 8TU 0 000 0 MI0 0 000 281.002 0000 133.473
Quantfly tune) of Fuel Burned 0 0 0 2887 0 5
Avg Cos1 of FueVuntt, 8s Delvd Lo b. dudng year D ooa 0 000 D OQO 0 000 0 000 0 000
I 21 I Codants and Water lhlvclear Pranks 0nh.l I
43 44
I 23 I steam From m e r Sources I 01
Average Cost or Fuel Burned per Kwh Net Gen loow (0.000 10 000 -7.528 lo 000 10 0oo Average 8TU per Kwh Nat Ganefatran 0.000 10 000 10 000 00.00 I O.Oo0 10 000
* .
I 24 I Steam Transdad ICd I Ol 25 Ebctrlc Expenses 0 I1987
27 Rants 0 16517 28 Allowanoes 0 0 29 MaInfenanee Supewlsion and Engintenng 0 33219 30 Malntenanm of Stmdures 0 19545
26 Muc Steam (or Nuelear) Power fxpenras 0 366236
1 31 I Malntanance of Bpllar (or raadorl Plant I 01 231167 I 32 MaIntenanw of EleetrIe Plant I 01 44458 33 Malnhnance olMisc Staam (or Nudcar} Plant 01 60600
35 Expenses per Net Kwh -15 3060 36 Fuel: Klnd (Coal. Gas. Oil. or Nudean I I Gas I loll
34 Total Production kpenses 1591821
FERC FORM NO. .I IREV. 12-03) Pane 402.1
Dkpatchfng, and OthsrI5psnse9 Cbrrrfied as Mher Power Sup& Exparues 547 and 549 Uno 25 "Elsdric Expenses," and Malntenanca Account Nos. 553 and 554 on Une 32. TMahlnnanca of Ekctdc Plantu Indieate plank desqned for peakload rarvlce. Oeilgnate automabcally operated plants. ti. Far a plant equTpped wnh comblnatfons of hssU hret steam, nuclear steam, hydro, internal combustion orgashlrbtne equlprnent, tepod each as B separale plant. However, If a gasCrbtne unafunetions In 8 tomblned cyde operation wlth a wmentlonal sleam unit, Include #e gas-turblne with the steam plant 12. Ifa nuckar p w e r ganeraUng plant. briefly explain by botnole (a) accountlng method for mst of power generated hdudlng any axwss cost$ amiutcd b mearch and dwatoprnanS (b) types of w l u n h used kr the various components olfual a s k and (c) any omor Infomath data mneernlng plant type fuel urd, fud entkhmenl type and quanltty forthe repor! perlod and other physlcat and operating charaderisks ot plant.
f0. For IC and GTplanb, wrt Opcratrng I5panse3, Aewunt NOS.
312 0
72 72 0
I sham I
0 7 0 8 0 9 0 ?O 0 i f
- .
Full Outdoor I 4943 19%
183 00 0 0 0
131 131
0 2 3 0 m 4912802
17821 5161475 66.1728
5074
1 4
- 16583 13
514933 14 307894 15 123270 16
' 962688 17 2.6818 18
0 19
1 -837000
0 a 0 0
I -722 -
0 21 0 2 2 0 23 0 24
9 0615 416604 912525
I 0
I 23126 0 0
35652 I 912534 I 184.77
.. . ~.
.. .- ..
O W 0000 1 am 0 000 0000 I om 0000 -1.090 t 0 . m
Gas Turblne Stearn 1 Outdoor Outdoor 2
1970 1961 3 1970 1961 4
78 00 359m 5 0 0 0
445963 I 3172) 201
450 1 01 251 55781 I 01 26
0' I O ! 27
. 1582 I) 30
0 0 31 47949 0 32 40079 0 33
598339 31721 34
I I I .. . .
FERC FORM NO. I (REV, 12-03]
. . - . . -. . . - - .. . .. ...
Page 403.1
r - - - - - - . __ . . - -. . . - - Eniergy Arkansas, Inc.
U .. I I
STEAM-ELECTRIC GENERATING PtANT SIA7lSTICS (Large Plants) ICanthuW 1. Report data for plant In SaMw only. Z htga plants am steam planb wW Installed wpactty ( n m plale mbng) Of25,W Kw or mom, Report In thb page gas-hrrbtnpr and Infernal mbustlon plants of 10,000 Kw or mom, and nudear plank 3. lndkata by a IOOtoot8 any plant hared or operated as a lOIntfadlity. 4. If net peak damand for 60 mlnules Is not avaPable, give data which b mailable. Specifying pad&, 5. If any emplgrml ettend mom lhan one plant, report an tine 11 the approximate evwage number of tmpbyCBs asslggnable to each plant 6. If gas is used and purchased on a therm barls report tha Bhi content or the gas and the quanUty of fuel burned converted to McL 7. Quanbillei of fuel burned (Lhe 38) and avamgs cost per un8 of !bet burned (the 41) nwst be consistent wiih charges to expenso accounb 501 and 547 (Line 42) as shw on Line 20. 8. If mom than one fuel b burned In a plant turnlsh on@ Uw composite healrala for all fu0k burned.
FERC FORM MU. 1 IREV. 1243) Parre 4021
'Name of Respondent , This Report Is: Date of Report (Mo, Da, Yr) (1) X An Original
Entergy Arkansas. Inc (2) I A Resubrnissjm I t ...
F O O T W E DATA I
YearlPedod of Report
201 3Im
bcfiedtlle ~ a s e : 403 t h e NO.: -1 ~ojumn: e I Lake Catherine
Lake Catherine Uni t s 1, 2, and 3 were retired i n 2013.
Bctmdu/a Pam: 403 Une NO,: -f column: f I Robert Ritchie 3
Robert Ritchie 3 Unit was retired in 2013,
Pchedrrle Page: 402 Una No.: I Column: c I White Bluff
Reflects Entergy Arkansas, Inc.@s 57% interest in White Bluff Units I, 2, and Common Plant.
bcheduie Page:403 Uno No.: t Column: d ' I Independence
Reflects Entergy Arkansas Inc.'s 31.5% interest in Independence Unit 1 and its 15.75% interest in Common Plant.
bcheduie Page: 403 Une No.: I Column: f 1 Robert Ritchie 3
Reflects Entergy Arkansas, Inc.'s 100% interest in Robert Ritchie 3 and I t 3 40.74% interest in Common Plant.
bcheduh Page: 4OZA LIne No.: 4 Column: 6 1 Hamilton Moses
Hamilton Moses Units I and 2 were retired in 2013.
bchedule Paqe: 402.f Llne No.: -f Column: c 1 Cecil Lynch
Cecil Lynch Units 2 and 3 were retired in 2013.
bchedule Page: 403.f Une No.: 4 Column: d I Harvey Couch
Harvey Couch Unit 2 was retired in 2013.
pchedule Page: 403.1 LIne No.: -I Column: e 1 Mabelvale
Mablevale Uni ts 2 and 4 were retired in 2013.
- -- ~FERC FORM NO. 7 (ED. 12-871 1 Page 402903 Footnote.1
b
Name of Respondent This Report is: Date of Report YearlPenod of Report (1) An Original (Ma, Da, Yr)
Entergy Arkansas, Inc (2) I A Resubmission I I 201 31Q4
FOOTNOTE DATA -
IFERC FORM N 0.1 (ED. 12-87) I Page 402-403 Footnote2
Entergy Arkansas, Inc.
1 Klnd of Rant (Run-of-Rtver of Storsge) Storags Storage
3 Year Orlglnany Constructed 1932 1923
2 Pbnl Construdon lypa (Convedonal or Outdoor) Outdoor Ouldwr
4 Year Last Unt was Instalred 1933 1923
5 Tobl Installed cap (Gan nama p h h Ratlng In Mw) 55.00 O M )
I w I I
HYDROELECTRIC GENEWING PUNT STA'FISTICS (raga Plank) 1. Large plants am hydra plank or 10,000 Kw or mom of Installed EapacQ (name plaIe ratings) 2. Many plant Is based, operated under a Uwnsa fmm tha Fsdural Energy Regulatory CmrnIsslon. or operated as alolnt faalriy, indleate such facts In a todotncte.* If Iimmd project, give projeel number. 3. If no! pakdemand for 60 minutes Is not svanable, give mat whlch Is avallabh speclfylng ped&. 4. If B group of employees attends mom lhan ona ganerallng pbnl, repoitan line ? t h e approximate average number of employees 8sstgnabla to each
10 Item f ERC Lhnsed m]ed No. 0 0. Phnf Mama: Carpentat
(a) @I
FERC Uensed Pmjed NO. 0 PlantNarnw Remrnel
(C}
27
L .
48
.
FERC FORM NO. I (REV. 11.031 Pane 410
Endof dUIYU4 \l.'", YY, I ', I I Entetgy Arkansas, Inc.
3. Ut plantr appmpdakly undersubheadlngs for steam, hydro, nudear, Internal combusbon and gas turblne plantr. For nuclear, See lmtrudon 11, Page 403. 4. If net peakdemand for60 mlnutes b not wallable, give &e whlch h avabbh, spawng prbd wmblnatlons of steam, hydm Internal combusllon or gas turblne aqulpmenl, report each as 8 separate plant However, Ktha axhaust hcatfmrn tha gas turbha b utiked In a steam hlrblne regenamtin ked walar cycle, or for preheated combusfion alr In a boiler, report as on0 plan!.
. 5. If any pknt Is equ$ped with
FERC FORM NO. I (REV, t l -03) Page 411
Name of Respondent Thfs Report is: Data of Report (Mo, Da, Yr) (I) &An Original
Entergy Arkansas, l n c (2) -A Resubmission ' I t
bchedule Page: 470 Line No.: I Column: 8 I Cecil Lynch diesel unit was retired in 2013.
YearlPenod of Report
20I9Mis -
[FERC FORM NO. I (ED. 12-87) 1
BLANK PAGE
(1) BAn OrlgInal . . . ..
Entergy Arkansas, Inc (2) n A ResubmissIon tRANSMlSSlON LINE STATIST
D k m o n VQLTArjt (tndlcate wA% other than
End of 201 3lQ4 (Mo, Da, 7r) t i
CS
7 Independence Dell 6015 5nO.Oq
9 While BluA SherldanGO11 500.M 8 Independence Ksu 6016 5oo.oc
10 AN0 MayA~werBOO2 5W.q 11 MaboIvabLR Pinnlde MavRwer6007 mcd
35
121ANO IJa Mabhr 6001 I mod
mayat South AWMO State Una 6368 161 od Redor ARM0 State Une 6247 f61.CQ
14lWesr Mmnhls habahrals 6009 I 500 Ml 151 M l s i River West Memphis 6008 I 500 [H:
16lJctMlabhr OGdE Connedlon 6008 - m.oc 17(Mabuhale Et Dorado 6005 5MI 01 I S { Sheridan Hot Springs 6017 * m.oc 19IHoIland Bottom KEQ 0806 500 Od
22 I 23 ElDomdo LA State Une 6101 2-45 0 4 24 Total 345kv Unes ! 25 I
27 RItdl-Wdwrd SMta Rwskev Taa 6205 230.d 26 LBka Village Bagby Mfss 5t Une 6201 23n.q
291 Ritcble lBrtnklav 6202 I 230 Od
3 321 - 30 Ritchla Woodward 8204 I 2 3 Q . d
Total 230kv Unes 1 I If Rdchls Miss Rbei -
I I
* (#2) 6208 I 230 Qd 331 1 1 1
1 I t I
36 I I I I
.- atStlA I 17251 1 atSUA atSLlA
iyed Ste iyed st0 37.76 alSUA l S l A 1 64.101 I Sl Sq A 10 63 ai Slt A 60 8B a 1 8 A 29 91 iqed Atv 49 as atSUA 2021 at Stl A 135301
1 1 1
I I I 1 1 I I
0 661 I
FERC FORM NO. 1 (ED. 12471 Page 422
1 I TRANSMISSION LINE STATISTICS (Contmued)
7. Do not reportffrs same transmksbn Ins stnrclura M#. R~port hervoltage Una and htghervabge Unes as one Ihe. Des!ggnate h a fmLna!a fl you do nolInduda Lowervoltage IInmwith hIgher waltaga Ilnes. H W m or mora transmIsshn ltne slruchrns $upport Bnei offha same voltage, reportthe pole rnikies or the primary stnrctum In column (9 and lhe pole rnfles of the otherline(s) In column (9) 8. DesiQgnate any transmislon tino or powon thereof forwhkh the reipondentls not ha sole OWner. If such property Is has& from another company. glue name ofla9ror, dale and terms of Laai~, and amount of rent for yciar. For any transmlssfon line other than a leased Rne, or portion th8mol. lor whlch the mspondant Is not Ihs sole owner but whlch the respondent operates or shams In the operation of. furnhh a sucdnctstatemsnt axptalntng the srrangemnt and ghrlng partkutan (dabPs) of such matters as parcant ownenhip by respondent In the Itno, namd of co-owner, basts of sharing expensea 0Iha fie, and how the swpsnsas borne by the respandent 818 accounted tor, and a m n t s afedd. Spadfywhethsrhssor. -nor, or other patty b an msoclaled company. 9. Derbnate sny transmission [ne leaseed to another company and gbe name of Lessee, date and terms of bass, annual rent for year, and how 'delennlned. Specify whehhsrlessw b an aasodaled company. 10. Ease the plant most figures d l p d for In mlumns (jl to (l) on the book cost at end cryear.
