Major Electric Utilities, Licensees - APSC

Item 1: [J An lnitial(Original)Submission

OR n Resubmission No. _

THIS FILING IS Form'l ApprovedOMB No.l9O2-A021(Expires 11/30/2016)

Form 1-FApprovedOMB No.19A2-A029(Expires 11/30/201ô)

Form 3-Q ApprovedOMB No.1902-0205(Expires 11/30/2016)

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FERC FINANCIAL REPORTFERC FORM No. 1: Annual RepoÊ of

Major Electric Utilities, Licenseesand Others and Supplemental

Form 3-Q: Quarterly Financial Repoñ

Thess reports are mandatory under the Federal power Açt, Sections g, 4(a), A04 and g0g, and18 CFF f 41.1 and 141.¡lOO. Failure ìo report may result in crimínal fines, ctuil penalties andqther sanclions as prov¡ded by law. the Federal Energy Regulatory commission doês notconsider these reports to be ol confitlential nalure

Year/Period of Report

End of 2015/Q4

Exact Legal Name of Respondent (Company)

Southweslern Electríc Power Company

FERC FORM No.1/3-Q (REV.02-04)

TNDEPENDENT AIIDITORS' REPORT

To the Board of Ðirectors and Shareholder ofSouthrvestern Electric Porver Company:

We have audited the accompanying financial statements of Southwestern Electric Porver Company (the

"Company"), rvhich comprise the balance sheet - regulatory basis as of December 31, 2015, and the

related statements of income - regulatory basis, retained earnings * regulatory basis, and cash flows -regulatory basis for the year then ended, included on pages I I 0 through I 23 of the accompanying Federal

Energy Regulatory Commission Form l, and the related notes to the financial statements.

Management's Responsibilify for the Financial Statements

Management is responsible for the preparation and fair presentation of these fTnancial statements inaccordance with the accounting requirements of the Federal Energy Regulatory Commission as set forthin its applicable Uniform System of Accounts and published accounting releases; this includes the

design, implementation, and maintenance of intemal control relevant to the preparation and fairpresentation of financial statements that are free f¡om material misstatement, whether due to fraud oreÍor.

Auditors' Responsibility

Our responsibility is to express an opinion on these financial statements based on our audit. Weconducted our audit in accordance with auditing standards generally accepted in the United States ofAmerica. Those standards require that we plan and perforrn the audit to obtain reasonable assurance

about whether the Frnancial statements are free from material misstatement.

An audit involyes performing procedures to obtain audit evidence about the âmounts and dìsclosures in

the flnancial statements. The procedures selected depend on the auditor's judgment, including theassessment of the risks of material misstatement of the financial statements, whether due to fraud orenor. In making those risk assessments, the auditor considers internal control relevant to the Company'spreparation ¿nd fair presentation of the financial statements in order to design audit procedures that are

appropriate in the circurnstances, but not for the purpose of expressing an opinion on the effectiveness ofthe Company's internal control. Accordingly, rile express no such opinion. An audit also includesevaluating the appropriateness of accounting policies used and the reasonableness of significantaccounting estimates made by managem€nt, as well as evaluating the overall presentation of the financialstâtements.

We believe that the audit evidence we have obtained is suffìcient and appropriate to provide a basis fio¡

our audit opinion.

Opinion

In our opinion, the regulatory-basis financial statements referred to above present fairly, in all materialrespects, the assets, liabilities, and proprietary capital of Southwestern Electric Power Company as ofDecember 31, 2015, and the results of its operations and its cash flows for the year then ended inaccordance with the accounting requirements of the Federal Energy Regulatory Cornmission as set forthin its applicable Uniform System of Accounts and published accounting releases.

Basis of Accounting

Às discussed in Note I to th€ financial statements, tåese financial statements were prepared inaccordance with the account¡ng requirements of the Federal Energy Regulatory Cominission as set fo*hin its applicable Uniform System of Accounts and published accounting releases, which is, a basis ofaccounting other than accounting piinciples generally accepted in the United States of America. Ouropinion is not modified with respect to this matter.

Restricted Use

This report is intended solely for the information and use of the Board of Directors, Shareholder, andmanagement of the Company and for filing with the Federal Energl Regulatoqy Commission and is notintended to be and should not be used by änyone other than these specified parties,

+ ñ*/L ¿r-pApril 8,2016Columbus, Ohio

INSTRUCTIONS FOR FILING FERC FOHM NOS. 1 and 3.Q

GENTRAL INFORMATION

Purpose

FËRC Form No. 1 (FEHC Form 1) is an annualregulatory requirement for Major electric ulilities, licensees and others(18 C.F.R. S 141.1). FEFìC Form No. 3-Q ( FERC Form 3-Q)is a quarterly regulatory requiremenl which supplements theannual financial reporling requirement (18 C.F.R. $ 141.400). These reports are designed to collect financial andoperational inlormation from electric utilities, licensees and others subiect to the jurisdiction of the Federal Energy

Flegulatory Commission. These reports are also considered to be non-confidential public use forms,

ll. Who Must Submit

Each Major eleclr¡c utility, licensee, or other, as classified in the Commíssion's Uniform SystemPrescribed for Public Utilities and Licensees Subject To the Provisions ol The Federal Power Act (18 C.F.R.must submit FERC Form 1 (18 C.F.R. $ 141.1), and FERC Form 3-Q (18 C.F.R. S 141.400).

of AccounlsPart 101),

Note: Major means having, in each of the three previous calendar years, sales or transmission service thatexceeds one of the following:

(1) one million megawatt hours of total annual sales,(2) 100 megawatt hours ol annual sales for resale,{3) 500 megawatt hours of annual power exchanges delivered, or{4) 500 megawatt hours of annualwheeling for olhers (deliveries plus losses}

lll. What and Where to Submit

(a) Submit FERC Forms 1 and 3-Q electronically through the forms submission software. Retain one copy of each reportfor your files. Any electronic submission must be created by using the lorms submission software provided free by theCommission at its web site: http:l/www.ferc.qovldocs-filingleforms/form-1/elec-subm-soft.asp. The software isused to submít the electronio filing to the Commission via the lnternet.

{b) The Corporate Oflicer Certification musl be submitted electronically as part of the FERC Forms 1 and 3-Q filings.

(c) Submit immediately upon publication, by either eFiling or mail, two (2) copies to the Secretary of the Commission, thelatest Annual Report to Stockholders. Unless eFiling the Annual Report to Stockholders, mail the stockholders report tolhe Secretary ol the Commission at:

SecretaryFederal Energy Regulatory Commissíon888 First Street, NËWashington, ÐC 2042â

(d) For the CPA Certilication Statement, submit within 30 days atter filing the FERC Form 1, a letter or report (notapplicable to filers classified as Class C or Class D prior to January 1, 1984). The CPA Certification Statement can beeither eFiled or mailed to the Secretary ol the Commission at the address above.

FEHC FORM 1 & 3-Q {ED.03-07}

The CPA Certification Statement should:

a) Attest to the conformity, in all material aspects, of the below listed (schedules and pages) with theCommission's applicabfe Uniform $ystem of Accounls (including applicable notes relàting thereto and theChief Accountant's published accounting releases), and

b) Be signed by independent certified public accounlants or an independent lícensed public accounlantcertified or licensed by a regulalory authority of a State or other political subdivision of the U. S. (See 1B

C.F.R. $S 41.10-41 .12lor specific quatifications.)

Relerence Schedules Paqes

Comparative Balance SheetSlatement of lncomeSlatement of Fìetained EarningsStatement of Cash FlowsNotes to Financial Statements

1 10-1 13114-117'l't8-119

124-121122-'123

e) Tho following format rnust be used for the CPA Certificalion Statement unless unusual circurnstances or condilions,explained in the letter or report, demand that it be varied. lnsert parenthelical phrases only when exceplions arereported.

"ln connectíon with our regular examination of the financial statements of _ for the year ended on which we havereportedseparatelyunderdateof-,wehavealsoreviewedschedules

@oåliKi,:r,tr;i.J,:liliäÍ:l1i:ill:ixE;Hiåäff,ff 'åiii,f ,:îîi'å,i?;lî,",uapplicable Uniform System of Accounts and pubfished accounting releases.

-Our review fbr lhis purposê included such

tesls of the accounting records and such other auditing procedures as we considered necessary in the circumstances.

Based on our review, in our opinion the accompanying schedules identilied in the preceding paragraphþxcept as n_oted below) conform in all material respects with the accounting requirements of the Federãl þnergyRegulatory Commission as set forth in its applicable Uniform System of Accounts and published accounting releases.,,

Thê lettêr or rêport must state which, if any, of the pages above do not conform to the Commission's requirements.Describe lhe discrepancies that exist.

(f) Filers are encouraged to file their Annual Fleport to Stockholders, ând the CPA Certification Slalement using eFiling.To further that effort, new selections, "Annual Report to Stockholders," and *CPA Certification Statement" have beenadded to thê dropdown "pick lisf'lrom which companies must choose when eFiling. Further instructions are found on theOommíssion's websito at http://www.ferc.qov/help/how-to.asp.

(g) Federal, State and Loeal Governments and oiher authorized users may oblain additional blank copies ofFERC Form 1 and 3'Q free of charge from http://www.ferc.qov/docs-filing/eforms/form-1/form-1.pdf anohttp ://www.ferc.qov/docs-fiInç/efqrms.asn#3Q:ças .

lV. When to Submit:

FEHC Forms 1 and 3-Q must be lifed bythe following schedule:

ItFERC FORM't & 3.Q (EÐ.0s-07)

a) FERC Form 1 for each year ending Ðecember 31 must be f iled by April t gth of the following year {18 CFn S 141.1}, and

b) FERC Form 3-Q for each calendar quarler must be filed within 60 days after the reporting quarter (1S C.F.R, S14r.400).

V. Where to Send Comments on Publlc Reportlng Burden.

The publÍc reporting burden for the FEHC Form 1 collection of iniormation is estimated to average 1,144hours per response, includíng the lime for reviewing instructions, searching exisling data sources, gathering andmaintaining lhe data-needed, and completing and reviewing the collection of information. The public reporting burden forthe FERC Form 3-Q colfection of information is estimated to average 150 hours per response.

Send comments regarding these burden estímates or any aspect of these collections of information, includingsuggestions for reducing burden, to the Federal Energy Regulatory Commission, 888 First Street NË, Washington, DC2A426 (Altention: lnformation Clearance Officer); and to the Office of lnformation and RegulatoryAffairs, Ollice olManagement and Budget, Washingrton, DC 20503 {Attention: Desk Officer for the Federaf Energy RêgulatoryCommíssion). No person shall be subject to any penalty if any collection of information does not display a valid controlnumber (44 U.S.C. $ 3512 (a)).

ll¡FERC FORM 1 & 3-Q {ED. 03-07}

GENERAL INSTRUCTIONS

l. Prepare this report in conformity wilh the Uniform System of Accounts (18 CFR Part 101) (USofA). lnterpretall accounting words and phrases in accordance with the USofA.

ll. Enter in whole numbers (dollars or MWH) only, except where otherwise noted. (Enter cents for averages andfigures per unit where cents are important. The truncating of cents is allowed excepl on the four basic linancial statemenlswhere rounding is required.) The amounts shown on all supporting pages must agree with the amounts entered on theslatements that they support. When appÌying thresholds to determíne sígnificance lor reporting purposes, use for balancesheet accounts the balances at the end of the current reporting period, and use for statement oi income accounts thecurrent year's year to date amounls.

lll Complete each question fully and accurately, even if it has been answered in a previous report. Enter theword "None" where it truly and completely states lhe facl.

lV. For any page(s) that is not applicable to the respondent, omit the page(s) and enter 'NA,' 'NONE," or "NotApplicable" in column (d) on the List of Schedules, pages 2 and 3.

V, Enter the rnonth, day, and year for all dates. Use customary abbreviations. The "Date of Report" included in theheader of each page is to be completed only for resubmissions (see Vll. below).

Vl, Generally, except for certain schedules, all numbers, whelher they are expected to be debits or credits, mustbe reported as positive. Numbers having a sign that is different from the expected sign must be reported by enclosing thenumbers in parentheses.

Vll For any resubmissions, submit the electronic filing using the form submission software only. Please explainlhe reason for lhe resubmission in a footnote to the data lield.

Vlll. Do not make references to reports of previous periods/years or to olher reports in lieu of required entries,except as specilícally authorízed.

lX. Wherever (schedule) pages refer to figures from a previous period/year, the figures reported must be basedupon those shown by the report of the previous period/year, or an appropriate explanation given as to why the differentfigures were used.

Delínitions for statisticalclassificalions used lor compleling schedules for transmission system reporting arê as follows:

FNS - Firm Network Transmissíon Service for Self. uFirmu meâns service that can not be interrupted for economic reasÕnsand is íntended to remain reliable even under adversê conditions. "Network Service" is Network Transrnission Service asdescribed in Order No. 888 and the Open Access Transmission Taritf. "Self' means the respondent.

FNO - Firm Network Service for Others. "Firm" means that service cannot be interrupted for economic reasons and isintended to remain reliable even under adverse conditions. "Network Servíce" is Network Transmission Service asdescriþed in Order No. 888 and the Open Access Transmission Tariff.

LFP - for Long-Term Firm Point-to-Point Transmission Reservalions. "Long-Term" means one year or longer and" firm"means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverseconditions. "Point-to-Point Transrnission Fleservatíons" are described in Order No. 888 and the Open AccessTransmission Tariff. For all transactions identified as LFP, provide ín a footnote the

lvFERC FORM 1 & 3.Q (Er).03-07)

terminalion date of the contract delined as the earliest date either buyer or seller can unilaterally cancel the contract.

OLF - Other Long-Term Firm Transmission Service. Report service provided under contracts which do not conform to theterms of the Open Access Transmission Tariff. "Long-Term" means one year or longer and'Iirm" means that servicecannol be interrupled for economic reasons and is intended to remain reliable even under adverse conditions. For alltransactions identified as OLF, provide in a footnote the termination date of the conlract defined as the earliest date eitherbuyer or seller can unilaterally get out of the contract.

SFP - Short-Term Firm Point-to-Poínt Transmission tleservalions. Use this classification for alllirm point-to-pointtransmissíon reservations, where the duration of each period of reservation is less than one-year.

NF - Non-Firm Transmission Service, where firm means that service cannot be interrupted for economic reasons and isintended to remain reliable even under adverse condilions.

OS - Other Transmission Sen¡ice. Use this classification only for those services which can not be placed in theabove-mentioned classifications, such as all other service regardless of the length of the contract and service FËFÌC Form.Describe the type ol service in a foolnote lor each entry.

AÐ - Out-of-Period Adjustments. Use this code for any accounting adjustmenls or "true-ups" lor service provided in priorreporting periods. Provide an explanalion in a footnote for each adjustment.

INITIONSCommission Authorization (Comm. Auth.) -- The authorization of the Federal Energy Regulatory Commission, or any

Commission. Name the commission whose authorizalion was obtained and give date of the authorization.

ll. Respondent -- The person, corporation, licensee, agency, ãuthority, or other Legal entity or inslrumentâlity in whosethe report is made.

FERC FORM 1 & 3-O tED. 03-07) v

EXCËHPTS FROM THE LAW,

Federal Power Act, '16 U.S.C. g 791a-825r

Sec. 3. The words defined in this section shall have the following meanings for purposes of lhis Act, to with:

(3) 'Corporation' means any corporation, joínt-stock company, partnership, association, businesg lrust,organízed group of persons, whether incorporated or nol, or a receiver or receivers, trustee or lrustees of any of theforegoing. lt shall not include'municipalities, as hereinatter defined;

(4) 'Person' means an individual or a corporation;

(5) 'Licênsee, means any person, Stale, or municipality Licensed under the provisions of seclion 4 of this Act,and any assignee or successor in interest thereof;

. lZl 'municipality means a city, county, irrigation district, drainage district, or other political subdivlsion oragency of a State compelent under the Laws thereof to carry and the business of developing, iransmitting, unitizing, ordistributing power; ......

., (1'l) "projecl' means, a complete unit of improvement or developmenl, consist¡ng of a power house, allwaterconduits, all dams and appurtenant works and struclures (including navigation structures) which arô a part of said unit, andall storage, diveding, or fore bay reservoirs directly connected therewith,lhe primary line or lines transmitting power therefrom to the point of junction with the dÍstribution system or with the interconnected þrimary transmission sysiem, allmiscellaneous structures used and useful in connection with said unit or any part thereof ,'and all water riçjhts,rights-of-way, dítches, dams, reservoirs, Lands, or interest in Lands the use and occupancy of which are-necessary orappropriate in the maintenance and operation of such unit;

"Sec. 4. The Commission is hereby authorized and empowered

(a) To make investigations and to collect and record data concerning the utilization of the water'resources of any region tobe developed, lhe waler-power industry and its relation to other indubtries and to interstate or foreign commerce, andc,oncerning the location, capacity, development -costs,tand relalion to markets of power sites; ... to the extent theCommissíon may deem necessary or useful lor ihe purposes of this Act.',

"Sec' 304" (a) Every Licensee and every public utility shallfile w¡th lhe Commission such annual and other periodic orspecial' reports as lhe Commission may be rules and regulations or other prescribe as necessary or appropriate to assistthe Commission in thê -proper administration ol this Act. The Commission may prescribe the manner ååO pgnC Form inwhich such reports salt be made, and require from such persons specific answers to all questions upon which theCommission may need information. The Commission may require that such reports shall'include, among other things, fullinformation as lo assets and Liabilities, capilalizalion, net inveslment, and reductíon thereof, gross receiþts, ínteresidueand paid, deprecialion, and olher reseryes, cost of project and other facilíties, cost ol maíntenance and operation of theproject and other facilities, cost of renewals and replacement of the project works and other facilities, depreciation,generalion, transmission, distribution, delivery, use, and sale of electric energy. The Commission may require any suchperson to make adequate provision for currently determíning such cosls andïtner facts. Such reportå snåll ne made underoath unless the Commission olhen¡r¡íse specifies'.10

FERC FORM 1 & 3-Q tED.03-07) vl

"Sec. 309, The Commission shall have power to perform any and all acts, and to prescribe, issue, make, and rescínd suchordetrs, rulos and regulations as it may find necessary or appropriate to carry out lhe provisions of this Act. Among otherthings, such rules and regulations may define accounting, lechnical, and trade terms used in this Act; and may prescribethe FEffC Form or FERC Forms of allstatemenls, declarations, applications, and reports to be filed with lhe Cornmíssion,the information which theyshall contâln, and Ìhe lime within which they shall be lield..."

General Penaltles

The Comrnission may assess up to $1 rnillion per day per violation of its rules and regulations. ,Ses

FPA ü 316(a) (2005), 16 U.S.C. $ 825o(a).

FËRC FORM r & &O {EB, 03-r}4 vlt

FERC FORM NO. 1I3-Q:

Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and wiltinglyfalse, ñclitious or täudulent statements as lo äny matter within its jurisdiction.

to make to any Agency or Department of the United States any

02 TtleAssistant Controller

04 Þate Signed

(Mo, Da, Yr)

04/08t2016F. Scott Travis

03 Signature01 NameF. Scott

The undersigned officer certif¡es that:

I have exâmined this report and to lhe best of my knowledge, information, and belief all statements of fact contained in this r€port âre correct statementsof the business affaits óf the respondent and the finãnciaf statements, and other fnanciãl information contâined in this report, conform ¡n atl materiâlrespects to lhe Unifo¡m System of Accðunts.

ANNUAL CORPORATE OFFICER CERTIFICATION

10 Date of Report(Mo, Ða, Yr)

lt

09 This Report ls

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

08 Telephone Õf Contact Person,lncludingArea Code

(614) 716-1000

07 Address of Contact Person fSf¡eef, City, State, Zip Code)AÊP Service Corporation, 1 Riverside Plaza, Columbus, Ohio 73215-2373

06 Title of Contact PersonAccountant

05 Name of Contact PersonJason M. Johnson

04 Address of Principal Office at End of Period lsfreef, City, State, Zip Code)1 Riverside Plaza, Columbus, Ohio 43215-2373

03 Previous Name and Date of Change (if name changed during year)

tt

02 Year/Period of Report

End of 2:0151Q4

01 Exact Legal Name of RespondentSouthwestern Electric Power Company

FERG FORM No.1/3-Q {REV. g2-a4t Page 1

266-267Accumulated Defened lnvestrnent Tax Çredits36

262-263Taxes Accrued, Prepaid and Charged Durlng the Year35

261Reconciliation of Feporied Net lncome with Taxable lnc for Fed lncTax34

256-257Long-Tem 0ebt33

NA2UCapital Stock Êxpense32

253Oth€r Paíd-ln Capilâl31

250-251Capilal Stock30

234Accumulated Ðefened lncóme Taxes29

233Miscellaneous Delered Debite28

232O{her Regulatory Assets27

NA231Transm¡ssion Service and Generalion lnterconneclion Study Costs26

NA230Un¡ecovered Plant and Fegulalory Study Costs28

NA2æExtraordinary Properly Losses24

228(ab)"22e(âb)Allowances23

227Materials and Supplies22

224.225lnveslment of Subsidiary Companies21

219Accumulated Provision for Depreciation ol Electric Ut¡lity Plant20

216Conslruction Work in Progress-Ëlectrlc19

214Electric Plant Held for Future Use18

NA213Êlectric Plant Leased to Others17

204-207Electrlc Plant In Service1ô

NA2V¿.203Nuclear Fuel Mate¡ials15

2c0¡201Summaryof Utility Plant & Accumuläted Provisions lor Dep, Amort & Dep14

1æ(aXþ)Stâtement of Accum Comp lncome, Comp lncome, and Hedging Activ¡ties13

't22-123Notes to Financial Statements't2

12ù't21Statement of Cash Flows11

1't8-'t 19Slatement of Reta¡ned Eamings for the Year10

Pagê 116- NA11+1',t7Statement of lncome lor lhe YearI110.1 13Comparative Balance SheetI108-109lmportant Changes During the Year7

106(aXb)lnformation on Formula Rates6

105Direc'tors5

't04Officers4

103Corporations Controlled by Flespondent3

102Control Over Bespondent2

101General lnlormationI

Remarks

(c)

ReferencePage No.

(b)

Title of Schedule

(a)

UneNo.

Enler in column (c) lhe terms 'none,' 'not applicable,' or 'NA,' as appropriate, where no information or amounts have been reported lorcertain pages. Omit pages where the respondents are 'none,' 'not applicable,' or'NA'.

Year/Period ot Report2011Q4Ênd of

Date of Report(Mo, Da, Yr)tt

This Report ls:(1) [lAn original(2ì, TlA Resubmission

Name of Respondent

Southwestem Eleclric Power Company

FEBC FORM NO, r (EÞ. 12-96) Page 2

NA410-411Generating Plant 9latístics Page.r6ô

NA40&409Pumped Storage Genðrating Plant Statistic$65

NA4û6-407Hydroelectric Generating Plant Statistics64

402.MSteam Eleclric Generaling Plant Slatislicsô3

qtMonthly Peaks and Odput62

4t)1Electric Energy Account61

NA4CnaMonthly lSô/RÎÕ Tnnsmisskrn System peak Loadô0

4ûOMonthly Transmlsslon Slrstem Peak Loåd59

NA398Purehaseand Sale ol Ancillary Serv¡cas58

397Amounts included in |So/RTO Settlement Statom€nts57

NA356Common Utilig Flant and Ëxpenses56

35+355Distribut¡on ol Salarles and Wages55

\tÍr¿-\tahtBesearch, Development and Demonstration Activitiesil350'351Regulalory Oommissíon Expensess3

336-337Deprecialion and Amortization of Electric Plant52

s35Miscellaneous General Expenses-Electric51

332Transmission ol Ëlectricig by Others50

NAtr}1Transmission of Electricity by ISO/RTOs49

328-330Transm¡ssion of Electr¡city tor Others4{t

326-327Purchased Power47

32&323Electric Operation and Maintenance [xpenses46

310-31 1Sales for Resale45

304Sales of Ëlectric¡ty by Rate Schedules44

NAs02Regiond fransmisslon Service Revenues (Account 457.1)43

300-301Electric Operatíng Rêvenues42

2t8Other Regulatory Llabilities41

276-277Accumulated Þeferr€d lncome Taxes-Oüer40

27+276Accum ulated Detened lncome Taxes-Other Property39

NA272-279Accum ulated Defened I ncome Taxes-Acceleraled Amortization property38

269Qther Oçlened Creditsél

Hemarks

(c)

ReferencePage No.

(b)

Tille ol Schedula

{a)

No.

Enter in column (c) lhe lerms'none,' 'not applícable,'or'NA,' as appropríale, where no informalion or amounls have been reported forcerlain pages. omít pages where the respondents are 'none,' 'not applfcable,. or .NA..

Year/Period of Report2015/Q4End of

Date of Beoort(Mo, Da, Yi)tt

AnSoulhwestern Efectric Power Company12) A Rêsþbmisslon

FEfiC FOBM NO. 1 (ËD. 12.9Ê) Pags 3

Reports Checlt appropriate box:

[l Two copies will be submitted

I No annual report to stockholdôrs is prepared

45ôFootnote Þala71

429TransactÌons with Associa_ted (Afliliated) Companles70

42æ27Substations69

424.425Transmíssion Lines Added During the Year68

422-423Trânûm¡ssion Une Statisl¡as Fages67

Flemarks

(c)

ReferencePage No.

(b)

Tille of Schedule

(a)

Líne

Na.

Enter in column (c) lhe lerms 'none,' 'not applicablê,' or 'NA,' as appropriate, where no inlormation or amounts have been reported for

cerlain pages. Omit pages where the respondents ars 'rtong,''not âpplicable,' or 'NA'.

Year/Period ot Report2015/Q4End ol

Ðat6 of Report(Mo, Da, Yr)tl

ls:Original

Southwestem Electlc Power Company (2) Resubmission

FERC FOFtt NO,1 {EO.12-96) Pâ96 4

5. Have you engaged as the principal accountanl to audit your financial statements an accountant who is notthe principal accountant for your previous yea/s certified linancial statements?

(1) tl Yes...Ënter the date when such independent accountant was initially engaged:(2) E No

4' State the classes or utility and other services furnished by respondent during the yeãr in each State in whichthe respondent operated.

Publlo utlllty cngaged :Àl gaacratf.lgr, Durcba¡:lag, t¡a¡¡ÊúLttl.ng, dlatrlburlus and eclll¡rg elêctric €¡6r!ry.Quållfl.'tl Ëo do bullnc¡¡ j'a tbê stateB of .ãrk¡nsas, tær¡l,sle¡a, okl,ahù¡ a¡¡d 1¡år.rg. '¡lbe Ccqra¡x!' orr¡st¡¡ng¡d¡¡lon tacllitlca buÈ 9:røv1,ôö! ¡¡o Ë16cürlc eplvl,ce a! rstal.! lD ohlah@a.

3. lf at any time during the year the property of respondent was heldrece¡ver or trustee, (b) date such receiver or trustee took possession,trusteeship was created, and (d) dale when possession by receiver or

by a receiver or trustee, give (a) name of(c) the authority by which the roceivershíp ortrusteê ceased.

Noü åopllc*ble

2. Provide the name of lhe State under the laws of whichlf incorporated under a special law, give reference to suchof organization ând the dats organized.

respondent is incorporated, ând date of incorporation.law. lf not incorporated, state that fact and give the ¡/pe

Stats oÉ Delawa¡r¡ifuûå 29, 1912

' 1' Provide name and title of oflicer having custody ol lhe general corporate books of account and address ofotfice where the general corporate books are kept, and address of otfice where âny olher corporate þooks of accountare kept, if different from thal where the generalcorporate books are kept.

F. gcot,t llravLa, À8sj,sta¿è CÐÂtrol1êr272 E.eE glxtb Str6ê!In¡lsa, oklÊbq!å 7¿119

GENERAL INFORMATION

Year/Period of Fleport

End of " 2015/Q4

Date of Report(Mo, Ða, Yr)

lt

Thís Report ls:(1) m An Original(2) ü A Resubmission

Name of Respondent

Southwestem Electric Power Company

FERC FORM No.1 {ED. 12.8Ð PAGE IO1

American Electric PowerCompany, lnc., a registered holding company, owns 100% of the Respondent's outstanding sharos ofCommon Stock.

I. ll any corporallon, business lrust, or similar organization or a combination of such organizations joinlly hefdcontrol over lhe repondent at lhe end of the year, state namê ol controlllng corporation or organization, mânner inwhich control was held, and extent ol conlrol, ll control was in a holding company organization, show lhe chainof ownership or control to the main parent company or organization. lf conlrol was held by a lrustee(s), slatename of trustee(s), name ol benaficiary or beneficiearies lor whom trust was maintained, and puçose of the trust.

CONTHOL OVER RESPONDENT

Year/Period of Beport

End of 2o15/Q4

Date of Report(Ma, Ða, Yr)

tt

This Report ls:

(1) m An Original(2) ü A Flesubmission

Name of Rospondent

Southwestern Elecldc Power Company

FERC FOBl,t NO. t (ED. t2-9ô) Page 102

joinlly w¡lh Cleco Fower Company LLC27

Ownership of lhe Oxbow Mining Compâny is held26

Foolnote 3 -25

24

purchasô l0O% ol the lignite mined,23

Entities - Respondenl conl¡acts to22

Accounting guidance for Variable lnlerest21

Footnote 2 -20

19

and Oklahoma Gas and Électric Company.18

jointly with Arkansas Power and Light Company17

Ownership of The Arklahoma Corporation is held16

Footnots 1 -15

14

100Energy CompanyMulual Energy SWEPCO, LLC13

't2

350Lignite Mine ResefvesOxbow Ligníte Company, LLC11

f020Lignite Mine OperatorSabíne Mining CompanyI

I100Ugníte Mine OperatorDolet Hills Lignite Company7

6

147.6Electric TransmissionThe Arklahoma Corporation5

4

Acquisition.t

100Aid in Right of WaySoulhwest Arkansas Utíl¡ties Corporation2

1

FootnotsReî,(d)

Percent VotingStock Owned

(c)

Kind of Business

(b)

Name of Company Controlled

(â)No.