C m m F m E (1 MPENSES, EXCEPT DEPRECLATlON ANDTAXES ncluda III Column Q] Land, SIra of Land @h&. and Jearing dght-of-way)
on and
I tn I n
I 1
I 35.078.4q 248591,M 1
I I
1024 5 A M 1 1 523.1td 2.733.42
1272 ACSR 3070 MCSR 1534 ACAR 1272 ACSR 3070 MCSR ---
1.802287 33.678.74
FERC FORM NO, 1 (ED. t2-871
Totat Cost openbun Maintenance Rents rota1 I Expenses (01 (PI
Expansas Expenses [r) (ml (n)
1 i
1
1 I I I I i
283.610,125 21 22 23
25 3255,543 I 24
850,638,1[30 13,627,961 4.313552 58,293 17399.806 36
(1) NAnOdglnal -. .
EnteFgy Arkansas, IIIL p) IJA Resubrnlsrlon TRANSMISSION UNE STATlST
E d o f 2013(14 (Mo, Da, Yr) I !
CS
FERC FORM NO. 1 [ED. 12-81] Pam 422.3
36 ------- I I
TOTAL 4.670.79 15826 209
\ I , pJ#U, v l r y l l l a l
(2) n A Resubmissbn Enferyy Arkansas, he.
I MPWSES, a C E P T DEPRECIATION AN0 TAXES nduda a Column (I) b n d , Ska of Land hhb, and clearlng right-of-way)
EMof z01w4 ,'.nu. "-I 0 11
IJ
Conductor ,
tand Consbudon and Total Cost Operation m e r Costs Expenses snd Matedal
(r) 0) i (kl (I) (m)
*'RANSMISSION LINE STATISTICS (Conhued)
, 336 ACSR 1590ACSR 666 ACSR
1 1 I I
GAGS3 . 1 I I I E ACSR I
1
83 2 5 0,5 4 9 850.638.100 t 3,627.96
1 2 3 4 5 6 7 8 9 I I
12 13 14 15 16 17
20 21 22 23 24 25 26
.
I I ( 2 1 I ~
I 2a 29 30 31 32 33 34
FERC FORM NO. I (ED. 12-87] Page 423.1
- -- - -- Enlergy Arkansas, Inc.
34 35
36
(I) ~ A I I Orlglnal 1 (2) n A Resubmission
Total 161kv tEnes
TOTAL 4.670 19 15826 209
I I , I I
TRANSMISSION LINE STATISTICS
1. Report Infomarmn mncemlng transmlsalon Ines, mst of Il~es, and expenses fur year. Ust each trarumlsrion line having nomlnal wollage of 132 M!wo!b orgreater. Reporttrsnsmisslon Unei b e h the- voltages tn group lotats only for eachuoltags. 2. Transmlssjon fines Include all Hnes ewered by h e dsflnlUon o~iranrmlssIon system plant as gtvan In ths Unlform System of Accounts. Do nut mport substation cosls and expenses on Ulfs page. 3. RspDrt data by Indlvkiual lnaa Tor alI voltages if so requlred by a State commlssbn. 4. EjIcluds from thh pago m y transmlsslon llnes for whlch plant costs am tnduded in Account 124, Nonutlllty Property. 5. Indla!e whether the typ of supporting structure nported In column (e) Ls: (I) alngle po!e wood or steel: (2) Kframe WODd, or sleel pobs: (3) tower: or (4) undargmund consmidon If a transmirslon line has mors than one type of supporting struch~re, Indlcate the mllaaga of each type of construetlon by the urn of brackets and extra Ilnes, Minor porlions of 8 b9nsmIsslon he of a differant type olconsWcUon need nat be dlstingubhed fmm !he remafnder oftha fine. 6. Report in columns (f) and {g) the tolal pole mtles of each tmnsmbshn line. Show In column (fj the pole mBes of llna on shutturns her mort of whkh h repoffed forthe Bne designated. conversely, s h w In m!um (g) the pole mas of Lne on shdums the cost olwhich Is mportd for another he. Report pola mfles of nne on leased or p a w owned sfructures In d u m n (9). In a M o t e , axplatn the bash of such occupancy and state whather expenses wHt respect to such structures are hdudsd In !he axpensss mported for be [Inn dssIggnated.
2 Mosas Parktn (F C i N Tap) 6327 161 4 woPdn.Fr 2 69
4 Harrlson East SWEPCO Cmn. 6314 181 Wood M r 40 16 5 Hamlet-Hb Spgs S G r Frj (Greenbrar Tap) 631 t 161.q wood wr 1198 6 Jonasbom SPA War 6320 16l.C-d WoodH.Fr 0.83
3 Parkln Kunh Road 6338 1 6 t 4 wood HSr 18 aa
L U l&u4 I ' - 4 I"' u'"'- ..=...-. r..". " , p] mA Reaubmisdon I I 1
63,250,549
I I 1 I I I TRANSMISSION LINESTATISTICS (Contmiredb
3!
76?.3&7,551 8M.638,lW 13,627,961 4,313,552 58.293 17,999.80 3
7. Do not report the same transmtsslon IIm stnrttum l w b . R~port Lower voltage Unas and hlghar voltage now as one tlne. Designata In a lootnote If youdo not lndude Lower voltage 1Ims wrth higher voilage Ilnsa If Wo or more transmlsslpn llna stnrctumi support Enes of the same Wltage. report the pole mibs d the primary rtnrctura tn column I9 and the pole miles of the other he@) In mhmn (g) 8. Designate any b-ansdsslon line or portlon thereofforwhIchtha respondent Is notthe sola m e r . If such proparty h leased fmm another company, g h name of lessar, date and terms o l tease, end amount of rent for year. For any trensmtdon llne otfisrthan a leasvd tlna. or portran themof, for whlch !he raspondant b not lha sole owner butwhlch the respondent operalas or shams In the operation of, furnish 8 sucdnct stalernent explablng the arrangement and gMng partlcuIan (details) of such manen as perant ownenhlp by respondent in the Uno, name af -mer, bash otshadng expenses af the Une, and how the expanses borne by the respondent am accounted Far, and aeeDunb affected. Specify whether lessor, m n e r , or other party Is an assdated company. 9. Dealgnale any transmlsslon h a leased to mother company and g i w narm of Lessee, date and tm of lease. annual rent for year, and how delermlnsd. Spaufywhether bssss t 8n assodated company. 10. Base the plant cost Rgures called for In columns d) to [I) on h e bock cost at end of year.
FERC FORM NO. I (ED. 12-87) Page 4239
(1)- ah Odglnal (Mo, Oa, Y r) &dof 20131a . . ..I. -.
(2) n A ResubmIsslon I t Edergy Arkansas, Ine.
1. RepoRhfmmafIon eonmmlng tranrrnlsshon Ilnes, cost of Ices, and expenses for year. Wt each transmb3lon Ihs havlng nomlnat voltage o? 132 kibvoib orgnaler. Report transmPsIon lines below thaw vollages in grovp blab only for sacb vollage. 2. Transmhsbn Unes hrdude ell lInai w r a d by the deRnrtIon of hnsrnhrlon system plant ns glven In the Unlfom S p t k ofAmunb. 00 not report subslaUon costs snd expenses on thb page. 3, Report data by lndlvldual lines for all W a g e s if so requltad by a State commlsslon. 4. Exduds horn thh page any transmlJilDn lines forwhlch plant mstf are Included In Aeeount 121, Nonulrllty Property. 5 Indlmtewktharthe typa ot suppodng strudura rapmtd In column (e) 1s: (1) slngh poIe wood or steal; (2) Whma wood. or steel poles: (3) tower. or (4) underground ccnsbvcbon If a bansrnksiion Ihs has mom than ons lypa dsupparllng shcture, Indlcale the mlleage or each type of conrlrudon by tho use of brackets and e x h Iles. Minor porlions of a banamisdon h e of B dllremnt type of wnslructjon need not be dlstjngubhad from the remalnder of Uta fine. B. Report In a l u m s (f) and @) the total pole mlles of each hnsrnbakn Una. Show In column (I) the pole d e s of lIne on shctutes th8 cost ofwhlch Is repotted for the tinine daslgneted; mnveoely, show In cpbmn {g) uls pole miles of ltne on shruthrres tha cost ofwtilch h reported for another Ilne. Report pole mlks of [Ins on leased orpadly owned structures In column (g). In ia footnote, expldn the bash d such ocetlponcy and state whathsraxpanms with reaped to sueh stmudurns are tnduded In I ~ R expenses reporled for !he tlne designated.
TRANSMISSION LINE STATISTICS
No. I
4i
lot 111
i------- 17 181
30 31 1 32 33 34 35
FERC FORM NO. I (ED. t2-871
To @I
I I I
ota1115 I I I v m rklahoma - Danvllle I I I maledl t I I
1 ' -r- I 1 I I
otal69k ! I lwwd H.Ff
I
I TOTAL
P a w 4223
LE G H Pole iles) u Bergrou iine:,
f e ~ o t t ~ t r ~ l R rnilesl Nu&
J
4.670 79 15826 20 I I
4.670 791 158261 20
Entergy-nsas, Inc . . , I I "ISMISSION LINE STATISTICS (Contmued)
r. Do not report the same transm!sston line struehrm Wm R ~ p o t t L m e r voltage Urws snd hlgher voltage flnas as one Iine. Deslgnato h a foobrale tf ruu do not Indude h r voltage nnas w M higher volhge finas. Hbu or mom transmklon line s t n t ~ r e s support Inas ofthe Same uottags, report the d e mibs oftha primary stnrchrra h column (9 and the gple mlks ofthe other Ilne(s) In molrrmn (g) 5. Derlgnate m y transdsslon Une or podon thenof for whlch the respondentls not the rote ownar. H such property 1s leased frwn anothareornpany. jive name ol Iessor, date end terms of Lease, and amount of rent for year. For any Eransmlsslon line other than a hasad Ilne, or portion thamof, for Hhlch the respondent Is not the sole owner but whlch the respondent operates or shams In the operation of, fumM B sucdnctstatement explablng the mangemant and g'ning pehculan (detalls) olsurh matters as percentowoenhlp by mspondent In the he, name d mwner , bash PI shadfig gxpmsas of the Une, and how the expenses b o w by the respondent are aaunted for, and accounts afkeded. SpeciQwbether lessor, co+wsr. or >mer pa* Is an assoclatad company 3. Deslgnale any bnsmtsslon llna k a s d lo anulhwcompany and give nam of L m m , data and tern ol 1 8 8 5 ~ ~ annual nnt for year, and h w letermlned. Spec'@ whether bssea ls an essodated wmpany. 10. Sass We plan1 cost figures called for In coIumm 0 to (I) on the book cost at end ol year.
C O S r n I N t (Indude in Column ci) Land, EXPENSES, a C E P T DEPRECIATION AN0 TAXES Land righb, ~ n d cbadng rlghtsf-way}
FERC FORM NO. I EO. 32-87] Pane 4233
Entergy Arkansas, Inc . .
L J I TMSMlSSION UNES ADDED DURING YEAR
I. Report belw the information malted for cormmirtg Tpsmission lines added or altered during tha year. It Is no! necessary to report mlnor revisions of tines. 2. ProvM0 separate subheadlmgs for overhead and under- gmund wnsfructlon and show each bansmhsion tine separately. If actual costs d competed wnstntdlon are not readily available for reporting columns (I) to (o), It Is pedssible !o repart In lhese columns the
43 I
44 TOTAL 21.M 8 35 1 ,.
FERC FORM NO. 1 (REV. 12-03] Pam 424
Endof mJIU4 \ I ) un" uriginar (MU, U d , 11)
(2) n A Resubmlsston I I Entergy Arkansas, Inc.
costs. Designate, however, If estimated amownts are reported. Include wsts of Clearing Land and Rightssf-Way, and Roads and Traits, In column (I) wlh appropriate fadnote, and casts of Underground Conduit In column (m). 3, If deslgn voltago differs from operating voltags, hdimb such fad by footnote; also h e m line Is other than 60 cycle, 3 phase, indicate s u d ~ other charadedstic.
TRAN%lSStON LINES ADDED DURING Y m (Contmued)
1 9.268.058 , . 11,947.86S 3,553,478 3.553,475
1
I 14
I 4:
28.342.8B4) 4
FERC FORM NO. t (REV. 12-03) Page 425
.. I
SUBSTATIONS
1. Report below !he information d i e d for concemlng substations dithe respondent as of the end of the year. 2. Substattons whlch hewe only one Industria1 OF street milway customer should not be Ilsted below.. 3. Substalons with capacities of Less than 10 MVa except those sewing customers with energy for resale, may be grouped according to hrndional character, bul the number af such substatlons must be shown. 4. Indlcate In column (b) the fumtlonal character of each substation, deslgnaung whether transmisston or dsltibutlon and whether anended or unattended. At h e end of Ihe page, surnmarke according ta function the wpades reported for he Indiddual stations In column (0.
Nama and Locallon of Subslation Charactor of Substatlon
ARMOREL
ATKlhlS
BALD KNOB BARTON BATESVlUE (a) MUCUM BAUXITE
Oisbb. Unatlanded 161.03 13 80 Oistnb. Wnamnded 161.W 13.80
Distnb. Unatbndd 115[10 13 80
Di5tnb. Unattended $81 MI 13.80
Distnb. Unettsndsd 115 00 13 80
Dlstnb Unattandad 115 00 '13.00 Distrtb. UnattandM 115 MI 13 80
Oistnb Unattendad 34 501 12.40 35 BRINKLEY EAST DisW. Unattended 1 15.00) 13.80 36 ERINKLEY WEST DIs~. Unattended 1 15.00i
I Dtstnb. Unattended I 115 001
Datnb. Unattended
I I I I I
38 BULLSHOALS Distnb. Unattended 161 W I 3 801
39 BUTLERHAU,4470 Dalrtb. Unattended 34 50 12 40
40 BUTTERFIELD Datnb. Unattended 1t500 33 BO
FERC FORM NO, 1 ED. f2-96) Paas 428
Entergy Arkansas, Ine. (1) x Anurrgmal I I21 H A ResuhIsslon . .. . , . - 0 , 1
SUBSTATIONS (Conttnuad) 5. Shwv In molumns (I), Ij)$ and (k) speclal equipment such as mhry mnverfen, rectifiers, condensers, ete. and auxilfary equipment for lnereashg apacily. 6. Designate substations or malor Rems of equipment leased fmm others, jolnUy owned with others, or operated othendse than by reason of sole ownership by the respondent. For any substation M equipment operated under Ieasa, glve name of lessor, dale and p e d d of lease, and annual rent. For any substation OF equipment operated other than by reason of sole ownership or lease, glue name of c m e r or other party, explah bash of shadng expenses or other accounting between the parties, and state amounts and aecounls afieded In respondenrs books of account. Spedfy In each a s e whether lessor, c m e r , OF olher party 1s 3n assodated company.
{MO, ua, rrl Enlergy Arkansas, Ine. I t mdoJ 2013Q4
Une No.
1 2 3 4
32 IDAIT0
Name and Locallon of Substatran
(a) CABOT(AP1) CAUCOROCK CAMDENMAGUlRE CAMDENNORTH
OIStnb, Unattended Dtstnb. Unsttanded
VOLTAGE (In MVa) Chammr of Subslation
Primary Secondary Temry
Dlstnb. Unatlanded I t 5.00 13 80 Dlstrb. Unahnded 161 OD 13.00
115 00 13.80 315 00 13.80
5
6 7 6
9
10
11 12 13 14 15 i 6
I? 18 19 20
21 22 23 24 25 26 27 28
29
3U
CAMPBELL
CARUSLE(APL) CARPENTERDAM CARTHAGEtAPL) CASH CAvEcm CEDARGROVE CHERRY VALLEY CIARENDON CUNTON(APL) COUEGECrn CONWAY INDUSTRIAL CO
CONWAY S O m CO
CONWAY WEST CO CORNING 115 CORNING 34.5
C O T T O N P M COlTON PLANT CITY 4 160 COUCH SES SWCHYARD
CROOKEDLAKE CROSSE1T NORTH CROSSEIT PAPER MILL CROSSE'ITWEST CUSHMAN
OAIARK I DANVlLtE {APL)
O E M . Unattended OiShb. Un8k?nded Distnb. Unattendad Dsblb. Unattended Dlstnb. Unattended Distnb. Unattended Distnb. Unattended OIstttb, Unalte&d Dlstrtb. Unattmded Dlstrlb. Unattended
t i500 13 80 115.00 13 80 115 QO 13 80
181.00 13 80
161.00 34 50 361.00 13 80
16l.00 13 80 115 (10 43 80
161.00 13 80 34.50 12.40
Distnb. Unatbnded DIsblb. UnaKended 'Dtstnb. Unattended Dtstrlb. Unattended blsbilb. Unattended Dlsb-lb. Unattended
161 MI 13.80
16!.00 t3 80 f I5 00 24.50
34.50 12 40
115 00 13.80 13.80 4 80
FERC FORM NO. 1 LED. q2-811 Pam 420.1
Disfnb. Unattended Dtstrlb. Unanended 'Drstnb, Unattended 'Dtstnb. Unattondad Distnb. Unattended Dlstrlb UnaHended btsblb UnaMnded
161 .OO 3450 115 # t3.80 115 00 13 80
115 00 13 80
101.00 13 80
11500 34.50
161.00 13 aol
1 Dlrhb. Unattended I It5001 2.401
1 Distnb. Unattanded 34 501 13 801 ~~ ~
Distnb. Unattended 34 50 2.40 !~istnb. UnaReMed 115.00 13 80
IOtstnb. UnaKandsd 11500 13.80
I Oistnb. Unattended 115 00 13.80
IDlshnb Unattended 115 00 13 80
thstnb. Unattended 34.50 Y3 85 [hatnb. Unattended 115 00 I3 80
33 34 35
36 37 38
DELIGHT DELLCITY DERMOIT
DESARC D E V A U B L U F F DEWIlT
Enlergy Arkansas, In%
7 1 25 i 6 1 63 3
INlU, UL, 111 b d 01 ZU1YU4 I t
I Report below the Information d e d for concerning substatlons of the respondent as ofthe end of UIO year. 2. Substations which serve only one Industrial or street railway wstomer should not be fisted belm. 3. Substations with mpacitles of Less than 10 MVa except those servlng customers with energy for resale, may be grouped according . to functional eharader, but the number of such substations must be shown. 4. lndlcate In mlumn (b) the frrnelional character of each substalIon, deslgnatlrrg whether Iransmissloon or distribution and whether attended or Unattended. At the end of the page, summarlre according to function the capacities reported for the Indivldual stalIans In column (9.
34 GREEN FOREST S0Utl-l Dlstnb. Unattanded 35 GREENBRIER Dlshb Unattended 36 GREENWAY Distnnb Unattended 37 GRIFFlTHWtLE Oistnb. Unananded 38 GUION Dmtnb. Unatlandad 39 GURDON Dismb. UnaKanded 40 H.S. EAST Datnb. Unanended
Name end Locatlon of Substation
361 .OO
161.00 34 50
t 15.00
1a1.00
Character of Substabon I
13 80 13 81)
4 80 13.80
13 BO
VOLTAGE (In MVa)
Prlrnary 1 Secondaty I Terllary
115.00 13 80
115 00 13.80 115 W 13 00
115 MI 1380 115.00 13 80 iM.00 tJ.80 I15 00 13 80
11 5.00 13.60 115.00 13.80
115 00 13 80 115 00 13 80
115 w I 3 80 115 00 13 80
11500 t3 80 -1 61 .ooy 34 501
lSl.OO] 13 801
? 15.00. 13.80 t81.00 13 80
t61.00 13 80 i t 5 OQ 13 80 11500 13 ao 161.00 13.80
-1Sl.OOl 13.801
13.80
11500 101.00 13.80
161.00
I15 00 13 80
FERC FORM NO. 4 (EDf3. 12-96) P a w 4262
I Entergy Arkansas. In& , .-, , , SUBSTATIONS (Conbnued)
5. Show In columns {I), 0, and (k) speelal equipment such 85 rotary converters, rectifiers, condensers, ete. and aWitjafy equipment for
6. Designate substations or major items of equipment teased from others, jointly owned wlth others, or operated otfierwlse than by reason of sole ownersMp by the respondent. For any substation or equipment operated under lease, give name of lessor, dale and period of lease, and annual rent. For any substatJon or equipment opemtd other than by reason of sale pwnenhlp or lease, ghre name ,of co-owner or other party, explain bask of sharing expenses or other accounting behrreen the parties, and state amounts and amounts affected in respondent's buoks of account. Specify In each mse whether lessor, -mer, or other party Is an associafed company.
increasing capac'@. - .
Entargy Arkansas, Inc.
1 2
, .-. - SUBSTATIQNS
1. Repod below the information called for concemhg substations of the respondent as of the end of the year. 2. Substations which sew8 only one Industrial or street railway customer should not be listed bdnw. 3. Subshatims with eapacities of Less than 10 MVa except those serving customers with energy for resale, may be grouped a d i n g to funetional charader, but the number of such substations must be shown. 4. Indieate In column (b) the functional character of each substation, designating whether transmission or distribution and whether anended or unattended. At the end of the page, summarize accordhg to function the eapacities reported for the individual stations h column (fj.
(a) (61 (4 (d) (a) H.S. INDUSTRIAL Dtslrib. Unattended 11500 13 80 H.S. MILTON Dktrib. Unattended 11500 13 80
Name and Location of Substation
..
4 5
6
Character of Substation
. . . . . . . . .. 1
HS.NORTH Dnblb. Unattended 115.00 i3.m
H S U O Y A L Dlstrib Unabnded 1 15.00 13.80 HSSOUTH Distnb. Unattended I15 00 13.80
VULTAGE (In MVa)
Primary 1 Secondary 1 Tertlary
H S. VAUEY SfREm H.S. VllLAGE
Dlstnb. Unaltended 11500 13.80
Distnb. WmUentled 115 W 13 80
- . - . . . . . - . - . I 1 1 1
31HS.MT.VALLEY i Dbblb. Unattended 1 115001 13.801
H.S WEST \Dhtrib. Unattended
iHAMLET Dlsblb. Unansnded HARDIN WEST Dhtrlb. Unattended
HAMBURG Mstnb. Unattended
HARDY NORTH Dbknb. Unattended HARRIS8URG Olstrib. Unartended HARRISON EAST Olstrib. Unattended M R I S O N WEST Dlstrfb. Unattended MSKEU Olstnb. Unatlmdad
115 00 i 3 80
11 5.00 13.80 i61.00 2.40
11500 13.80 16t.00 13.80
101 .oo 13.80
t61 00 13.80 181.0C 13.80
11500 13.80
1 I I 7 I H.S. UNtON CARBIDE I Dlrtrh. Unattended 1 1 15.001 i%eol 1
19
20 --21 22
I
HAYS CITY DLtrIb. Unattended 11500 13.00 HAZEN Dlsbtb. Unattended 115.00 13.80 HEBERSPRINGS wnusmw Drstrlb. Unattended 161 .OD 13 BO
HEBER SPRlNGS SOUTH DhMb. Unattended 161.00 13 80
I
1 DiatrIlb. Unattended 11 5.001 t3801. I
I
HENSLEY HERMITAGE (APL) HIGHLAND (APL)
HEHWAY #7
I
- . - -. -. -. . -. . -. . . - . . 1
Dmtnb. Unattended ' 115 00 13 BO
Dlstnb. Unattended 115.00 13.80 DlsLrlb. Unattended 161 .OU 13.80
DIstnb. Unattended 34 50 13-80
I
HlLO Dlstrib. Unattended i t 5.00
I
13 BQ - HUGHES HUlTlG I M 8 0 0 EN
1
Mstrlb. UneKended 181AO 13.80
Dlsbib Unattended 11500 13 80 t
Dbbb. Unattended I 69 00 34.50 p 32
1 I I I FERC FORM NO. I {ED. $248) Faas 4283
I 1 1 I 1 I
I. Report below the information catled for concerning substations of the respondent as of the end of h e year. 2. SubsBUons whlch serve only one indusln'al or street railway customer should not be listed ~ I o w . 3. Substations with wpacities of Less than I O MVa except those serving customers with energy for resale, may ba grouped according to functional character, but the number of such substations must be shown. 4. Indieale In column @) the functional character of each substation, deslgnating whether transmission or distribution and whether atlended or unanended. At the end of !ha page, summarize according to hmclion Ihe capacities repotled for the Indivldual stations In column (0.
37 38 39 40
u7 NO.
L U N S F O A O ~ Dlstnb. Unaltendedpp 69 00 13 80 MAEIELVAEEHV Distnb. Unattended 11500 13 80 MAGNOUAWW Distrtb. Unattended 11500 13 80 MAGNOLIAEAST Dtstrlb. Unattended 115.00 13 80
Name and Location of Subslation VOLTAGE (In ma)
Character or SubstaUon
1 KUHN ROAD IDIsbib. Unattended 161 001 13 801 LR 145THST 1 Dtsb-ib. Unattended 115 oal 13.801
FERC FORM NO. 1 (ED. 12.961 P a m 425.4
Entsrgy Arkansas, Inc Endof 2013M4 LMO, IJd, 1 IJ
I t
I 33 I 30
1 32 23 2 3.1
13 55
83 100
~ ~ 22 1 2 23 2 24 2 25
~~
,.-.- -- ..--r--.--..-
Enlergy Arkansas, Inc
Nams and LocatIoo afSubstation
Endof 2 0 ~ Q 4 (Ma Da, Yo I I
$U BSTATIONS
1. Report below the Information d i e d for coneernlng substatrons of the respondent as of the end of the year. 2. Substations whkh sewn only one industrial or street railway customer should no! be listed below. . 3. Substations with eapacities of Less than I O MVa except those servhg customers with energy for resale, may be grouped according to functional charader, but the number of s u d ~ substations must be shown, 4. Indicale In column (b) the funelionat: character of each substallon, dedgnating whether transmisslon or distributiun and w h e h r a!tended or unattended. At the end of the page, summarfie acwrding to fundon the =pacities repofled for the Individual statlons in 1 column (n.
(a1 1 MAGNOLL4 SOUTH 2 hlAGNOllASTEEL 3 MAGNOLIAWEST --
15 MARVEIL 16 MAUMEUE EAST 37 MMWONr t B MCCRORY 19 MCGEHEE
20 MCNEltEHV
21 MELBOURNE
Dbtrfb. h 8 t h I d & 115 00 13 ao Dhtnb. Unananded 115.00 13.80
OlMb. Unattended 11 5.OO 13 80
,DLblb. Unattended 34 50 1240 ,Dlslnb. Unattended 34.50 2 4 0
1 DlstrIb Una!tended 1 15.00 13.80
Uhtnb Unattended 161.00 13 80 Dlstnb. Unattended t61.00 13.80 Dktnb. Undlended 34.50 1240
;Olstrlb. Unattended 34.50 1 2 4 0
/Dlatrlb. Unattended 161.00 3 50
VOLTAGE (In Mva) Charscbt of Substatlon
4 MAtVERNNORTH 5 WVERHSOUTH
6 WltA 7 W S O N 3 4 . 5
8 MhRlANNh 9 MARION .-
la WEDTREE 11 MARMADUKE I2 MARMADUKEARI 13 MARMADUKE RAIL 16tKV
14 MARSHALL
Drshb. Unattended I 115001 13 BO)
IDIstrib. UnaKerided 1 11500l 13.801 MsMb. ltnallandect t 15.00
Dlstrib. Unattended 161.00 Dbtrlb Unathnded 115 00
iDtsblb. Unattended 11500 1380
29
MOUNTAIN VIEW Dlstrlb. Unattended I61 .OO 13 BO MT IDA Climb. Unattended 11 5.00 13 ao MT PINE NORTH Msbib Unattended 11500 I 5 00
MT PINE SOUTH DIshb. Unattanded 11500 13 80
N L R. DIXIE DIstrIb Unatlanded 115 00 13 80
N LR LEVY DlstrIb. Unattended 115 00 13 80
FERC FORM NO. 1 IED. 12461 Prrw 426.5
. . 1
SUBSTATIONS {Contaued) 5. Shwv In columns (I). 0). and (k) spedal eqqdpment such 8s rotary converten. rectfien, condensers, etc, and auxifiary qulpment for lncreashg w pacity. 8. Designate substations or malor Rems of equipment leased from olhen, Ioltntly owned With others, or operated oherwlss than reason of sole ownership by the respondent. For any substation or equipment operated under lease, glue name of lessor, data and period of lease, and annual rent. For any substation or equipment opemaled other than by reason of sole ownership or lease, give name of m e r or oRer patty, explain bask of sharing expenses or other accounting &tween the parties, and state amounts and acwunts aReded In respondent's books of amount. Speaiy In each wse whelher lessor, m e r . or other party Is an assodated company.