Name of

Soulhwestern Electric Power Company Original Dâ,End of 5/Q4

(2) Resubmission 1l

1. Report below the narnes of all corporations, business trusts, and similar organizations, conlrolled direcily or índirectly by respondentat any time during the year. lf control ceased prior to end of year, g¡ve particulars (details) ¡n a footnote.2' lf control was by other means than a direct holding of voting rights, state in a foôtnote the manner in which control was held, namingâny intermediaries involved.

ll control was held ¡ointly with one or more other inlerêsts, slat6 the lact in a fÕotnole and name lhe other interests.

Definitions1. See the Uniform System of Accounts for a definition of cÕntrol.2. Direct conlrol is that which is exercised wilhout interposition ot an intermediary.3' lndirect conlrol is that which is exercised by the ínterposition of an intermediary which exercises direct control.4. Joint control ¡s that in which ne¡ther intelest can effectively control or direct aclion without the consent ol the other, as where thevoting conlrol is equally divided between two holders, or each party holds a veto power over the other. Joint control may exist by mutualagreement or understanding between two or more parties who together have control within the meaning of the definition of control in theuniform system of Accounts, regardless of the relative voting rights of each party.

FERC FORM NO.1 (ËD. 12-96) Page 103

44

€42

41

Ð39

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37

3ô

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't2

t1

10

II7

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5

4

.t

2

1

üataryfor Yeár

{c}

NAme oI (Jrrcer

(b)

t tilê

ta)

uneNo.

1. Report below the name, title and salary lor each executive officer whose salary is $50,000 or more. An 'executive offícer' ol arespondent includes its president, secretary, treasurer, and vice president in charge of a principal business unit, division or lunction(such as sales, administration or linance), and any olher person who perlorms símilar policy making funclions.2. lf a change was made during the year in ths incumbent of any pos¡tíon, show name and total remuneration ol lhe previousincumbenl, and the date the chang€ in incumbency was made.

OFFICERS

Year/Period of ReportÉndof 2O1lQ4

Date of Beoort(Mo, Da, Yi)ttSodhwestern Electric Power Company

(1)

(2)AnA Rest¡bmission

FEBC FOFM NO. r (EÞ, 12-36) Pag€ 104

DATA


20lvQ4

Date ol Repoñ(Mo, Da, Yr)

This Report is:(1) X An Original(2) _ A Resubmission

Name of Flespondent

Southwestern Electric Power Company

,04 Llne

Executiye Compensation TableThe following table pmvides summary ínformation conceming compensat¡on paid lo or accnred by us on behalf of our Chief Executive Oflicer. our Chief Financial Offìcer andthe three other most highly compensated executive officers, to rvhom we refer coltectively as rhe nanred executive officers,

Non-Equily

IncentivcPlan

Compen-salioo(sx3)

(9

ChaugeinPensionValue

andNon-

N¡me snd Principal Pæilion(a)

Salary($x1)

(b)

Stock.{.çardsi$x2)

(d)

Compen-sation

Earnings($x{)

(s)

AnOther

Compen.salion

f,arnings($)(5)

(h)

qualil'redDefe¡red

Bonus Total($)(i)

($)(c)

Nicholâs K. Àkins -Chairm¿n of the Board andChief Executive Officer

Brian X. Tierney -Executiye Vice President andChief Financial Officer

Robert P. Poçers -Executive Vice President andChief Operating Ofìcer

l.?79,900

'109,?46

709,246

6,719.981 3,1J0,000 199,027 103,658 t 1.452,5óó

1.907.2t6 t.100,000 0 84,r25 3.800.587

I,888.008 I,075,000 0 90,234 3,?ó2.488

David 1l{. Felnberg*Executive Vice President ândGeneral Counsel

59t,426 998,394 800.000 59.069 ó8,t63 2,5n,A52

Ch¿rles 8.7¡hula -Exeû¡tive Vice Presidenþ416.3 t0 1,496.037 570,000 J r.420 54,279 2,6¡ 8,046

Energy Supply

( I ) Åmounts in the salâry column are composed of executive salarics earned for the year shown, which include 26 t days of pay fo¡ 2015. This is one day more rhan thes¡anda¡d 2óO calendar work days and hôlidâys in ä year.

(2) 'lle amornts ¡eported in lh¡s column_ reflect ¡he aggregale grant dâte fair value, calculared in accordance with FÅSB ASC Topic 7 t 8, of performance units and RSUsgrånted.undel our Long-Term lncentive Plan, See Note l5 to the Consolidated Fina¡cial Sratements included in our Form I GK for the yiar ended Deccmber 3 t. 2015 for adiscussion of the relevant assurnptions used in calculating these amounts. With re;pect ro the performance uni6, the eslimates ofthe grant date fair values detemrined inaccordance with FASB ASC Topic 7l 8 assumes the vesting of 100% of rhe performance units awa¡ded. The value realized for rhe performance uniß, if any. will dependon the Cornpany's performance dlring â three-year p€rformance and ves¡ing pe¡iod. 'fhe potential payort. can range from 0 pcrcenr to 200 percenr of the taiget number ofperformance unils' plus any dividend equivalents. Therefore, the maximum amount payaúte for r¡e 2-0lS performãnce unirs'is equal to 59.à07.974 for Mr. ÃkinslS2,é70.090 for Mr. Tiemey: $2,643,176 for Mr. Powen; S1,397,704 for Mr. Feinberg and S 1.25,1,484 forM¡. Zebulq and the m'aximum a¡nount payable for the 2014performance units is equal to 59,408,054 for Mr. Akins, S2.ó33"798 for Messn. Powen and Tiemey, 91,34?,502 for Mr. Feinberg and S Ll4t.72å for M¿ Zbula. The2013 performance units vested on December 31, 20lJ and are shown in the OFion Exercises and irock vesred for 20lJ rable. 'Iie RSUs vesr over a forty month period.

t3) The amounts shown in this column are annual incentíve compensation paid under the Senior Officer Incentive Plan for the year shown. At the ourset of each year, the HRCommittee ser annual incentiYe ta¡8ets and performance criteria that are used añer year-end to determine if and the extentio which executive officen may receive annualincentive award payments under this plan.

(4) Thê amoünts shown ¡n lhis côlumn âre allributable lo lhe increase in the acluarial values of each of the named executive oflicer's combined benefìls under AEp's qualifiedand non-qualified defìned benefit plans determined using interest rate and mortality assump{ioß consistent with rhose used in the Company's financial sraaements. SeeNole 8 to the Consolidated Financial Statements included in our Form lG.K for the year ended Dectmber 31. 2015 for a d'rscussion of ¡he ¡eleva¡t assumptions. Nme ofthe nam€d executive officer received preferential or above-markeN earnings on deferred compensation. The actual change in pension value in 20li for Mi Tierney was(521.6ó4) and for Mr. Powers was (S701.968).

{5) Amounts shown in the Àll Other Compensalioû columû for 201J ínctude: (a) Company contributions to the Company's Retirement Savings plân, (b) Companycontributions to the Company's Supplemental Re¡irement Savings Plan and (c) perquisires. The amoun¡s are listed in rhe foltowing rable:

1 1 450.1

YearlPeriod ol Report

201VQ4I

Date of Report(Mo, Ða, Yr){1) Oríginal

A Resubm

o Respondenl

AII Other Compensation

Mcho¡rs K.ASas

Brta¡ llllerney

RoùcrtP.?orrers

Ð¡vtd IVL

FeiobereCh¡rlesE;

Zebul¡

Ret¡rement Savings Plan MatdrSupplemental Retiæniimt Savings Plan MarchPerçisitesTotal

r t,6tr778,075.13,896

¡03,6J8

r r,9256?,100

5,10084;l2J

I t,9256t,390t?.91990234

n,925,44,911Ir,30768.163

11,9253l ¡008l I,34ó54,279

oftìcers may also have the ocðasional personal use ofevent tickens when such tickets are nc being used for business purpsas, however, therç is no associâted incemental

NO. 1 450.2

48

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42

4'l

40

3S

38

37

36

35

34

33

32

31

30

29

28

The Flespondent does not have an Execut¡ve Comm¡ttes.27

2ô

25

24

23

22

21

20

19

Columbus, OhioDennís Ë. Welch, Vice President't817

Chiet Financial Officer16Columbus, OhioBriân X. V¡ce President ând15

14

Columbus, OhloRobert P. Powers, Vice President't312

Cofumbus,OhioMark C. McCullough, Vioe President11

'10

Columbus, OhioLana L. Hillebrand, Vice P¡esÍdentII

Columbus, OhioÞavid M. Feinberg, Secretary7

oColumbus, OhloLisa M. Barton, V¡ce President5

4

Chief Executive Ofícer3Columbus, OhioNicholas K. Akins, Chairman of lhe Board and2

1

tess J\qotessFfincipa¡ FrName tan&)rn¡e) of D¡rectorutt9No,

1, Repod below lhe infonnalion called for c¡næming æch direclor ol the respondënt who held ofice at any lime during the year. lnclude in column (a), abbreviatedtillæ of the dirætors vlho are otficers ol thê respondenl.

2. Designato members ol lhe Exefltivê Committee by a triple asterisk and lhe Chalman ol thê Erêdrtive Cornmittee by a douHê âstedsk.

DIFËCTORS

Year/Period of ReportEnd of 2015tQ4Originaf

Southwestem Electric Power Company(2) A Flesubmlssion lt

FERC FORM NO. t (8D.12.95) Pag€ 16

41

40

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32

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2A

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15

14

Addendum 4 to Atlachmênl H, Parts 1 and 213

ER07-'t069SPP FERC Electric Tariff 6th Revision Vol. No. 1,12

11

EËt12-4S9-000Rate Schedule 12910

ER12-203-000RateSchedule 1289

EFl12-202-000Rate Schedule I27IEFr l-4632-000Flate Schedule 12ô7

ER12-114-000Rate Schedule 1256

EË12-500-000Flate Schedule '1205




ÊFì12-58-000Hate Schedule 1101

FERC ProceedingFERC Rate Schedule or Taritf Number

uneNo.

1, Please lisl the Commission accepted lormula rales including FËF|C Rate Schedule or Tarifl Number and FERC proceeding (i.e. Docket No)accepting lhe rate(s) or changes in the acoepted rate.

ffi ves

INoDoes the respondent havs formula rates?

' INFOÊMATION ON FORMU|j FATES

FÉRC Bate Schedule/Tadtf Number FEBÇ Proceeding


9¡6 s1 2011Q4Date of Reoort(Mo, Da, Yi)

ttThis Beoorl ls:

(1) El An orisinal(2) n A Resubmission

Name of Respondent


FERC FORM NO. 1 {NEW.12-08) Page 106

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19

18

17Trans FR Updalr16

SPP OATTAtt. H.4AEP SPP 2O1I8R07.1069-00005/14201520150604.518615frans Fñ Updatr14

SPP OATT AIt. H.4AEP SPP 201.8R07"106S-000lAOA2AU20141208-537913Trans FR Updatr12

SPP OATT Att. H.4AHP SPP 2O1i8R13.1606-0000w241201320'13091&300411

Trans FR Updatr10SPP OATT Att, H.4AEP SPP 201:ER07-1069-00005t23t2a1220120523-5V¿4ISPP OATT Âtt, H.4Errala of 2011 UpdatrERI 1.1069-0001?/21t2A112011122,1-5253I

Trans FR Updatra

SPP OATT Att, H-4AEP SPP 201.ER1 1-4671-000o9/2v20d',l201f0928-51236Trans FR Updatr5

SPP OATTAtt. H.4AEP SPP 2O1IER10-355-0000512512A1A20100525-61094SPP OATT Att. H.4Errala of 2009 UpdatrER09-1 198-000081311200920090831-52703

Trans FFI Updatr2SPP OATÎ Att, H.4AËP SPP 2OOIER09-f 1 98.00005/2d200s20090526.53021

Formula Rate FERC RateSchedule Number orTaritl NumberÐescriptionDocket No.

DocsmentDate

\ Filed DateAccession No"

LineN0.

2' lf yes, provide a listing of strh lilings as contained on the Comm¡sslon's eLibrary website

fi yes

INoDoes lhe respondent lile with thê Commission annual (or more lrequent)lilings containíng the inputs to the lormula rate(s)?

INFOHMÀTION ON FORMUIá RATESFËHC Hale Schedule/Taritf Number FEHC proceeding

Year/Period of ReportE¡66¡ 2015/Q4

Dale of Reoort(Mo, Da, Yi)

ttThis Reoort ls:

(1) El An orislnal(2) f] A Fesubmlssion

Name of Respondent

Southweslem Eleclric Power Company

FERC FORM NO. r (NËW.124S) Page l06a

Mß42

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40

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38

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34

3e

32

31

30

29

2B

27

26

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?2

21

2A

2(b)Dislribution ol Salaries and Wages35+35519

Other (Account 2&3)18

'19(k)Accumulated Defened lncome Taxes -276-27717

Other Properly (Account 282)1ô

11(k)Accumulated Delened lncome Taxes -2t+275t58(b) - (0Other Defen€d Credils26914

(Account 190)13

18(c)Accumulated Oelened lncome Taxes -2U't2

1, 12(c)Materials & Supplies227't1

Êlectric Utility Plant't0

25-26(c)Accumulated Provision lor Depreciation ol215s

1(b)Construction Work ln Progress - Elect¡ic218I86-92,94.95, 97, 1047

46,49, 50, 58, 75,(s)Electric Plant in Service204-2076

for Depreciation, Amortization and Þepletion5

33(0)Summary of Utility Plant & Accumulaled Provisions200-2014

24tc)Comparal¡ve Balance Sheet112-l't33

1€CIÇom paratlve Balance Sheet1't2-1132

57(c)Comparative Balance Sheet110-1r11

llne NoColumnSchedulePage No(s),

UneNo.

1. ll a respondent does not submit sr.nh filings lhen indicate ¡n a footnote to the applicable Form 1 schedule t¡vhere lormula rate ¡nputs differ lromamounts reported in lhE Form 1.

2. The foolnole should provide a narative description explainirq how the 'ral€' {or billing} was derived il dÌlferent from the reported amount in heFonn 1.

3. The lootnote should explain amounts excluded lrom the ralebase or where labor or ot¡er allocation tactors, operalÌng expenses, or other itemsimpacting formula nto inputs differ from amountg reported in Form 'l schedulo amounls.

4. Where thle Commission has provided gu¡dancê on formula rate inputs, the spec¡fic proceeding should be noted in the footnote.

INFOBMATION ON FORMULA HATE.SFormula Bate Variances

Year/Period of ReportE¡¿61 201flQ4

Name0riginal

Southwestem Eleclric Power çompany(1 An(2) A Flesubmlssíon tl

FERG FORU NO. I (NEW.12-08) Page 1{l6b

TI{IS PAGE INTENTIONALLY LEFT BLANK

INTENTIONALLY LEFT BLANKSEE PAGE 109 FOR RËQUIRED INFORMATION

Give particulars (details) concerning the maiters indicaled below. Make thê statements explícit and precise, and number lhem inaccordance w¡th the inquiries. Each inquiry should be answered. Enter'none,' 'not applicablê,' or'NA' where applicable. lfinlormation which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears,1. Changes in and important additions to franchise rights: Describe the actual conslderalion given therelorê änd state lrom whom thelranchise rights were acquired" ll acquired without the payment of consideration, slate that lact.2. Acquisilion ol ownership in other companies by reorganization, merger, or consolidation with olher companies: Give names olcompanies involved, particulars concerning lhe {ransactions, name of the Commission authoriz¡ng the transaction, and reference toCommission authorization.3. Purchase or sale of an operating unit or syslem: Give a brief description ol thê properg, and ol the transactions relating thereto,and reference to Commission aulhorization, if any was required. Give date journal entries called lor by the Uniform System ol Accounlswere submitted to the Commission.4" lmporlant leaseholds (other than leaseholds for natural gas lands) that have been acquired or given, assigned or surrendeled: Giveeffeclive dales, lengths of lêrms, namês of parties, renls, and other condition, State name of Commission authorizing lease and give

reference lo such authorizaiion.5. lmportant extension or reduction of transrnission or distribution Eyslem: State territory added or relinquished and date operâtiônsbegan or ceased and give rêference to Commission authorization, if any was required. State also the approximate number ofcustomers added or lost and approximate annual revenues ol each class of service. Each natural gas company must also state majornew continuing sources ol gas made available to it kom purchases, development, purchase contract or otherwise, giving location andapproximale total gas volumes available, period of contracts, and other parties to any such arrangemenls, etc.6. Obligations incurred as a result of issuance of securities or assumption of liabilities or guarantees including issuance ol short-termdebt and commercial paper having a maturity of one year or less. Give reference to FERC or State Commission authorizalion, asappropriate, and the amount of oblígalion or guarantee.7. Changes in articles oî incorporation or amendments to charter: Explain the nature and purpose of such changes or amendments,8. State the estimated annual effect and nature of any imporlant wage scale changes during the year.9. Statê briefly the stalus of any materially important legal proceedings pending at lho end of the year, and the rêsults ol any suchproceedings culminated duríng the year,10. Describe briefly any mâtoriãlly important lransactions of the respondent not disclosed elsewhere in this reporl in which an offícer,director, security holder reporled on Page 104 or 105 of the Annual Report Form No. 1 , voting lrustee, a$sociated company or knownassociate ol any of lhese persons was a party or in which any such per$on had a material interest.11. (Resen¡ed.)12. lf lhe ¡mportânt changes during lhe year relating to lhe respondent company appearing in lhe annual report to stockhofders areapplicable in every fespect and lurnish ths datâ required by lnstructions 1 lo "l 1 abovè, such notes may be included on Ìhis page.13. Describe fully any changes in officers, directors, major security holders ând voting powers of the respondent that may haveoccurred during lhe reporting period.

14. ln the event that the respondent participates in a cash management program(s) and ils proprietary capilal ratío is less than 30percent please descrìbe the significant events or lransactions causíng the proprietary capital ratio to be less than 30 percent, and the€xtent to which the respondenl has amounts loaned or money advanced 1o its parent, subsidiary, or afliliated companies through acash managemênt program(s). Addilionally, please describe plans, il any to regain at leasl a 30 percent proprietary ralio.

IMPORTANT CHANGES DURING TI.IE OUARTER/YEAR

Year/Per¡od of ReporlEnd of 2O15/Q4

Date of Report

ttlnis Heport ls:(1)(2)

An OriginalA Resubmission

Name ol Hesponclenf


FERC FOFM NO. 1 (ED.12-96) Page 108

CHANGES DURING QUARTER¡TEAR


2015/Q4

Date of Report(Mo, Da, Yr)


Name of Respondent

Southwestem Eleckic Power Company

t

2. None

3. None

4. None

5. None

6. FERC Authoritv: Docket No. ES15-7-000lssued $400.0M, 3.9o/o senior unsecured Notes, series J, maturing April t,2a4sRemarketed $53.5M ,1.6yo parish of Desoto pollution control Revenue

Refunding Bonds (southwestern Electric power company project),Series zAtO, maturing January L, ZA1-?.

7. None

8. None

9. Please refer to the Notes to Financial statements pages tz2-!23

,l lì Àl^-^ÅLr. tìtLrt tE

LL. (Reserved)

12. Not Used

None

Twenty-Five {25) year franchiseewal expíring on November 12, 2040ren

City ofLongview, TX

Renewed onNovember 12,2AL5

None

Twenty-Five {25} year franchiserenewal expiring on January 30, 2040

Village ofEdgefield, LA

Renewed onJanuary 31,2015

Consideration

Period of Franchise &TerminationCommunity

Date Acquired

Or Extended

NO. r D.1 109.1

IMPORTANT CHANGES OURING THÊ QUARTER/YEAR {Conlinued)


201€/O4


ttThis Fleport is:

{1) X An Original{2\ A Resubmíssíon

Name ol Respondenl

Southwestem Ëleclrlc Power Companv

13. Michael 5. lsenberg resigned as Vice President 04/23/2AßDennis E. Welch resigned as D¡rector A8,ßtlzALsÐennis E. Welch resigned as Vice President 0Sl3U2Ðt5A. Wade Smith elected as Vice President A8/281201sJeffrey D. Cross resigned as Assistant Secretary L013A/2015

William E. Johnson elected as Assistant Secreta rV L2/L7 /2015

14. Proprietary capital ratio exceeds 30%

FERC FORM NO.1 D.1 109.2

FERC FORM NO.1 (REV.12-03) Page 110

02'l'l and 1Allowances52

0202-203t227Nuclear Materials Held for Salo510227Other Materials and (1500227Merchandise49

73,666,4997t227Plant Materials and (1480227and Exlracted 5s)Flesiduals47

I227Fuel Stock Expenses Undistr¡buted4898,841227Fuel Stock45

34J4A324IAccounts Beceivable from Assoc.4441,033,220Notes Fleceivable from Associated43

515,94969J91Äcct.-Cred¡t,{ccum. Prov. lor4275525,665,011Qther A.ccounts Beceivablê41

38,720,1Cuslomer Accounls Fleceivable4004tNotes Receivable390Cash lnvestments380Fund37

75734)361.660,8611

1Cash350Cash and Funds34

CURBENT ANO ACCRUED ASSETS331975l49,1 8-21 and 23-31and lnvestmenlsTOTAL Other32

0Portion of Derivative Assets -31

0Portion ol Ðerivativ€ Assets ('t3021,427,1331 1,7312e)Funds29

0Other 1Funds280Amortization Fund' Federal2701Fund260Funds25

179,45211,1Other lnvestments240228.229Portion ol Allowances23

224,lineCost of Account 1 23.1 , See Footnote22133,828,224-225123.1lnvestment ¡ñ Com21

0lnveslments ín Associated Com20741and Amort,Accum. Prov. for't9

3,2412118

OTHER PROPEÊW AND INVËSTMENTS170Gas Stored J- Noncurrent16

-5S,712,575-58,581{1Plantuti155,433,731,8235,832,Total ol lines 6 and IPlantNet14

0Total of lines 7-11 less 1Net Nuclear Fuel130202-203Accum. Prov. for Amort. ol Nucl, Fuel Assemblies 20.5)120Nuclear Fuel Under 20.6)Leases110ñuclear Fuel100Nuclear Fuel Assemblies in ReactorI0Materials and Assemblies-Slock AccountNuclearI0202-20520.1and Fab.in Process of Ref., Conv,Nuclear7

5,433,731,823Total of line 4lessPlantNei6732,620,4422,8?8,867,841200-20111Accum. Prov. for Amort r15)1115

8,166,352,2658,ô6ITotal of lines 2 andPlantTOTAL4471 ,556744,71A,200-201Construclion Work in3

70976,527701-106,11Plant2

UTILITY PLANT1

Prior YearEnd Balance

12t31

Current YearEnd of Quarterlfear

BalanceRef,

Page No.(b)

Title of Account

Line

No.

coMpARATtVË BALANCE SHEET (ASSETS AND OTHER D EBrTS)


End of 2015/04


This Report ls:(1) e AnOriginal

A Resubmission

Name of Respondent

Southweslern Electric Power Company

FERC FOHM NO.1 {BEV. 12-03} Page 111

6,4r9,33s,2876,770,503,269TOTALASSÊTS (lines l4-16,32,67, and 84)85

645,553,0'tSM4,65S,580Total Ðefered Debils (lines 69 through 83)84

00Unrecovered Purchãsed Gas Costs (191)83

180,042,979185,093,625234Accumulated Oefe¡red lncome Taxes {'tgO}82

6,952,3095,998,037Unamorlized l-oss on Reaquired Oebt {189}81

00352€53Rêsearch, Devel. and Ðemonslration Expend. {188)80

00Def. Losses trom D¡sposilion of Utility Plt. (187)7g

33,493,39ô33.836.831233Miscellaneous Delerred Þ€bits ('f 86)78

0(Temporary Facilities {'l 85}77

97,6s3201,88çClearino Accounts {'184)76

0COther Preliminary Survey and lnvestiqation Charqes (183.2)76

0CNalural Gas and 183.174

236,021379,851Prêlim. and7g

417,432,594408,919,856282Olher Begulalory Assets (182"3)72

0c290bUnrecovered Planl and Regulatory Study Costs (182.2)7'.|

00230aExlraordlnary Property Losses {1 82.1)7A

7,298,06710,229,491Unamorti¿ed Debt Expenses (181)69

DEFFHRED DEBIT$68

3/.7,770,823302,084,85€Total Current and Accrued Assels (Unes 34 through 66)67

0((Less) Long-Term Portion ol Derivative lnstrument Assels - Hedges (17666

0(Derivat¡vê lnstrumenl Assets - Hedges (176)65

0((Less) Lonq-Term Portion ol Derivative lnstrument Assets {175}64

30,874758,27eDerivative lnslrumenl Assets {175)63

2,030,000cMiscellaneous Çur¡ent and Accrued Assets (174)62

27,948,9612'1,726,861Accrued Revenues61

1,337,7071,497,275Rents Recêivable {172}60

61,38556,21!lnterest and D¡vidends Receivable ('l 71)59

00Advances for Gas {166-1671s8

'14,033,288Prepayments (165)57

00Liquefied Natural Gas Stored and Held for Processing {164.2-1S4.3)56

0(Gas Stored Underground - Cunent {'164.1)55

0(227Stores Expense Undistr¡but€d (f 63)54

0((Less) Noncunent Porlion of Allowances53

PrÌor YearËnd Balance

12t31(d)

Current YearËnd of Quarle/fear

Balance(c)

RèI.Page No.

(b)Title of Account

(a)

LlneNo.

COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBlTSlcontinued)


End of 2015/Q4

Date of Report(Mo, Da, Yf

lt

This Report ls:(1) I AnOriginal{2) n A Resubmission

Name of Respondent

Southwestern Ëlectríc Power Company

t'|2FERC FOHM NO. 1 {rev.I2-09}

0Term DebtMatured450

Þeclared4447,æ1lnterest Accrued4333,78S,49365,51262-263Taxes Accrued42

6t41

'l116,48tÍ1,1Accounts400

toNotes3941

,fAccounts38

Notes37LIASILITICUHFENT36

104,625,llNoncurrent Liabilíties 26Totâl3546,555.Asset Retirement

of Derivative lnstrum 6nt33ool De¡ivative32

7to12,741Accumulated Provision lor Fate Relunds3't0

Accumulated Miscellâ¡eous ProvisÍons30'|1

Accumuhted Provision lor Pensions and genefits2S77.1andAccum ulated Provision lor28

0lnsurancelorAccumulated2792,056Leases - NoncurenlUnder

OTHEF NONCURBENT LIABILITIES25,885

18DebtTotal241f51

Unamoñized Discount on Term23

Premium onu256-2ö7DebtOther21

Advances from Assoclaled20

'19256-267IBonds18

LONG-TERM DEBT172,096,I2Totalf6

7-9,331lncomeOther15

114

1Stock1327,641'118-{1S1Undistributed12

1119I(2'15, 215.1, 2tRetained110zs/,b

't0 0254Discount onI 0252Recoived on StockII253Paid-ln7

0Premium on StockÞ0

lor ConversionStock50

Stock Subscrib'ed4025G'251Preferred Stock lssued3

1250.251Common2

PROPRIEl'ABY1

Prior YearËnd Balance

12t51(d)

Current YearEnd ol Quarterllear

Balance(c)

Ref.Page No.

(b)

Title of Accounl(a)

No.Une

COMPARATIVE BALANTE SHEET (LtABtLtTtES AND OTHER CRËD|TS)

Year/Period ol Report

2015/Q4end of

Date of Fleport(mo, da, yr)

tt

This Report is:

) m An OriginalA Resubmission

Name of Respondent

Soulhwestem Electric Power Company

FERC FORM NO.1 (rev. t2-03) Page'113

ô,419,333,2876,770.503.26çTOTAL LIABILITIES ANO STOCKHOLÞER EQUITY (lines 16, 24, 35, 54 and 65)66

1,601 ,025,3731 ,644,721,51ÊTotal Ðeferred Qredits (lines 56 through 64)65

266,367,7s7279,236,354Accum. Defened lncome Taxes-Other (283)64

1,229,044.8051,277,724,601Accum. Delened lncomç Taxes-Other ProperU (282)63

0c272-277Accum. Defened lncome Taxes-Accel. Amort.(281)62

53,34542,234Unamortized Gain on Reaquired Debt (257)6l71,001,8S956,715,424278Olher Regulalory Uabilities (254)ô0

24,726,ô9622,524,O14269Other Oeferred Credits (253)59

0cDefened Gains from Þisposition ol UtiliV Plant (256)58

9,830,8718,478,886268.267Accumulated Delened lnvestment Tax Credits (255)57

0cCuslomer Advances for Construction (252)56

DËFEÊRËÞ CREDITS55

558,334,368632,300,303Total Cunent and Accrued Uabilities {lines 37 through 53)54

00(Less) Long-Term Portion oÍ Derivative lnskumenl Llab¡lities.HedSes53

00Ðerivalive lnslrument Liabilities' Hedges (245)s2

2,090,613{Less) Long-Term Portion of Derivative lnstrumenl Liabìlities51

I.082.0395,219,082Derivat¡ve lnslrument Liabilitles (244)50

4,321 ,2774,397,48:Obligations Under Capital Leases-Çunent (243)49

I28,514,9741Misoellaneous Currenl and Accrued Uabilities (242)48

5,153,il94,905,042Tax ColleÇtions Payable (241)47

0(Malured Interest {240)46

Prior YearËnd tsalance

12131(d)

Current YearSnd ol Quarter/Year

Balance(c)

Flet.

Page No.(b)

Title of Account(a)

Line

No.

COMPARATIVE SALANCE SHEET (LlABlLlTlES AND OTHER CREDlTSntinueo¡


end ol __ 201_51a4

Date of Report(mo, da, yr)

ll

Thís Report is:

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

Name of Respondent

Southwestern Eleckic Porver Çompany

I(Mo, Þ9, Yg)

Formula Ratê usos 13 month average.

1

FOOTNOTF DATA


2015/Q4


ttThls Report is:(1) X An OriginalQ) A Resubmission

Name of Respondent

Southwestem Eleclrio Power Cornpany

c

Formula Rate uses 13 month average.