. . . . . . . . . . .. t t
7 OIA Oistrtb. Unattended 11500 13.80
8 OMAHA DMb. Unattended I61 .OO
9 OSCEOLA Dsttlb. Unattended 181.00 13.80
10 OSCEOIA INDUSTRIAL Olstrib. Unattandcd 161.00 13 80
---- - ..
1 I I 2 1 N LR WESTGATE I Dbtd b. Unaftended I 115001 13801
Una No Name and Locatlon ol Substatron
E
VOL'AG E (In ma) Characlsr of Substauon
Pdmay I Sewndary 1 Tertlary
I NEWARK Dlstob. Unatlended 161 .OO 13 m NEWPORT Dlstnb. UnaRended 161.00 13.80 NEWPORTAB Diskltlb. Unattended 161.00 13 80 N M O R T IND DisbIb. Unattended 161 00 13 80
11 12 13
OSCEOIA NORTH DlsMb. Unabended 161.00 t3 80
P B . 3 4 M L W N Distnb. Unattanded 115 00 13 80
P8.ARSENALD Dmtrlb. Unattended 1 15.00 13.80 t
14 15
I Olstnb. Unattended I 1 t5 001 13 801 16 I P.B. INDUSTRIAL 17 1 P 8. MCCAMANT I Illstrib. Unattended i15Od 13 801
P.B. DIERKS OIstnb. unattended 11500 13 80 P . 8 . M Dhtnb. Unattended 11500 13 ao
. .
18 19
. . . . . . . .
PB.PORT Dlstnb. Unananded 115.OD 13.00
PB.SOUTH Dlstdb Unattanded t 15.00 13 ~ ( 1
1 Distnb. Unattended I 1 15 001 12.401
1
20 1P.B. WATSON C W E L 21 f P B. WEST
25 26
27
- -
Dlstrlb. Unatlanded 115 00 1380 Dlsbii. Unattended 115.00 13.80
PARKIN POCAHONTAS NORTH POCAHONTAS SOUTH
Dlstnb. Unattended 161.00 13 a0
Ofstrlb. Unattended 161 00 12 40
Orstrlb. Unattended 34 sot 1240)
28 29 30
PORTIA Disfnb. Unattandad 24 50 2.40
POYEN DlsMb. Unanended I15 00 t3 ao PRESCOIT Dlstnb. Unatlendcd 11500 1380
I I 0 I I
PROMISED lAND Q U N RECTOR REYNO RICHWOOD RISON RlTCHlE SES PIAM ROHWER
D a r n . UnaHanded 34 50 t2 40
Distnb. Unattanded 161 .OO 13 80
Distnb. Unattanded 161 .QO 1240
Oatnb. Unattended t t500 t3 80
DIstnb. Unamndsd I t500 t 3 80
Otstnb. Wnabnded 230 00 13 00 Oistrtb Unatlended 115 00 13 ao
Dlstnb. Unattended 34.50 4 ao
39 40
1
RUSSEUVlUE EAST Dlstnh Unatfended 161 9 0 13 80
RUSSELLVILLE NORTH Otstrib. Unattended 161 .OO 13 ao
Increaslng capacity. 6. Designate subslations or malor Hems of equipment leased from others, Jolntty &ed with others, OT operated othenvlse ban by reason of sole ownershlp by h e respondent. For any substallon or equipment operated under tease, ghre name of lessor, date and period of leasa, and annual rent For any substation or equipment operated other than by reason of sole ownership or lease, give name of m n e r or olher party, explain bask of sharing expenses or other accounting between the parties, and state amounts and amunts sffeefed In respondent's books of account. Specify In each case whelher lessor, mowner, or other party is 3n assodated company.
End of 2013Q4 {MU, ua, yrj . . - . - . . .
Entergy Arkansas, Inc I !
I. Report below the Information calted for concerning substations of the respondent as of the end of the year. m2, Substations which s e m only one industrial or street mlhvay customer should not be tisled below. 3. Substations with mpacities of Less than 10 MVa except those serving customen with energy for resale, may be grouped according to functlonat character, but the number of such substations must be 5hown. 4. Indicate In column @) the functional character of ea& substation, deslgnatlng whethertransmisslon or distribulon and whether a!tended or unaltended. At the end of me page, summarize acmrdjng 10 fundtion the wpacitIes reporled for the IndivIduat stations In
SU BSTATI 0 NS
Name and Locatbn of Substalbn Character of Substatlon
FERC FORM NO. 3 ED. 12.881 Paaa 426.7
(MO, ua, YI) E n d d 2a13JQ4 . . .
Entergy Arkansas, l n c I I SUBSTATlONS (Continued)
5. Show In cotumns (I), o4 and (k) spedal equipment such as rotary CoMlerlm, r d f i e r s , condensers, etc. and auxllary equipment for Increasing mpaclly. 6. Deslgnate substations or major Rems of equlpment leased from others, jotntly m e d with others, OF opemkd othewlss than by reason of d e ownership by the respondent. For any substation or equlpment operated under lease, give name of lessor, date and period of tease, and annual rent For any substation or equlpment werated other than by reason of sole ownership or lease. give name of c m e r or other party, explain bask of sharing expenses or other accounting between the parties, and state amounts and accounts af€efeded In respondenh books of amount. Specify In each mse whelher lessor, cmwner, or other party Is an associated company.
1, Report below the Inlormatlon =!led for concembg subslatlons of the respondent as of fie end of the year. 2. Substations whlch serve only one industrial or street rallway customer should not be listed Maw. 3. Substations wllh WpacIttes of Less than I O MVa except hose se&g wstornew with energy for resale, may be grnuped according to functional character, but the number of such subslations must be ahawn. 4. Indicate In column @) the fundonal character of each substation, designating whether transmission or disbin’bution and whether attended or unatlended. At tho end of the page, summarkze according to fundon the capadies reporled for the Individual stations In column (9.
18 19 20 21 22 23 24 25
26
I /Una I No.
DELEHV ELDOWOOEMI
HS.EHV INDEPENOENCE-ISES JIMHILL LRPINNACLE LAKEVILMGEBAGBY MABELVALEEHV MAY FLOWER EHV
Name and Location olSuhstatbn
Trans Unattended ,Trans UflaKended
VOLTAGE (In MVa) Chanetsr of Subdabon
500 M1 115 00 500 00 115 00
18 1 DANVILLE (APL)
ITranr Unattended mi ao
17 lOAm0
161.00 1 Tmns Unattended 1 Tmns Unatlanded
Trans Unattended I 1Sl.Wl 115001
181.00 11500 361.00 115 00
1Tranr Unattended 230.00 Trans UnaKendgd 500.00
I Trans UnaKended I 500 00
I t 5 0 0 - $15 0 11500
27
28 29
MCNEILEW MOSESSES MURFREESEORO SOUTH ITrans Unittended I 138.00l ~ 11 5.001
p a n s Unattended Ifrans. Unattended
500 00 115 00
IS1 00 f t5 00
I I I I I
30 PARAGOULD Trans Unaasnded 16f.OD 11500 31 PLEASANTHILL Trans Unanended 500.00 16I.00 ------ 32 RITCHIE SES SWlTCHYARO Trans UnaRanded 230 00 115 oo
Entafyy Arkansas. Inc. End of 2013lQ.d
5. Show in columns (I), Qr and (k) specia! equipment such 8s rotary eonuerten, rectifiers, condensers, etc. and auxiliary equtpment for Increasing capacity. 6. Designate substations or major items of equlprnsnt leased from offlers, jointly owned with others, or operaled otherwise than by reason of sole ownership by he respondent For any substation or equipment operated under base, ghre name of lessor, date and p e d d of lease, and annual rent. For any substallon of equlpment operated other than by reasan of sole ownership or lease, give name of cwwner or other paw, explain basis of sharing expenses or other accounting between the parks, and state emounts and accounts affeded In respnderfs books of account Spew In each case whether lessor, CpOwIIer, ar other party Is an assndatd company.
1. Report below the InfurmatIon catled for concernbg substaliom of the respondent as of the end of !ha year. 2. Substations which serve only one lndustn'al or streel railway customer should not be listed below. 3. Subshtlons with capacXe3 of Less than I O MVa except hose serving cuslorners with energy €or resale, may be grouped according lo functional character, but the number of such substatIoons must be shown. 4. Indimfe In column @) the functhnal chawcter of each substation, deslgnating whether tmnsmlssbn or distribution and whether atlended OF unaHended. At the end of the page. sumrnafko according to function the rapacltiea reported for the individual stations In wfumn (9.
[Uns NO,
1 2
3
VOLTAGE (In Mva) Primary Secondary Tefflary
Name and Locatlon of SubsLatlon Character of Substation
(a1 Ibl Id Id) I d WOODWARD (Trans Unaltanded 230 00 I 15.00
TotalCapaW 1 48294.70 8290.50 WRlGtrrSVllLE )Tmns Unattended 500.00 11500
[Uns NO,
1 2
3
VOLTAGE (In Mva) Primary Secondary Tefflary
Name and Locatlon of SubsLatlon Character of Substation
(a1 Ibl Id Id) I d WOODWARD (Trans Unaltanded 230 00 I 15.00
TotalCapaW 1 48294.70 8290.50 WRlGtrrSVllLE )Tmns Unattended 500.00 11500
----. 21 22 23 24
25 26
5
8
7 8 9
10 '11
1 1
28 I 1 29
Dtstnbubon Unatlended 331 Transmission Unatlended 3t
EASED SUBSTATIONS MARKMAN FERRY -M4RKMAN FERRY, OK Trans. Unattanded i61.00 115 W ARKLAHOMA "A' - JONES MILL, AR Trans. Unattended 115.00 13.80
I
30 31
1 32 33 34
Entergy Arkansas, Inc An Orlglnat A ReaubmIssln . . . . . 1 . . , ,
SUBSTATIONS (Cootmued)
5. Show in columns (I), 0. and (k) spec ia l equipment such as rotary conveden, redfiers, condensers, eic, and auxiliary equipment for ncreasing apacity. 3. Designate substations or major items of qulpment leased from others, jointly owned with others, or operated otherwlse than by reason of sole m r s h f p by the respundent For any substatlon or equipment operated under lease, give name of lessor, date and perIod of lease, and annual rent. FDr any substation or equipment operaled other than by reason of sob ownershlp or tease, give name of coowner or other party, explain basis of sharing expenses or other acwunting between the parties, and state amounts and aecounts affeeted in respondent's books of account Specify In each case whether lessor, m o w e r , or other party Is an associated company.
t
39 40
+
Name of Respondent This Report is: Date of Report (Po, Da, Yr) (1) XAn Original
Entergy Arkansas, Ine (2) I A Resubmission I I
bchedule P a w 428 Une No.: f Column: a 1 These substations are jo in t ly leased from t h e Arklahoma Corporation by Entergy Arkansas and other owners of t h i s Corporation beginning December 9 , 1947 and automatically renewed annually. Comon stock of the Arklahama Corporation is jointly owned by Entergy Arkansas (34%), Oklahoma Gas and Electric (34%), and Southwestern Electric Power Company (32%). Operation and maintenance expenses are reported in total . in the transmission l i n e schedule,
Bchedde Page: 428.9 Une #o.: I Column: a 1 These substations are j o i n t l y leased from the Arklahoma Corporation by Entergy Arkansas and other owners of t h i s Corporation beginning December 9, 1947 and automatically renew annually. (34%}, Oklahoma Gas and Electric (34%), and Southwestern Electr ic Power Company (32%). Operation and maintenance expenses are reported in total in the transmission line schedule I
Comon stock o f the Arklahorna Corporation is jointly owned by Entergy Arkansas
YearlPenod of Report
20tw4
[FERC FORM NO. 1 (EO. 12-87) 3 Page 42M27 Footnote.1
BLANK PAGE
Y a m ol n~syurluullL
Eniergy Arkansas, Ine
Z.The' repohing threshold for reporting purposes is $250,OW: fhe 6reshdd sppnes to the annual amount billed to b e respondent or billed to. an assodatedlaffillaled cornDanY for now-Dowr 11oods and servlccs. The Qood or servlca musth lpeciflc In nature Respondents ahould not
iir z.@G '-.dgfnal - . (MO. aa, Y i j End of 2013144 (2) n A Resubrnlsslon I t
TRAHSACTIONS WITH ASSOCWTED (AFFIWTEDJ COMPANIES - 1. Renort M o w the Informabon wtled for concernlna all nonooweramds or smtces received from or Dmwdsd to assoaated (affillatedl w~npsnies.
I 1 1
ammpt to [nctuda or aggregate Lrnounts In 8 noiispacWc megory such a i 'genetar. 3. Where amounts blllad to or receiwid from Ute assodaled {affiliated] company are based on an a1tcGNon pmcsss. exphb In a IboOuta.
Une AssodatedlAffillated Charged of Charged or No. Desuiptlon oftha Non-powclr G o d or Swlm
1 Non-power Goods or Services Provlded by AIflllated
3 See botnota kraflocatlon method dstatIs.
Nam of ACCOU nt Amount
Company Credtled Credtted (GI .. (4 Ib)
2 Sea foolnok krschedub detah. I I ,
71 I I I at I
22 23 24
25 26
I t2 13 14 15 16
*
30 39 40
41 42
. .
Name of Respondent This Report Is: Date of Repart YearlPenood of Report (1) &An Original (Mo, Da, Yr)
Entergy Arkansas, Ink A) A Resubmisslon I I 20131c14 \
pchedule Page: 429 Une No.: 2 Column: a I
Account Charged or Credited
Entergy service companies, including Entergy Operations, Ine. and Entergy Services, Inc., provide recurring, ongoing services t o Entergy affiliates, Service company transactions are reported in t h e schedule below by type ~f categoryr where the amount charged or credited fo r each category is equal to or greater than the $250,000 threshold. All other Non-service company affiliate transactions reported in this schedule, if any, ate reported by individual detailed transaction.
Amount Charged or Credited
fne lo.
Deacrzptdon o f the Hama o f Non-Power Good or ZUsociated/A€fiLiated
Service Company I la) t bl I (el i (d)
Ikon-nower Goods or Services Provided bv Affiliated 2
3
4
5
Corporate Support - General
Nuclear - Regulated
Nuclear Corporate s upp 0 r t
System Benefits
.07000, 163000, 174200, !53107, 40B110, 408122, 108123, 400142, 42650Tt 1265'3x8 517000, 519000, i20000, 524000, 528000, m O O 0 , 530000 S31000,
330200 i32000, 920000r 926000,
- a
;nt erg y Operations, ne.
4,294 I 840
:ntergy Operations, :nc
174200; 253107; 42650T; 524000, 926000 L07000, 163000, 174101, 174 104, 174200, 184001, 408110, 421000, 426400, 426500, 431000, 454000, 500000, 506000, 507000, 5110001 51400OI 517000r 520000, 524000, 525000r 528000, 529000, 532000,
569000, 573000, 575201,' 580000, 588000, 589000, 591000, 590000, 070000, 880000, 886000, 8940001
560000, 566000, 568000,
9010001 907000, 9090001 910000, 92OOOO, 921000, 923000, 926000, 930200, 930210, 931000, 935000 107000, 174 101, 2531071
htcrgy Operations, :nc.
3,670,237
1,079,866
htergy Operations, :ne.
7
Zntergy Services, :nc.
Capital Project 3ntergy Services,
t74200, 253107, 12650T, 4265!CX, 519000, 520000, 528000, 529000, 531000, 532000, 321000, 926000
,53107 4 08110, LO70001 1630001
!265TX, 517000, ;28OOO, 531000,
408110,
524000, 530000, 92 0 0 00 I
5170001
174104 8
42650T, 524000, 532000,
320000, 925000, 926000 I 107000; 163000, 174104, I 24 I 229,023
Page 429 Footnote.1 - . .-
rf Respondent This Report is: Date of Report (I) An Original (Mo, Da, Yr)
'Arkansas, !ne. (2) I A Resubmisslon i i FOOTNOTE DATA
Zxcel lenee Inc.
2hief Entergy Services, kdministrat iva he. 3 f f ices zorporate - Legal Entergy Services8 Servl ce s fnc.
Eorporate - Office Entergy Services, of khe Chief Inc. Executive Officer
Corporate - Public Entergy Services, Relations 3nc.
Corporate Support Entergy Services, - General Inc.
108110, 426500, 42650TI 1265TX1 500000, 506000, i12000, 519000, 517000, i24000, 560000, 566000, 320000, 921000, 923000, 326000, 930200 108110, 426100, 426500, 320000, 921000t 923000, 326000; 930200- l.07000, 174101, 174200, L81CPDI 228100, 253107, 108110, 426400, 42650Ti 1265TX; 506000, 524000, j600001 566000, 920000, 321000, 923000, 9260008 328000, 930200, 931U00, 335000 184001, 408110, 426400, 126500; 920000, 921000, 323000, 925000, 926000, 130100, 930200, 9310001 nsoao L07000,
426100, L84ESTI
500000, 909000,
926000, 930200, 107000, L63000,
920000 #
L74200, L 6 4 0 FS, 186AM1, 253107, r108152, 426400, 4265TXI 506000, 513000, 519000, 528000,
541000,
557 000, 561100, 561500,
531000,
5 5 IO 0 0,
566000, 569100, 580000, 584000,
593000, 596100, 901Q00, 903002,
m o o o ,
134101, 228100, 426400, 517000, 9 1 O O O O r 921000, 928000, 931 000 8
108220, 17 4101, 181CPD, 1840NCI 220100; 4c31RM, 4212AMt 426500, 430000, 510000, 514000, 5200oc, 528001, 532000, 54 6000 553000, 5600001
561600,
570000,
5 61200
56B000,
5a1000, 586000, 590000, 595000, 597000,
905000, 902000,
174104, 4081101 426500, 908000,
923000, 9301001 935QQO 108230, 174109 184 001, f84ESTt
9130008
2284 00 , 408110, 426100, IEGSOT,
S l Z O 0 O l 517 000 , 530000,
549000, 556000,
500000,
5240008
5350008
5610001 561300,
5 69000,
533000,
592000,
5980001
562000,
575201,
~ 7 0 0 0 ,
596000,
903001, 907000,
YearlPeriod of Report
2013504
376, 627
11, 458, 457
650,551
3,741,711
19,912,881
Page 429 Footnote2
Respondent
Irkansas. Inc. i . -
I t I(2j I 4 Resu bmission 1 FOOT NOT^ DATA
908000, gogooo, 9iooao, 912000, 916000, 920000,
925000, 926000, 928000, 9 2 1 O O O y 9230001 924000,
930100, 930200, 930201,
ustorner Service upport
- nc .
list ribut i o n
184EST; 253107, 408110, 4265OTt 4265TXr 560000, 580000/ 586000, 587000, 588000, 901000, 902000, 403001, 903002, 905000, 907000, 910000, 913000, 9160001 920000, 9210008 m o o o , m o o o , 931000,
?hanee - Finance tnd Accounting
Finance - In format i o n reehnology
F o s s i l Operations
I FORM NO. 1 {ED. 12-8'
Date of Report (Mo, Da, Yr)
1935000 nterav Services. 1107000, 174101, 184001,
htergy Services, :ne.
1935000 1107000, 174101, 184001.
42650T, 426STX, 560000, 561200, 568000r 569000, 580000, 581000, 588000, i40000, 591000, 5920001 i98000, 903002, 320000,
I
Cntergy Services, Xnc.
Entergy Services, Ine
126000- .07000# l63000t -74200, 181CPDI .840FS, 1840NCl
1081231 4082021 126400, 4265008
!28100, 253107,
1265TX, 500000, i60000, 56800OY i98000, 901000, 303002, 905000, 320000, 921000, 3240001 925000, 328000, 9301001 330201. 931000.
1741011 104001, 18 4 EST 408110, 426100, 4 265OT0 506000, 580000, 903001,
923000,
930200, 935000 .
908000,
92 6000,
* .
107[1008 163000, 1741010 174104, 174200, 184001, LBGRMl, 228100, 253107, IOEllQ, 426100, 42650Tf
5060000 5 O 7 O O O j 514000,
532000, 539000t 54 9000, 550000, 5 S 4 O O O j 556000, 560000, 561200, 566000,
4265TX, 454000, 5000001
517000, 524000, 525000,
567000, 568000, 569100, 573000, 580000, 588000, 589000, 598000, 901000,
907000, 908000, 910000,
923000, 926000, 930200,
107000, 152000, 163000, 1741011 184OFS, 253107,
9020001 903001/ 903002,
916000, 9200001 921000,
931000, 935000
fearlPerhd of Report
2013Q4
9,862,879
396,169
2 0 , 5561395
Page 429 Footnote3 - .+
' Respondent
mansas, he.
~~
Entergy Services, 1070001 174101, 184001, Inc. 228100, 253107, 1108110,
426100, 426500, 42650Tt 4265TXp 5000001 506000, 517000, 524000, 560000,
913000, 920000, 921000, 923000, 926000, 928000, 930200, 931000, 935000
Entergy Services, 107000, 163000, 174101,
573000, ~ E O O O O , EMOOOO,
Inc. 174104, 1840NCI 2531071 4081101 4082021 426100, 42640U, 4265OT, 4265TX, 517000, 519000, 520000, 524000, 525000, 528000, 529000, 530000, 5330001 532000, 903002, 920000, 921000, 926000, 930201
' ~n tergy Services, 107000, 174104 253107, I Tnc I 408110, 42650T1 4265TX,
:man Resources
408110, 42650Tl 506000, 511000 , 514000, 541000,
566O0Or i923000, 1931000
551000,
luclear Corporate ;uppor t
RTO Implementation
Supply Chain
System Benefits
FORM NO. 1 (ED. 12-87)
qucle ar Operation:
431000- Entergy Services, 107000, 184001, 253107, Inc. 408110, 426502, 4265TX,
500000, 506000, s56000,
921000, 923000, 925000,
931000 '
560000t 5660001 920000,
9260001 928000, 930200,
Entergy Services, 107000, 108220, 108230,. Inc. 163000, 174101, 174200,
228100, 253107, 408110, 42650Tt 4265TXJ 500000,
580000, 586000, 508000, 50 6000, 512000 , 5600001
420000, 92l000, 923000, 926000, 930100, 930200
Entergy Services, 101000, 108220, 108230, fnc. 163000, 174101, 1741040
7
Dperations and Perf omance
\This Rtknort is: I Date of Report ( I ) % A i Original (Mo, Da, Yr) (2) P Resubmbsjon / I
FOOTNOd DATA
1 (Mo, Da,Yr) / I ((2) pl Resubmbsjon 1
FOOTNOd DATA
426400, 4 2 65TX 1
507000, 512000, 535000, 54 6000, 553000,
926000 920000,
426500, 500000, 510000, 513000, 539000, 549000, 560000, 922000, 930200,
517000, 524000, 528000,
430201 920000, 9210001 926000,
1
Entergy Services, 1070001 17410Lj 184001, Ine. 184ESTn 253107, 408110,
426100; 426400, 426500t 42650T, 4265TX, 500000, 506000, 5600001 5660001 580000, 920000, 921000, 923000, 926000, 930200,
'earlPetiod of Report
20131Q4
71 451,252
13,734,796
498,097
2,7361106
6,062,375
3,7391 402
23164 4 t 075
Page 428 Foofnote.4 -. . .
me of Respondent $zz-
3 1 8 9 7 1 8 9 2
This Rhport Is: (1 1 X A i Original
Date of Report (Mo, Da, Yr)
(2) P, Resubmisslon I I FOOTNOd DATA
;ystem Planning
YearlPeriod of Report
* 2Q131Q4
ax And Interest xpense
Entergy Services, I
ransmission
1 - 25
-
k i l i t y Managemen ind Support i e r v i e e s
28iOO; 253107; 408110, 26100, 4265OTi 4265TXI
07000, 514000, 556000, 57000, 561200, 908000, 16000, 920000, 921000,
54000, ~ O O O O O , 5omao,
23000. 926000, 928000, I
Jti l i ty Support - 3i s tr fbution
30206; 931000; 935000 ! 08122, 408123, 408142,
I 926000, 931000 1 07000, 163000, 174101, 1 5,938 077
,n tergy Services, nc.
:ntergy Services, :ne.
3ntergy Servicest Inc.
Entergy Services, Inc.
08152, 40ai65, 409ii2, 04114, 410101, 410120, .llllO~ 411120, 4114301 ;19000, 419011, 426310, i30000, 431000 .O7OOO. 108230, 174101, .j,ioo; i s eoo i , I ~ ~ E S T , !28100, 253107, 408110,
iOO000, 560000, 561100, i61200, 561300, 561500,
i6700O8 568000, 569000, 569100, 570005, 571000, 573000, 535201, 580000, 582000, 588000, 589000# 590000, 592000, 593000,
126100, 4265OTt 426STXt
i61600, 5620001 566000,.
303001, 920000, 9210001 323000, 926000, 9280001 930200 107000, 174101, 1142001
426100, 426500, 42650Tt 4265TXp 517000, 560000, 580000, 588000, 903001,
916000, 920000, 9 2 1 O O O t 9230001 926000, 928000, 930100. 930200, 931000,
imoo i , 253107, 4 o a i i a ,
909000, 412000, 413000,
253107,
580000, 589000, 5 9 5 0 0 0, 548000, 921000, 92 6000
42 65PX,
935000' 107OOOt 174101, 184001, 1840FS, 184QNC, 184ESTt 2284001 42650TI 5660001 5 8 8 0 0 0 s91000, 596100, ,920000, 1925000, 1935000
4081101 5600001 5 8 7 0 0 0, 590000, 596000, 916000, 923000) 930200,
21 289,295
221 276,162
[FERC FORM NO. I (ED. 12-87) I
Page 429 Footnote.5 - _ - -
Name of Respondent This Report is: Date of Report (Mo, Da, Y r) (1) XAn Original
Entergy Arkansas, fnc. A Resubmission I t
YearlPeriod of Report
20131Q4
30
31
Utility Support - Operations
Customer Service Support - Provide Call Center
Support - Repairs, Coordination and Management of Storm Restoration- Distribution Support - Return meters to stores inventory. Fossil Operations - Provide Operations ,Supervision. 'Fossil Support - Ouachita Plant Operations and
36 Support:. Inventory Transfers of Materials and
38
39
40
Support - Repairs, Coordination and Management of Storm Restoration. System Benefits Support - Design and administration of benefit plans. Inventory Transfers of Materials and Supplies. Storm Distrfburior Support - Repairs, Coordination and Management of Storm Restoration. Storm Distributior Support - Repairs, !Coordination and /Management of
Entergy Texas, Inc, 408110, 903001, 926000
7531 721 107000, 174101, 1f14ESTI 253107, 40B110, 42650T, 4265TX, 560000, 561500, 580000, 588000, 589000, 593000, 903001, 511000, 916000. 920000, 921000,
:ntergy Services, :nc.