24 Column: c


I 'l1

248,600,60f276,590,æ6Net Util Oper lnc (Ênter Tot line 2 less 25) Çany lo pgt lT,line 27261,U5,740,2751,523,074,623TOTAT Utility Openating Expenses (Ënter Total of tines 4 thru 24125

1,493,33'I,874,199Aæretion Epense (41 1.10)24

Losses irom Ðisposition oi Âlto,,eanæs (4,l L9)235r9w,474(Less) Gains from Oisposidon ol Atlowances (41 I.B)22

Losses from Disp. of Utility Plant (al t.7) '21

(Less) Gainsfrom Ðisp. ot Utility Phnt (411.6)20-f,376,532-1,351,98526ôlnvesù¡ent Tax Oredit Adj. - Net (al f.a)1985,279,021153,324,t94234,272.277(LesslProvision lot 0elened lncome Taxes{r. (411,.l)18

324,870.46t192,903,61r2U,272-2nProv¡s'ron lor0efened lncome Ïaxes (410.11172,984,æ52,125,652262-263otlcr (409.1)16

-r74,738,39644,862,813262-263lncome ïaxes - Fedenl (409.1)1584,285,01188,039,939262-263Taxes OlherThan fncoma Taxes (408.1)14

72,00072,000(Less) Hegulatory Credits (407.4)t3I,952,52Sr,403,456Reguhtory 0ebits {407.3)12

Anort ol &nvers¡on E4enses (407)11

Amort. Property Losses, Unreæv Phnt and Regulatory Study Cosls (407)JO

33ô-337Amort. of Uïfty Plant Aq. Âdj. {406)99,788,43012,008,664336.337Amort. & Depl. ol Urility planr (404403)8

537,267825,3333s6-337Ðepræiation Expensô tor Asset Retiremenl Costs (409..l)

r72,928,056177,862,041336-3370epreciation Ëxpense (403)6r49,242,8861 55,932,517320-323Maintenanæ Expenses (402)5

1,159,124,4361,000,207,051320.323operaton Expenses (401)4

Operating Expenses3r,8sd340,876I,799,684,919300-301Operating Revenues (400)2

UTILIW OPERATING INCOMÉ'|

Prior 3 Months

Ended

Quarterly Only

No 4th Quarler

(0

Çunent 3 Monlhs

Ënded

Quartedy Only

No 4th Quarter

(e)

Total

Prior Year to

Date Bähnce for

Quârler/Year

{d)

IolalCuíent Year lo

Date Balanæ for

Quaderffear

(c)

(Bef.)Page No.

(b)

Title of Account(a)

LineNo.

Southwestem Eleêtric Power Company(1)(2)

AnDate(Mo'

End of 20151c'4A Resubmission

Quarterly1. Report in colum n (c) the current year to date balance, Column (c) equals the total of adding the data tn colum n (s) plus the data tn cofumn {i) plus the

rn column ß) Report ¡n column (d) similar dâta for the previous year, This ¡nformation ts reported tn the annual liling onlyEnter tn cÐlumn (e) lhe balance for the reporting quarter and tn colum (0 lhe balance for the sâme threê month pefiod for the pr¡or year.Feport In column (s) the quarter to date am ounts for elêctric utility lunction; tn column (i) the quarler lo date amounls fo¡ gas ut¡ lity, and tn column (k)quarter to date amounts for othêr ulility function lor the curr€nt year quarter.

Beport rn column (h) the quarter lo date amounls for êleclric utility funclion; tn cofum n ü) the quarter ìo date amounts for gas uti riry, and in column (r)quarter io date amounls for other utility function for the prior year quarter,

ll addltional columns are needed, place lhem in a foolnote.

or Quarterly it âpplÍcableDo not report fourth quader data in columns (e) and (f)

6. Report amounts for accounts 412 and 413, Revenues and Expenses from Utility Plant Leased 1o Others, in another utility columnin a similar manner toa utility department. Spread the amount(s) over lines 2 thru 26 as appropriate. lnclude these amounts in columns (c) and (d) totals.7. Fleport amounts in account 414, Other Utility Operating lncome, in thê same manner as accounls 412 and 4lg above.

FERC FOFM NO. r/3.o (REV.02{4} Pag€ 114

262.t8,600,601276,590,296

25't,M5,744,2751,523,074,623

24't,493,3321,874,199

23

22519222,474

21

20

19-1,378,5321,35't ,985

1885,273,021'r53,324,194

"t7324,870,461192,903,6't1

162,984i3352,125,652

15-'t74,738,39644,862,8r3

1484,285,01188,039,939

l372,ûO72,ñO

121,952,5e91,403,456

l'l't0IB9,788,4{'012,008,ô64

7547,?:67826,333

6'l72,928,0561ã,862,041

5149,242,88615s,932,5r7

41,159,124,4361,000,207,051

3

2't,894,340,8761,799,ôô4,919

1

UneNo.

Prevpus Yeat l0 uate

{in dollars)

{t}

{jurenl Yeef lo uale

(in dolhrs)

(k)

Pfevious Year to Ðate(in dollars)

ü)

Çufrent Year to Date(in dollars)

(i)

Prev¡ous Year to Date(in dollars)

(h)

Çurrent Year to Dale(in dollars)

(s)

OTHER UTILITYGAS UTILITYELECTRIC UTILITY

g. Use page 122 for imporlant notes regarding lhe statem€nt ol income for any account thereof.10. Give concise explanatione concèrning unsettled rate proceed¡ngs where â contingency ex¡sts such that refunds of a material amount may need to bemade to lhe utility's customers or wh¡ch may result in material refund to the ut¡l¡ty with respect lo power or gas purchases. State lor each year effectedthe gross revenues orcosts lq wtìlch th€ conting€ncy relates and the tax eflects logeth€r with an explanation of the major faclors which affecl lhe rightsol the utility to relain srch revenues or recover amounts paid with respecl lo pou,er or gas purchases1l Give concise explanations conceming significant amounts of any refunds made or received during the year resulting from settlement of any rateproceeding affecling revenues received or costs ¡ncuned for power or gas purches, and a summary of the adjustments madg to balance sheel, income,and expense acc{unts.12. lf any notes åppearÍng in lhe report to stokholders are applicable to the Statement of lncome, such notes may be included at page 122.'13. Énter on page 't22 a concise explanation of only those changes ln accounting melhods made during the year which had ân effect'on, net ¡ncomë,including the bas¡s of allocalions and apport¡onments from lhose used in the preceding year. Also, give the appropriate dollar effect of such changes.14. Explaín in a footnote il the previous yeallquartels figures are d¡fferent lrom thal reported in prior reports.15. lf lhe columns are insuficient lor reporting additional ulility depãrtrnents, supply the appropriate account tilles report the information in a footnote toth¡s scheduls.


End of 2O15/Q4Oate of Reoort(Mo, Da, Yi)lt

This Reoort ls:(1) fiAn Original(2) TIA Bêsubm¡ssion

Name of Respondent


FERC FORM NO.1 tEo.12.96) Page 11S

TIIIS PAGE INTENTIONALLY LEFT BLANK

140,36925?192.348,180Net lncom€ (ToþI ol linê 71 and ?)78

Extnordhary ltems After Taxes (lin6 75 þss line 76)77

262.2ô3lncome Taxes-Federal and O$er (409.3)7ô

N€t Éxtraordinary ltems FoÞl of line 73less l¡nÊ 74)75

{Les} Exfudinarv Deductions (435174

E¡üaordinary lncorn (434ì73

Extaordhary ltems72

140.369257192.346,180lncomê Eetore Exfaordinary ltens (Tobl ol lines 27, 60 and 70)7t

'116.020,639f 1û,98S,1nNel lilercS Chargos flohl ol l¡n€s 62 üru 69)70

6,948,96514327,180(Less) Állowance for Borowed Funß Used During Consüudion{r. {432}69

8.0652956.9ô3.576Oher lnleresl ão€ns€ {4í}1168

188,40,{75253lnteresl on Debl lo Assoc. Comoanies (430)67

lf .n2r f,1 t2Gess) &norlization of Gain on Heaquired 0ebt4¡edit {429.1)66

&ess) Arnort ot Premiun on Debt€redil {4æ)65

't,213,1829í4C73Amortizatlx ol Loss on Beaquired Debt (428.1)M1,938,3æ2,144,123Amoû ol oebtOisc. and Expenso {428)63

f 1 1,595,5r1 15,690¿{4lnteros't on Long-Tenn Debt {427}62

lnterest Charges61

7.789¿9526.745.0ô1Net Oher lncon¡e and Deductions Cfobl of linos 41, 50, 59)ô0

-2.304.597.2.364.602TOTAL Taxes on Oher lncone and Deduc{ions fTotal of lines 52{8)59

(Less) lnvestn€nt Tax Credits (420)58

lnvesùnent Tax Credit Adi.-Net (41 1.5ì57

r,096,041845,977t34,272-2n[ess) Prsvbþn for oefened lrcome Taxes{r. (41 1.2)56

't,494,147t.756,953231,272.2nPro¡sion lor Oefened Inc. Ta(es {410.2}55

-76,21f73,692262-263lnæme Taxes0üpr {4{X}2}s-2,626,492-3,37r,59t262-263lncome Taxes-Federal (409.2153

n,2l262-2ô3Taxes Oüer Than lnæms ïaxes (4082)52

Taxes Appl¡c. lo Oher lncome and Deductions51

10,34ô,1848,310,0t6TOïAL Oüer lncome Deductions {Tohl of lines 4i, üru 49)50

7.533.3677,065,538Oüer Oeductions (42ô.5)49

1.248,9.ôt.0n.s2Erp. fø Ceñain Civic, Political & Fehted ,Cc,l¡vilþs (426.4)48

60,94817,345Penafües (4ã63)47

Life losuranca (428.2)46

r,502.552196,6't7Donations f428.f)45

Miscellaneous Amortízalion (425)44

3,09110.r94Loss on Ð¡soosition of Proærty {42f .2)ßOüer lnconp De<luc'lions42

15,830.88232.690175TOTAL Ohet lncüre (Enter ToÞl of lines 31 $ru 40)41

r0,403Gain on Disposilioo ot Property (42'1.1)40

1,088,9328s4,53€Miscelhnæus Nonop€nlinq lnæme (421)39

1't,947,35126,396,865Allowancs lor Olher Funds Used Dudnq Constuc'tion (419.1)38

298,8251,23ô,821lnterest and 0ivilend lnc0me {{19)37

2.2't8.3783.866.217119Equity in Eamings of $ubsidhry Companies {418.1)36

277.39ô325.633Nonope¡aling Renhl lncorn€ (418)35

(Less) Eloenses ol Nonulilitv oreralions (4l7.lluRevenues From Nonutilitv Ogsntions (4.l7)33

(Les) Costs and E¡o. ol Merciandisíno, &b. & Conüact Wod< (416132

Fevenues From Metchandisinq, Joblinq and ConfadWort (415131

Nonutilly Openating lnærc30

Other lncom€29

Oher lncome and Oeductions28

248,600,ô01276,590,296Net Utility Operatinq lncome {Caried foMard fom paqe 1f 4)27

Priof 3 Months

Ënded

Quartedy On[No 4th Quärler

{f)

oußent 3 Months

Ënded

Quarterly Only

No 4ü¡ Quarler(e)

Previous Year(dt

Cunent Year(c)

{ñef.}Page No.

(b)

Tille of Account(a)

LineNo.

TOTAL


End of 2O15lQ4Date of Report(Mo, Da, Yr)ttSoulhwestem Electric Power Company

{2}


FERC FORM NO.1/3Q (REV.02-04) Pags 't17

APPROPRIATED RËTAINED.EARNINGS (Account 21 5)

1,274252,3571,338,732,361Balance - End of Period ffolal 1,9,15,16,22,29,36,37)38

Transfers from Acct 216,1, Unapprop. Undistrib. $ubsidiary Eamings37{ r00,000,000}-120,000.000TOTAL Dividends Declared-Common Stock (Acct.,lg8)36

35

u33

32( r00,000,000)-120,000,000S19¡{ yql e - 7,536,640 shares oulstanding3l

Dividends Oeclared-Common Stook (Account 438)30

TOTAL Dividends Declared-Preferred Stock (Acct. 437)23

28

27

26

25

24

Dividends Declared-Pref erred Stock {Account 437}23

TOTAL Appropriatíons of Retained Earn¡ngs (Acct.436)22

21

20

19

18

Appropriations of Retained Eamings (Acct. 436)17

138,150,879r88,479,964Balance Iransferred from lncome (Account,l33 less Account 418.1)16

TOTAL Debits lo Retained Eamings (Acct. 439)15

14

13

12

11

10

TOTAL Credits to Retained Eamings (Acci a39)I8

7

6

5

4

Adiustments to Retained {Account,139}3

Changes2r,292,10f,5t81,270,252,A97Balance-Eeginning of Period1

UNAPPROPRIATËD BËTAINED ÊARNINGS (Account 216)

PreviousQuarterlfearYear lo ûate

Balance

(d)

CurrentQuarterffearYear lo Date

Balance

(c)

Contra Primary\ccount Atlected

(b)

Item

(a)

Line

No.

1. Do not report Lines 49-53 on lhe quarterly version.2. Report åll changes in appropriated retained earnings, unappropriated retained earnings, year to date, and unappropriatedundistr¡buted subsidiâry earnings lor the year.3. Each credil and debit during lhe year should be identilied as to the retained earnings âccount in which recorded (Accounts 4gg, 496- 439 inclusive). Show the contra primary account affected in column (b)4. State the purpose and amount of each reservation or appropriation of retained earnings.5. Lisl llrst account 439, Adjuslments to Retaíned Earnings, reflecling adjustments to the opening balance of retained earnings. Followby credit, then debit items ín lhat order.6. Show dividends lor each class and series of capital stock.7. Show separately thê State and Federaf income lax etfect of items shown in accounl 439, Adjustments to Fletained Earnings.8. Explain in a footnole the basis lor determining the amount reserved or appropriated. lf such rsservation or appropriation is to berecurrent, stale the number and annual amounts to be reserved or appropriated as well as the totals eventually lo be accumulaled.9. lf any noles appearing in the report to stockholders are applicable to lhis statement, include lhem on pages 1 22.123.

STATEMENT OF H

Year/Period of ReporlEndof 2015/Q4

Name Respondeot

Southwestem Ëlectric Power CompanyAn (Mo, Da,

tt(z',, A Resubmission

FERC FORL NO. 1l$€¡ (REV. 02-04) Pag€ fig

I

23,735,63527Balanoe-End of Yêâr ffotal lines 49 thru 52)53

52

{Less} Dividends Received (Debit)5l

2,218,3783,866,217Equity in Earnings for Year (Credit) (Account 418.1)50

21,517,25723,735,635BalancaBeginning of Year (Debit or Credit)49

Report only on an Annual Basis, no Quarterly

UNAPPROPRIATED UNDISTFIBUTED SUBSIDIARY EARNINGS (Account

1,270,252,3971,338,732,361TOTAL Retained Ëamings (4cct.215, 215.1,216) {Tolal 38, 47) (216.1)48

TOTAL Approp. Retained Eamings (Acct. 2'15, 215.1) ffotal 45,46)47

TOTAL Approp. Retained Eamings-Amort, Beserve, Federal (Acct. 215,1)46

APPROP, RE-|A|NED ÊARNINGS - AMORT. Fleserve, Federal (Ac6ount 215.1)

TOTAL Appropriated Retained Earninqs (Account 215)45

44

43

42

41

40

39

PreviousQuarler/YearYêar lo Date

Balance

(d)

CurrentQuarterffearYear to Ðate

Balance

(c)

Conka PrimaryAccount Atlected

(b)

Item

(â)Une

No.

1. Do not report Lines 49-53 on the quarterly version.2. Report all changes in appropriated retained earnings, unappropriated retained eârnings, yeâr to date, and unappropriated

und¡str¡butëd subsldlåfy êärningö for lh6 year.

3. Each credil and debit during the year åhould bê identified as 10 thê relained earnings âccount in which recorded (Accounts 433, 436- 4Í19 inclusive). Show thq contra primary account aftecled in column (b)4. State the puçose and amount ol each reservalion or appropriation of retained earnings.5. List first accounl 439, Adjustments to Retained Earnings, reflecting adjustments to the opening balance of retained earnings. Follow

by credit, then debit items ín that order.6. Show dividends for each class and series ol capital stock.7. Show separately the Statê and Federal income låx effect of items shown in account 439, Adjustments to Retained Ëarnings.

L Explain in a footnole the basis lor determining the amount reserved or appropriated. lf such reservation or appropriation is þ berecurrent, state the number and annual amounls to be reserved or appropriated as well as the totals eventually to be accumulated.

9. ll any notes appearing in the report to stockholders are applicable to thls statement, include them on pages 122-123.

STATEMENI OF RETAINED EABNINGS


Endof 2015/Q4Date ot Fleoort(Mo, Da, Yi)ttSouthwestem Eleckic Power Company

ls:Original

(21 A Flesubmission

FERC FORM NO. 1/3-O (FEV.02{4) PagE 't19

Proceeds lrom Sales of lnvestment Securities (a)45

Purchase of lnvestment Securities (a)44

4!l

Associated and Subsidiary Companies42

Dispos¡tion of lnveslments in {and Advances to)41

Contr¡butions and Advances lrom Aosoc. and Subsidíary Companies40

lnvestmenls in and Advances to Assoc. and Subsidiary Companiee39

1,215,5821,576,207Proceeds from Disposal of Noncunent Assets - Fixed Assets38

Proceeds lrom Dísposal of Noncurrent Assets (d)37

Acquis¡tion ot Other Noncurrent Assets (d)36

35

-506,236,562"527,882,974Cash Outflows for Plant (Total of lines 26 thru 33)34

33

4,2A8,207-50,1 12Assets32

Other (provide details in footnole):31

-11,947,951-26,396,865(Less) Allowance for Other Funds Used Ouring Conslruction30

Gross Additions to Nonut¡l¡ty Plånt29

Gross Additions to Common Ut¡lity Plant28

Gross Addilions to Nuclear Fuel27

-s16,975,706-5s'.229,727Gross Addilions lo Utility Plant (less nuclear fuel)26

Construction and Acquisition of Plant (including land):25

Cash Flotr¡s lrom lnvestment Activities:24

23

550,131,268397,362,603Net Cash Provided by (Used in) Operaling Áctivities (Total 2 thru 21)22

21

2,133,1623,40{¡,641Mark-to-Maßet of Risk Managemenl Contracts20

-13,581,10331,456,876Fuel Over/lJnder Recovery, Net'19

18,819,283-28,681,76718

2,218,3783.866,217(Less) Undistributed Eamings from Subsidiary Companies17

11,947,35126,396,865(Less) Allowance for Other Funds Used Dudng Construction1ô

-24,024,842-20,859,740Net lncrease (Decrease) in Other Regulatory Liabil¡Ìies15

-7,298,410't,382,118Net (lncrease) Decrease in Other Regu'atory Assets14

-7,802,89716,797,338Net lncrease (Decr€ase) in Payables andAccrued Expenses13

5,663-2f ,950Net (lncrease) Decrease in Allowances lnventory12

7,661,250-21,434,593Net (lncrease) Decrease in lnvenlory11

24,2æ,33822,065,680Net (lncrease) Deorease in Receivables10

-1,376,532.1,351,985lnvestment Tax Credit Adiustment (Net)I239,989,54640,490,393Delerred lncome Taxes (Net)I

7

6

1,880,5291,331,,156Amortization of Êegulalory Debits and Credits, Net5

JBS,25g,7s3190,696,038ÞepreciatÍon and Depletion4

Noncash Çharges (Credits) to lncome:3

140,369,25719?,346,180Net lncome (Une 78(c) on page 117)2

Net Cash Flow fiom Operating Actlvillesl1

Prev¡ous Year 10 DateQuarterlYear

(c)

çurrent Year to ÐateQuarterllear

{b}

Descriplion (See lnstruction No. I for Explanation of Codes)

(a)

LlneNo.

(1) Codes lo be used:(a) Net Proceeds or Payrnents;(b)8onds, debenlures and olher long-lerm debt; (c) lnclude commercial paper; and (d) ldent¡fy s€paratsly such items âsinveslments, l¡x€d assêts, intangibl€s, elc,

Equivalenls al Eñd of Períod'wilh relat€d amounts on the Balance Sheet.

in thoss aolivit¡ês. Show in the Notes to ths Financials lho amounls of intersst paid (net of amount cspitaliz€d) and incorn€ taxes pa¡d.

dollar âmount of leases capitelizsd !!ilh thg plânt cosl.

STATEMENT OF CASH FLOWS

Year/Period ot ReportEndot 2q1qaj

Date of Report(Mo, Da, Yr)tt

This Reoort ls:(1) [¡Rn originat(2t ¡A Resubmission

Name ol Eespondent

Southweste¡n Eleclric Power Company

FEHC FORM NO.1 {8D.12-96) Pags 120

1,660,861't,s72,&'lCash and Cash Equ¡valents at End of period90

89

1,414,1881,660,8ô1Cash and Cash Equivalents at Beginning of Pedod88

87

24ô,673-88,220ffoþl of línes 22,57 and tr]86

Net lncrease (Decrease) in Cash and Çash Equivalents85

84

-8,903,56981,573,708(Total of lines 70 thru 81)83

Net Cash Provided by (Used ln) Financing Activilles82

-100,000,000-'t20,000,000Dividends on Common Stock8lDividends on Prefened $tock80

79

N€l Decrease in Short-Term Ðebt (c)78

-9,180,'t24Notes Payable ta Assoc¡alêd Compân¡es - Relired77

Other (provide deta¡ls in footrlote):7ß

Common Stock76

Preferred Stock74

-303,500,000Long-term Debt (b)73

Paymênls lor Retirement of:72

7l100,276,555505,073,708Cash Provided by Outside Sources (Iotal 61 thru 69)70

69

58,330,323Notes Payable to Associated Companies68

Other (provide details in foohote):67

Net lncrease in Short Term Debt (c)6ô

861,400793,941Froceeds on Capital Leaseback65

.584,845Long-Tern Ðebt lssuancs Costs64

Common Stocl(63

Preferred Stock62

100,000,000453,500,000Long-Tem Debt (b)61

Proceeds from ¡ssuânce of:60

Cash Flows from Finâncing Aclivities:t958

-90,981,026.479,024,531Total of lines 34 thru 55)57

Net Cash Provided by (Used in) lnvesting Activities5ô

-41,033,22041,03S,220Notes Receivable lrom Associated Companies55

2,423,U6234,403(lncrease) Decrease in Other Special Ðeposits54

Other (provide details in footnote):53

Net lncrease (Ðecrease) in Payables and Accrued Expenses52

Net {lncrease) Decrease in Allovì€nces l-leld for Speculatíon51

Net (lncrease ) Decrease ¡n lnventory50

Net (lncrease) Decrease in Receivables49

2,643,8286,0t4,61348

Collections on Loans47

Loans Made or Purchased46

Prev¡ous Year lo DateQuarlerllear

(c)

Current Year lo ÐateQuarter/fear

{b}

Descrípt¡on (See lnstruction No. 1 for Explanation of Codes)

(a)

LlneNo.

(1) Codes to bo used:(a) N€l Proceeds or Paynenls;(b)Bonds, debenlures and olher lóng-term debu (c) lnclud€ commercial papor; and (d) ldenlily separately such ¡tems as¡nvesvnênls, lixed ass€ts, intangibl€s, elc.

Equivalenls at End of Poriod' with relat€d amounts on the Balanca Sh€€L

in thos6 aötivilies. Showin lhe Nglos to thé Fínancials thê amounts of ¡nlÊrêst pa¡d (n6t of amount câp¡lal¡zêd) and lncome taxes paid.

dollar âmount of leas€s capitalizod with the plant cosl.

STATEMENT OFCASH FLOWS

Year/Period of ReporlEnd of 2015/Q4

Date of Reoort(Mo, Da, Yi)tt

(1)(¿',)

An OrigínalA Resubmission

Southwestem Ëlectric Power Company

FERC FORM NO. I (ED. 12-96) Pags 121

FOOTNOTE DATA


2015/Q4


This Fleport is:(1) XAn Odgind{2) - A Resubmission

Name of Respondent

Southweslern Eleclric Power CompanV

a120

Column lbÌ Column (c) I

2015Cash Flowlncr I {Decr}

2014Cash Flowlncr / (Decr)9ther Operalino Activities - Continued¡

Ulility Planl, NelProperty and lnvêstments, NetMargin DepositsPrepaymentsAccrued Utility Revenues, NetUnamortized Debt ExpenseCIther Deferred Debits, NetOther Comprehensive lncome, NetUnamortized DiscounVPremium on Long-Term DebtAccumulated Provisions - MiscCurrent and Accrued Liabilities, NetOther Ðeferred Credits, Net

Total $

(15,415,524)(1,859,607)

(225,224t17,837,517)6,222,14A

943,45721,877

1,997,852459,828

(8,229,131)

{1,997,712){2,791,966)

{28,681,767)

(14,342,679)(56)

57,7272,446,48A

01,424,5932,922,5602,299,350

354,4144,366,690

19,625,272(335,077)

19,919,293

$$

$

120 Line No,: 48 Calurnn: a

Column

2015Cash Flowlncr I {Decrl

2014Cash Flowlncr I {Ðecr)Other lnvsstinq {Line 48}:

Contribution in Aid of Construction ProceedsEIS lnsurance Proceeds (Energy lnsurance Services)

Tolal

$

$

$

$

2,287,AA93,727,6446,014,613

2,649,928

2,649,9290

FËRC FORM NO,1 ,+50.1

PAGE l22INTENTIONALLY LEFT BLANKSEE PAGË 123 FOR REQUIFIED INFORMATION.

1. Use the spâce below for importanl notes regarding the Balance Sheet, Statement of lncomo for the year, Slatement of RetainedEarnings lor the year, and Statement of Cash Flows, or any account thereol. Classify lhe notes according to each basic statement,providing a subheading for each statement except where a note is applicable to more than onê statement.2. Furnish particulars (details) as to any signilicant contingent assets or liabilities exisling at end of year, including a brief explanation ofany action iniliated by the lnternal Revenue Service involving possible assessment of additional income laxes of material amount, or ofa claím lor refund ol income taxes ol a material amount initiated by the utility. Give also a brief explanation of any dividends in arrearson cumulalive preferred stock.3. For Account 'l 16, Ulility Plant Adjustments, explain the origin of such amounl, debils and credits during the year, and plan ofdispositíon contemplated, giving references to Cormmission orders or other author¡zalions respecting classificalion of amounts as plantadjustmenls and requirements äs to disposítion thereot.4. Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, givean explanation, providing lhe rate treatment given these items. See General lnslruction '17 of the Uniform System of Accounts.5. Give a concise explanation of any retained earnings restrictions and state lhe amounl of retained earnings affected by suchrestrictions.6. lf the notes to financial stâtements relating to the respondent company appearing in the annual report to thê stockholders areapplicable and furnish lhê data required by instructions above and on pages 1 14-121 , such notes may be included herein.7. For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim informalion notmisleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may beomitted.8, For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of lhe most recent year have occurredwhich have a rnaterial effect on the respondent. Respondent must include in the notes significant changes since the most recentlycompleted year in such ilems as: accounting principles and practices; estimales inherent in lhe preparation of the linancial statenents;status of long-lerm contracts; capitalizatíon including significanl new borrowings or modilications of existíng linancing agreements; andchanges resulting from business combinations or disposítions. Howêver were matefíal contingencies exíst, the disclosure ol suchmatt€rs shall be provided even lhough a significant change since year end may not have occurred.9. Finally, it the notes lo lhe financial statements relating lo the respondent appearing in the annual reporl to the $tockholders areapplicable and furnish lhe data required by the above instructions, such noles may be included herein.

NOTES TO FINANCIAL STATEMÊNTS

Year/Period of ReportEnd of 201s/Q4

Date of Report

ttThis Report ls:(1)(2)


Name ol Hespondent


FERC FOHM NO.1 (ED. 't2.96) Page 122

TO FINANCIAL STATEMENTS (Continued)


2015tQ4


This Report is:(1) X An Origínal(2\ _A Resubmission

Name of Flespondent

Southwestern Electric Power Comoany

l2.3.4.5.6.7.8.

9.10.

t l.12.13.

t4.t5.16.

INDEX OF NOTES TO T'INANCTAL STATEMENTS

Glossary of Terms for NotesOrganization and Summary of Significant Accounting PoliciesNew Accounting PronouncementsComprehensive IncomeRate MattersEffects of RegulationCommitments, Guarantees and ContingenciesBenefit PlansBusiness SegmentsDerivatives and HedgingFair Value MeasurementsIncome TaxesLeases

Financing ActivitiesRelated Party TransactionsProperty, Plant and EquipmentCost Reduction Program

GLOSSÀRY OF TBRMS FOR NOTES

When the following terms and abbreviations åppear in the text of this report, they have the meanings indicatedbelow.

Term Meanins

AEGCoAEP

AEP Credit

AEP East CompaniesAEP System

AEPEP

AEPSC

AEP Generating Company, an AEP electric utility subsidiary.American Electric Power Company, Inc., an investor-owned electric public

utility holding company which includes American Electric Power Company,Inc. (Parent) and majority owned subsidiaries and affiliates.

AEP Credit, Inc., â subsidiary of AEP which securitizes accounts receivable andaccrued utility revenues for affiliated electric utility companies.

APCo,I&M, KPCo and OPCo.American Electric Power System, nn electric system, owned and operated by

AEP subsidiaries,AEP Energy Partners, Inc., a subsidiary of AEP dedicated to wholesale

marketing and trading, asset managernent and commercial and industrialsales in the deregulated Texas market.

American Electric Power Service Corporation, an AEP service subsidiaryproviding management and professional services to AEP and its subsidiaries.

FERC FORM NO.1 D.1 123,1

NOTES TO FINANCIAL STATEMENTS (Continued)


2015/Q4

Date ol Report(Mo, Da, Yr)

This Fìeport ìs:

{1) X An OriginalQ) A Resubmission

Name of Respondent

Soulhweslem Electric Power Company

GLOSSÀRY OF TERMS FORNOTES (Continued)

l{hen the fotlowing terms antl abbreviations âppeâr in the text of this report, they have the meanings indicated

below.

Term Meanine

AFUDCAGRAOCIAPCoAPSCAROASUCLECOCWIPDHLC

EISFACFASBFederal EPAFERCFCDFfR

TRS

KGPCOKPCoLPSCMISOMMBtUMTMMWMWhNox

I&MI¡lterconnection Agreement

Allowance for Funds Used During Construction.AEP Ceneration Resources Inc., a nonregulated AEP subsidiary.Accumul¿ted Other Comprehensive Income.Appalachian Power Company, an AEP electric utility subsidiary.Arkansas Public Service Commission.Asset Retirement Obl igation.Accounting Standards Update.Central Louisiana Electric Company, a nonaffiliated utility company.

Construction'Work in Progress.Dolet Hills Lignite Company, LLC, a wholly-owned lignite mining subsidiary of

SWEPCo.Energy Insurance Services, Inc., a nonaffiliated cûptive insurance company.

Fuel Adjustment Clause.Financial Accounting Standards Board.United States Environmental Protection Agency.Federal Ënergy Regulatory Comrnission.Flue Gas Desulfurization or scrubbers.Financial Transmission Right, a financial instrument that entitles the holder to

receive compensation for certain congestion-related transmission charges

that arise when the power grid is congested resulting in differences inlocational prices,

Indiana Michigan Power Company, an AEP electric utility subsidiary.An agreement by and âmong APCo, I&M, KPCo and OPCo, which defined the

sharing of costs and benefits associated with their respective generâtionpiants. This agreement was terminated January l, 2014.

Internal Revenue Service.Kingsport Power Company, an AEP electric utility subsidiary.Kentucky Power Company, an AEP electric utility subsidiary.Louisiana Public Service Commission.Midwest Independent Transmission System Operator,Million British Thermal Units.Mark-to-Market.Megawatt.Megawatthour.Nitrogen oxide.

FERC FORM NO. T I 123.2

NOTÊS TO FINANCIAL STATÊMENTS (Continued)


241üQ4

Date of Re(Mo, Da,

portY0

This Report is:(1) X An Original(2\ _A Hesubmission

Name of Respondent


GLOSSARY OF TERMS FOR NOTES (Continued)

When the following terms and abbreviations appear in the text of this report, they have the meanings Índicatedbelow.

Term Meaning

OATTOPCoOPEBOperating Agreement

OTCParent

PJMPSOPUCTRisk Management Contracts

RTO

SIA

sozSPPStallUnit

SWEPCoTurk Plant

Utility Money Pool

rtm^^vv r\-u

Open Access Transmission Tariff.Ohio Power Company, an AEP elecrric utility subsidiary.Other Postretiremenr Benefit Plans.Agreement, dated January I, 1997, as amended, by and among PSO and

Slt/EPCo governing generating capacity allocation, energy pricing, andrevenues and costs of third party sales. AEPSC acts as the agent.

Over the counter.American Electric Power company, Inc., the equity owner of AEP subsidiaries

within the AEP consolidation.Pennsylvania - New Jersey * Maryland regional transmission organization.Putrlic Service Company of Oklahoma, an AFP electric utility subsidiary.Public Utility Commission of Texas.Trading and nontrading derivatives, including those derivatives designated as

cash flow and fair value hedges.Regional rransmission organization, responsible for moving electricity over

large interstate areas.System Integration Agreement, effective June 15, 2000, as amended, provides

contractual basis for coordinated planning, operation and maintenance of thepower supply sources of the combined AEP.

Sulfur dioxide.

Southrvest Power Pool regional transmission organization.J. Lamar Stall Unit at Arsenal Hill Plant, a 534 MW natural gas unit owned by

SWEPCo.Southwestern Electric Power Company, an AËP electric utility subsidiary.John W. Turk, Jr. Plant, a 600 MV/ coal-fired plant in Arkansas ¡hat is 737o

owned by SIVEPCo.centralized funding mechanism AEP uses to meet the short-term cash

requirements of certain uti I ity subsidiaries.'tiheeiing Power Company, an ,q,EP eiectric uriiiry subsitiiary.

FERC FORM NO.1 ED.1 123.3



2015/Q4

Date oi Report(Mo, Da, Yr)

ttThis Fleport is:(1) X An Original(2)

- A Fìesubmission

Name of Respondent

Southwestern Electric Power Companv

1. ORGANIZATION ÀNp SUMMARy-OF SIGNTFTçANT ACCO{JNTING POLICIES

ORGANIZATION

As a public utility, SWEPCo engages in the generâtion and purchase of electric power, and the subsequent sale,

transmission and distribution of that power to âpproximately 531,000 retail customers in its service territory in

northeastem and panhandle of Texas, northwestem Louisiana and rvestern Arkansas. SWEPCo sells electric power at

wholesale to other utilities, rnunicipalities and electric cooperatives. SIVEPCo shares off-system sales margins rvith its

customers,

In March 2014, SPP changed from an energy imbalance service market to a fully integrated power market. Previously,

PSO and SWEPCo satisfied their load requirements with their own generation resources or through the Operating

Agreement. In the new integrated power market, PSO and SWEPCo operate âs stândalûne entities and offer their

respective generation into the SPP power market. SPP then economically dispatches the resources.

AEPSC conducts power, coal, nâtural gas, interest rate and, to a lesser exteût, heating oil, gasoline and other risk

management activities on SWEPCo's behalf. S'trEPCo shares in the revenues and expenses associated with these risk

management activities, as described in the preceding paragraph, with PSO. Power and natural gas risk management

activities are allocated based on the Operating Agreement. Risk management activities primarily include power and

natural gas and physical transactions, financially-settled swaps and exchange-traded futures. AEPSC settles the majority

of the physical forward contracts by entering into offsetting contracts.

Under the SIA, AEPSC allocates physical and financial revenues and expenses from transaçtions with neighboring

utilities, power marketers and other power and natural gas risk management activities based upon the location of such

activity, with margins resulting from trading and marketing activities originating in PJM and MISO generally accruing to

rhe benefit of APCo, I&M, KPCo and WPCo and trading and marketing âctivities originating in SPP generally accruing

to the benefit of PSO and SWEPCo. Margins resulting from other transactions are allocated among APCo, I&M, KPCo,

PSO, SWEPCo and WPCo based upon the common shareholder's equity of these companies.

SWEPCo is jointly and severally liable for activity conducted by AEPSC on the behalf of PSO aud SWEPCo related to

power purchase and sate activity.

FERC FORM NO.1 {ËD.12-88} Pase 123.4

NOTES TO FINANCIA[ STATEMËNTS (Continued)


2015/Q4


ll

This Feport is:(1) X An Original(2\ A Resubmission

Name of Respondent

Southwestern Ëlectric Power Company

SUIVIMARY OF SIGNIFICANT ACCOTTNTINç POLTCIES

Rates and Semíce Regulatíon

SWEPCo's rates are regulated by the FERC, APSC, LPSC and PUCT. The FERC also regulates affiliated transactions,including AEPSC intercompany service billings which are generally at cost, under rhe 2005 Public Utility HoldingCornpany Act and the Federal Power Act. The FERC also has jurisdiction over the issuances and acquisitions ofsecurities of the public ulility subsidiaries, the acquisition or sale of certain utility assets and mergers rvith anotherelectric utility or holding company. For non-power goods and services, the FERC requires a nonregulated affiliate to billan affiliated public utility company Íìt no more than market while a public utility must bill the higher of cost or market toa nonregulated affiliate. The APSC, LPSC and PUCT also regulate certain intercompany transactions under variousorders and affiliate statutes. Both the FERC and state regulatory commissisns are permitted to review and audit therelevant books and records of companies within a public utility holding company system.

The FERC regulates wholesale power markets and wholesale power transactions. SWEPCo's wholesale powertransactions are generally market-based. Wholesale power transactions are cost-based regulated when SWEpConegotiates and files a cost-bâsed contrâct with the FERC or the FERC determines that SIùEPCo has "¡narket power" inthe region where the transaction occurs. SIVEPCo has entered into wholesale power supply contracts with variousmunicipalities and cooperatives that are FERC-regulated, cost-based contracts. These contracts are generally formularate mechanisms, which are trued up to actual costs annually.

The APSC, LPSC and PUCT regulate all of the retail distribution operations and rates of SWEPCo on a cosr. basis. Theyalso regulate the retail generatiorlpower supply operations and rates.

The FERC also regulates StrVEPCo's wholesale transmission operâtions and rates. Retail transmission rates are basedupon the FERC OATT rate when retail rates are unbundled in connection with restructuring.

In addition, the FERC regulates the SIA, the Operating Agreement, the Transmission Agreement ând the TransmissionCoo¡dination Agreement, all of rvhich allocate shared system costs and revenues among the utility s¡bsidiaries that areparties to each agreenìent.

FERC FORM NO.1 1 123.s

NOTES TO FINANCfAL S]'ATEMENTS (Continued)


2015/Q4


ttThis Report is:(1) X An Originalt2). A Fìesubmission

Name of Respondent


B*is af Accounting

SV/EPCo's accounting is subject to the requirements of the APSC, LPSC, PUCT and the FERC. The financial

sratements have been prepared in accordance with the Uniform System of Accounts prescribed by the FERC" The

principal differences frorn accounting principles generally accepted in the United States of America (GAAP) include:

r The classification of deferred fuel as noncnrent rather than current.

r The classification of interest on defened fuel as Interest Accrued rather than deferred fuel.

r The classification of interest on deferred fuel as interest and dividends receivable rather than defered fuel.

¡ The requirement to report defened tax assets and liabilities separately rather than as a single amount.

o The classification of accrued taxes as a single amoilnt rather than as assets and liabilities.

r The exclusion of current maturities of long-term debt from current liabilities.

r The accounting for transactions with Sabine Mining Company as a nonaffiliated company rather than

consolidating the entity in accordance with the accounting guidance for "Variable Interest Entities."

. The classification of accrued non-ARO âsset rsmoval costs as accumulated depreciation rather than

regulatory tiabilities.

r The classification of capital lease payments as operûting activities instead of financing activities.

o The classification of gainsllosses from disposition of allowances as utility operating expenses rather thân as

operating revenues.

r The classification of noncurent tax liabilities related 1o the accounting guidance for "Uncertainty in Income

Taxes" as a current liability rather than a noncurrent liability.

. The classification of an accrued provision for potential refund as other noncunent liability rather than a

current liability.r The classification of regulatory assets and liabilities related to the accounting guidance for "Accounting for

lncome Taxes" as separate assets and liabilities rather than as a single amount.

r The presentation of capital leased assets and their associated accumulated amortization as a single amount

instead of as separate amounts,

r The classification of factored accounts receivable expense as a nonoperating expense instead of as an

operating expense.

¡ The presentation of over/under fuel recovery in revenue rather than as a component of operating expense.

r The classification of certain nonoperating revenues as miscellaneous nonoperâtiflg income instead of as

operating revenue.

r The classification of certain nonoperating expenses as miscellaneous noroperating expense instead of as

operating expense.

r The separate classification of income tax expense for operating and nonoperating activities instead of as a

single income tax expense.

r The classification of accrued unbilled revenue as a curent and accrued âsset rather thân netted against

accounts payable for affiliated companies.

r The classification of unamortized loss on reacquired debt in deferred debits rather than in regulatory assets.

FERC FORM NO.1 1 123.6

NOTES fO FINANCIAL


241ilQ4

Dale of Report(Mo, Da, Yr)

This Report is:(1) X An Original{2) A Resubmission

Name of Respondent

Southwestern Eleclr¡6 Power Company

r The classification of accumulated deferred investment tax credits in deferred credits rather than in regulatoryliabilities and defened investment tax credits.

r The classification of plant impairment in utility plant adjustments rather than in property, plant andequipment - electric generation.

r The classification of plant impairment in utility plant adjnrstments rather than in property, plant andequipment - accumulated depreciation and amortization.

o The classification of plant probable of abandonment in Utility Plant and Construction Work in Progressrather than as Other Propert), Plant and Equipment.

r The classificatio¡t of certain other âssets and liabilities as current instead of noncurrent.

r The classification of certain other assets and liabilities as noncurrent instead of current.o The classification of SPP net purchases as purchases and sales instead of net sales.

. The classification of debt issuance costs as noncurrent assets instead of noncunent liabilities.

Accounting for the Effects of Cost-Based Regulttìon

As a rate-regulated electric public utility company, SWEPCo's financial statements reflect the actions of regulators thatresult in the recognition of certain revenues and expenses in different time periods than enterprises that âre notrate-regulated. In accordance with accounting guidance for "Regulated Operations," SWEPCo recôrds regulatory assets(deferred expenses) and regulatory liabilities (defened revenue reductions or refunds) to reflect the economic effects ofregulation in the same accounting period by matching exp€nses with their recovery through regulated revenues and bymatching income with its passage to custorners in cost-based regulated rates.

Use of Estímates

The preparation of these financial statements requires mânagement to make estimates and assumptions that affect theamounts reported in the financial statements and accompanying notes. These estimates include, but are not limited to,inventory valuation, allowance for doubtful accourts, longJived asset impairment, unbilled electricity revenue, valuationof long+erm energy contracts, the effects of regulation, long-lived asset recovery, storm costs, the effects ofcontingencies and certain assump¿ions made in accounting for pension and postretirement benefits. The estimates andassumptions useri are baseci upon management's evaiuation of the relevant facts and circumstances as of the date of thefinancial stâtements. Actual results could ultimately differ from those estimates.

Cøsh and Cøsh Equivalents

Cash and Cash Equivalents on the statements of cash flows include Cash, llorking Fund and Temporary CashInvestments on the balance sheets with original maturities of three months or less.

FE FORM 1 123.7

NOTES TO FINANCIAL STATEMENTS (Contìnued)


201Slo'4

Date ol Re(Mo, Da,

lt

portYr)

This Report is:

{1) X An Oríginal(2\ A Flesubmission

Name ol Respondent


Supplementary I nþr mation

For the Years Ended December 31,

Cash was Paid (Received) for:

Interest (Net of Capitalized Amounts)

Income Taxes (Net of Refunds)

Noncash Acquisitions Under Capital Leases

As of December 31,

Construction Expenditures Included in Current and Accrued Liabilities

2015 2gL4

(in millions)

$ 103.7

t2.7

2.3

92.9

106.7

( 1s5.9)

4.1

$

94.3

Special Depasíts

Special Deposits include funds hetd by trustees primarily for operation and maintenance expenditures related to a

jointly-owned facility and margin deposits for risk management activities.

Inventory

Fossil fuel, materials and supplies inventories âre generally carried at average cost.

Accounts Receívable

Cuslomer accounts receivable primarily include receivables from wholesale a¡ld retail energy customers, receivables from

energy contract counterparties related to risk managemenl activities and customer receivables primarily ¡elated to other

revenue-generating activities.

Revenue is recognized from electric power sales when power is delivered to customers. To the extent that deliveries have

occurred but a bill has not been issued, SWEPCo accrues and recognizes, as Accrued Utility Revenues on the balance

sheets, an estimale of the revenues for energy delivered since the last billing.

AEP Credit factors accounts receivable on a daily basis, excluding receivables from risk management activities, through

purchase agreements with SIVEPCo. AEP Credit has a receivables securitization agreement with bank conduits. Under

the securitization agreement, AEP Credit receives financing from bank conduits for the interest in the billed and unbilled

receivables AEP Credit acquires from affiliated utility subsidiaries. See "Sale of Receivables * AEP Credit" section of

Note 13 for additional information.

FERC FORM N 1 1 123.8

NOTES TO RNANCIAL STATËMENTS (Conlinued)


2015/O4

Ðate of Report(Mo, Da, Yr)

This Report is:(1) X An Original{2\ A Resubmission

Name of Respondent

Southwestern Eleclric Power Company

Allowønce for U ncollectíble Acc ounts

Generally, AEP Credit records bad debt expense based upon a l2-month rolling average of bad debt write-offs inproportion to gross accounts receivable purchased from S\YEPCo. For customer accounts receivables relating to riskmanagement activities, accounts receivables are reviewed for bad debt reserves at a specific counte¡party level basis. For

miscellaneous accounts receivable, bad debt expense is recorded for all amounts outstanding 180 days or greater at 100Vo,

unless specifically identified. Miscellaneous accounts receivable items open less than 180 days may be reserved using

specific identification for bad debt reserves.

Concentrations of Credit Rísk ønd Sígnìficant Customers

SWEPCo does not have any significant customers that comprise l07o or more of its operating revenues as of December

31,2015.

SV/EPCo monitors credit levels and the financial condition of its customers on a continuing basis to minimize credit

risk. The APSC, LPSC and PUCT allow recovery in rates for a reasonable level of bad debt costs. Management believes

adequate provisions for credit loss have been made in the accompanying financial statements.

Emissíon Allowances

SWEPCo records emission allowances at cost, including the annual SO2 and NOx emission allowance entitlements

received ât no cost from the Federal ËPA, Allowances are consumed in the production of energy and are recorded inOperation Expenses at average cost on the statements of income. The purchases and sales of allowances are reported inthe Operating Activities section of the statements of cash flows.

Property, Plant and Equipment

Electric utility property, plant and equipment for rate*regulated operations are stated at original cost. Additions, major

replacements and betlerments are added to the plant accounts. Under the group composite method of depreciation,

conlinuous interim routine replacements of items such as boiler tubes, pumps, motors, etc. result in original cost

retirements, iess saivage, being charged to accumulated depreciation. The group composite method of depreciation

assumes that on average, asset components are retired at the end of their useful lives and thus there is no gain orloss. The equipment in each primary electric plant account is identifled as a separate group. The depreciation tates that

are established take into account the past history of interim capital replacements and the amount of rernoval cost incurred

and salvage received. These rates and the rel¿ted lives are subject to periodic review, Removal costs are charged to

accumulated depreciation. The costs of labor, materials and overhead incurred to operâte and maintain plant and

equipment are included in operating expenses.

FERC FORM NO.1 (ED.12-88) Page 123.9

TO FINANCIAL STATEMENTS (Continued)


2015/Q4



Name of Flespondent

Southwestern Êlectric Power Company

Long-lived assets are required to be tested for impairment when it is determined that the carrying value of the assets may

no longer be recoverable or when the assets meet the held-for-sale criteria under the accounting guidance for "Impairment

or Disposal of Long-Lived Assets." V/hen it becomes probable that an asset in service or an asset under construction will

be abandoned and regulatory cost recovery has been disallowed, the eost of that asset shall be removed from

plant-in-service or C1üIP and charged to expense.

The fair value of ¿ln asset is the amount at which that asset could be bought or sold in a current transaction betwee¡r

willing parties, as opposed to a forced or liquidation sale. Quoted markel prices in active markets are the best evidence of

fair value and are used as the basis for the measurement, if avail¿ble. In the absence of quoted prices for identical or

similar assets in active markets, fair value is estimated using various internal and external valuation methods including

cash flow analysis and appraisals.

I nv estment ín Sub sidiary Cornpanies

SIVEPCo has two wholly-owned subsidiaries, DHLC, which is engaged in lignite-mining operations and Southwest

Arkansas Utilities Corporation, which is engaged in right of way acquisition. Investment in the net assets of DHLC iscarried at cost plus equity in its undistributed eamings since acquisition. Investment in the net assets of Southwest

Arkansas Utilities Corporation is canied at cost.

Allowance for F unds U sed During Consbuctíon

AFUDC represents rhe estimated cost of borrowed and equity funds used to finance construction projects that is

capitalized and recovered through depreciation over the service life of regulated electric utility plant.

Valuation of N o nderivøtiv e F ínancíal Instruments

The book values of Cash, Special Ðeposits, V/orking Fund, Notes Receivable from Associated Companies, Notes Payable

to Associated Companies, âccounts receivable and accounts payable approximate fair value because of the short-term

maturity of these instruments.

FEHC FOR NO.1 ED 123.10

NOTES TO FINANCIAL STATEMENTS (Continued}

YearlPeriod of Heport

2A15lA4


This Report is:(1) X An Original{2) - A Resubmission

Name of Respondent

Southweslern Eleclric Power Companv

Fair Vqlue Messurements of Assets and LíahíIítíes

The accounting guidance for "Fair Value Measurements and Disclosures" establishes a fair value hierarchy that

prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjasted quoted prices in

active markets for identical assets or liabilities (Level I measurement) and the lowest priority to unobservable inputs(Level 3 measurement). Where observable inputs are available for substantially the full term of the asset or liability, the

instrument is categorized in Level 2. When quoted market prices are not available, pricing may be completed using

comparable securities, dealer values, operating data and general market conditions to determine fair value. Valuationmodels utilize various inputs such as commodity, interest rate and, to a lesser degree, volatility and credit that include

quoted prices for similar assets or liabilities in active markets, quoted prices for identical or similar assets or liabilities ininactive markets, market corroborated inputs (i.e. inputs derived principalty from, or conelated to, observable market

data) and other observable inputs for the asset or liability. The amount of risk taken is determined by the Comrnercial

Operations and Finance groups in accordance with established risk management policies as approved by the Finance

Committee of AEP's Board of Directors. AEPSC's market risk oversight staff independently monitors risk policies,

procedures and risk levels and provides members of the Commercial Operations Risk Committee (Regulated RiskCommittee) various reports regarding compliance with policies, lirnits and procedures. The Regulated Risk Committee

consists of AEPSC's Chief Operating Officer, Chief Financial Officer, Executive Vice President of Ceneration, Senior

Vice President of Commercial Operations and Chief Risk Officer.

For commercial activities, exchange traded derivatives, namely futures contracts, are generally fair valued based on

unadjusted quoted prices in active markets and are classified as Level l. Level 2 inputs primarily consist of OTC brokerquotes in moderately active or less active markets, as well as exchange traded contracts where there is insufficient market

liquidity to warrant inclusion in Level 1. Management verifies price curves using these broker quotes and classifies these

fair values within Level 2 when substantially all of the fair value can be corroborated. Management typically obtains

mulliple broker quotes, which are nonbinding in nature but are based on recent trades in the marketplace. 'When multiplebroker quotes are obtained, the quoted bid and ask prices are averaged. In certain circumstances, a broker quote may be

discarded if it is a clear outlier. Management uses a historical correlation analysis between the broker quoted location

and the illiquid locations. If the points are highly correlated, these locations are included within lievel 2 as well. Certain

OTC and bilaterally executed derivative instruments are executed in less active markets with a lower availability ofpricing information. Illiquid transactions, complex structured transactions, FTRs and counterparty credit risk may require'.^-...-^-t,^¿ L^-^l :----a- ô---- -4 ^l^--- !.----^- -,,, l,- : ^- - -ll-. t. t IIrut¡utarKËr u¿lsçu rr¡Purs. ùutnc ur. r¡rcsç rr¡pu$ rnä,y oç tnternatty (IeYe¡opeg or exlrapotale(] ano uultze{l to esumate ïalrvalue. IVhen such inputs have a significant impact on the measurement of f¿ir value, the instrument is categorized as

Level 3. The main driver of contracts being classified as lævel 3 is the inability to substantiate energy price curves in the

market. A portion of the l¿vel 3 instruments have been economically hedged which limits potential earnings volatility,

FERC FORM NO.1 ED. I 123.11

NoTES To FINANCIAL STATEMENTS (Continued)


20151Q4

Date of Repod(Mo, Da, Yr)

tl

This Report is:(1) X An Originale\ A Resubmission

Name of Respondent


AEP utilizes its trustee's external pricing service to estimate the fair value of the underlying investments held in the

benefit plan trusts. AEP's investment managers review and validate the prices utilized by the trustee to determine fair

value. AEP's management performs its own valuation testing to verify the fair values of the securities. AEP receives

audit reports of the trustee's operating controls and valuation processes. The trustee uses multiple pricing vendors for the

assets held in the trusts.

Assers in the benefits trusts are classified using the following methods. Equities are classified as Level I holdings if they

are activety traded on exchanges. Items classified as Level I are investments in money market funds, fixed income and

equity mutual funds and domestic equity securities. They are valued based on observable inputs, primarily unadjusted

quoted prices in active markets for identical assets. Items classified as Level 2 are primarily investments in individual

fixed income securities and cash equivalent funds. Fixed income securities generally do not trade on exchanges and do

not have an official closing price but their valuation inputs are based on observable rnarket data. Pricing vendors

calculate bond valuations using financial models and matrices, The models use observable inputs irtcluding yields on

benchmark securities, quotes by securities brokers, rating agency actions, discounts or premiums on securities compared

to par prices, changes in yields for U"S. Treasury securities, corporate actions by bond issuers, prepayment schedules and

histories, economic events and, for cenain securities, adjustments to yields to refleet changes in the rate of

inflation. Other securities with model-derived valuation inputs that are observable are also classified as Level 2

investments. Investments with unobservable valuation inputs are classified as Level 3 investments. Benefit plan assets

iucluded in Level 3 are primarily real estate and private equity investments that are valued using methods requiring

judgment including appraisals. The fair value of real estate investments is measured using market capitalization rates,

recent sales of comparable investments and independent third-party appraisals. The fair value of private equity

investments is measured using cost and purchase multiples, operating results, discounted future cash flows and markel

based comparable data. Depending on the specific situation, one or multiple approaches are used to determine the

valuation of a real esfate or private equity investment.

Defened Fuel Costs

The cost of fuel and related emission allowances and emission control chemicaldconsumables is charged to expense

when the fuel is burned or the allowance or consumable is utilized, Fuel cost over-recoveries (the excess of fuel-related

revenues over applicable fuel costs incurred) are generally defened as regulatory liabilities and under-recoveries (the

excess of applicable fuel costs incur¡ed over fuel-related revenues) are generally defened as regulatory assets. These

defe¡rals âre amortized when refrlnded or when billed to customers in later months with the APSC'S, LPSC's and

PUCT's review and approval. The amount of an over-recovery or under-recovery can also be affected by actions of the

APSC, LPSC and PUCT. On a routine basis, the APSC, LPSC and PUCT review and/or audit SWEPCo's fuel

procurement policies and practices, the fuel cost calculations and FAC defenals. FAC defenals are adjusted when costs

are no longer probable of recovery or when refunds offuel reserves are probable,

FERC NO. 1 123.12

NOTES TO FINANCiAL STATEMENTS (Conlinued)

Year/Period of Repoñ

2015/Q4



Name of Fìespondent

Southweslern Êlectric Power Company

Changes in fuel costs, including purchased power in Arkansas, Louisiana and Texas are reflected in rates in a timely

ntanner generally through the FAC. The FAC generally includes some sharing of off-system sâles margins. A portion ofmargins from off-system sales are given to customers through the FAC and other rate mechanisms in Arkansas, Louisiana

and Texas.

Revenue Recognítíon

Regulalory Accounling

The financial stâtements reflect the actions of regulators that can result in the recogrrition of revenues and expertses in

different time periods than enterprises that are not rate-regulated. Regulatory assets (defened expenses) and regulatory

liabilities (deferred revenue reductions or refunds) are recorded to reflect the economic effects of regulation in the same

accounting period by matching expenses with their recovery through regulated revenues and by matching income with its

passage to customers in cost-based regulated rates.

\Vhen regulatory assets are probable of recovery through regulated rates, assets are recorded on the balance

sheets" Regulatory assets are tested for probability of recovery at each balance sheet date or whenever new events

occur. Examples of new events include the issuance of a regulatory commission order or passage of new legislation. If itis determined that recovery of a regulatory asset is no longer probable, the regulatory asset is written off as a charge

against income.

Electrícity Supply and Ðelivery Activitìes

SV/EPCo recognizes revenues from retail and wholesale electricity sales and elecrricity transmission and distribution

delivery services. SWEPCo recognizes the revenues on the statements of income upon delivery of the energy to the

customer and include unbilled as rvell as billed amounts. In accordance with the APSC, LPSC and PUCT regulatory

treatment, SWEPCo does not record the fuel portion of unbilled revenue. Wholesale transmission revenue is based on

FERC approved fo¡mula rate filings made for each calendar year using estimated costs. The annual rate filing is

compared to actual costs with an over- or under-recovery being trued-up with interest and refunded or recovered in afuture year's rates.

ivÍost oíiire power produce'i ai ihe generaiion pianis is soitj to SPP. SWË,PCo purchases power f¡oni SPP io suppiy

power to its customers. Generally, these power sales and purchases are reported on a net basis as revenues on the

statements of income. However, purchases of power in excess of sales to SPP, on an hourly net basis, used to serve retail

load are recorded gross as Operation Expenses on the statements of income.

Physical energy purchases arising from non-derivative coûtracts are. accounted for on a gross basis in Operation Expenses

on lhe statements of income" Energy purchases arising from non-trading derivalive contracts are recorded based on the

transactio¡r's facts and circumstances, Purchases under non-trading derivatives used to serve accrual based obligations

are recorded in Operation Expenses on the statements of income. All other non-trading derivative purchases are recorded

net in revenues,

123.'13D.'lFERC FORM NO.1

STATEMENTSNOTES TO


20ßta4


lt

This Fìeport is:(1) X An OriginalQ\ A Resubmission

Name of Hespondent


In general, SWEPCo records expenses when purchased electricity is received and when expenses are incuned. SîVEPCo

defers unrealized MTM amounts as regulâtory assets (for losses) and regulatory liabilities (for gains).

Energy Marketing and Risk Managetnent Activíties

SIVEPCo engâges in power, capacity and, to a lesser extent, natural gas marketing as a major power producer and

participant in electricity and natural gas markets. SWEPCo also engages in power, capacity, coal, natural gas and, to a

lesser extent, heating oil, gasoline and other commodity risk management activities focused on markets where the AEP

system owns assets and adjacent markets. These activities include the purchase-and-sale of energy under forward

contracts at fixed and variable prices. These contracts include physical transactio¡rs, exchange-traded futtlres, and to a

lesser extent, OTC swaps and options. Certain energy marketing and risk management transactiotts are with RTOs.

SWEPCo recognizes revenues and expenses from marketing and risk masagement transactions that are not derivatives

upon delivery of the co:nmodity. SWEPCo uses MTM accounting for marketing and risk management transactions that

are derivatives unless the derivative is designated in a qualifying cash flow hedge relationship or elected normal under

the normal purchâse normâl sale election. SSIEPCo includes realized gains and losses on marketing and risk

management transactions in revenues or exp€ûse based on the transaction's facts and circumstances. The unrealized

MTM amounts and some realized gains and losses are defened as regulatory assets (for losses) and regulatory liabilities

(for gains).

Certain qualifying marketing and risk management derivatives transactions are designated as hedges of variability in

future cash flows as a result of forecasted transactions (cash flow hedge). SWEPCo initiatly records the effective portiori

of the cash flow hedge's gain or loss as a component of AOCI. When the forecasted transaetion is realized and affects

net income, SWEPCo subsequently reclassifies the gain or loss on the hedge frorn AOCI into revenues or expenses within

the same financial statement line item as the forecasted transaction on their statements of income. S'ülEPCo defers the

ineffective portion as regulalory assets (for losses) and regulatory liabilities (for gains). See "Accounting for Cash Flow

Hedging Strategies" section of Note 9.