1423000; 926000; 931000' :ntergy Gulf States 1408110, 903001, 926000 477,384
721,200
iouisiana, L.L. C.
Icontact. 321Storm Distribution
iouisiana I L. L ,C. 926000
- 33
- 34
- 35
(3091 172 _ _ LLC
I
Zntergy Louisiana, 1408110, 546000, 926000 307,021
2,188, 521
2 , 277,939
I# 665,655
. f _ I
..._
3ntergy Louisiana, LLC
163000, 408130, 546000, 540000, 549000, 551000,
1553000, 920000, 926000
154PAs Entergy Louisiana, LLC
Enrergy Louisiana, LLC
I Encergy Louisiana, 11630008 926000 3 4 4 , 924 LLL
1
Entergy Mississippi, (154PAS 375,888 fnc.
562,466 Entergy M i s s issippi, Inc.
- 41 253,7 99 17410L, 408110, 920000,
926000 Entergy New Orleans, he.
Storm Restoration.
Support - Provide 32gY 652
:ER FORM NO. 1 ED. 12-8; 7 I 4 -
Page 429 Foohote.6 .. - -
4 5
Call Center Contact. Storm Distribution Support - Repairs, Coordination and Management of Stcrm Restoration,
Entergy Texas, Inc.
Non-power Goods or Customer Service
' I.
SeAcQs Provided for Zntergy Gulf States
Support - Truck !stock lighting and materials
4 6
4 7
4 8
4 9
Support - Provide Call Center Contact - Customer Service Support - Provide Call. Center Contact . Distribution support - Installation of distribution circuit , transformer, and related f a c i l i t i e s and equipment. Distribution Support - Installation of meters, wires, and l ighking. Includf ng maintenance and safety. D i 3 t r i b u t i o n
land compliance, ~Icustorner Service
. 5 0
51
installation. Inventory Trans€ers of Materials and Supplies. Supply Chain Support - Materials testing
Icontact. 541Distribution
53
support: - Installation of
Support - Provide B i l l i n g and Account Maintenance, Customer Service Support - Provide Call Center
FER FORM NO. 1 ED, 12-8; R===
Louisiana, I.. L. C.
5ntergy Louisiana, Zc
lntergy Louisiana, LLC
Entergy Louisiana, LLC
Entergy Louisiana, LLC
Entergy Louisiana, LLC
Entergy Louisiana, LLC
Entergy M i s s i s s i p p i , rnc.
Entergy Mississippi, Inc.
Entergy Mississippi, rnc .
~ r t is: Date of Report Original (Mo, Da, UJ) Lesubmisdon IATA
I I
74101, 408110, 920000, 126000
Ff iliate . 0 8 l l O , 903001, 926000
L07000, 580000
107000, 580000
LS4 PAS, 163000
108110, 586000, 588000, 926000
4081101 903002, 926000
408110, 903001, 926000
107000, 580000
YearlPenod of Report
201WQ4
428,638
_ _
662,987
985,136
518.503
2,010,645
1, 124,961
4,l30,001
317,303
445,507
691,826
530,804
* Page 429 Footnote.7 - .
I
installation. Inventory Transfers of Materials and Supplies . Customer Service Support - Provide C a l l Center Contact. Customer S e r v i c e :Support - Provide 'Call Center kon tac t .
meters, wires, and l ight ing . Including maintenance and
L54PAs
308110, 903001, 926000
308110, 903001, 926000
L54 PAS
Iaafety. 55 I Distribution
l8 310,230
284,704
445,071
667,452
- 56
- 57
- 58
cneral
uclear Corporate Support uclear - Regulated
ystern Benefits
EMPLOEOlr SPLEOIPL, SPLEUNIT EMFLOEOI, SPLEOIPL, SPLEUNLT EMPLOEOI, SPLEOIPLI SPLEUHTT
59
W n i s t r a t i o n
apical Project Excellence
Inventory Tranafcrs of Materiala and
APPSUPAL, ASSTSALL, CAPAOPCO, CUSEOPCO, CUSTCALL, CUSTEGOPr EMPLOFOS, EMPLOREG, EMPLOYAL, GENLDREG, GENLEDm, LBRBILAL, LBRCORPT, LBREXAFFr L3RLEGAL, LVT-tSVCAL, MACCTALL, PKLOADAL, RECDMGNTf SNUCSXTE, SQFTALLC, TELPHALL, TELXGEEJS, TRASUBOP, TRSBLNOP APPSUPAL, ASSTSALL, CAPAOPCO, CUSEGXTX, EMPLOYAL, L B R B I W ,
IThis Rt
3fficer Corporate - Legal Services APPSU PAL, ASSTSALLI CAPAOPC08 COALARGS, CUSEOPCO, CUSTEGOP,
EMPLOFOS, EMPLOREGf EMPLOYAL, EMPLTRAN, EMPLUTOP, GENLEDAL, ITSPENDA, LBR3ILALt EBRCORPT, LBRLEGAL, LBRSUFCN, LBRUTOPN, LOADSYAG, LVLSVCAL, OtINXSFI8 PKLOADAL, RECDHGNT, SNUCUNIT,
FOOTNOTl
Entergy M i s s i s s i p p i , rnc.
Entergy Mississippi, Xnc.
Entergy N e w Orleans, Inc
Entergy Texas, Xnc.
Entergy Texas, Xnc.
Fort is: Date of Report YearlPend of Report 0 rig inat (Mo, Da, Yr} qesubmission ' I t 2013iQ4
Bchedub Page: 429 Uno No.: 3 Column: a I Listed below arc the allocation factors used to allocate c o s t s to the affiliate. Note: Where no allocation factor is provided for the non-power goods o x services l i s t e d on Schedule 429# the costs associated with those goods and services were directly charged and n o t allocated.
Description of tho Cost Alloeator(a) Non-Ponor C o d or S a r d e o
- 1 PKLOIlDAL, SNUCUNJIT- h i e f Administrative IASSTSALL, EMPLOYAL, XTSPENDAl LBRCRPUT? PKLOADAL, SCPSPALL
I
FERC FORM NO. 1 (ED. 42-87) '
Page 429 Footnote.8 ...__
* Name al Respondent This Report Is:
(1) XAn Original EntewRrkansas. lnc. (2) - A Resubmission
*
Date of Report YearlPenod of Report (Mo, Oa, Yr}
I I 2013lQ4
3rpOrate - Office Of t h e lief Executive Officer xporate - Public slations
'inance - Finance and ccount ing
FOOTNOTE DATA
SQETALLC, TEIAGENS, TRSBLNOP ASSTSALL, CUSEOPCO, LBRCORPT, LVLSVCAL, SNUCSITE
ASSTSALL, CAPAO PCO, CUSEOPCO, CUSTCALL, CUSTEGOPr EMPLOREG, EMPLOYAL, LBRBILAL, LBRCORPT, LBREXAFF, LBRLEGAE, LBRSUPCN, LBRUTOPN, LOADSYAG, LVLSVCAL, MACCTALL, PKLOADU, SNUCSITE,
EMPLOCSS; EMPLOY=, LBRUTOPN, MACCTALL, TRSBLNOP CUSEOPCO, CUSTEGOP,
orporate Support - eneral
USXOmer Service Support
PEUOADAL; SQFTALLC; APPSUPALI APTRNALL,
SQFTALLC, TELXGENS, TRSBLNOP RPPSMVSXf APPSUNIXf APPSUPAL, APPSWINTI APTRNALL, ARTRNALL, ASSTSALL, ASSTSREG, BNKACCTA, CAPANWES, CAPAOPCO, CAPXCOPC,
CUSEOPCO, CUSTCALLf CUSTEGOP, CUSTEXTX, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLPRES, EMPLTRW, EMPLUTOP,
CEAOUTAL, COAURGS, COMCMM, CUSEGALL, CUSEGRXT, CUSEGXTX,
FXBWREG, GENLDREG, GENLEDAL, XNSPREAL, ITSPENDA, LBRBILAL, LBRELEDS, LBRBLNUC# LBRCRPUT LBREXAFFr LBRFINAN, LBRIN FOR, LBRLEGAL, EBRSUPCN/ LBRUTOPN, LOADOPCO, LOADSYAG, LVLSVCAL, MACCTALLr MACCTNLA, MACCTXTX, ONNISFI, PCNUMALL, PCNUMXNR, PKLOADAL, FLLOSSAL, PRCHKP;LL, PWRSNUCA, RADIOALL, RECDMGNT,
SCPSPXNC, SCTDSPALI SCTSPALL, SECT263Ar SNUCSITE, SNUCUNfT, SCDSFALL, SCFSPALL, SCLDTMLS, SCMRTRAN, SCMATXNU, SCPSPJILL,
SQFTALLC, TELPHALL, T ~ I N O P , TRANSFND, TKASUBQP~ TRSBLNOP, VEHCLFOS, WHCLNLIC, VEHCLUSG CUSTCALL, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX,
EMPLUTOP, LBRCORPTI LBRFINAN, LBRLEGAL, PKLOADAL, SQFTALLC, TELPHALL, TELXGENS,
EMPLFRAN, EMPLOYAL, EMPLUTOP, LBRCORPT, TELPHALL, TELXGENS, TRASUBOP. TRSBLNOP ARTRNALL, ASSTSALL, ASSTSREG, BNKACCTA,
CUSEOPCO, CUSTCALL, CUSTEGOP, EMPLOREG, , EMPLOYAL, EMPLPRES, GENLDREG, GENLEDAL, INSPREAL, ITSPENUA, LBRBILAL, LBRCORPTp LBREXAFF, LBRFINAN, LBRINMR, EBRLEGALI LBRSUPCN, L3RUTOPNI LOADOPCO, LOADSYAG, LVLSVCAL, OWNXSFI, PKLOADAL, PLLOSSAL,
SNUCSPTEJ SNUCUNIT, SQFTALLC, TELPHALL, TELXGENS, TRALINOF,
CAPAOPCO, CAPXCOPC, CEROUTAL, C O A U R G S , CUSEGRLL, CUSEGXTX,
PRCHKRZ;LI RADIOALL, scmTm# SCMATXNU, SCPSPALL, SECT263A,
FERC FORM NO. 1 (ED. 12-87)
ITRANSPND, TRSBLNOP, EHCLEUS VEHCENUC, VEHCLUSG 'inance - Xnformation IAPPSMVSX. AFPSUNIX, APPSUPAL, APPSWINT, APTIWALL, ASSTSALLl
1
'eehnology CAPAWL; CAPAOPCO; CEAOUTAL; CUSEGRXT, CUSEGXTX, CUSTCALL, CUSTEWL, CUSTEGOP, CUSTEXTXr EMFLOYAL, GENLEDAL, ITSPENDA, LBRBXLAL, LBRCORPT, LBRFINAN, LOAOOPCO, LVLSVCAL, MACCTALL, PCNUMALL, PCNUMXNR, FRCHKALL, RADIOALLI RECDMGNT, SCDSFALL, SCLDTMLS, SCMATXNU, SCPSPALL, SCPSPXNC, SCTDSFAL, SNUCSITE,
Lurnan Resources
luclear Corporate Support
JucLear Operations )Perations and Performance
EMPLOYAL, LBFSfULL, LBRCORPT, LBRFINAN, PKLOADAL, SQFTALLC, TELFHALL, TRSBLNOP, VEHCLFOS ASSTSALL, CAPAOPCO8 CuSTCuL8 CUSTEGOP, EMPLFRAN, EMPLOFOS, EMPLOREG, EMPLOYAL, EMPLPRES, EMPLTRAN, LBRBXLAL, LBRCORPTr LVLSVCAL, PKLOADAL, PRCHKALL,
C 0 S EO PCO , LBRSUPCN, PKLOADAL, SCMATRAN, SQFTALLC, VEHCLUSE EMPLOFOS, SCDSPALLr
ff BRMREG 8
EMPLOCSS, EMPXENUC , SNUCSXTE
SQFTALLC, TRSBLNOP, VEHCLUSG APTRNmL, ASSTSALL, EMPLOY=, XTSPENDA, LBRCORPT, LBRSUPCN, LVLSVCAL, PWRSNUCA, SCFSPALL, SCMATRANI SCPSPALL, SNUCSXTE, SNUCUNIT, TRSBLNOP, VEHCLNUC EMPLOY=, LBRCORPT, SNUCSITE, SNUCUNIT ASSTSALLJ CAPAOPCQ, CUSEOPCO, CUSTEGOP, EMPLFRAN, EMPLOFOS, I EMPLOYAL, EMFLTRAN, LBRBKLLL, LBRCORPT~ LBREXAFF~ LVLSVCAL, I
Page 429 Footnote.9 . . __
\Name of Resmdent I )This Report is: 1 Date of Report IYeadPenod of Report I
PKLDADAL, SCPSPALLi SNUCSITE, TRANSPND, TRSBLNOP RTO Implementation ASSTSALL, CAPXCOPC, CEAOUTALt CUSEO!?CO~ CUSTEGOP, EMPLOYAL,
LBREXAFF, LOADSYAG, PKLOADAL, TRSBLNOP Supply Chain APTRNALLi ASSTSALL, CAPAOPCO, CUSEGXTX, CUS EOPCO, CUSTEGOP
EMPLOYALi ITSPENDAi LBRCORPT, LBRSUPCNI LVLSVCAL, SCDSPALL,
3
System Planning
S y s t e m Benefits ASSTSALL, ASSTSREG, BNKACCTA, CAPAWES; CAPAOPCO, CAPXCOPC, CEAOUTALt COALARGS, COMCLRIM, CUSEGALLl CUSEGRXT, CUSEGXTX, CUSEOPCO, CUSTCALL, CUSTEGOP, CUSTEXTX, EMPLFRAN, EMPLOCSS, EMPLOFOS, EMPLOREG, EMPLOYAG, EMPLPRES, EMPLTRAN, EMPLUTOP, EMFOPCPEl FIBRMREG, GENLDREG, GENLEDAL, INSPREALi ITSPENDA, LBRBIIAL, LBREXAFF, LBRFXNAN, LBRINFOR, LBRLEGAL, LBRSUPCN, LBRUTOPN, LOAWPCO, LOADSYAG, LVLSVCRL, MACCTALL, MACCTNLA, MACCTXTX, OWNISE'I, PCNUMALL, P C N m N R , PaOADAL, PLLOSSAL, P R C H W L , PWRSNUCA, RRDIOALL, RECDMGNT, SCDSPRLL, SCFSPALL, SCLDTMLSt SCMATRRN, SCMATXNUt SCPSPALL, SCFSPXNCt SCTDSPAL, SCTSPALLi SECT263At SNUCSITE, SNUCUNIT, SQFTALLC, TELPHALL, TRALINOP, TRANSPND, TRASOBOP, TRSBLNOPI VEHCLFOS, VEHCLNUC, VEHCLUSG ASSTSALL, ~ P A o P C o i CAPXCOPC, COALARGS, CUSTEGOP, EMPLOYAL,
SCFS PALL, SCLDTMLS SCMATXNU, SCPSPRLL, SCPS PXNC, SCTSPALL, SQFTALLC, TELXGENS, TRSBLNOP, VEHCLUSG APPSMVSXI APPSUNIX, APPSUPAL, APFSWINT, APTRNALL, ARTWALL,
Transmission
Utility Management and Support Services
Cost Allocator Cost AllOCatOr Cost Allocator rleacription 1 T i t l e Entergy Operations, Inc. EMPLOEOI Nuclear South Site Based on Nuclear South site