SPP Integrøted Power Market

In March 2014, SPP changed from an energy imbalance service market to a fully integrated power market. In the past,

PSO and SWEPCo would satisfy their load requirements with their own generation resources or through the Operating

Agreement. In the new integrated power market, PSO and SIVEPCo operate as standalone entities by offering their

respective generation into the SPP power market, which then economically dispatches the resources. This change further

enables retail customers to obtain power through either internal generation or power purchases from the SPP market. The

new integrated power market now operates in a similar manner as the PJM power market for the AEP East Companies.

The change in the SPP integrated power market did not have a significant effect or the results of operations or cash

flows.

FERC FORM NO.1 I 123.14

NOTES TO FINANCIAL SIATEMENTS (Continued)


2015/Q4


This FìepoÉ is:(1) X An Original(2) _ A Flesubmission

Name of Respondent


Maintenance

SWEPCo expenses maintenance costs as incuned. ff it becomes probable that SWEPCo will recoverspecifically-incurred costs through future rûtes, a regulatory asset is established to match the expensing of those

maintenance costs with its recovery in cost-based regulated revenues. SWEPCo defers costs above the level included inl¡ase rates and amortizes those deferrals commensurate with recovery through rate riders.

Income Taxes snd Investment Tax Crcdìts

SWEPCo uses the liability method of accounting for income taxes. Under the liability method, defened income taxes are

provided for all temporary differences between the book and tax basis of assets and liabilities which will result in a futt¡retax consequence.

When the flow-through method of accounting for temporary differences is reflected in regulated revenues (that is, when

deferred taxes are not included in the cost of service for determining regulated rates for electricity), deferred incometaxes are recorded and related regulatory assets and liabilities are established to match the regulated revenues and taxexpense.

Investment tax credits are accounted for under ths flow-through method except where regulatory commissions have

reflected investment tax credits in the rate-making process on a deferal basis. Investment tax credits that have been

deferred are amortized over the life of the plant investment.

SIVEPCo accounts for uncertain tax positions in accordance with the accounting guidance for "Incorne

Taxes." SWEPCo classifies interest expense or income related to uncertain tax positions as interest expense or income as

appropriate and classifies penalties as Penalties.

Exeise Taxes

As an agent for some state and local govemments, SV/EPCo collects from customers certain excise taxes levied by those

state or local governments on customers. SWEPCo does not record these trxes as revenue or expense.

Debt

Gains and losses from the reacquisition of debt used to finance regulated electric utility plants are deferred and amortized

over the remaining term of the reacquired debt in accordance with their rate-making treatment unless the debt isrefinanced. If the reacquired debt associated with the regulated business is refinanced, rhe reacquisition costs attriburableto the portions of the business that are subject to cost-based regulatory accounting are generally defened and amortizedover the term of the replacement debt consistent with its recovery in rates.



YearlPeriod of Report

2015/Q4


This Fleport is:(1) X An Original(2\ A Resubmission

Name of Respondent


Debt discount or premium and debt issuance expenses are defened and amortized generally utilizing the straight-line

metho<l over the term of the related tlebt. The straight-line method approximates the effective interest method and is

consistent rvith the treatment in rates for regulated operations.

Investments Held in Trust for Future Liabílítìes

AEP has several trust funds with significant investments intended to provide for future payments of pension and OPEB

benefits. All of the trust funds' investments are diversified and managed in compliance with all laws and

regulations. The investment strategy for the trusl funds is to use a diversified portfolio of investments to achieve an

acceptable rate of return while managing the investment risk of the assets r€lative to the associated liabilities. To

minimize investment risk, the t¡ust funds are broadly diversified among classes of assets, investmenl strategies ând

investment manâgers. Managemerrt regularly reviews the actual asset allocations and periodically rebalances the

investments to targeted allocations when appropriate. Investment policies and guidelines allow investment managers in

approved strategies to use financial derivatives to obtain or manage market exposures and to hedge assets and

liabilities. The investments are reported at fair value under the "Fair Value Measurements and Disclosures" accounting

guidance.

Benefit Plans

All benefit plan assets are invested in accordance with each plan's investment policy. The investment policy outlines the

investment objectives, strategies and target asset allocations by plan.

The investrnent philosophies for AEP's benefit plans support the allocation of assets to minimize risks and optimize net

returns. Strategies used include:

. Maintaining a long-term investment horizon.

r Diversifying assets to help control volatility of retums at acceptable levels.

. Managing fees, transaction costs ând tax liabilities to maximize investment earnings.

' Using active rnanagement of investments where appropriate rislcfteturn opportunities exist.

r Keeping portfolio structure style-neutral to limit volatility compared to applicable benchmarks.

. Using alternative asset classes such as real estate and private equity to maximize return and provide additional

portfolio diversification.

FERC M NO.1 1 1 23.r 6

NOTES TO FINANCIAL STATEMËNTS (Continued)


2015/Q4



Name of Respondent

Soulhwestern Eleclric Power Companv

The objective of the investment policy for the pension fund is to maintain the funded status of the plan while providing

for growth in the plan assets to offset the growth in the plan liabilities. The current target asset allocations are as follows:

Pension PIan Assets TargetEquityFixed IncomeOther InvestmentsCash and Cash Equivalents

OPEB Plans Assets

257o

59Vo

lSVa

t?o

TargetEquityFixed IncomeCash and Cash Equivalents

65a/o

33Vo

2Vo

The investment policy for each benefit plan contains various investment limitations. The investment policies establish

concentration limits for securities and prohibit the purchase of securities issued by AEP (with the exception ofpropûrtionâte and immaterial holdings of AEP securities in passive index strategies). However, the investment policies

do not preclude the benefit trust funds from receiving contributions in the form of AEP securities, provided that the AEPsecurities acquired by each plan may not exceed the limitations imposed by law.

For equity investments, the concentration limits are as follows:

r No security in excess of SVo of all equities.r Cash equivalents must be less than l07o of an investment manager's equity portfolio.o No individual stock may be more than lATo andTVo for pension and OPEB investments, respectively, of each

manager's equity portfolio.r No investment in excess of 57o of an outstanding class of any company.r No securities may be bought or sold on margin or other use of leverage.

For fixed income inveslments, the concentration limits must not exceed:

¡ 3lo in any single issuer.

r 5?o for private placements.

; 5?o for conve¡tible securities.

t 6A7o for bonds rated AA+ or lower.a 507o for bonds rated A+ or lower.: lt%o for bonds rated BBB- or lower

EÞ.12-88) Pãge 123.17FORM NO. IFË

LST



This Report is:(1) X An Original{2\ A Flesubmission

Year/Period ol Fleport

2015/Q4

Date of Beport{Mo, Da, Y$

tt

For obligations of non-government issuers within the fixed income portfolio, the following limitations apply

r AAA rated debt: a single issuer should account for no more than 5lo of the portfolio.

r AA+, AA, AA- rated debt: a singte issuer should account for no more lhan3Øo of the portfolio.

r Debt rated A+ or lower: a single issuer should account for no more than 2o/o af the portfolio.

r No more than l07o of the portfolio rnay be invested in high yield and emerging market debt combined at âny

time.

Each investment manager's por-tfolio is compared to a diversified benchmark index

A portion of the pension assets is invested in real estate funds to provide diversification, add return and hedge against

i¡flation. Real estate properties are illiquid, difficult to value and not actively traded. The pension plan uses external

real estâte investment managers to invest in commingled funds that hold real estate properties' To mitigate investment

risk in rhe real estate portfolio, commingled real estate funds are used to ensure that holdings are diversified by region;

property type and risk classification. Real estate holdings include core, value-added and development risk classifications

and some investments in Real Estate Investment Trustso which are publicly traded real estate securities.

A portion of the pension assets is invested in private equily. Private equity investments add return and provide

diversification and typically require a long-term time horizon to evaluate investment performance. Private equity is

classified as an alternative investment because it is illiquid, difficult to value and not actively traded. The pension plan

uses limited partnerships and commingled funds to invest across the private equity investment spectrum. The private

equity holdings are with multiple general partners who help monitor the investments and provide investment selection

expertise. The holdings are currently comprised of venture capital, buyout and hybrid debt and equity investment

instruments. Commingled private equity funds are used to enhance the holdings' diversity.

AEp participates in a securities lending program with BNY Mellon to provide incremental income on idle assets and to

provide income to offset custocly fees and other administrative expenses. AEP lends securities to borrowers approved by

BNy Mellon in exchange for collateral. All loans are collateralized by at least IAZVo of the loaned asset's market value

and the collateral is invested. The difference between the rebate owed to the bonower and the collateral rate of return

determines the earnings on the loaned security. The securities lending program's objective is providing modest

incremental income with a limited increase in risk.

FERC FORM NO.1 123.18



2015tQ4

Date of Fleport(Mo, Da, Yr)

This Feport is:(1) X An Origînal(2) _ A Flesubmission

Name of Hespondent


Trust owned life insurance (TOLI) underwritten by The Prudential Insurance Company is held in the OPEB plan

trusts. The strategy for holding life insurance contracts in the taxable Voluntary Employees' Beneficiary Association

trust is to minimize taxes paid on the asset growth in the tmst. Earnings on plan assets are tax-deferred within the TOLIcontract and can be tax-free if hetd until claims are paid. Life insurance proceeds remain in the trust and are used to fundfuture retiree medical benefit liabilities. With consideration to other investments held ìn the trust, the cash value of the

TOLI contracts is invested in two diversified funds. A portion is invested in a commingled fund with underlying

investments in stocks that are actively traded on major intemational equity exchanges. The other portion of the TOLIcash value is invested in a diversified, commingled fixed income fund with underlying investrnents in government bonds,

corporate bonds and asset-backed securities.

Cash and cash equivalents are held in each trusl to provide liquidity and meet short-term cash needs. Cash equivalent

funds are used to provide diversification and preserve principal. The underlying holdings in the cash funds are

investment grade money market instruments including commercial paper, certifìcates of deposit, treasury bills and other

lypes of investment grade short-term debt securities. The cash funds are valued each business day and provide dailyliquidity.

Comprehensíve I neome (Loss)

Comprehensive income (loss) is defined as the change in equity (net assets) of a business enterprise during a peiiod fromtransactions and other events and circumstances from nonowner soürces. It includes all changes in equity during a period

except those resulting from investments by owners and distributions to owners.

Subsequent Events

Managemenr has evaluated the impact of events occurring after December 31, 2015 through February 23,2016, the date

that AEP's Form lO-K was issued, and has updated such evaluation for disclosure purposes through April 8, 2016. These

financial statements include all necessary adjustments and disclosures resulting from these evaluations.

FORM NO.1 1 123.19

STATEMNOTES TO



This Fleport is:(1) X An Original(2) - A Resubmission


2015/Q4

Date of Repod(Mo, Da, Yr)

2. NEW ÅCCOUNTING PRONOTINCEMENTS

Upon issuance of final pronouncements, managemenl reviews the new accounting literature to determine its relevance, ifany, to SIVEPCo's business. The following final pronouncements will impact the financial statements.

AS{I 2014-09 "Revenue from Contracts wíth Customers" (ASU 2t14'09)

In May 2014, the FASB issued ASU 2014-09 clarifying the method used to deterrnine the tirning and requirements for

revenue recognition on the statements of income. Under the new stand¿rd, an entity rnust identify the performance

obligations in a contract, determine the transaction price and allocate the price to specific performance obligations to

recognize the revenue when the obligation is completed. The amendments in this update also require disclosure of

sufficient information to allow users to understand the nature, amount, timing and uncertainty of revenue and cash flow

arising from contracts.

The FASB defened implementation of ASU 2014-09 under the terms in ASU 2Aß-l4, "Revenue from Contracts with

Customers (Topic: 60ó): Ðeferral of the Effective Date." The new accounting guidance is effective for interim and

annual periods beginning after December 15, 2017. Early adoption is permitted for annual periods beginning after

December 15,2016. As applicable, this standard may change the amount of revenue recognized in the income statenìents

in each reporting period. Management is analyzing the impact of this new standard and, at this time, cannot estimate the

impact of adoption on revenue or net income. Management plans to adopt ASU 2014-09 efTective January l, 2018.

ASA 2U5-05'o$ccaunting for Fees Paid ín a Claud Camputing Arangemenf' (ASU 2015'05)

ln April 2015, the FASB issued ASU 2015-05 providing guidance to customers about whether a cloud computing

arrangement includes a software license. The new accounting guidance is effective for interim and annual periods

beginning after December 15, 2015 with early adoption permitted. Management adopted ASU 2015-05 prospectively,

effective January 1,2016, with no impact on results of operations, financial position or cash flows.

lLSU 2015-II "Símplìfying the llleasurement of Inventory" ØSU 2015'11)

In July 2015, the FASB issued ASU 2015-ll simplifying the guidance on the subsequent measurement of inventory,

excluding inventory measured using last-in, first out or the retail inventory method. Under the new standard, inventory

shoulcl be at rhe lower of cost anä net realizable value. The new accounting guidance is effective for interim and annual

periods beginning after December 15, 20t6 with early adoption permitted. Management does not expect the new

standard to impact its results of operations, financial position or cash flows. Management plans to adopt ASU 2015-l I

prcspectively, effective January 1, 2017 .

FORM 1 Þ.1 123.24



20t5/Q4


This Report is:

{1) X An Original(2) _ A Flesubmission


Southwestem Electrìc Power Company

ASU 2A15-13 "Applícøtíon of the Norma| Purchases and Normal Sales Scape Exceptìon to Certaín ElectricityContraetswithìn Nodal Energy Markets" ØSA 20ß-13)

In August 2015, the FASB issued ASU 2015-13 clarifying whether a contract for the purchase or sale of electricity on aforward basis should be eligible to meet the physical delivery criterion of the normal purchases and normal sales scope

exception when either the delivery location is within a nodal energy market or the contract necessitates transmissionthrough a nodal energy rnarket and one of the contracting parties incurs charges (or credits) for the tra¡rsmission ofelectricity based in part on locational marginal pricing differences payable to (or receiyable fron) an independent system

operator. Under the new standard, the use of locational marginal pricing by an independent system operator does notcause a contract to fail to meet the physical delivery criterion of the norrnal purchases and normal sales scope exception.As a resuft, an entity may elect to designate that contrâct as a normal purchase or normal sale.

The new accounting guidance is effective upon issuance and applied prospectively. Management has analyzed the impactof this new søndârd and determined that it had no impact on the accounting of SWEPCoTs contracts. Additionally,adoption had no irnpact on net income. Management adopted ASU 2015-13 upon its issuance date.

ASU 2016-01 "Recognítíon and Measurement of Fínøncíal Assets and Fìnancíal L:íabilitíes" (ASIJ 2016-01)

In January 2016, the FASB issued ASU 2016-01 enhancing the reporling model for financial instrumenrs. Under the new

standard, equity investments (except those accounted for under the equity method of accounting or those that result inconsolidation of the investee) are required to be measured at fair value with changes in fair value recognized in net

income. The new standard also amends disclosure requirements and requires separate presentation of financiat assets and '.

liabilities by measurement category and form of financial asset (that is, securities or loans and receivables) on the balance

sheet or the accompanying notes to the financial statements. The amendments also ctarify that an entity should evaluatethe need for a valuæion allowance on a defened tâx asset related to available-for-sale securities in combination with the

entity's other deferred tax assets.

The new accounting guidance is effective for interim and annual periods beginning after December 15, 201? with earlyadoption permitted. The amendments should be applied by means of a cumulative-effect adjustment to the balance sheet^^ ^f, +L^ A^^:-^:-- ^6*L^ f!^^^l .,^^- ^ç ^l^-¿i^- tf^-^^-.^^-. :- ---l-.-:-- ^t-- l--- ,--- ,c Lt-r-(rù vr LrtE r.rçË¡¡ilru¡Ë \rr Ltrç rtòça¡ Jc¿rr vr .luuPrruil. rvrarraËgilrçttt ¡s a¡taly¿lllg t¡19 llnpaçl oI Lflls new stan(]aro ano, at tnlstime, cannol estimate the impact of adoptiou on net income. Management plans to adopt ASU 2016-01 effective January

l,2018.

FERC NO. D..l 123.21

NOTES TO FINANCIAL STATEMENIS (Continued)


2015/Q4


ttThis Report is:(1) X An Origínal(2) _ A Resubmission

Name of Respondent


ASII 2016-A2 "Accountìng for Leøses" (ASU 2016'02)

In February 2016, the FASB issued ASU 2016-02 increasing fhe transparency and comparability among organizations by

recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing

arïangements. Under the new standard, an entity must recognize an asset and liability for operating leases on the balance

sheets. Additionally, a capital lease will be known as a finance lease going forward. Leases with lease terms of 12

months or longer will be subject to the new requirements. Fundamentally, the criteria used to determine lease

classification will renain the same, but will be more subjective under the new standard,

The new accounting guidance is effective for annual periods beginning after December 15, 2018 with early adoptién

permitted. The guidance should be applied by means of a modified retrospective approach. The modified retrospective

approach will require lessees and lessors to recognize and measure leases at the beginning of the earliest period presented

as well as a number of optional practical expedients that entities may elect to apply. Management expects the new

standard to impact its financial position, but not its resuÌts of operations or cash flows. Management plans to adopt ASU

z}Ií-Q?effective January l, 2019.

ERC FORM NO.1 1 123.22

NOTE$ TO FINANCIAL STATEMENTS (Conlinued)


20't5/Q4


This Fleport is:(1) X An Original(2) * A Resubmission

Name of Respondenl

Southweslem Electric Power Comoany

3. COMPRETIENSIVE INCOME

Presentation of Comprehensíve I ncome

The following tables provide the components of changes in AOCI for the years ended December 31,2015 and 2014. Allarnounts in the following tables are presented net of related income taxes.

Changes in Â.ccumulated Other Comprehersiye Income (Loss) by ComponentFor the Year Ended December 31, 2015

Cash Flow Hedgrs Pension and OPEB

Commodity

Interest Rateand ForeignCurrency

Amortizationof Deferred

Costs

Changesin Funded

Stâh$ Total

Balance in ÀOCI as of Ðecember 31, 2014 $

(in mitlions)$ (l 1.1) s 3.6 $

Change in Fair Value Recognized in AOCIAmounts Reclassified from AOCINet Current Period Other Comprehensive

Income (Ioss)

Change inFair Value Recognized in AOCIAmounts Reclassified from AOCINet Cunent Period Other Comprehensive

Income fl-oss)

,ï)2.O (1.0)

$ (7.5)(2.e)I.0

2.0 (1,0) (2.9) (r.9)Sal¡nce in AOCI as of December 31, 2015 $ $ (9.1) $ 2.6 $ (2.e) $_. (9.4)

Changes in Accumulated Other Comprehensiye fncome (Loss) by ComponentFor Êhe Year Ended December 31,2014

Cash Flow Hedecs

Commodity

Interest Rateand ForeignCurrency

Penslon and OPEBAmortization Changesof Deferrcd in Funded

Costs Status Total(in millions)

Balance in AOCI as of December 31,2013 $ S ( 13.3) $ 4.s $ 0.3 $ (8.5)

))(0.3)

(0.e)(0.3)

1.3

1.0

Balanee in AOCI as of December 31, 20r.4 $2.2

$ 01.1)(0.e) (0.3)

$ 3.6 $ - $ (7.s)

NO.1 129.23

NOTES ÏO FINANCIAL STATEMENTS (Continued)


2015/Q4

Date of Repod{Mo, Da, Yr)

This Reporî is:(1) X An Originale\ A Resubmission

Name ol Respondent


Recløssífîcøtíons fron Actumulated Other Comprehensíve Incame

The following table provides details of reclassifications from AOCI for the years ended December 31, 2015 and

2014. The amortization of pension and OPEB AOCI components are included in the computation of net periodic pension

and OPEB costs. See Note 7 for additional details.

Reclassifications from Accumulated Other Comprehensive lncorne (Loss)

Amount of (Gain) LossReclassified from AOCI

Gains and Losses on Cash Flow HedgesYears Ended Decenrber 31'201s 2014

Commodity:Regulatory Assets/(Liabilities), Net (a)

Subtotal - Commodity

Interest Rate and Foreign Currency:

Interest on Long-term Debt

Subtotal- Interest Rate and Foreign Currency

Reclassifications from AOCI, before Income Tax (Expense) Credit

Income Tax (Ëxpense) Credit

Reclassifications from AOCI, Net of Income Tax (Expense) Credit

Pension and OFEBAmsrtization of Prior Service Cost (Credit)Amortization of Actuarial (Gains)llosses

Reclassifications from AOCI, before Income Tax (Expense) CreditIncome Tax (Expense) CreditReclassÍfïcations from AOCI, Net of Income Tax (Expense) Credit

Tot¿l Reclassifications from ÄOCI, Net of Income Tax (Expense) Credit $

(a) Represents realized gains and losses subject to regulatory accounting treatment.

${Ín millions)

s (0.r)(o.l)

3.1 3.5

3.1 3.5

3.1

1.t3.4t.2

2.4 2.2

(l.e)0.4

(l.e)0.5

( 1.5)(0.5)

{1.4){0.s)

(t.0) (0.e)

t.0 $ 1.3

FËRC FOHM NO.1 123,24

NOTËS TO FINANCIAL (Continued)


2015tQ'4


This Report is:(1) X An Original(2) _ A Flesubmission

Name of Respondent

Southwestern Electr¡c Power Company

4. RATE MATTERS

SWEPCo is involved in rate and regulatory proceedings at the FERC, APSC, LPSC and PUCT. Rate matrers can have amaterial impact on net income, cash flows and possibly financial condition. SWEPCo's recent significant rate orders andpending rate filings are addressed in this note.

2012 Texss Base Rate Case

ln 2012, SWEPCo filed a request with the PUCT to increase annual base rates primarily due to the completion of theTurk Plant, In 2013, the PUCT issued an order affirming the prudence of the Turk Plant but cletermined that the TurkPlant's Texas jurisdictional capital cost cap established in a previous Certificate of Convenience and Necessity case alsolimited SWEFCo's recovery of AFUÐC in addition to limits on its recovery of cash construction costs. Additionally, thePUCT deferred consideration of the requested increase in depreciation expense related to the change in the 2016retirement date of the Welsh Plant, Unit 2.

Upon rehearing in 2014, the PUCT reversed its initial ruling and determined that AFUDC was excluded from the TurkPlant's Texas jurisdictional capital cost cap. As a result, in the fourth quarter of 2013, SWEPCo reyersed $114 million ofpreviously recorded regulatory disallowances. The resulting annual base rate increase was approximately S52 million. InMay 2414, intervenors filed appeals of that order with the Texas District Courl. In June 20 t4, SWEPCo intervened inthose appeals and filed initial responses.

If certain parts of the PUCT order are overturned or if SIMEPCo cannot ultimately recover its Texas jurisdictional share

of the Turk Plant investment, including AFUDC, it could reduce future net income and cash flows and impact financialcondition.


NOTES TO FINANCIAL STATEMENTS {Continued)


2015104


This Report is:(1) XAn Original{21 A Resubmission

Name of FÌespondent

Southweste¡n Electric Power Company

2012 Louisíøna Fortnula Rale Fìlìng

ln 2O12, SWEPCo initiated a proceeding to establish new forrnula base rates in Louisiana, including recovery of the

Louisiana jurisdictional share (approximately 29Va) of the Turk Plant. In February 2013, a settlement was filed and

approved by the LPSC, The settlement increased SWEPCo's Louisiana total rates by approximately $2 million annually,

effective March 2013, which consisted of an increase in base rates of approximately $85 million annually offset by a

decrease in fuel and other rates of approximately $83 million annually. The March 2013 base râtes are based on a lOTa

retum on common equity and cost recovery of the Louisiana jurisdictional share of the Turk Plant and Stall Unit. The

rates are subject to refund based on the prudency review of the Turk Plant. The settlement also provided that the LPSC

review base rates in 2014 and 2015 and that SWEPCo recover non-fuel Turk Plant costs and a full weighted-average cost

of capital return on the prudently incuned Turk Plant investment in jurisdictional rate base, effective January 2013. In

December 2O14, the LPSC approved a settlement agreement related to the staff review of the cosl of service' The

settlement agreement reduced the requested revenue increase by $3 million, primarily due to the timing of both the

allowed recovery of certain existing regulatory assets and the establishment of a regulatory ¿sset for certain previously

expensed costs. If the LPSC orders refimds based rpon the pending prudence review of the Turk Plant investment, it

could reduce future net income and cash flows and impact financial condition.

2014 Lauísíana For*tulø Rate FíIíng

In April 20 14, SIVEPCo filed its annual formula rate plan for test year 2Ol3 with the LPSC' The filing included a $5

million annual increase, which was effective August 2014. SWEPCo also proposed to increase rates by an additional $15

million annually, effective January 2015, for a total annual increase of $20 million. This additional increase reflects the

cost of incremental generation to be used to serve Louisiana customers in 2015 due to the expiralion of a purchased

power agreement attributable to Louisiana customers. In December 2014, the LPSC approved a partiâl settlement

agreement that included the implementation of the $15 million annual increase in rates effective January 2015. These

increases are subject to LPSC staff review and are subject to refund. If any of these costs are not recoverable, it could

reduce future net income and cash flows and impact financial condition.

2015 Inuísíana. Formula Rate Filing

In April 2015, SWEPCo filed its formula rate plân for test year 2Al4 with the LPSC" The fiting included a $14 million

annual increase, which was effective August 2015. This increase is subject to LPSC staff review and is subject to

refund, If any of these costs are not recoverable, it could reduce future net income and cash flows and impact financial

condition"

FERC M NO,1 1 123.26



201s/Q4


This Report is:(1) X An Original(2)

- A Resubmission

Name of Respondent


Welsh Plant - Envíronmental Impaet

Management currently estimates that the investment necessary to meet proposed environmental regulations through 2025for V/elsh Plant, Units I and 3 could cost approximately $900 million, excluding AFUDC. As part of this investment,SWEPCo is currently constructing environmental control projects to meet Mercury and Air Toxics Standards for WelshPlant, Units 1 and 3 at a cost of approximately $400 million, excluding AFUÐC. As of December 31, 2015, SlVEpCohad incuned costs of $343 million, including AFUDC, and had remaining contractual construction obligations of $40million related to tlese projects. SWEPCo will seek recovery of these project costs from customers through filings at the

state commissions and the FERC. Management continues to evaluate the impact of environmental rules and relatedproject cost esl¡mates. As of December 31, 2015, the net book value of Welsh Plant, Urrits I and 3 was $5?B million,before cost of removal, including materials and supplies inventory and CWIP. Welsh Plant, Unit 2 is scheduted forretirement during 20 16 and is probable of abandonment. As of December 3 I , 20 15, the net book value of Welsh plant,

Unit 2 was $82 million, before cost of removal, including materials and supplies inventory and CWIP.

If any of these costs are not recoverable, including retirement-related costs for Welsh Plant, Unit 2, it could recluce futurenet income and cash flows and impact financial condition.

FËRC FORM NO.1 D.1 123.27

(Cont¡nued)NOTES TO FINANCIAL ST


2A15tc,4


tlThis Report is:(1) X An Originale\ A Resubmission

Name of Hespondent

Soulhweslem Electric Power Companv

5. EFFECTS OF REGULATION

Regulatory assets and liabilities are comprised of the following iterns

Regulatory Assetsr

December 31,

2015 2û14

Remaining

Recovery

Period

vanous

31 years

12 years

3 years

2 years

9 years

3 years

2 years

vârrous

Regulatory asscts pending final regulatory approvall

Regulatory Assets Cunently Not Earning a Return

Shipe Road Transmission Project

Asset Retirement Obligation

Carbon Capture and Storage Comrnercial Scale Facility

Rate Case Expense

Other Regulatory Assets Pending Final Regulatory

Approval

Total Regulatory Assets Pending Final Regulatory

Approval

Regulatory åssets approyed for recovery:

Requlatorv Assets Cunently Earning a Rerurn

Under-recovered Fuel Costs

Acquisition of Valley Electric Membership

Corporation (VEMCO)

Other Regulatory Assets Approved for Recovery

Regulatory Assets Cunently Not Earning a Return

Income Tax Assets

Pension and OPEB Funded Status

Rate Case Expense - Texas

Unrealized Loss on Forward Commitments

Medicare Subsidy

Deferred Resbucturing Costs - l¡uisianaPeak Demand ReductionÆnergy Efficiency

Vegetation Management Program - Louisiana

Other Regulatory Assets Approved for Recovery

Total Regulatory Assets Approved for Recovery

5.9 t2.t

3.9 2'l.5 I year

$

0,4 t.2

(in millions)

3.1 s1.7

0.4

0.3

2.3

l.l0.4

8.1

4.2

t.80.1

277.2

98.7

6,8

5,5

4.8

3.5

1.0

261.5

96,6

l.t5.3

5.1

2.2

2.5

t.6t.4

403.0 405.3

Totsl FERC Account 182.3 Regulatory Assets $ 408.9 $ 417.4

FERC FORL¡l NO. I 123.28

NOTÊS TO FINANCIAL STATEMENTS (Continued)


2A15lc'4


This Report is:(1) X An OriginalQ\ A Resubmission

Name of Flespondent


December 31,

201s 2014

Remainïng

Refund

Period

Regulalory Liabilities:

Regulatory liabilities approved for payment:

Regulatory Liabilities Cunentlv Paving a Rerurn

Retundable Construction Financing Costs - I¡uisiana

Over-recovered Fuel Costs

Excess Earnings - Texas

Over Recovered Generation Recovery Rider Costs -

¡\rkansas

Reglrlatory Liabilities Cunentlv Not Pavine a Refurn

Income Tax Liabilities

Other Regulatory Liabilities Approved for Payment

Total Regulatory LiabilÍties Approved for Payment

Total FERC Account 254 Regulatory Liabilities

$

(in millions)

37.4 $

7.9

2.1

3 years

I year

38 years

1.7 2 years

3l years

various

58,2

2.8

1.5

5.4

1.8

6.6

t.7

s6.7 71.0

$ s6.7 $ 7r.0

6. COMùÍ{TMpNTS" GUARANTEES ÄNÐ CONTTNGENCTES

SS/EPCo is subject to certain claims and legal actions arising in the ordinary course of business. In addition, SWEPCo's

business activities are subject to extensive governmental regulation related to public health and the environmenr. The

ultimate outcome of such pending or potential litigation cannot be predicted. Management accrues contingert liabilitiesonly when management concludes that it is both probable that a liability has been incurred at the date of the financialstâtements and the arnount of loss can be reasonably estimated. When management determines that it is not probable, butrather reasonably possible that a liability has been incurred a¿ the date of the financial statements, manageme¡lt discloses

such cont¡ngencies and the possible loss o¡ range of loss if such estimate can be rnade. Any estimated range is based on

currently available information and involves elements of judgment and significant uncertainties. Any estimated range ofpossible loss may not represent the maximum possible loss exposure. Circumstances change over time and actual results

may vary significantly from estimates.

For current proceedings not specifically discussed below, management does not anticipate that the liabilities, if any,

arising f¡om such proceedings would have a mater¡al effect on the financial statements.

FERC FORM NO" 1 1 123.29

TO FINANCIAL STATEMENTS


20151O'4


nThis Fìeport is:(1) X An Original(2) A Resubmission

of Bespondent

Southwestern Electric Power

COMMITNTENTS

C o n struc tíon and C o mm ítm e nts

SWEpCo has substantial construction commitments to support its operations and environmental investments. In

managing the overall construction program and in the normal course of business, SWEPCo contractually commits to

third-party construction vendors for certain material purchases and other constmction services. Fuel, materials, sttpplies,

services and property, plant and equipment are also purchased under cûntracl as part of the normal course of

business. Certain supply contrâcts contain penalty provisions for early termination.

In accordance with the accounting guidance for "Commitments", the following table summarizes the actual contractual

commitments as of December 3l , 2015:

Contractual CommitmentsLess Than

1 Year 2-3 Years 4-5 YearsAfter

5 Years îotal

Fuel hrrchase Contracts (a) $ 198.5

Energy and Capacity Purchase Contracts 27.3

Construction Contracts for Capital Assets (b) 4'8

Totat $ 230'6

$ 69.8 S

204.6483.7365.6

4.8

$ 2A2.8 S 146.3 8 274.4 $ 854.1

(in millions)136.8 $ 78.6 $66.0 67.7

(a) Represents contractual commitments to purchase coâ|, natural gas and other consumables as fuel for electric

generation along with related transpottation of the fuel.

(b) Represents only capital assets for which there are signed contracts. Actual payments are dependent upon and

may vary significantly based upon the decision tg build, regulatory approval schedules, riming and escalation of

project costs.

GUARANTEES

Liabilities for guarantees are recorded in accordance with the accounting guidance for o'Guarantees." There is no

collateral hetd in relation to any guarantees. In the event any guarant€e is drawn, there is no recourse to third parties

unless specified below.


NOTES TO FINANCIAL STATEMÊNTS (Conlinued}


201s/Q4



Name of Respondent


G uarantees of Thírd- Party Oblþatíons

As part of the process to receive a renewal of a Texas Railroad Commission permit for lignite mining, SWEPCo providesguarantees of rnine reclamation of $l l5 million. Since SWEPCo uses self-bonding, the guarantee provides for SV/FPCoto commit to use its resources to complete the reclamation in the event the work is not completed by Sabine MiningCompany (Sabine). This guarantee ends upon depletion of reserves and completion of final reclamation. Based on the

latest study completed in 2010, it is estimated the reserves will be depleted in 2036 with final reclamarion completed by2O46 at an estimated cost of approximately $5S ¡nillion. Actual reclam¿tion costs could vary due to period inflation and

arty changes to actual mine reclamation. As of December3l,2015, StilEPCo has collected approximately $65 rnillionthrough a rider for final mine closure and reclamation costs.

Sabine charges SWEPCo, its only customer, all of its costs. SWEPCo passes these costs to customers through its fuelclause.

I ndemníftcøtions and Other Guarantees

Contracts

SWEPCo enters into certain types of contrâcts which require indemnifications. Typically these contracts include, but are

not limited to, sale agreements, lease agreements, purchase agreements and financing agreements. Generally, these

agreemenls may include, but are not limited to, indemnifications around certain tax, contractual and environmentalmatters. With respect to sale agreements, exposure generally does not exceed the sale price. As of December 31, 2015,there were no material liabilities recorded for any indemnifications.

SWEPCo is jointly and severaily liable for activity conducted by AEPSC on behalf of PSO and SWEPCo relared ropower purchase and sale activity.

Lease Abfigations

SIVEPCo leases certain equipment under master lease agreements. See "Master Lease Agreements" and "Railcar lÆase"-^^.:^..^ ^fXf-¿^ l^ f,--- l:-^l------ -¡¡,- -ssçLlulls ul l.\ur.c rZ' tuI. ulsL:tusurg ut lease re8tgual va¡ug guarantees,

FERC FORM NO. 1 'l 't23.31

NOTES TO FINANCIAL STATEMENTS (Cont¡nued)


2015/Q4


This Report is:(1) X An Original(2) - A Resubmission

Name of Respondent


CONTINGENCIÐS

The Comprehensìve Enyíronnental Response Compensatîon and Liabílíty Act (Superþnd) and State Remediatían

By-products from the generation of electricity include materials such as ash, slag and sludge. Coal combustion

by-products, which constitute the overwhelming percentage of these materials, are typically treated and deposited in

captive disposal facilities or are beneficially utilized. ln addition, the generation plants and transmission and distribution

facilities have usecl âsbestos, polychlorinated biphenyls and other hazardous and nonhazardous materials. SìVEPCo

currently incurs costs to dispose of these substances safely.

Superfund addresses clean-up of haza¡dous substances that are released to the environment. The Federal EPA

adrninisters the clean-up programs. Several states enacted similar laws. As of December 31, 2015, there are two sites for

which SWEPCo received information requests which could lead to Potentially Responsible Party (PRP) designation.

SWf,PCo has also been named potentially liable at one site unde¡ state law. In those instances where SWEPCo has been

named a PRP or defendant, disposal or recycling activities were in accordance with the then-applicable laws and

regulations. Superfund does not recognize compliance as a defense, but imposes strict liability on parties who fall within

its broad statutory categories. Liability has been resolved for a number of sites with no significant effect on net income.

Management evaluates the potentiâl liability for each Superfund site separately, but several general state¡nents can be

made about potential future liability. Altegations that materials were disposed at a particular site are often

unsubstantiated and the quantity of materials deposited at a sile can be small and often nonhazardous. Although

Superfund liability has been interpreted by the courts as joint and several, typically many parties are named as PRPs for

each site and several of the parties are financially sound enterprises. At present, management's estimates do not

anticipate material cleanup costs for identified Superfund sites.

Insurønce and Potential loss¿s

SWEPCo maintains insurance coverage normal and customary for electric utilities, subject to various

deductibles. SWEPCo also maintains property and casualty insurance that may cover certain physical damage or

third-party injuries caused by cyber security incidents. Tnsurance coverage includes all risks of physical loss or damage

to nonnuclear assets, subject to insurance poticy conditions and exclusions. Covered property generally includes power

plants, substations, facilities and invenlories" Excluded property generally includes transmission and distribution lines,

poles and towers. The insurance progrâms also generally provide coverage against loss arising frorn cerlain claims made

by third parties and are in excess of retentions absorbed by SWEPCo. Coverage is generally provided by a combination

of the protected cell of EIS andlor various industry mutual and/or commercial insurance carriers.

FERC MNO.1 1 123.32

NOTES TO FI IAL STATEMENTS (Continued)


2015/Q4


This Fleport is:(1) X An Oríginal(2) * A Flesubmission

Name of Respondent


Some potential losses or liabilities may not be insurable or the amount of insurance carried may not be sufficient to meetpotential losses and liabilities, including, bul not limited to, liabilities retating to a cyber security incirlent. Future losses

or liabilities, if they occur, which are not completely insured, unless recovered from customers, could reduce future netincome and cash flows and impact financial condition.

7. BENBFITPLANS

For a discussion of investment strategy, inveslmenl limitations, target âsset allocations and the classification ofinvestments within the fair value hierarchy, see "Fair Value Measurements of Assets and Liabilities" and "fnvestmentsHeld in Trust for Future Liabilities" secfions of Note l.

SWËPCo participates in an AEP sponsored qualified pension plan and trvo unfunded nonqualified pensionplans, Substantially all AEP employees are covered by the qualified plan or both the qualified and a nonqualifiedpension plan. SWEPCo also participates in OPEB plans sponsored by AEP to provide health and tife insurance benefitsfor retired employees.

SWEPCo recognizes the funded status associated with defined benefit pension and OPEB plans in the lralancesheets. Disclosures about the plans are required by the "Compensation - Retirement Benefits" accountingguidance. SWEPCo recognizes an asset for a plan's overfunded status or a liability for a plan's underfunded status, andrecognizes, as a component of other comprehensive income, the changes in the funded status of the plan that arise cluringthe year that are not recognized as a component of net periodic benefit cost. SWEPCo records a regulatory asset insteâdof other comprehensive income for qualifying benefit costs of regulated operations that for ratemaking purposes are

deferred for future recovery. The cumulative funded status adjustment is equal to the remaining unrecognized deferralsfor unamortized actuarial losses or gains, prior service costs and transition obligations, such that remaining deferred costsresult in an AOCI equity reduction or regulatory asset and deferred gains result in an AOCI equity addition or regulatoryliability.

Aetuaríal Assumptíons far Benefit Oblígatíons

The weighted-average assumptions as of December 3l of each year used in the measurement of benefit obligations areshown in the following table:

Pension PlansOther Postretirement

Benefit PlansAssumptions 2Aß 2014 2015 2ßt4

Discount RateRate of Compensation Increase

430 Vo

4.80 Vo (a)4.00 Vo

4.8O 7o (a)43O 7o

NA4.00 ?o

NA

(a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for exemptenployees and overtime and incentive pay for nonexempt employees.

NA Not applicable.


NOTËS TO FINANCIAL STATEMENTS (Continued)


2015/Q4


ttThis Fìeport is:(1) X An Original{2) - A Resubmission

Name of Flespondent

Southwestern Eleckic Poler Com pany

A duration-based method is used to determine the discount rate for the plans. A hypothetical portfolio of high quality

corporate bonds is constructed with cash flows matching the benefit plan liability. The composite yield on tlrchypothetical bond portfolio is used as the discount râte for the plan.

For 2015, the rate of compensation increase assumed varies with the age of the employee, ranging from 3.570 per year to

l7Vo per yea¡ with the average increase shown in the table above.

Actuarial Assumptiansfar Net Periadîc Benefrt Costs

The weighted-average assumptions as of January I of each year used in the measurernent of benefit costs are shown in

the following table:


Benefit Plans

Àssumptis¡rs 20ls 2ût4 2015 2*L4Ðiscourlt RateExpected Return on PIan AssetsRate of Compensation Increase

4.OA 7c

6.OA 4o

4.80 7a (a)

4.7OVo 4.7AVo

6.754aNA

4,OOVo

6.ffiVo 6;15 Vo

4.857o (a) NA

(a) Rates are for base pay only. In addition, an amount is added to reflect target incentive compensation for

exempt employees and overtime and incentive pay for nonexempt employees.

NA Not applicable.

The expected return on plan assets was determined by evaluating historical returns, the current investment climate (yield

on fixed income securities and other recent investment market indicators), rate of inflation and current prospects for

economic growth.

The health çare trend rate assumptions as of January I of each year used for OPEB plans rneasurement purposes are

shown below:

Health Care Trend Rates 2tl5 2AMInitialUltimateYear Ultimate Reached

6.25?a5"ÛAVo

2020

6.50Vo

5.A0Vo

2024

FERC FORM NO.1 {ED. 12.88} Page 123.34

FINANCIAL STATEMENTS


2015tQ4


This Report is:(1) XAn Original(2) A Resubmisslon

Name of Respondent


Assumed health câre cost trend rates have a significant effect on the amounts reported for the OPEB health care plans, Al?a change in assumed health care cost trend rates would have the following effects:

17o lncrease 17o Decrease

$

(in millions)

0.2 $

3.5

Effect on Total Service and Interest Cost Components of NetPeriodic Postreti¡ement Health Care Benefit Cost

Effect on the Health Care Component of the AccumulatedPostretirement Benefit Obligation

(0.1)

(2.e)

Signifîcant Concentratíons af Risk within Ptan Assets

In addition to establishing the target asset allocation of plan assets, the investment policy also places restrictions onsecurities to limit significant concentrations within plan assets. The investment policy establishes guidelines that governmaximum market exposure, security restrictions, prohibited asset classes, prohibited types of transactions, minimumcredit quality, average portfolio credit quality, portfolio duration and concentration limits. The guidelines wereestablished to mitigate the risk of loss due to significant concentrations in any investment. Management monitors theplanstocontrolsecuritydiversificationandensurecompliancewiththeinvestmentpolicy. AsofDecember3tr,20l5,theassets were invested in compliance with all investment limits. See "Investments Held in Trust for Future Liabilities"section of Note I for limit details.

FERC FORM NO. 1 D.f 123.35



2015/Q4

Date ol Hepoil(Mo, Da, Yr)

This Report is:(1) X An CIriginalet A Resubmission

Name of Hespondent


ßenefit Pkn Oblîgøtíons, Plan,4ss¿ls and Funded Status as of December 31,2A$ and2014

The following table provides a reconciliation of the changes in the plans" benefit obligations, fair value of plan assets and

funded status as of December 31. The benefit obligation for the defined benefit pension and OPEB plans are the

projected benefit obligation and the accumulated benefit obligation, respectively.


Benefit Plans2Aß 2014 2û15 2tt4

Change in Benefit ObligationBenefit Obligation as of January l,Service CostInterest CostActuarial(Gain) LossBenefit PaymentsParticipant ContributionsMedicare Subsidy

Benefit Obligation as of December 31,

Change in Fair Value of Plan AssetsFair Value of Plan Assets as of January l,Actual Gain (Loss) on Plan AssetsCompany ContributionsParticipant ContributionsBenefit Payments

Fair Value of Plan Assets as of December 31,

s 282.89 298.2 $ 86.1 $ 85.0

$ 290.2 $1.6

8.1

s 298.2 $8.3

I 1.8

{r6.2)( r e.3)

{in millions)2''tt.6 $

6.612.7

27.5(19.2)

85.0 $0.83.42.t

(7.4)2.t0.1

87.01.0

4.0(2.3)(7.7)2.s0.5

(re.3) (7.7)

$279.426.5

3.9

{19.2}

106.4 s(3.3)

2.t(7.4)

ß7.73.9

2.5

$ 280.6 g 290.2 $ 97"8 S 106.4

S'unded (Underfunded) Status ns of December 31, $ Q.2\ $ (8.0) $ ll.7 $ 2t.4

FERC FORM ilO.1 (ED.19.88) Paqe 123.36

NOTES TO FINANCIAL SI (Continued)

Year/Feriod of Report

2015/Q4


Thís Report is:(1) X An Origínal(2) _ A Flesubmission

Name of Flespondent


Awounts Recognízed on the Balance sheets as of December 31, 20ts ønd 2014


Benefït Plans

2û15December3l,

2AL4 20ls 2014

Special Funds - Prepaid Benefit CostsMiscellaneous Cunent and Accrued Liabilities -

Short-term B enefit l,iabilityAccumulated Provision for Pensions and Benefits -

Long-term Benefit LiabilityFunded (Underfunded) Status

ComnonentsNet Actuarial LossPrior Service Cost (Credit)

Recorded asRegulatory AssetsDeferred Income TaxesNet of Tax AOCI

Actuarial (Gain) Loss During the YearAmortization of Actuarial LossAmorlization of Prior Service Credit (Cost)

Change for the Year Bnded December 31,

$ $

(in millions)$ I1.7 s 2t.4

(0.1)

(2.t)

(0.1)

(7.e)

$ (2.2) $ (8.0)

Amounts lncluded ín A0CI and Regulotory Assets as af Ðecember JI,2aß ønd2014

Pension Plans

$ ¡r.7 $ 21.4

Other PostretirementBenefit Plans

2015Ðecember 31,

2014 20ts 2014

$ 97.t $0.4

{in rnillions)t0/'.g $

o.743.3 $

(41.6)

t.2 $4.2û.3

32.4(46.8)

(8,e)( l.e)(3.6)

s 97.5 S 105.6 $

Components of the change in amounts included in AOCI and regulatory assets during the years ended December 31, 20lsand 2014 are as follows:


Benefit Plans2015 2At4 2015 2014

Components$ (1.8) $

(6.0)(0.3)

(in millioos)r6.s $(7.1)(0.3)

n.a $(1.1)5.2

0.8(1.2)5.2

$ (8.1) $ e.l $ l6.t $ 4.8


NOTËS TO FINANCIAL STATEMENTS (Contínued)


2A15lQ¿4

Date of Hepon(Mo, Da, Yr)

ltThis Report is:(1) X An Original(2) ,A Resubmission

Name of Hespondent


Pensían and Other Postretíramenl Benefifs Plans' Assets

The fair value tables within Pension and Other Postretirement Benefits Plans' Assets present the classification of assets

for AEP within the fair value hierarchy. All l-evel 1,2,3 and Other êrnounts can be allocated to Slñ/EPCo as of

December 31, 2015 and 2Ol4 using the petcentages in the table below:

Pension Plan0ther Postretirement

BenefïtPlans

2015 2tt4 2015 20L45.91a 5.ïVo 6.2Vo 6.3Vo

FERC 1 1 123.98

NOTES TO FINANCIAL


2015tQ4

Date oi Report(Mo, Da, Yr)

This Report ís:(1) X An Original(2) _ A Flesubmission

Name of Respondent

,9qq!!rye¡lqrn Eleclric Power Company

The foilowing table presents the classification of pension plan assets for AEP within the fair value hierarchy as ofDecember 31, 2015:

Asset Clâss Level 1 Level2 Level 3(in millions)

$

Other TotalYear EndAllocation

Equities:DomesticlnternationalOptionsReal EsÍate Investment TrustsCommon Collective Trust - ClobalCommon Collective Trust -

lnternationalSubtotal - Equities

Fixed Income:Common Collective Trust - DebtUnited States Government and

Agency Secu¡itiesCorporate DebtForeign DebtState and Local Covemmentôther - Asset Backed

Subtotat - Fixed Income

InfrastructureReal EstateAlternative InvestmentsSecurities LendingSecurities Lending Collateral (a)Cash and Cash EquivalentsOther - Pending Transactions and

Accrued Income {b)

722.O 401.4

$ 3t5.7 $402.3

4.0r 5.6

369.7

t6. r

3t5.7402.3

15.64,0

369.7

6.6 Va

8.4 Vo

0.3 7o

O.I 7o

$ $

Vo7.8

t 6.l A3 Vo

r,t23.4 23.5 Vo

34.2 0.7 Vo34.2

42t.91,983.2

42t.412,8

23.4

0.1

421.91,983.2

42t.512.823.4

8.9 Vo

41,6 Vo

8.8 {aA3 7o

t.5 70

2,896.9 0.1

42.O

253.1378:7

2,897.O 64.8 7o

263.A

48.6(264.7)

42.t253,7378.72$.4

(264.7)48.6

4.9 7o

5.3 Vo

8.A 7o

5,5 Va

(5.SJ?o

l.O 7o

25.9 ?5.9 A.5 70

Total 722^O $ 3,609.9 674.5 $ (238.8) S 4,767.6 1ffi.0 o/a

(a) ,A'mounts in "Other" cok¡mn primarily r€present an obligation to repay collateral received as part of the Securities LendingProgr¡frl- _-d-__'-

(b) Amounts in "Other" column primarily represent accrued interest, dividend receivables and transactions pending settlement.

FERC FORM 1 1 123.39


Year/Feriod oÍ Flëport

2015/Q4


ttThis Report is:(1) XAn Original{2) A Resubmission

Name ol Flespondent


The following table sets forth a reconciliation of changes in the fair value of AEP's assets classified as t¿vel 3 in the fair

value hierarchy for the pension assets:

ForeignDebt

$ 0.r $

(3.6)

0.3

32.8

Resl AlternatlveInfrastructure Estate Investrnen-ts

(in millíons)r2.s $ 235.8 $ 378.9 $Balance as of January 1, 2015

Actual Retum on Plan Assets

Relating to Assets Still Held æ of the Reporting Datc

Relating to Assets Sold During the Period

Purchases and Sales

Translers into lævel 3

Transfers oul of l¿vel 3Balance as of Ðecember 31, 2015

TotalLevel 3

12.5

23.8(t8.4)

(2s.e>

37.6(l l.e)

627.3

(r7.0)6t.72.5

$ 0.1 $ 42.0$ 253.7$ 378.7 $ 674.5

1MFERC 123.40

NOIES TO FINANCIAL STATEMENTS (Continued)


2015tQ4


This Report is:(1) X An Original(2) * A Resubmission

Name of Hespondent

Southwestern Êlectric Power Com pany

The following table presents the classification of OPEB plan assets for AEP within the fair value hierarchy as ofÞecember 31, 2015:

Asset Class Level I Level2 Level3 Other TotalYear EndA,llocation

Equities:DomesticlnternationalOptionsCommon Collective Trust - GlobalCommon Collective Trust -

InternationalSubtotal - Equities

Fixed Income:Common Collective Trust - DebtUnited States Government and

Agency SecuritiesCorporate DebtForeign DebtState and l-ocal GovernmentOther - Asset Backed

Subtotal -Fixed Income

Trust Owned Life Insurance:Internâtional EquitiesUnited States Bonds

Subtotal -Trust Owned Life Insurance

Cash and Cash EquivalentsOther - Pending Transactions and

Accrued Income (a)

Total

(a)

949.4 47.2

100.9

$

(in millions)

$ -$ $465.1 $484.3

465.1484.3

15.6r9.0

t2.6

29.5Vo3O.77o

t.t70l.2lo

15.619.0

12.6 O.ïVo

996.6

r00.9

63.2?o

6.4Vo

58.4n7.724.74.28,4

s8.4n7.72A.7

4.28.4

3.7Vo

7.4Vo

t.3700.37oA.5Va

310.3

28.3184.3

310.3 19.6Vo

28.3r84.3

l.ïVoI 1.7 Ç/o

44.9

2t2.6

7.2

2t2.6

52.1

5.8

13.5Vo

3.3Vo

4.47o5.8

$ 994.3 $ 577.3 $ 5.8 $ 1,577.4 tCf..OVa

Amounts in "Other" column primarily r€present accrued interest, dividend receivables and lransactions pending settlement.



YeariPeriod of Report

2015/Q4


ttThis Report is:(1) X An OriginalQ\ A Resubmission

Name of Hespondent


The following tabte presents the classification of pension plan assets for AEP within the fair value hierarchy as of

December 3L,2Al4:

Asset Class Level l" Level 2 I,evel 3(in millions)

OtherYearEndAllocation

Equities:DomesticInternationalOptionsReal Estate Investment TrustsCommon CollectiveTrust - GlobalCommon Collective Trust -

InternationalSubtotal - Equities

$ $ $ $

14,I54.3

r 8.5

l,l45,l 409.6 t,554.7

,-{-otal

s88.6 $502.2

588.6502.2t4.l54.3

377.0

tl.9 ?o

IQ.l Vo

A3 7o

l.l Va

0,4 7a

377.O

r 8.5

7.6 Vo

Fixed Income:Common Collective Trust - DebtUnìted States Government and

Agency SecuritiesCorporat'e DebtForeignDebtState and l-ocal GovemmentOther - Asset Backed

Subtotal - Fixed Income

Infrastn¡ctureReal EstateAltemative lnvestmentsSecurities LendingSecurities knding Collateral (a)

Cash and Cash EquivalentsOther - Pending Transactions and

Accrued Income (b)

3{J.2

449.81J99.5

400.5t4.929.l

0.1

30.2

449,81,199.5

400.6t4.929,1

31.4 7o

O.6 Ço

9.0 7o

36.2 ?o

8.1 7a

0.3 o/o

O.6 lo2,724.A

219.8

0.1

12.5

235.8378.9

2J24.t 54.8 70

A3 c/o

4.7 lo7.6 7o

4.4 0/o

(4.S)Vo

l.l Va

O.2 Ça

53.3

(221.5)

12.5

235,8378.9219.8

(221.5)s3.3

9.9 9.9

Total $ I,t45.l $ 3,406.7 $ 627.3 $ (21 L6) S 4,967.5 100.0 ?o

(a) Amounts in "Other" column primarily represent an obligation to repay collateral received as pan of the Securities Lending

Program.

(b) Amounts in "Other" column primarily represent accrued interest, dividend receivables and transactions pending settlement.

C FORM NO.1 1 123.42

STATEMENTS (Contlnued)NOTES


20151Q4


uThts Fleport is:(1) X An Original(2)

- A Resubmission

Name of Respondent

Soulhwestem Electric Power Companv

The foltowing table sets forth a.reconciliation of changes in the fair value of AEP's assets Çlassified as l,evel 3 in the fairvalue hierarchy for the pension assets:

ForeiglDebt

RealEslate

ÄlternativeInvestments

TotalLevel 3

Balance as of Jaauary 1,2014Actual Retum on Plan Assets

Relating,to Assets Still Held as of the Reporring DateRelating to Assets Sold During the Period

Purcha¡es and Sales

Tra¡rsfers into l-evel 3

Transfers out of l¿vel 3

Balance as of I)ecemlrer 31,2014

$ 0.r $

Infrastructure

(0.3)

0.1

ta

(inrdllions)

- $ 238.2 $ 329.6 $ 567.e

5.5

¡9.0(26.e)

32.0

15.8

1.5

37.2

34.9(t2.7')

$ 0.1 $ t2.5 $ 235.8 $ 378.9 $ 6273

NO.1 I 't23.43

NoTES TO FINANCIAL STATËMENTS (Continued)


2015/O4


ttThis Report is;(1) X An Original(2) A Resubmission

Name ol Respondent


The following table presents the classification of OPËB plan assets for AEP within the fair value hierarchy as of

Ðecenrber 3l,2Al4:

Asset Class Level 1 -. I.eJgl 2 Level3 Other TotalYear EndAllocation

(inmillions)Equities:

DomesticInternationalOptionsCommon Collective Trust - Global

Subtotal - Equities

$ $ $

|,032.7 46.0 1,0?8.7

$ 466.r $s66.6

466^t566.6

t6.429.6

27.57o33.SVo

l.ÙVol.8lo

t6.429.6

Fixed Income:Common Collective Trust * DebtUnited States Government and

Agency SecuritiesCorporate DebtForeign DebtState and Local GovernmentOther * Asset Backed

Subtotal - Fixed Income

Trust Owned Life Insurance:International EquitiesUnited States Bonds

Subtotal -Trust Owned Life Insurance

Cash and Cash Equivalents

Other * Pending Transactions and

Accrued Income (a)

Total $ 1,079.5 $ 610.¿l $

103.7 143.7

7 t.tt25.521.3

5.94.9

63.89o

6.14o

4.27o7.47ol.3loo.3voA3Vo

7 1.,125.52t,3

5.94.9

332.4 332.4 19.69o

A.67o12.57o

10.32t2.1

r0.3212.1

46.8

7)) L

9.6

222.4

56.4

4.0

13.1Vo

3.37a

O.24o4.0

$ 4.0 $ l,ó93.9 too.avo

(a) Amounts in "Other" column prirnarily represent accrued interest, dividend receivables and üansactions pending settlement.

FÊRC FORM NO.1 D.1 123.44

NOTËS TO FINANCIAL STATEMENTS ued)


201s/Q4


ttThis Report is;(1) X An OriginalQ\ A Resubmission

Name of Flespondent

Southweslem Electric Power Company

Determinatian cf Pensian Expense

The determination of pension expense or income is based on a market-related valuation of assets which reducesyear-to-year volatility. This market-related valuation recognizes investment gains or losses over a five-year period fromthe year in which they occur. Investment gains or losses for this purpose are the difference between the expected returncalculated using the market-related value of assets and the actual return.

The accurnulated benefit obligation for the pension plans is as follows:

Underfunded Pension PlansDecember 31,

¡lccumulated Benefit Oblieation 2û15 20t4

Qualified Pension PlanNonqualified Pension Plans

Total

Projected Benefit Obligation

Accumulated Beneñt ObligationFair Value of Plan Assets

Underfunded Accumulated Benefit Obligation

$

(in millions)267,7 $

1.628l.2

t.8$ 269.3 $ 2 .0

For the underfunded ¡ænsion plans that had an accumulated benefit obligation in excess of plan assers, the projectedbenefit obligation, accumulated benefit obligation and fair value of plan assets of these plans as of December 31,2015and 2014 were as follows:

December 31,2015 2814

$

(in millíons)1.7 $ 1.8

$ 1.6 $ 1.8

$ ( 1.6ì $ ( 1.8)

Estimaled Future Benefit Payments and Contríbutíons

SWEPCo exp€cts contributions and payments for the pension plans of $7 million during 2016. For the pension plans,this amount includes the pnyment of unfilnded nonqua!ified bellefits plus contributions to the qua!ified trust fund of atleast the nrinimum a¡nount required by the Employee Retirement Income Security Act. For the qualified pension plan,SWEPCo may also make additional discretionary contributions to maintain the funded status of the plan.