SPLEOZ PL Nuclear South Plant Based on the number of Nuclear Employees employees
1 -
SPLEUNXT
Lax And Interest Expense
S i tes Nuclear South Units
South Plant Sites Based on the number of Nuclear South Units
istributfon
tility Support -
LBRBILAL, LBRLEGAL; LOAWPCO, LOADSYAG, MACCTALL, OWNISFI, PKLOADAL, SQFTALLC, TRSBLNOP EMPLPRESt LBRBILAL, LVLSVCAL, PKLOADALt TRSBLNOP ASSTSALL, CAPAOPCO, CUSEOPCO, CUSTEGOP, CUSTOEAMt EMPLOYAL, EMPLTRANr EMPLUTOFi ITSPENDAr LBRBILAL, LBRCORPT, LOADOPCO, LOADSYAG, PCNUMXNRi PKLOADAL, SQFTALLC, TELXGENS TRALXNOP, TBANSPND, TRASUBOP, TRSBLNOP ASSTSALL, CUSEGXTX, CUSEOPCO, CUSTEGOP, EMPLFRAN, EMPLOREG, EMPLOYAL, EMPLPRES, KMPLUTOPt GENLEDALr LBRCORPT, LBREXAFF, LBRLEGAL, LBRUTOPN, LOADSYAG, LVLSVCAL, MACCTALL, MACCTNLA, MACCTXTX, PKLOADALI SQE'TALLC, TEEPHALLI TELXGENS, TRANSPNDi TRSDLNOP COMCLAXM, CUSEOPCO, CUSTEGOP, EMPLFRAN, EMPLOYAL, EMPLUTOP, GENLEDAL, LBRCORP'P, LBRFINAN, LVLSVCALi MACCTALL, PKIx)ADAL, SQFTALLC, TELXGENS, TRALINOP, TRANSPND, TRSBLNOP, VEHCLFOS, VEHCLNUC, VEHCLUSG ASSTSALL, CUSEOPCO, CUSTCALL, EMPLFRAN, EMPLOYAL, EMPLUTOPi
pperations- . I MACCTALL, RADIOALL, TRALINOP, TRANSPND, TMUBOP, TRSBLNOP
Entergy Services, fnc. R P PS MVSX Server & Mainframe Based on mainframe usage
Usage (MVSJ
IFERC FORM NO. 1 (ED. 12-87) , - I
Page 429 Footnote.tU . _--
IName of Respondent /This Report Is: I Date of Report IYearlPemd of Report I Entsrgy Aikansas, Inc
(1) x Ar; OtigrnaI {Mo, Da, ur) (2) A Resubmisslon I i 201 3 Q 4
APPSUN IX Server & Mainframe I
APPSUFAL Server & Mainframe Usage ( V M )
Usage - Composite Usage (NTSI
Transactions
APPSHINT Server C Mainframe
APTRNALL Accounts Payable
ARTRNALL Accounts Receivable Invoices
ASSTSALL Total Assets ASSTSREG Total Assets -
Regulated BO'S BNKACCTA Bank Accounts
XPACALL System Capacity - Reg and Non-Reg
Nor t hWe s t
C A PA0 PC 0 System Capacity
Nor t hWe s t
CAPXCOPC System Capacity without Coal and
XAOUTAL open CEA's
COALARGS Coal Consumption
ZQMCLRI M Workers *
CUSEGALL Electric h Gas Compensation C l a i m s
Customers - Retail
Nuclear I
USEGRXT FERC FORM NO. 1 {ED- i2-87)
Customers
Electric & Gas
3ased on UNIX server usage
3ased on a weighted composite of ]NIX and NT servers and mainframe isage 3ased on WINTEL server usage
3aked on a twelve month number of accounts payable transactions ?racessed 3ased on a twelve month number of accounts receivable transactions a m c e s s e d , - - - - - - -
Based on total assets at period end Based on total assets at period and for a l l Regulated business unfts Based on number of bank accounts at period end Based on the power levelr in kilowatts, that could be achieved if a l l non-nuclear generating units (including Harrison County, RISEC and a l l R e g companies) were operating a t maximum capability simultaneously Based on the power level, in '
kilowatts, that could be achieved if all non-nuclear Northwestern Region (EA1 5 ETI) generating unfts were operating at maximum capacity simultaneously Based on t h e power level, in kilowatts, that could be achieved if a l l non-nuclear generating units were operating at maximum capabil i ty simultaneously Based.on the pawer level , in kilowatts, that could be achieved if all non-coal and non-nuclear generating units were operating at maximum capabi l i ty simultaneously Based on average outstanding CEA's (Capital Expenditure Authorizations 1 Based on the quantity o f tons of coal delivered to each coal plant wi th in the Entergy System Based on number of Open Workers' Compensation claims Based on a twelve month average number of electric and gas residential, commercial, industrial, government, and municipal customers fo r Legal E n t i t i e s EAX, EGSL, ELL, EMI, ENOI, and ET1
Page 429 Footnote.1 I
Name of Respondent
Enlergy Arkansas. Ine
This Report Is: ( I ) X An Original
USEGXTX
Date of Report YearlPertcd of Report (Mo, Da, Yr)
,etail Customers - xcluding Texas ,lectric 5 Gas :ustomers - xcluding Texas
;lecfric Customers
:ustomer C a l l :enters :lectric Customers
of electric and gas re tai l customers, excluding Texas (ETX) Based on a twelve month average number of electric and gas residential, commercial, industrial, government, and municipal general business customers excluding Texas IETf) Based on a twelve month average number of electric residential, commercial, i n d u s t r i a l , government, and municipal customers Based on a twenty-four month average of customer c a l l s Based on a twelve month averaqe
FERC FORM NO. 1 (ED. 12-87)
2USEOPCO
ZUSTCALL
EMPLFWN
EMPLOCSS
EMPLOFOS
EMPLOREG
EMPLOYAL
EMPLPRES
EMPLTRAN
* Retail Customers
W.1 and Part T h e hployees of EAf,
:TI, ESf, EO11 h INOX 3111 and Part Time
IGSL, ELL, EML,
:lectric and Gas :us tomers
Plant Operations Based on the number of full. and p a r t t h e employees a t period end
ETI, and ESI
Based on t h e number of full and
for EAf, EGSL, ELL, EMI, ENOI, EOI,
:lectric Customers - excluding Texas
3nployees -
:lectric Customers - EA1 and EM1
President Organizations Based on t h e number of ful l . and
hployees - kanchlse )perat ions hplayees - :ustomer Support iervices hployees - Fossil 'lank Operations
number of electric residentiai, commercial, Industrial, govexnment, and municipal. customers for Legal. Entities EM, EGS-LA, ELL, EMIr ENOI, and ET1 Based on a twelve month average number of electric and gas residential, commercial, industr ia l , government, and municipal general business customers Based on a twelve month average number of electric residential, commercial, indus tr ia l , government, and municipal customers for Legal E n t i t i e s EAX, EGSL, ELL, EMI, and EN0 1 Based on a twelve month average number of electric residential, commercial, industrial, government, and municipal customers for EA1 and EM 1 Based on the number of full and part time employees within Franchise Operations Based on the number o€ f u l l and part time employees within Customer Sumort Service Based on the number of full and part time employees within Fossil
lmployee s halovees - S t a t e IBased on the number of f u l l and
Ipart time employees a t period end
?rksi;lent ]part time employees within State
Page 429 Footnofe.42 .-
Name of Respondent This Report Is: Date of Report YearlPenod of Report (1 1 X. An Original (Mo, Da, Yr)
Entern Arkansas. Ine. 2013lQ4 FOOTNOTE DATA
Based on the nuher of full and part time employees a t period end for EAX, ETX, ELL, EMI, ENOI, EGSL, ;and EO1 Based on the number of f u l l and part time employees a t period end, excludina ENUC
MPOPCPE r ENLDREG F
MPXENUC
BRBLNLIC K BRCORPT IL
LBRXNFOR I
~LSRBLFOS
Senera1 Ledger Pransactions insurance Premiums
Based on general ledger transactions Based on non-nuclear insurance premiums
ITSPENDA
LBRBILW
E S I Labor Bil led - Corporate
Nuclear functibn - -
Based on total Labor dollars billed to each company by ESI for the
w BRUTQPN
LBRCRPUT
LBREXAFF
LB R F 1 NAN
FERC FORM NO. 9 [ED. 12-87)
Finance
ESI Labor B i l l e d - IT
ESI Labor B i l l e d -
:ranmission
to each company by ESI for the Finance funct ion Based on t o t a l labor dol lars b i l l e d to each company by ESI for t h e IT func t ion Based on total labor d o l l a r s billed
Zmployees - Utility Ipera t i o n s
? u U and Part Time 2mployees of EAI,
301, ETf, and EO1 X S L , ELL, EMI,
-Supply Chain
ESf Labor Billed- U t i l i t y Operations
:mp1oyees - lxcluding ENUC
"her Miles
to each company by ESX fox the Supply Chain function Based on total labor dollars billed to each company by ESI for the
part time employees within Transmiss ion Based on the number of full and part time employees within U t i l i t y Operations
Based on capacity and usage of the Entergy System’s fiber optic network Based on general ledger transactions for regulated I ;enera1 Ledger
Pransactions - 3euuLated ComDanies comsanies
,I - --
Information IBased on Information Technoloqy 12 rechnology Total Spending E S I Labor Costs Billed E S I Labor Billed - Fassil
E S I Labor B i l l e d - Nuclear
- - month total spending
Based on total labor dollars billed to each company by ESX Based on t o t a l labor dol lars billed to each company by ESI for the Fossil function Based on total labor dollars billed t o each company by E51 fur the
lcorporate function E S I Labor Billed - ]Based on total labor dollars b i l l e d Corporate C Utility I t o each company by ESI for the DP3 ESX Labor Billed - IBased on total labor dollars b i l l e d
lcorporate & V t i 1 i i . v O ~ S functions
External Affairs I t o each company by ESI for t h e [External Affg irs func t ion
ESI Labor B i l l e d - IBased on total. labor dollars billed
lLega1 function ESI Labor B i l l e d IBased on total labor dollars billed
1
Page 429 Foatnote.13
Name of Respondent Date of Report YearlPeriod of Report (Mo, Da, Yr)
Enkrgy Arkansas. Inc. I 1 20331u4
U t i l i t y Operations function LOADDPCO Responsibility Based on the ratio company's load
Ratio at time of system peak load. The load is the average twelve monthly highest c l o c k hour demands in ki lowatts of the company's interconnected system, occurring each month coincident with the system peak load.
LOADSYAG Responsibility Based on t h e ratio company's load Ratio f o r System at time of system peak load. The Agreement companies load is the average twelve monthly only highest clock hour demands in
kilowatts of the company's interconnected system, occurring each month coincident with the system peak load. Excluding companies that are not a part of the system agreement.