RC NO.1 1 't23.45



2015/Q4

Date of Fìeport(Mo, Da, Y$

ttThis Report is:

i1) XAn Original{2) A Resubmission

Name of Respondent


The table below reflects the total benefits expected to be paid from the plan or from SWEPCo's assets. The payments

include the participants' contributions to the plan for their share of the cost. Future benefit payments are dependent on

the number of employees retiring, whether the retiring employees elect to receive pension benefits as annuities or as lump

sum distributions, future integration of the benefit plans with changes to Medicare and other legislation, future levels of

interest rates and variances in actuarial results. The estimated payntents for the pension benefits and OPEB âre as

follows:

Estimated Pavments

Pensìon Plans

OtherPostretirementBenefit Plans

$

(in rnillions)18.6 $20.22t.l2l,B22.4

na.2

Conponents of Net Períodíc Benefit Cost

The following table provides the components of net periodic benefit cost (credit) for the plans for the years ended

December 31, 2015 and 2014:


Benefit Plans

2015Yearc Ended December 31,

2014 2015 2014

$iin millions)

6.6 $ 0.8 $t2.7 3.4

( ls.4) (6.e)0,3 (s,2)7.1 l.l

r0,4 l1.3 (6.8) (6.0)(3.2) , (3.4) 2.t 1.8

$ 7.2 $ 7.e $ (4.?) $ {4.2}

20162At720r 8

2At92020Years 2021 ø 2A25, in Total

Service CostInterest CostExpected Return on Plan Assets

Amortization of Prior Service Cost {Credit)Amortization of Net Actuarial l¡ssNet Periodic Benefit Cost {Credit)Capitalized PortionNet Periodic Benefit Cost (Credit)

Recognized in Expense

8.3 $I 1,8

(r6.0)0.36.0

1.04.0

(7.0)(s.2)t.2

7.eLl8.38,48.7

47.6

FERC FORM NO.1 1 't23.46

NOTES TO FINANCIAL STATÊMENTS (Continued)

Year/Period oi Report

201s/Q4



Name of Respondent

Soulhwestern Electric Power Company

Estimated amounts expected to be amortized to net periodic benefit costs (credits) and the impact on the balance sheet

during 2016 are shown in the following table:

Pension Plans

OtherPostretirementBenefit Plans

ComponentsNet Actuarial LossPrior Seryice Cost (Credit)

Total Estimated 2016 Amorlization

Bxpected lo be Recorded as

$

(in millions)4:7 $

0,3t.8

(s. t)b 5.0 $ (3.3)

Regulatory AssetDeferred Income Taxes

Net of Tax AOCITotal

$ 5.0 $ (2.t)(0.4)(0.8)

5.û $ (3.3)

American Electric Power System Retirement Savíngs Plan

SIVEPCo participates in an AEP sponsored defined contribution retirement savings plan, the American Electric PowerSystem Retirement Savings Plan, for substantially all employees. This qualified plan offers participants an opportunity tocontribute â portion of their pay, includes features under Section aOl(k) of the lnternal Revenue Code and provides forcompany rnatching contributions. The matching contributions to the plan are 10A6/o çf the first lVa oî eligible employee

contributionsandJAo/o of the next Sa/o of contributions. The cost for matching contributions to the retirement savingsplans for the years ended Ðecember 31, 2015 and 2014 was $6 million and $5 million, respecrively"

8. BUSINBSS SEGMENTS

SWEPCo has one reportable segment, an electricity generation, transmission and distribution business. SWEPCo's otherâctiYities are insignificant.

$

ERC FORM NO.1 1 123.47


Year/Period CIf Report

2015/Q4

Date ol Repod(Mo, Da, Yr)

This Fleport is:(1) X An Original(2) A Resubmission

Name of Respondent

Southwestern Electric Powor Company

9. DERIVATIVES AND HEDGING

OBJECTIVES FOR UTILIZATION OF DERIVATIVÐ INSTRUMENTS

AEPSC is agent for and transacts on behalf of SWEPCo

SSIEPCo is exposed to certain market risks as a major power producer and participant i:r the electricity, capacity, natural

gas, coal and emission allowance markets. These risks include commodity price risks rvhich may be subject to capacity

risk, interest rate risk, credit risk and, to a lesser extent, foreign currency exchange risk. These risks represent the risk ofloss that may impact SWEPCo due to changes in the underlying market prices or rates. Management utilizes derivative

instruments to manage these risks,

STRATEGIES FOR UTILIZATION OF ÐERTVATIVE INSTRUÙIENTS TO ACHIEVE OBJECTIYES

Rísk Management Strategie s

The strategy surrounding the use of derivative instrurnents primarily focuses on managing risk exposures, future cash

flows and creating value utilizing both economic and formal hedging strategies. The risk management strategies also

include the use of derivative instruments for trading purposes which focus on seizing market opportunities to create value

driven by expected changes in the market prices of the commodities. To accomplish these objectives, SWEPCo primarily

employs risk managemerìt contracts including physical and financiat forward purchase-and-sale contracts and, to a lesser

extent, OTC swaps and options. Not all risk management contracts meet the definition of a derivative under the

accounting guidance for "Derivatives and Hedging." Derivative risk management contracts elected normal under the

normal purchases and normal sales scope exception are not subject to the requirements of this accounting guidance.

SWEPCo utilizes power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and other

commodity contracts to ¡nanage the risk associated with the energy business. SWEPCo utilizes interest rate derivative

contracts in order to manage the interest rate exposure associated with the commodity portfolio. For disclosure purposes,

such risks are grouped as "Commodity," as these risks are related to energy risk management activities. SWEPCo also

utilizes derivative contracts to manage interest rate risk associated with debt financing and foreign currency risk

associ¿ted with future purchase obligations denominated in foreign currencies. For disclosure purposes, these risks are

grouped as "Interest Rate and Foreign Currency." The amount of risk taken is determined by the Commercial Operations

and Finance groups in accordance with established risk management policies as approved by the Finance Committee ofthe Board of Directors.

FERC FORM NO.1 (ED. T2.E8I Paqe 123.48

NOTES TO FINANCIAL STATËMENTS {Continued}


2015/Q4

Date of Fleport(Mo, Ða, Yr)

This Report is:(1) X An Original(2) A Resubmission

Name of Respondent


The following table represents the gross notional volume of outstanding derivative contracts as of December 31, 2015

and 2014:

Notional Volume of Derivative Instruments

VolumeDecember 31,

Primary Risk Exposure 2015 2AM Unit of Measure(in millions)

Commodity:PowerCoalNatural Gas

Heating Oil and Gasoline

14.02.8o.20.9

20.51.5

0.7

MWhsTons

MMBtusGallons

Cøsh F'low Hedgíng Strategíes

SWEPCo utilizes cash flow hedges on certain derivative transactions for the purchase and sale of power ("Commodity")in order t0 manage the variable price risk related to forecasted purchases and sales. Management monitors the potentialimpacts of commodity price changes and, where appropriate, enters into derivative transactions to protect profit marginsfor a portion of future electricity sales and purchases. SIVEPCo does not hedge all comrnodity price risk.

SWEPCo's vehicle fleet is exposed to gasoline and diesel fuel price volatility. SWEPCo utilizes financial heating oil andgasoline derivative contracts in order to mitigate price risk of future fuel purchases. Cash flow hedge accounting forthese derivative contracts was discontinued effective March 31,2014. SWEPCo does not hedge all fuel price risk.

SWEPCo utilizes a variety of interest rate derivative transactions in order to rnanage interest rate riskexposure. SIMEPCo also utilizes interest rate derivative contracts to manage interest rate exposure related to futurebonowings of fixed-rate debt. SWEPCo does not hedge all interest rate exposure.

At times, S\ilEPCo is exposed to foreign currency exchange rate risks primarily when some fixed assets are purchased

from foreign suppliers. ln accordance with AEP's risk management policy, SIVEPCo may utilize foreign cußencyderivative transactions to protect against the risk of increased cash outflows resulting from a foreign currency'sappreciation against the dollar. SIVEPCo does not hedge all foreign currency exposure.

FERC FORM NO. I Ð.1

TO FINANCIAL STATEMENTS

Name of Respondent

Southwestem Electric Power Com

Date ol Report{Mo, Da, Yr)

ItA Resubmission

This Report is:(1) X An Original


2015to4

ÀCCOTINTING FOR DERIVATIVE INSTRUMBNTS AND THE IIVIP^{CT ON THE f'TNANCIAL

STÀTEMANTS

The accounting guidance for "Derivatives and Hedging" requires recognition of all qualifying derivative instruments as

either assets or liabilities on the balance sheets at fair value. The tãir values of derivative instruments accounted for

using MTM accounting or hedge accounting are based on exchange prices and broker quotes. If a quoted market price is

not available, the estimate of fair value is based on the best information available including valuation models that

estimate future energy prices based on existing market and broker quotes, supply and demand market data and

assumptions. In order to determine the relevan[ fair values of the derivative instruments, SWEPCo applies valuation

adjustments for discounting, liquidity and credit quality'

Credit risk is the risk that a counterparty wiil f¿il to perform on the contract or fail to pay amounts due. Liquidity risk

represents the risk that imperfections in the market will cause the price to vary from estimated fair value based upon

prevailing market supply and demand conditions. Since energy markets are imperfect and volatile, there are inherent

risks related to the underlying assumptions in models used to fair value risk management contracts. Unforeseen events

may cause reasonable price curves to differ from actual price curves throughout a contracl's term and at the time a

contract settles. Consequently, there could be significant adverse or favorable effects on future net income and cash

flows if market prices are not consistent with mânagement's estimates of current market consensus for fonryard prices in

the current period. This is particularly true for longer term contracts. Cash flows may vary based on rnarket conditions,

margin requirements and the timing of settlement of risk management contracts'

According to the accounting guidance for "Derivatives and Hedging," SWEPCo reflects the fair values of derivative

instruments subject to netting agreements with the same counterpârty net of related cash collateral. For certain risk

management contracts, SWEPCo is required to post or receive cash collateral based on third party contractual agreements

and risk profiles. For the Decernber 31, 2015 and 2014 balance sheets, SWEPCo netted cash collateral received from

third parties against short-term and long-term risk management assets and cash collateral paid to third pa*ies against

short-term and long{errn risk management liabilities as follows:

Ðecember 31,2015 2A14

Cash CollateralReceived

Netted AgainstRiskManagement

Assets

Cash CollateralPaid

Netted AgainstRiskManagement

Liabilities

Cash CollateralReceived

Netted ÀgainstRiskManagement

Àssets

Cash CollateralPaid

Netted ÀgainstRisk Management

LÍ¡bilífÍes

$ $

(in millions)0.3 $ $ 0.1

EÐ.1FERC FOHM NO.1 123.50

TO


2015rQ4

Date of Beport(Mo, Da, Yr)

This Fleport is:(1) X An Oríginal(2\ A Resubmission

Name of Flespondent


The following tables represent the gross fair value deriv¿tive activity on the balance sheets as of December 3 I , 201 5 and20t4:

Fair Value of Derivative InstrumentsDecernber 31,20I5

Risk[fanagement

Contracts Hedging Conlracls

Cross Amountsof Risk

IllnrgementAsseld

LiabilitiesRecosnized

GrossAmounts

Offset in theSlatement of

FinancialPosition (b)

Nel Amounts ofÂssets/LlabtlitiesPresented in the

Slatement ofFinaneial

Posilion (c)

Interesl Raleand ForeignCurrenry (a)Ilalance Sheet Location Cornmodity (s) Commodity (a)

Derivative lnstrument Assets(in millions)

S s

Derivativc Instrument Li¡bilitiesLong-term Ponion of Derivative

lnstrument Liabilities

Derivative Instrument Asets

Derivativc Instrument Liabilitíes

0.8 s

5.5

2.1

-S 0.8 s

5.5

2.t

0.8

<t

2.1

(0.3)

Risktrfanagement

Conlråets

fair Value of Derivalire InstrumentsDecenber 31,2014

Hedsine Con{racls

Bal¡nce Sheet Location Commodity (a) Commodity (a)

Interest Râlernd ForelgnCurrency (a)

çross.{,mountsof Rlsk

l\lanagemenlAss€tc/

LiabilitiesRecosniz€d

GrossAmounli

Offset in theShfemen! of

FinancialPosition (b)

Net Amounts ofAssets/LiabilitiesPresented in the

Si8tement Õf

Financl¡lPosition (c)

0.5 s

1.6

-S (0.5) s

(0.5)

(in millions)s 0.5 s

t.6 r.l

(a) Derivative insruments within these categories are reported gross. These inskuments are subject lo master fletting agreements an¡! a¡e presented on thebalancc sheets on a net basis in accordance with the accounting guidance for "Þerivatives and Hedging."

(b) Amounls include counterparty netting of risk management and hedging contracls and associated cash colla¡eral in accordance with the accountingguidance for "Derivatives and Hedging."

(c) There arc no derivative cont¡acts subject to a master netting anarìgement or similar ageement which are not offset in rhe statement of financial position,

FERC FORM NO. I I 123.51



20151o'4



Name of Respondent

Southweslem Electrio Powe¡ Company

The table below presents the activity of derivative risk management contracts for the years ended December 3 I , 20 l5 and

7At4:

Amount of Gain (Loss) Recognized onRisk lllanagement Contracts

Location of Gain {Loss)Years Ended December 31,

2015 2014(in millions)(0.s) $(0.4)(4.3)

t5.I

Operation ExpensesMaintenance ExpensesRegulatory Assets (a)

Regulatory Liabilities (a)

Total Gain on Risk Management Contracts

$

(1.1)16.9

ffi

$ 9.9 $ 15,8

(a) Represents realized and unrealized gains and losses subject to regulatory accounting

treatment.

Certain qualifying derivative instruments have been designated as normal purchase or normal sale contracts, as provided

in the accounting guidance for "Derivatives and Hedging." Ðerivative contracts that have been designated as normal

purchases or normal sales under that accounting guidance are not subject to MTM accounting treatment and are

recognized on the statements of income on an accrual basis.

The accounting for the changes in the fair value of a derivative instrument depends on whether if qualifies for and has

been designated as parr of a hedging relationship and further, on the type of hedging relationship. Depending on the

exposure, managernent designates a hedging instrument as a fair value hedge or a cash flow hedge.

For contracts that have not been designated as part of .t hedging relationship, the accounting for changes in fair value

depends on whether the derivative instrument is held for trading purposes. Unrealized and realized gains and losses on

derivative insrruments held for trading purposes are included in revenues on a net basis on the statements of

income. Unrealized and realized gains and losses on derivative instruments not held for trading purposes are included in

revenues or expenses on the statements of income depending on the relevant facts and eircumstances. Certain derivatives

that economically hedge future commodity risk are recorded in the same expense line item on the statements of incorne as

that of the associated risk. However, unrealized and some realized gains and losses for both trading and non-trading

derivative instruments are recorded as regulatory assets (for losses) or regulatory liabilities (for gains) in accordance with

the accounting guidance for "Regulated Operations."

FERC FORM NO. 1 Ð.1 123.ö2

NOTES TO STATEMENTS

Year/Period of néport

2015/Q4


This Report is:(1) X An Originat(2) _ A Fìesubmission

Name of Respondent


Accountíng for Cash Flow Êledging Strategíes

For cash flow hedges (i.e. hedging the exposure to variability in expected future cash fiows that is attributable to aparticular risk), SWEPCo initially reports the effective portion of the gain or loss on the derivative instrument as acomponent of Accumulated other Cornprehensive Income on the balance sheets untit the period the hedged item affectsNet Income' SWEPCo's hedge ineffectiveness is recorded as a regutratory asset (for losses) or a regulatory liability (forgains).

Realized gains and losses on derivative contracts for the purchase and sale of power designated as cash flow hedges areincluded in operating Revenues or operation Ë'xpenses on the statements of income or in regulatory assets or regulatoryliabilities on the balance sheets, depending on the specific nâ.ture of the risk being hedged. During 2015 and 2014,swEPCo did not apply cash flow hedging to outstanding power derivatives.

swEPCo reclassifies gains and losses on heating oil and gasoline derivative contrâcts designated as cash flow hedgesfrom Accumulated other comprehensive lncome on the balance sheets into operation Expenses, Maintenance Expensesor Depreciation Expense, as it relates to capital projects,. on the statements of income. The impact of cash flow hedgeaccounting for these derivative contracts was immaterial and was discontinued effective March 3f ,2014.

swEPCo reclassifies gains and losses on interest rate derivative hedges related to debt financings from AccumulatedOther Comprehensive Income on the balance sheets into Interest on Long-term Debt on the statements of income in thoseperiods in which hedged interest payments occur. During 2015 and 20t4, swEpco did not apply cash flow hedging tooutstanding interest rate derivatives. "

,,

The accumulated gains or losses retated to foreign currency hedges are reclassified from Accumutated other ..,,comprehensive l¡ncome on the balance sheets into Depr€ciation Expense on the statements of income over the .depreciable lives of the fixed assets designated as the hedged items in qualifying foreign currency hedgingrelationships' Ðuring 2015 and 2014, swEPCo did not apply cash flow hedging to any outstanding foreign cuffencyderivatives.

During 2015 and 2014' hedge ineffectiveness was irnmateriat or nonexistent for all of the hedge strategies discloseda.bove.

For details on effective cash flow hedges included in Accumulated other comprehensive lncome on the balance sheetsand the reasons for changes in cash flow hedges, see Note 3.

FEFC FOR 23,5311


Year/Períod of Report

2015/O4


This Report is:{1) X An Original(2\ A Resubmission

Narne of Respondenl

Southwestem Eleckíc Power Company

Cash flow hedges included in Accumulated Other Comprehensive lncome on the balance sheets as of Ðecember 3 I , 20 t 5

and 2Ol4 were:

Impact of Cash Flow Hedges on the Balance SheetDecember 31, 2015

Interest Rateand Foreign

Currency Total

Hedging Assets (a)

Hedging Liabilities (a)AOCI Loss Net of TaxPortion Expected to be Reclassified to Net Income

Ðuring the NextTwelve Months

Hedging Assets (a)

Hedging Liabilities (a)

AOCI Loss Net of TaxPortion Expected to be Reclassified ro Net Income

During the NextTwelve Months

Impact of Cash Flow Hedges on the Balance SheetDecember 31, 2014

Commodity

$-

Comrnodity

s-

(in millions)$ -s

(e.l)

(1.7)

Interest Rateand Foreign

Currency

(e.l)

( 1.7)

Total(in millions)$ -$

(r l.l)

(2.0)

(l r"l)

(2.0)

(a) Hedging assets and hedging liabilities are included in Derivative Instrument Assets - Hedges and DerivativeInstrument Liabilities * Hedges on the balance sheets.

The actual âmounts reclassified from Accumulated Other Comprehensive Income to Net lncome can differ from the

estimate above due to market price changes. As of December 31, 2015, SIVEPCo is not hedging (with contracts subjectto the accounting guidance for "Derivatives and Hedging") any exposure to variability in future cash flows related toforecasled transactions.

FERC FORM 1 I '123.54

STATEMENTSTO FI


201s/Q4

Date of Fìeport(Mo, Da, Yr)

ttThis Repoft is:{1) X An Originat(2) _ A ResubmissíonCompany

e of RespondentNam

Soulhwestem Ëlectric Power

Credít Rísk

Management limits credit risk in marketing and trading activities by assessing the creditworthiness of potentialcounterpalties before entering into transactions with them and continuing to evaluate their creditworthiness on anongoing basis' Management uses Moody's, Standard and Poor's and eunent market-based qualitative and quantitativedata as well as financial statements to assess the financial health of counterparties on an ongoing basis.

When management uses standardized master agreements, these agreements may include collateral requirements. Thesemaster agreements facilitate the netting of cash flows associated with a singte counterparty. Cash, letters of credit andparentallaffiliate guarantees may be obtained as security from counterparties in order to mitigate credit risk. Thecollateral agreements require a counterparty to post cash or letters of credit in the event an expos$re exceeds theestablished threshold. The threshold represents an unsecured credit limit which may be supported by a parental/affiliateguaranty, as determined in accordance with AEP's credit policy. In addition, collateral agreernents allow for terminationand liquidation of all positions in the event of a failure or inability ro post collateral.

C ollate ral Trígg eríng Ev e nts

Under the tåriffs of the RTos and Independent System operators (ISos) and a limited number of derivative andnon-derivative contracts primarily related to competitive retail auction loads, SWEpCo is obligated to post an additionalamount of collateral if certain credit ratings decline below a specified rating threshold. The âmount of collateral requiredfluctuates based on market prices and total exposure. on an ongoing basis, AEp's risk managernent organization assessesthe appropriateness of these collateral triggering items in contracts. SWEpCo has not experienced a downgrade beÌow aspecified rating threshold that would require the posting of additional collateral. The following table represenrsSWEPCo's exposure if credit ratings were fo decline below a specified rating threshold as of December 31,2015 and2tt4:

Fair Yalue

of Contracts

with CreditDowngrade

Triggers

Amount of CollateralSWEPCo

Would llave Been Requiredto Pst for Ðerivative

Confrscfs as rvell as Non-Ðerivalíve Contracts Subjectto the S¡me Master Netting

Arrangement

¿tmount of CollateralSWEPCo

\{ould llaye Been Required toPost Attributable to

RTOs and ISOs

Amount ofCollsteral

Â,ttributable toOther

Contracfs(in millions)

December3l,20I5 $DcccmberSl,2014

$ $ $0.9

0.1

4.2

FERC FORM 123.55

NOTES TO FINANCIAL STATEMÉNTS (Continued)


20151Q4


This Fleport is:(1) X An Original(2) _ A Resubmission

Narne of Respondent

Southwestem Electric Power Companv

In addition, a majority of SWEPCo's non-exchange traded commodity conracts contain cross-default provisions that, iftriggered, would permit the counterpafiy to declare a default and require settlemenl of the outstanding payable. These

cross-default provisions could be triggered if there was :r non-performance event by Parent or the obligor under

outstanding debt or a third party obligation in excess of S50 million. On an ongoing basis, AEP's risk management

organization assesses the appropriateness of these cross-default provisions in the contracts. SWEPCo had no liabilitiesfor contracts with cross default provisions prior to contractual netting aßangements as of December 31, 2015 and 2014.

r0. FAr,R VALUB MEASUREMENTS

Faír Value Measurements of Long-term Ðsbt

The fair values of Long-term Debt are based on quoted market prices, without credit enhancements, for the same orsimilar issues and the cunent interest rates offered for instruments with similar maturities classified as Level 2measurement inputs" These instruments are not marked-to-market. The estimates presented are not necessarily indicativeof the amounts that could be realized in a current market exchange.

The book values and fair values of Long-term Debt for as of December 31, 2015 and 2014 are summarized in the

following table:

Ðecember 31,20t5 2tt4

Book Value Fair Value Book Value Fair Yalue

$ 2,205.5 $(in millions)

2,328.r $ 2,059.6 $ 2,309.1

FERC NO.1 1

NOTËS TO FINANCIAL STA

201sto.4

Year/Period of ReportDate of Hepod(Mo, Da, Yr)

This Report is:

{1) X An Original(2) _ A Flesubmission

Name of Respondent


Fair Value Measurements of Finøncial Assets and Líabílitíes

For a discussion of fair value accounting and the classification of assets and liabilities within the fair value hierarchy, seethe "Fair value Measurements of Assets and Liabilities" section of Note L

The following tables set forth, by level within the fair value hierarchy, SWEPCo's financial assers and liabilities thatwereaccountedforatfairvalueonarecrtrringbasisasofDecember3l,20l5and2014. Asrequiredbytheaccountingguidance for "Fair Value Measurements and Disclosures," financial assets and liabilities are classified in their entirerybased on the lowest level of input that is significant to the fair vah¡e measurement. Management's assessment of thesignificance of a particular input to the fair value measurement requires judgment and may affect the valuation of fairvalue assets and liabilities and their placement within the fair value hierarchy levels. There have not been any significantchanges in management's valuation techniques.

Assets and Liabilities lVfeasured at Fair Value on a Recurring BasisDecember 31, 2015

Level 1 Level 2 Level 3(in millions)

Other TotalAssets¡

Ðerivatiye Instrument ÄssetsRisk Management Commodify Contracts (a) (b)

Liabilities:

$

Derivative Instrument Liabilities

Risk Management Commodity Contracts (a) (b) $

Assets:

Deriva tive Instrument AssetsRisk Management Commodig Contracts (a) (b)

Liabilities:

Derivative Instrument Liabilities

$

$

$

$

$ 0.e $ (0.1) $ (0.s)

5.5$ 0.t$ (0.4)s 5.2

Assets and Liabilities Measured at Fair Yalue on a Recurring BasisDecember 31,2074

Level 1 Levsl? Level 3(in millions)

Other Total

$ 0.4 $ (0.4) $

$Risk Management Commodity Contracts (a) (b) S 0.7 $ 0.9 $ (0.s) $ r.l

(b)

Amounts in "Other" column primarily represent couûterparty netting of risk management and hedging contracts andassociated cash collateral under the accounting guidance for'Ðerivatives and Hedging."Substantially comprised of coal contracts.

(a)

FERC FORM NO.1 123.57

NOTES TO FINANCTAL STATEMENTS (Continued)


20151Q4

Date of Fìeport(Mo, Da, Yr)

This Report is:

{1) X An Original(2)

- A Fìesubmission

Name ol Respondent


There have been no transfers between Level I and Level 2 during the years ended December 31, 2015 and 2014"

The following tables set forth a reconciliation of changes in the fair value of net trading derivatives classified as Level 3

in the fair value hierarchy:

Year Ended December 31,2015Net Risk ilIanagement

Assets {Liabilities}(in millions)

Balance as of December 31, 2014Realized Gain (Loss) Included in Net Income (or Changes in Net Assets) (a) (b)Purchases. fssuances and Settlements (c)

Changes in Fair Value Allocated to Regulated Jurisdictions (d)

Balance as of December 31, 2015

Year Ended December 3I, 2014

s (0.s)q)

(8.7)0.8

s 0.8

Net Rìsk ManagementÀssets (Liabilities)

(in millions)Balance as of December 31, 2013Changes in F¿ir Yalue Allocated to Regulated Jurisdictions (d)

Balance as of December 3lrZAf4

$(0.5)

$ {0.s}

(a) lncluded in revenues ûn the statemenls of income.

(b) Represents the change in fair value between the beginning of the reporting period and the settlement of the ¡iskmanagefnent commodity contract.

(c) Represents the setttement of risk management commodity contracts for the reporting period.

(d) Relates to the net gains (losses) of those conFacts that are not reflected on the statements of income. These net gains

(losses) are recorded as regulatory assetyliabilities.

The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions as

of December 3l , 2015 and 2014:

Si gnificant Unobservable InputsDecember 31,2015

Fair ValueAssets Liabilitã

ValuationTechnique

SignifïcantUnobservable

Input (a)

Forward Price Range

Low , HiehlVeightedAverage

FTRs $

(in millions)

0.9 $Discounted

Cash Flow0.1Forward MarketPrice S (6.96)$ 8.43 $ 1.34

FEBC FORM NO.1 {ED.12.88} Page 123.58

ATEMENTSNOTËS TO

Year/Period o{ Report

201


A Fìesubmission

This Reporl is:(1) X An Original

Name of Respondent

Southwestern Electric

Significant Unobservable InputsDecernber 3l,2Al4

Fair ValueAssets Liabílities

(in millions)

0.4 $

ValuationTechnique

SignificantUnobseryable

Input (a)

Forward Price Ranse

Low HighWeightedAverage

0,9Discounted

Cash FlowForward Market

PriceFTRs $ s(14.63)$ 20.02 $ t.0l

(a) Represents market prices in dollars per M]Wh.

The following table provides sensitivity of fair value measurements to increases (decreases) in significant unobservableinputs related to Energy contracts and F fRs as of December 31, 2015 and 2014:

Sensitivity of Fair Value Measuremenfs

Significant Unobseryable Input PosÍtion Change in InputImpact on Fair Value

MeasurementForward Market PriceForward Markef Price

BuySelt

Increase (Ðecrease)Increase (Decrease)

Higher (Lower)Lower (Higher)

Years Ended December 31,2015 2814

11. INCOME TÂXES

Income Tax Expense

The details of income taxes as reported are as follows:

Charged (Credited) to Operating Expenses, Net;CurrentDeferreri

Defened Investment Tax Credits

Total

Charged (Credited) ro Nonoperating Income, Net:CurrentDeferred

TotalTotal Income Taxes

(in millions)

$ 47.A $39.6(1.4)

(t71.7)239.60.4)

85.2 66,5

(3.3)0.9

{2.7)0.4

{2.4) (2.3)

$ 82.8 $ 64,2

FERC FORM NO.1 1 123,59

NOTES TO FINANCIAL STATÊMENTS (Continuecl)


2015/Q4



Name of Respondenl


The following is a reconciliation of the difference between the amounts of federal income kxes computed by multiplyingbook income befo¡e income taxes by the federal statutory tax râte and the amount of income taxes reported:

Years Ended December 31,2015 2014

$

(in millÍons)192.4 $82.8

s 275.2 $ 204.6

140.464.2

Net IncomeIncome Tax Expense

Pretax Incsme

Income Taxes on Pretax Income at Statutory Rate (35olo)

Increase (Decrease) in Income Taxes Resulting liom the Follorving ltems:DepreciationDepletionInvestment Tax Credits, NetState and Local Income Taxes, NetAF'UÐCOther

Income Tax Expense

Defened Tax Assets

Defened Tax LiabilitiesNet Defened Tsx Liabilities

Property Related Temporary DifferencesAmounts Due from Customers for Future Federal Income TaxesDefened State Income TaxesRegulatory AssetsDefened Income Taxes on Other Comprehensive LossImpairment Lnss - Turk PlantNet Operating Loss CarryforwardAll Other, NetNet Deferred Tax Liabilities $ (1,371.9) $ ( r,315.4)

$ 96.3 $ 71.6

3.1(5.5)(1.4)4.8

(e.2¡(s.3)

2.9(4.1)(1.4)3.1

{4.2)(3.7)

$ 82.8 S 64,2

Effective Income Tax Rate 30.17a 3L.4Vo

Net Ðefered Tax Líability

The following table shows elements of the net deferred tâx liâbility and significant temporary differences:

December 31,20t5 2ß14

{in millions)185.r $

( I,557.0)

$ (1,371.9) $ (1,315,4),

$ 180.0(t,495.4)

$ (1,247.t) $(47.8)

(r32.3)(26,r)

5.û20.7t9.736.0

(1,208.4)(44.|t

(r24.r)( r9.4)

4.02t.L21.933.6

FERC FORM NO.1 D.1 123.60

STATEMENTSNOTES TO FI


201EtO4


tl

This Fìeport is:(1) X An Original(2)

- A Resubmission

Name of Respondent

CompanySouthwestem Eleclric Power

AEP System Tax ALlocatíon Agreement

SWEPCo joins in the filing of a consolidated federal income tax return. The allocation of the AEP System's cur¡entconsolidated federal income tax to the AEP System companies allocates the benefit of currenf tax losses to the AEpSystem companies giving rise to such losses in determining their cunent tax expense. The tax benefit of the parent isallocated to its subsidiaries with taxable income. TVith the exception of the loss of the Pa¡ent, the method of allocationreflects a separate return result for each company in the consolidated group.