System company LVLSVCAL ESI Service Level Based on ESI total billings to each
Managed Accounts ,
1
accounts MRCCTNLA Managed Accounts - Based on number o f retail managed
EAI, EMI, and ET1 accounts, excluding the accounts of a13 Louisiana companies
MACCTXTX Managed Accounts - Based on number of retail managed =I, EGSLR, ELL, accounts, excluding the accounts of EM1 and EN01 ET1
3WN I S FX Percentage Based on the percentage ownership Ownership - SFI of SFX
PCNIJMALL Number of PC's Based on the number of PC's within
PCNUMXNR Number o f PC's - Based on the number of PC's a t EAT, Excluding Non-Regs EGSL, ELL, EMI, ENOI, EOI, ESX, and
each business unit
ET1
Company's load to the peak load at t i m e of all companies peak Load. The calculation of Peak Load Ratio is performed using a twelve month rolling average of the coincident peaks.
of t h e property h liability losses paid by the system companies
P K LOR DAL Peak Load Ratio Based on the ratio of each Client
FLLOSSRL Property G Based on a five-year annual average Liability Paid Losses
Issued cheeks issued for each legal E n t i t y
Re actors Rater Reactors P lant units
FRCHECALL Payroll Checks Based on the number of payro l l
P w R S N UCA Pxessure Water Based on t h e number of'Pressure
RADIOALL Radio Usage Based on usage of Entergy's 2-way
RECDMGNT Records Management Based on t h e number of full and radio system
part time emplayees at period end, excluding t h e Nuclear function using records management services
SCDSPALtL Supply Chain Based on Supply Chain Procurement FERC FORM NO. 1 {ED. 12-87)
1
Page 429 Footnote.14
Name of Respondent This Report Is: Date of Report (Mo, Da, Ur) (1) &An Original
Entergy Arkansas. fnc. (2) - A Resubmissfon I /
Spending - I Distribution
YearlPeriod of Report
2013M4
Spending - F o s s i l
Labor Dollars
iCTS PALL
iECT263A
Total Spending for the Distribution Function Based on Supply Chain Procurement Total Spending for the Fossil Function Supply Chain Labor Dollars for the Transformer, Meter, and Light Shops
Spending - Distribution 6 Transmission Supply Chain Spendfng - Transmission Section 263A Tax
Supply Chain Transactions in materials transactions for each Passport business unit in Passport
Transactions in materials transactions for each Passport excluding business u n i t i n Passport excluding Nuclear the Nuclear function Supply Chain Total Based on Supply Chain's Procurement
Based on the number of Supply Chain
-p Supply Chain
SNUCUNIT
QFTALLC
(Spending ICPSPXNC JSuppLy Chain
Nuclear Uni t s
Square Footaqe -
Ispending -
TELXGENS
TRALXNOP
TRANSPND
TRASUBOP
I Excluding Nuclear CTDSPAL ISupply Chain
Excluding Remote. Transmission Line Miles
Transmission iBudgeted Capital Expenditures Transmission ISubs tations
Transmission Line Miles/Substation
Number of Vehicles
Based on the number of miles of transmission l i nes , weighted far design voltage {Voltage < 400kv - I; Voltage >400kv 52) Based on Transmission Budgeted Capital Expenditures
Based on the number of high voltage substations weighted for Voltage (Voltage < 500kv H 1; Voltage >= 500kv = 2) Based on two components: Transmission Line Mi les (30% weighting] and the Number of High Voltage Substations (70% weiqhting) Based on the number of vehicles
IS@ rvices NUCSfTE INuclear Plant sites
I A i l Companies ELFHALL INumber of
TRSBLNQP
F EHCLFOS
Total Spending Based on Supply Chain Procurement Total Spending; Excluding Nuclear for 12 months Based an Supply Chain's Procurement * - - Total Spending fo r Distributfon & Transmission functions
Based on Supply Chain's Procurement Total Spending for Transmission
Based on the expected t a x savings from s e c t i o n 263 Based on the number of Nuclear iPlant S i t e s Based on the number of Nuclear Uni ts Based on square footage within a l l business units Based on the number of telephones
Telewhones Iwithin each business unit Number of Telephones - Based on the number of telephones
excluding Remote Sites
1 FERC FORM NO. 1 (ED. 92-87) I
k g 8 429 Footnote.15
k
Name of Respondent This Report is: Date of Report (Mo, Da, Yr) (I) XAn Original
IFERC FORM NO. 1 IED. 12-87)
YearlPeriod of Report
Page 429 Fmtnote.16
Entergy Arkansas. he. (2) I A Resubmission I 1 2013lQ4
FOOTNOTE DATA
- Fossil owned or leased by each business unit: for the Fossil function only
owned ox leased by each business u n i t for the Nuclear function only
excluding Fossil h owned or leased by each business Nuclear
VEHCLNUC Number of Vehicles Based on the number of veh ic l e s - Nuclear VEHCLUSG Number of Vehicles Based on the number of vehicles
unit that participates in t h e usage based transportation allocation
Schedule
Accrued and prepaid taxes ........................................................................ 262-263 Accumulated Deferred Income Taxes .................................................................... 234
272-277 Accumulated provisions lor depredat ion OF
cornon utility plant ............................................................................. 356 utilfty plant .................................................................................... 219 utility plant (summary) ...................................................................... 200-201
Advances from associated companies .................................................................... 256-257
hllowances ....................................................................................... 228-229 Rmottizatinn
ml~eellancoui .................................................................................... 340 of nuclear fuel .............................................................................. 202-203
Appropriations a t Ratalncd Earning3 .............................................................. 118-119 Associated Cornpanic3
advances Itom ................................................................................ 256-257 corporations controlled by respondent ............................................................ 103 control aver respondent .......................................................................... 102 interest on debt to .......................................................................... 256-257
Attestation ............................................................................................ 1 Balance nheet
comparative .................................................................................. 110-113 notes t o ..................................................................................... 122-123
Bond3 ............................................................................................ 256-257 Capital Stock ........................................................................................ 251
txpcnsa .......................................................................................... 254 premium ......................................................................................... 252 reacquired ....................................................................................... 251
Cash flows. ntatcarnt o t ......................................................................... 120-121 Changes
important during p a r ........................................................................ 108-109 Construction
work in progress . colr*yln utility plant .......................................................... 356 work i n proggerss - wlwetrie ...................................................................... 216 work in prcqreri - other utility departments ................................................. 200-201
corporations controlled by reapondent ............................................................ 103 OVCE respondent .................................................................................. 102
control led by .................................................................................... 103 incorporated ..................................................................................... 101
CPA. background inKOmiation on ....................................................................... 101 Cph certftlcation. this report form ................................................................. i-ii
JUbaCcibtd ....................................................................................... 252
control
corporation
t
FERC FORM HO . 1 (ED . 12-93] Index 1
INDEX {continued)
Schedule paqe No . Deferred
credits. other ................................................................................... 269
income taxes accumulated - accelerated amortization property ........................................................................ 272-273 income taxes accumulated - other property .................................................... 2’14-275 income taxes accumulated - other ............................................................. 276-277 income taxea accumulated . Q O l l U t i O n control Fae%Lltits .......................................... 234
DtFinFtions. Ehls report Form ........................................................................ iif Depreciation and amortization
of comnn utility plant .......................................................................... 356 of electric plant ................................................................................ 213
debits . miscellaneous ............................................................................ 233 I
Directors ................................................ Distribution of s a l a r i e s and uagei ....................... Dividend appropriations .................................. Earnings. Retained ....................................... Electric energy acmunt .................................. Expenses
Electric operation and maintenance ...................
Discount - predum on long-term debt ..................... ..... ..... ..... ..... .. I.. ..... .....
................... ................... ................... ................... ................... ...................
...................
336-337 ................. 105 ............. 256-257 ............. 354-355 ............. 118-119 ............. 118-119 ................. 401
............. 320-323 electric operation and maintenance. summary ...................................................... 323 unamortized debt ................................................................................. 256
Extraordinary property losses ........................................................................ 230 F i l i n g requirements. t h i s report fom General information .................................................................................. 101 InstructFons f o r f i l i n g the F€UC Form 1 ............................................................. i - i v
Generating plant s t a t i s t i c s hydroelectric (large] ........................................................................ 406-907 pumped storage (large1 ....................................................................... 408-409 small plants ................................................................................. 410-411 sttam-electric (large) ....................................................................... 402-403
Hydro-electric generating plant statlatie3 ....................................................... 406-407 IdenEiLicatlon ....................................................................................... 101 Important: changes during year .................................................................... 108-109 Income
statement of. by departments ................................................................. 114-117 statement of. for the year (see also revenues) ............................................... 114-117 deductions. dsee l laneous amortization ........................................................... 340 deductions. other incume deduction ............................................................... 340
dcductions. other interest charges ............................................................... 310 Incorporation information ............................................................................ 101
Index 2
Interest
Investments charges. paid on long-term debt. ......... eEe ............................................... 256-257
nonutility property .............................................................................. 221 subsidiary companies ......................................................................... 224-225
Investment tax eredLts. secrunulated deterred ..................................................... 266-267 Law. excerpts applicable to t h h report form .......................................................... iV
L i s t of schedules. this report Lorn .................................................................. 2-4 Long-term debt ................................................................................... 256-257 Losses-Extraordinary property ........................................................................ 230 Materials and supplies ............................................................................... 227 Mircellaneous general expenses ....................................................................... 335 Notes
to balance sheet ............................................................................. 122-123 to statement of changes i n f inancia l pnsLtion ................................................ 122-123 tu statement of income ....................................................................... 122-123 t o statement of retained earning3 ............................................................ 122-123
Nonutility property .................................................................................. 221 Nuclear fuel materials ........................................................................... 202-203 Nuclear generating plant. statistics ............................................................. 102-403 Officers and offfcers' salaries ...................................................................... 104 operating
expenxs-electric ............................................................................ 320-323 expenses-electric (summnry) ...................................................................... 323
paid-in capltal .................................................................................. 253 donatfans xeceived from stockholders ............................................................. 253 gains on resale or cancel lat ion o f reacquired capital stock .................................................................................... 253 miscellaneous paid-in cspital .................................................................... 253 reduction Fn par or stated value of cnpltal atock ................................................ 253 regulatory assets ................................................................................ 232 regulatory liabilities ........................................................................... 278
'Peaka. monthly. and output ........................................................................... 403. Plant. Comon u t i l i t y
Other
. accumulated provision tar depreciation ........................................................... 356 acquisition adjustments ..............................-...................o........................ 3 5 6
'allocated to utility departments ................................................................. 356 completed eongtzuction not c l a s s i f i e d ............................................................ 356 construction work in progress .................................................................... 356 expenies ......................................................................................... 356 held for future usn .............................................................................. 356
in sewice ....................................................................................... 356 leaaed Eo others ................................................................................. 356
401-4 29 Plant data ................................................................................... ~ 3 6 - 3 ~ ~
FERC FORM NO . 1 [EO . 1245) Index 3
_ _ ..... ..
INDE% (continued)
Schedule Pam No . Plant - electric
accumulated provision for depreciation ........................................................... 219 construction work in progress .................................................................... 216 held for future use .............................................................................. 224 in service ................................................................................... 204-201 leased to others ................................................................................. 213
Plant - u t i l i t y and accumulated provisions for depredat ion amortization and deplet ion (surtaaary) ............................................................. 201
Pollution control facilities, accumulated deferred incame taxes ..................................................................................... 234
Power Exchanges .................................................................................. 326-327 Premium and discount on lang-term debt ............................................................... 256 Premium on capital atock ............................................................................. 251 Prepaid taxes .................................................................................... 262-263 Property - ~ O J S E S . cwtraordlnary ..................................................................... 230 Pumped storage generating plant atatistics ....................................................... 400-409 Purchased power t lnc lud lng power exchanges) ...................................................... 326-327 Reacquired capital stock ............................................................................. 250 Rcacqulred long-term debt ........................................................................ 256-257 Receivers' ctrtiflento~ .......................................................................... 256-257 RtconclllatLon of report-d net income wlth taxable income
from Federal lncurm t a x t a ...................................................................... 261 Rtgulatory emJss lon expenses deferred .............................................................. 233
Resrntth. d e e t l o p n t and demonstration activities ............................................... 352-353 Retained Earnings
amoztiratlon reaervm federal ..................................................................... 119 approprlrted ................................................................................. 110-119 ntatcmcnt ot. fo r the year ................................................................... 118-119 UnappKQpZf.ttd ............................................................................... 118-119
Revenues - E l t C K K l C owrating .................................................................... 300-301 sa lar ie s and w q c s
Regulatory e&rslon r x p t n l t r for year .......................................................... 350-351
directors i c e s ................................................................................... 105 distr ibut ion o l .............................................................................. 3 5 4 4 5 5 officers' .......................................................................................... 104
Sales of e~ectrlelty by r a t e schedule3 ............................................................... 304 Sales - for resale ............................................................................... 310-311 Salvage - nuclear fue l ........................................................................... 202-203 Schedules. t h i s report fom .......................................................................... 2-4 Securities
Statement of Cash Flows .......................................................................... 120-121 Statement o f incamc for the year ................................................................. 114-117 Statement o f retained earning3 for tha year ...................................................... 118-119 Steam-clcckric gcneratlng plant s t a t h t i c s ....................................................... 4 0 2 4 0 3
Supplies - materiala and ............................................................................. 227
cxchanga reg is t rmt ion ........................................................................ 250-251 .
Substations .......................................................................................... 426
I
FERC FORM NO . 1 (ED . 12.80) Index 4
Schedule Paqe No. Taxes
accrued and prepaid ......................................................................... 262-263 charged during year ......................................................................... 262-263 on income. deferred and accumulated ............................................................. 2 3 4
reconc~liation of net income with taxable income for ............................................ 261 Transformers, line - electric ....................................................................... 429 Transmission
lines added during year ..................................................................... 424-425 lines sta t is t ics ............................................................................ 422-423 o f electricity for others ................................................................... 328-330 of electricity by others ........................................................................ 332
debt discount ............................................................................... 2S6-251 debt expense ................................................................................ 256-257 premium on debt ............................................................................. 256-257
Unrecovered Plant and Regulatory Study Costs ........................................................ 230
272-277
Unamortized
FERC FORM NO . I (ED . 12-90] Index 6