Federal and Stute Income Tqx Audit Status

SWEPCo and other AEP subsidiaries are no longer subject to U.S. federal examinarion for years before 2011. The IRSexamination of years 2011,2012 and 2013 stârted in April 2014, Although rhe outcome of tax audits is uncerrain, inmanagement's opinion, adequate provisions for federal income taxes have been made for potential liabilities resultingfrom such matters. In addition, SV/EPCo accrues interest on these uncertain tax positions. Management is not aware ofany issues for open tâx years that upon final resolution are expected to materially impact net income.

SIVEPCo and other AEP subsidiaries file income tax retums in various state, local and foreign jurisdictions. Thesetaxing authorities routinely examine their tax rsturns. SS/EPCo and other AEP subsidiaries are currently underexamination in several state ând local jurisdictions. However, it is possible that previously filed tax retums havepositions that may be challenged by these tax authorities. Management believes that adequate provisions for incometaxes have been made for potential liabilities resulting from such challenges and that the ultimate resolution of theseaudits will not materially impact net income. SWEPCo is no longer subject to state or local income tax exarninations bytax authorities for years before 2009.

Net Íncome Tøx Operøting Loss Carryforwørd

In 2t12, SWEPCo recognized federal net income tax operating losses of $858 million which were driven primarily bybonus depreciation. SIVEPCo also has state net income tax operating loss carryforwards as of December 31, 2015 asindicated in rhe table below:

State

St&ie ì.{et incomeTax Operating

LossCarryforward

Year ofExpiration

l¡uisianaOklahoma

(in millions)375.7

3.2$ 2432

2035




201siQ4

Date of Beport(Mo, Da, Yr)

This Repoñ is:(1) X An Original(2\ A Resubmission

Name of Respondent


As a result, SWEPCo recognized defened federal, state and local income tax benefits in 20i l, and/or 2A12, andlor 2013,

and/or 2014 and/or 2015. Federal taxable income rvas sufficient enough in2014 that these remaining federal net income

tax operating loss tax benefits were realized in full. Management anticipates future taxable income will be sufficient torealize the remaining state net income tax operating loss tax benefits before the state carryforward expires for each state.

Tax Cr e dít C arryfo rw ar d

Federal net income tax operating losses sustained in 201I and 2009 along with lower federal taxable income in 2010

resulted in unused federal'and state income tax credits. As of December 31, 2015, SWEPCo had federal tax creditcarryforwards as indicated in the table below. If these credits are not utilized, federal general business tax credits willexpire in the years 2031 through2034.

Total FederalTax CredÍt

Carrvforward

Federal TaxCredit

CarryforwardSubject toExpiration

$

(in millions)0.7 s 0.6

SV/EPCo anticipates future federal taxable income will be sufficient to realize the tax benefits of the federal tax credits

before they expire unused.

A nc ertain Tax P o sitíon s

SWEPCo recognizes interest accruals related to uncertain tax positions in interest income or expense as applicable and

penalties in Penalties in accordance with the accounting guidance for "Income Taxes."

The follorving table shows amounts reported for interest expense and reversal of prior period interest expense:

Years Ended December 31,2015 zAM

Interest ExpenseReversal of Prior Period Interest Expense

(in millions)0.4 $$ 0.2

0.2

FEHC FORM NO.1 {EÐ. T2.88} Paq€ 123.62

NOTES TqFINANCtAL STATEMENTS (Continued)


2015/Q4


This Report is:{1) X An Original(2) _ A Flesubmission

Name of Respondent


The following table shows balances for amounts accrued for the payment of interest:

Ðecember 31.,

2015 zAM

Accrual for Payment of Intsrest and Pcnalties $(in millions)

t.4 $ 1.0

The reconciliation of the beginning and ending amounts ol unrecognized tax benefits are as follows:

20lS 2t1,1

$

(in millions)7.5 S

1.8

$ 9.3 $ 7.5

Balance as ofJanuary l,Increase - Tax Positions Taken During a Prior period

Decrease * Tax Positions Taken Ðuring a Prior period

Decre¡se - Lapse of the Appllcable Statute of LimitationsBalance as of December 31,

1.61,6

(0.8)(0.9)

Management believes that there will be no significant net increase or decrease in unrecognized benefits within l2 rnonthsof the reporling date. The total arnount of unrecognized tax benefits that, if recognized, would affect the effecrive tax ratewas $6 million and S5 million for 2015 and 2014, respectively.

Federat Tax Legíslation

The Tax Increase Prevention Act of 2014 (the 2014 Act) was enacted in Ðecember 2014. Ilcluded in the 2014 Act was aone-year exlension of the 507o bonus depreciation. The 2014 Act also retroactively extended the life of research anddevelopment, employment and several energy tax credits, which expirecl at the end of 2013. The enacted provisions didnot materially impact SWEPCo's net income or financial condition but did have a favorable impact on cash flows in2A15.

The Protecting Americans from Tax Hikes Act of 2015 (PATH) included an extension of rhe 507o bonus depreciation fortlrree years through 2017, phasing down to 407o in 2018 and 3QVo in 2019. PATH also provided for the extension ofresearch and development, employrnent and several energy tax credits for 2015. PATH also includes provisions toextend the wind energy production tax credit through 201ó with â three-year phase-out (2017-2Aß), and to extend the307o temporary solar investment tax credit for three years through 2Aß and with a lwo-year pha-se-out eA2A-zOZt^).PATH also provided for a permanent extension of the Research and Development tax credit. The enacted provisions didnot materially impact SWEPCo's net income or financial condition but will have a favorable impact on future cash f1ows.

FEEC FORM NO.1 D. 1 123.63

NOTES TO FINANCIAL STATEMENTS {Cont¡nued}

YearlPeriod of Fleport

2A15tQ4


This Report is:(1) X An Original{2) A Resubmission

Name of Respondent

Southwestem Eleckic Power Companv

12" LEASES

Leases of property, plant and equipment are for remaining periods up to l0 years and require påyments of related

property taxes, maintenance and operating costs. The majority of the leases have purchase or renewal options and will be

renewed or replaced by other leases.

Lease rentals for both operating and capital leases are generally charged to Operation Expenses and Maintenance

Expenses in accordance with rate-making treatment for regulated operations. The components of rental costs are as

follows:

Years Ended

December 31,

2015 20t4

$

(in millÍcns)6.6 $

4.6

1.6

$ 12.8 $ 11.0

The following table shows the property, plant and equipment under capital leases and related obligations recorded on the

balance sheets.

December 31,

20ls 20t4(in millisns)

Prcperty, Plant and Ëquipment Under Capital Leases

Net Lease Expense on Operating læases

Amortization of Capital Leases

Interest on Capital Leases

Total Lease Rental Costs

Production

Other Property, Plant and Equipment

Total Property, Plant and Equipment

Accumulated Amortization

Net Property, Plant and Equipment Under Capital Leases

Obligations Under Capítal Leases

Noncurrent

Cunent

Total Obligations Under Capital Leases

5.0

4.3

t.7

s 34.6 $I t.8

35.4

I 1.3

46.4

t6.2

46.7

t4.2

$ 30.2 $ 32.5

-28.2$ 25.8 $

4.4 4.3

$ 3û.2 $ 32.5

FERC FOHM NO.1 (ED. f 2-88) Page 123.64

NOTËS TO FINANCIAL STATE À/itrÀlTa (Continued)


2015/Q4


This Report is:(1) X An Oríginal(2) _ A Resubmission

Name of Respondent

Soulhwestern Eleclric Power Company

Future minimum lease payments consisted of the following as of December 3 I , 20 l5 :

CapitalLeases

Noncancelable

Operating

Leases

2016

20t7

2ûr 8

20t92020

I¿ter Years

Total Future Minimum Lease Payments

Less Estimated Interest Element

Estimated Present Value of Future &linimum Lease Payments

$

(in millions)5.8 $5.3

4.3

3.7

3.s

15.3

6.3

5.3

4.8

4.4

4.2

16.5

37.e $ 41.5

7.7

34.2$

Master Lease Agreements

SWEPCo leases certain equipment under master lease âgreements. Under the lease agreements, the lessor is guarantee<l aresidual value up to a stated percentage of either the unamortized balance or the equipment cost at the end of the leaseterm' If the âctuâl fair value of the leased equipment is below the guaranteed residual value at the end of the lease term,SWEPCo is committed þ pay the difference between the actual fair value and the residual value guarantee. Historically,at the end of the lease term the fair value has been in excess of the unamortized balance, As of December 3 I , 2015, themaximum potential loss by SWEPCo for these lease agreements assuming the fair value of the equipment is zero at theend of the lease term is $3 million.

Raílcar I*ase

In June 2003, AEP Transportation LLC (AEP Transpoñation), a subsidiary of AEP, entered into an agreement with BTMCapital Corporation, as lessoç to lease 875 coal-transporting aluminum railcars. The lease is accounted for as anoperâting lease. In January 2008, AEP Transportation assigned the remaining 848 railcars under the original leaseagreement to I&M (390 railcars) and SS/EPCo (458 railcars). The assignment is accounted for as an operatingl--.ô 'Fh- i-iri^l l-^^^ +^* ..,^^ t:.,^.,^^-^..,:rL ¿L-^^ ^^-^^-.-^:-,^ 1.-.-¡çqrv. rt¡! ¡¡r¡rrdr rLdrv LLllll w<¡ù tlYe Jc¿¡rt wltll UllçC {..:UllSCUULlVC llVg-yCA[fgllgw¡tl peflOOS IOf a mAX:mUm leAse tefÏn OI

twenty years. SWEPCo intends to renew the lease for the full lease term of twenty years via the renewaloptions. STVEPCo's future minimum lease obligation is Sll million for the remaining railcars as of December 31,2015. The obligation is included in the future minimum lease payments schedule earlier in this note.

FERC FORM 1 1 123.65

NOTES TO FINANCfAL STATEMENTS (Continued)


2015/O4


This Report is:(1) X An OriginalQ\ A Flesubmission

Name of Respondent


Under thç lease agteement, the lessor is guaranteed that the sale proceeds under a retum-and-sale option will equal at

least a lessee obligation amount specified in the lease, which declines ftom 83Vo of the projected fair value of the

equipment under the current five-year lease term to 77Vo at the end of the 2O-year term. SWEPCo assumed the guarantee

under the return-and-sale option. SWEPCo's maximum potential losses related to the guarantee is approximately $10

million, as of December 31, 2015, assuming the fair value of the equipment is zero at the end of the cuÍent five-year

lease term. However, management believes that the fair value would produce a sufficient sales price to avoid any loss.

13. FINANCING ÀCTIVITIËS

Long-tenn Debt

The following details long-term debt outstanding as of December 31, 2015 and 2014:

Type of Debl l{aturity

\{eightedAverageInterest

Rafe as ofDecember Jl,

2015

Interest Rate Ranges as ofDecember 31,

2015 2014

Outstanding as ofDecember 31,

2015 2014

Senior Unsecured Notes

Pollution Control Bonds (a)

Other Long-term Ðebt

Unamortized Discount, Net

Total Long,term Debt

2017-20l.52018-2019(b)

2Aú

3.55%-6.45%l.60%-4.95Eo

t.82Eo

3.55%-6.43c/o

3.25%-4.95Va

1.731a

{in millions)$ r,97s.0 $ 1,825.0

t3s.2 135.2

100.0 100.0(4.7) (t.6)

$ 2.205.5 $ 2.0J8.6

5.2850

3,62%

t.82%

(a) For certain series of pollution control bonds, interest rates are subject to periodic adjustment. Certain series may be purchased on

demand at periodic interest adjustme¡rt dates. Lctters of credit from banks and insurance policies support cenain series.

Long-term debt outstanding as of December 3 I , 2015 is payable as follows:

(in millions)20t62017201820t92420After 2O20

Principal AmountUnamoíized Discount. Net

Total Long-term Debt

$

r,025.0

350.0381.7453.5

2,2tA.2(4.7\

8 2,2A5.s

FERC FORM NO.1 {ED.12-88) Paqe 123.66



2015/Q4



Name of Respondent


Dív íde nd &,e stríctía n s

SWEPCo pays dividends to Parent provided funds are legally available. Various financing arangements and regulatoryrequireme¡lts may impose certain restrictions on the ability of SWEPCo to transfer funds to Parent in the form ofdividends.

SIVEPCo has credit agreements that contain a covenant that limits their debt to capitalization ratio t"o 67.SVa. As ofDecember 31,7015, $354 million of SWEPCo's retained enrnings had restrictions related to the payment of dividends toParent.

The Federal Power Act prohibits SWEPCo from participating "in the making or paying of any dividends of such publicutility from any funds properly included in ctpital account." As of December 3l , 2015, this restriction did not limit theability of SWEPCo to pay dividends out of rerained earnings.

Corporøte Eorcowing Pragram - AEP System

The AEP System uses a corporate borrowing program to meet the short-term borrowing needs of AEp'ssubsidiaries- The corporate borrowing program includes a Utility Money Pool, which funds AEP's utility subsidiaries.The AEP System Utility Money Pool operates in accordance with the terms and conditions of the AEp System UtilityMoney Pool agreement filed rvith the FERC. The amount of outstanding borrowings from the Utility Money pool as ofDecember 3l' 2015 is included in Notes Payable to Associated Companies on the balance sheet. The amount ofoutstanding loans to the Utility Money Pool as of December 3t,2014 is included in Notes Receivable from AssociatedCompanies on the balance sheet. SWEPCo's money pool activity and its corresponding authorized bonowing limits forthe years ended December 31, 2015 and zal4 are described in the following table:

Years EndedDecember 31.,

Maxi¡rumBorrowings

fromthe UtilityùIoney Pool

AverageBorrowings

from the UtilityIlIoney Pool

Loaru to(Borrowings Authorized

from) the Util¡ty Short-termMoney Pool as of Borrowing

December 31, Limit

MaximumLoans

to the UtilityMoney Pool

AverageLoans

to the UtilityLloney Pool

20152014

5 I r2.5 S

I53.5299.9 $5t.3

(inmillioru)48.! S

71.0!0_1.4 $24.4

r<e 1\ q

4t.01<rr n

350.0

FEBC FOFM NO.1 1 123.67

NOTES IO FINANCIAL SIATEMËNTS (Continued)


2015/Q4

Date of Flepod(Mo, Da, Y$

This Report is:(1) XAn OriginalQ\ A Resubmission

Name of Respondent

Southweslern Electric Power Companv

Maximum, minimum and average interest rates for funds either borrowed from or loaned to the Utility Money Pool were

as follows:

Years EndedDecember 3L,

Maximumlnterest Rates

for FundsBorrowed from

the Utilíty

Minimumlnterest Rates

for FundsBorrowed from

the UtilityMoney Pool

ùIaximumlnterest Rates

for FundsLoaned to theUtility Money

Pool

MinimumInferest Rates

for FundsLoaned to theUt¡l¡ty Money

Pool

Averagelnterest Rats

for FundsBorrorved from

the Utility

ÀverageInterest Rate

for FundsLoaned to theUtility Money

PoolPool Pool

20r52014

Q.87Vo

0.SOVo

4377o4.24c/o

t.59VoA.59Vo

0.4A7o

0.26Vo

O.537o

O.297o

4.48%8.324o

Interest expense related to short-term bonowing activities with the Utility Money Pool is included in Interest on Debt to

Associated Companies. SWEPCo incurred interest exp€nse for borrowings from the Utility Money Pool of $75 thousand

and $168 thousand for the years ended December 31, 20t5 and 2014, respectively.

Interest income related to short-term lending activities with the Utility Money Pool is included in Interest and DividendIncome on the statements of income. SWEPCo earned interest income for amounts advanced to the Utility Money Pool

of $351 thousand and $14 thousand for the years ended December 31, 2û15 and 2014, respectively.

Sale of Receivabtes - AEP Credit

Under this sale of receivables arrangement, SWEPCo sells, without recourse, certain of its customer accounts receivable

and accn¡ed unbilled revenue balances to AEP Credit and is charged a fee based on AEP Credit's financing costs,

administrative costs and SWEPCo's uncollectible accounts experience. SSIEPCo manages and services its customer

accounts receivable, which are sold to AËP Credit. AEP Credit securitizes the eligible receivables for SWEPCo and

retains the remainder.

AEP Credit's recçivables securitization agreement provides a commitment of $750 million from bank conduits topurchase receivables. The agreement was increased in June 2014 from $700 million and expires in June 2017.

The amount of accounts receivable and accrued unbilled revenues under the sale of receivables agreement as ofDecember 31,2015 and 2014 was $152 million and $149 million, respectively.

The fees paid to AEP Credit for customer accounts receivable sold were $7 million and $7 million for the years ended

December 3l,7AI5 and 2014, respectively.

SWEPCo's proceeds on the sale of receivables to AEP Credit were $1.6 billion and $1.7 billion for the years ended

December 31, 2015 and 2014, respectively.

FERC FORM NO.1 (ED.12-88) Page 123.68

(Conlinued)NOTES TO FINANCIAL


2015/Q4


lt

This Report is:

{1) X An Original(2) _ A Fìesubmission

Name of Respondent


14. RELATED PARTY TRANSACTIONS

For other related party transactions, also see "AEP System Tax Allocation Agreement" section of Note t I in addition to"Corporate Borrowing Program - AEP System" and "Sale of Receivables - AEP Credit" sections of Note 13.

I*terconnectio n Agreement

In accordance with manågement's Decenber 2010 announcement and October 2012 filing with the FERC, thelnterconnection Agreement was terminated effective January T,2Al4. The AEP System Interim Allowance Agreementwhich provided for, among other things, the transfer of SO2 emission allowances associated with transactions under the

Interconnection Agreement was also terminated"

AEPSC conducts power, capacity, coal, natural gas, interest rate and, to a lesser extent, heating oil, gasoline and otherrisk management activities on behalf of APCo, I&M, KpCo, pSO, S$/EpCo and WpCo. Effective January t, 2014 andrevised in May 2015, power and natural gas risk management activities for APCo, I&M, KPCo and rüpCo are allocatedbased on the four member companies' respective equity positions, while power and natural gas risk managementactivities for PSO and SWEPCo are allocated based on the Operating Agreement. Risk managernent activities primarilyinclude power and natural gas physical transactions, financially-settled swaps and exchange-traded futures. A.BpSCsettles the majority of the physical forward contracts by entering into offsetting contracts.

Operatíng Agreement

PSO, SWEPCo and AEPSC are parties to the Operating Agreement which was apptoved by the FERC. The OperatingAgreement requires PSO and SWEPCo to maintain adequate annual planning reserve margins and requires that capacityin excess of the required margins be made available for sale to other operating companies as capacity commitments. InJanuary 2014, the FERC approved a modification of the Operating Agreement to address changes resulting from ananticipated March 2014 SPP power market change. Subsequently and in March 2014, SPP changed from an energyimbalance service market to a fully integrated power market. In alignment with the new SPP integrated power marketand according to the modified Operating Agreement, PSO and SWEPCo operate as standalone enrities and offer theirrespective genera¡ion into the SPP power market. SPP then economically dispatches resources. By offering theirresources separately, PSO and STVEPCo no longer purchase or sell energy to each other to serve their respective internalload or off-system sales.

FERC FORM NO.1 t 123.69

NOTÉS TO FINANCIAL STATEMENTS {Conlinued}


2015/Q4


lt

This Report is:


- A Resubmission

Name of Respondent

Southweste¡n Ëleclric Power Company

Sy st e m I nte gration Agre e ment (S I A)

Under the SlA, AEPSC allocates physical and financial revenues and expenses from transactions with neighboring

utilities, power marketers and other power and natt¡ral gas risk management activities based upon the location of such

activity" Margins resulting from trading and marketing activities originating in PJM and MISO generally accn¡e to the

benefit of APCo, I&M, KPCo ¿nd '!YPCo, while trading and marketing activities originating in SPP generally accrue to

the benefit of PSO and SWEPCo. Margins resulting from other transactions are allocated among APCo, I&M, KPCo,

PSO, SWEPCo and IVPCo based upon the equity positions of these companies.

The SIA was designed to function as an umbrella agreement in addition to the Interconnection Agreement (prior toJanuary l,2Ol4) and the Operating Agreement, each of which controlled the distribution of revenues and expenses.

Affiíøted Revenues and Purchases

The following table shows the revenues derived from direct sales to affiliates, net transmission agreement sales and other

revenues for the years ended December 31, 2015 and 2014:

Related Party RevenuesYears Ended December 31,

2015 ?.8I4(in millions)

Direct Sales to East AffiliatesDirect Sales to ÏVest AfFlliatesDirect Sales ro AEPEPTransmission Agreement and Transmission

Coordination Agreement SalesOther Revenues

$

The following table shows the purchased power expenses incurred for purchases from affiliates for the years ended

December 3 l, 2015 and 2û14:

Related Part¡r PurchaeesYears Ended December 31,

2015 2014

Direct Purchases from West Affiliates $(in millions)

-$ 3.8

(0.2)

$ 10.00.3

15.2

1.6l4.l

1.8

FERC FORM NO,1 D. 123.70



2015/O4

Date of Re(Mo, Da,

poûYr)


Name of Respondent

Southwestern Eleckic Power Company

System Transmissíon Integratíon Agreement (STIA)

AEP's STIA provided for the integration and coordination of the planning,.operation and maintenance of transmissionfacilities. Since the FERC approved the cancellation of the STIA effective June l, 2014, the coordinated planning,operation and maintenance of transmission faeilities are the responsibility of the RTOs and the STIA is no longernecessary, Similar to the SIA, the STIA functioned as an umbrella agreement in addition to the Transmission Agreement(TA) and the Transmission Coordination Agreement (TCA). The TA andTCA are borh srill active. The STIA containedtwo service schedules that governed:

r The allocation of transmission eosts and revenues.e The allocation of third-party transmission costs and revenues and AEP System dispatch costs

APCo, i&M, KGPCo, KPCo, OPCo and WPCo are parties to the ?A., effective November 2010, which defines howtransmission costs through PJM OATT are allocated among the AEP East Companies, KGPCo and WPCo on a l2-monthÍìverage coincident peak basis.

PSO, SWEPCo and AEPSC are parties to the TCA, dated January l, 1997, by and among PSO, SIVEPCo and AEpSC, inconnection with the operalion of the transmission assets of the two AEP utitity subsidiaries. The TCA has been approvedby the FERC and establishes a coordinating committee, which is charged with overseeing the coordinated planning of thetransmission facilities of the parties to the agreement. This includes the performance of transmission planning studies,the interaction of such companies with independent system operators (ISO) and orher regiûnal bodies interested intransmission planning and compliance with the ierms of the OATT filed with the FERC and the rules of the FERCrelating to such a tariff.

Under the TCA, the parties to the agreement delegaæd to AEPSC the responsibility of monitoring the reliability of theirtransmission systems and ¿drninistering the OATT on their behalf. The allocations have been governed by theFERC-approved OATT for the SPP. SWEPCo's net revenues allocated among parties to the TCA pursuant to the SppOATT protocols were $15 million and $14 million for the years ended December 31, 2015 and2Al4, respectively. Thenet revenues were recorded in Operating Revenues.

f^^b aa^-t '71^-*:-^lvvv* vwa t 9t ,ta'ttu9

Cook Coal Terminal performs railcar maintenance services at cost for SWEPCo. AEGCo billed SSIEPCo $3 million and$3 million for the years ended December 31, 2015 and 2014, respectively, for railcar maintenance services. SWEpCorecorded the cost of the railcar maintenance services in Fuel Stock on the balance sheets.

FERC NO.1 EÐ 123.71

NOTES TO FINANCIAL STATEMENTS (Cont¡nued)

YeariPeriod of Report

2015/Q4


This Repoñ is:(1) X An Original(2) - A Resubmission

Name of Respondent


Central Machine Shop

APCo operates a facility which repairs and rebuilds specialized components for the generation plants across the AEP

System. SWEPCo recorded billings from APCo of $1 million and $72 thousand as capital or maintenance expenses

depending on the nâture of the services received for lhe years ended December 3 I , 20 15 and 2014, respectively. These

billings are recoverable from customers.

Affilíate Rai{ear Agre en ent

AGR, APCo, I&M, ?SO and S\trEPCo have an agreement providing for the use of each other's leased or owned railcars

when available. The agreement specifies that the company using the railcar will be billed, at cost, by the company

furnishing the railcar. SWEPCo recorded these costs or reimbursements as çosts or reduction of costs, respectively, in

Fuel Stock on the balance sheets and such costs are recoverable from customers. The following table shows the net effect

of the railcar agreement on the balance sheets:

Payment of Costs;

Reimbursement of Costs:

Years EndedDecember3l, rlPCo

-

201520r4

{inmillions)

-$ r.8$0.1 2.2

I&M PSO

0.60.2

$

:20152A14

1.2

t.l0.60.7

Ssles and Purchases of Property

SWEPCo had affiliated sales and purchases of electric property individually amounting to $100 thousand or more, sales

and purchases of meters and transformers, and sales and purchases of transmission property. There were no gains or

losses recorded on the transactions. The following table shows the sales and purchases, recorded in Utility Plant on the

balance sheets at net book value, for the years ended Ðecember 31, 2015 and 2014:

Years Ended December 31,2ü15 2At4

(in millions)0.8 $7.4

SalesPurch¿ses

$ 1.2

4.0

FERC FORM NO,1 (8D.12.88} Pase 123.72

NOTES TO FINANCIAL STATÊMENTS (Continued)


2015tO.4


This Report is:(1) X An Original(2) - A Resubmission

Name of Respondent


Intercampøny BílÍìngs

SWEPCo and other AEP subsidiaries perform certain utility services for each other when necessary or practical. Thecosts of these services are billed on a direct-charge basis, whenever possible, or on reasonable basis of proration fbrservices that benefit multiple companies. The billings for services are made at côst and include no compensation for the

use of equity capital.

AE?SC

AEPSC provides certain managerial and professional services to AEP's subsidiaries. The costs of the services are based

on a direct charge or on a prorated basis and billed to the AËP subsidiary companies af AEPSC's cost" AEPSC and itsbillings are subject to regulation by the FERC. SWEPCo's total billings from AEPSC were S141 million and $140million for the years ended December 3L,2015 and 2014, respectiyely.

15. PROPERTY. PLANT AND BOUIPMENT

Deprecíation

SV/EPCo provides for depreciation of Utility Plant on a straight-line basis over the estimated useful lives of property,generally using composite rates by functional class. The following table provides annual composite depreciation rates byfunctional class:

Year SteamOther

Generation Transmission Distribution General(in percentages)

2.32.2

20152tt4

2.2))

2.42.4

2.62.7

5.54.8

The composite depreciation rate generally includes a component for non-asset retirement obligation (non-ARO) remov¿lcosts, which is credited to accumulated depreciation. Actual removal costs incurred are ch*rged to accr¡mulated

depreciation.

A s set Retir e me nt Oblìgatío n s

SWEPCo records ARO in accordance with the accounting guidance for "Asset Retirement and EnvironmentalObligations" for legal obligations for asbestos removal and for the retirement of certain ash disposal facilities. SWEPCohas identified, but not recognized, ARO liabilities related to electric transmission and distribution assets as a result ofcertain easements on property on which assets are owned. Generally, such easements are perpetual and require only therctirement and removal qf assets upon the cessation of the property's use. The retirement obligation is not estimable forsuch easements since SIMEPCo plâns to use their facilities indefinitely. The retirement obligation would only berecognized if and when SWEPCo abandons or ceases the use of specific easements, which is not expected.


NOTES TO FINANCIAL STATEMENTS l0ontinued)


2015/Q4

Date of Repoû(Mo, Da, Yr)

lt

This Fleport is:(1) X An OriginalQ\ A Resubmission

Name of Respondent

Southwestern Ëleclric Power Company

SWEPCo recorded an increase in asset retirement obligations in the second quârter of 2015, primarily related to the final

Coal Combustion Residual Rule, which was published in the Federal Register in April 2015. The Federal EPA now

regulates the disposal and beneficial re-use of coal combustion residuals (CCR), including fly ash and bottom ash

generated at coaþfired electric generating units and also FGD gypsum generated at some coal-fired plants. The Federal

EPA regulates CCR as a non-hazardous solid waste and established minimum federal solid waste managemçnt standards.

Noncash increases related to the CCR Rule are recorded as Utility Plant. The following is a reconciliation of the 2015

and 2014 aggregate carrying amounts of ARO:

YearARO at

January 1,

¡lccretionExpense

LiabilitiesIncurred

LiabilitiesSettled

Revisions inCash FIowËstimates

ARO atDecember 31,

20152014

$ 46.6 $4 t.9

3.7 $3.1

(in millions)l7.l $ (s.0) $

(t.l)13.0 $2.7

75.446.6

J oí ntþ - ow n e d Et ec tríc F ac ílití e s

SSIEPCo has electric facilities that are jointly-owned with affiliated and non-affiliated companies. Using its ow¡financing, SrffEPCo is obligated to pay its share of the costs of these jointly-owned faeilities in the same proportion as its

ownership interest. SWEPCo's proportionate share of the operating costs associated with these facilities is included in its

statements of income and the investments and accumulated depreciation are reflected in its balance sheets under UtilityPlant as follows:

SIYEPCo's Share ¿s of December 31, 2û15

Facility

ConstructionWorkinProgress

(in millions)332.4 $ 3.9 $13r.4 195.0

572.t 5.9

I,ó49.0 5.5

$ 2,684,9 $ 210.3 $ 769,t

FuclType

LigniteCoal

Ligníte

Coal

Percent ofOwnersl¡ip

Utility Plantin Service

AccumulatedÐepreclalion

Dolet Hills Generating Station, Unit I (a)

Flint Creek tenerating Station, Unit t (b)

Pirkey Generating Station, Unit I (b)

T\¡rk Generating Plant (b)

Total

4t.2% 5

50,jvo85.9Vo

73.337o

205,970.0

389. r

t04. I

FËRC FORM NO.1 {EÐ.12.88} Pase 123,74

NOTES TO FINANCIAL STATEM


2015/Q4


This Fleport is:(1) X An Original{2\ A Fìesubmission

Name of Respondent


StrYEPCo's Share as of December 31. 2014

Fuel Percent ofOrynershiÞ

Utility PIantin Service

ConstructionWork inProgress

¡lccumulatedÐepreciationFacility Type

Dolet Hills Cenerating S¡ation, Unit I (a)

Flint Creek Cenerating Sration, Unit I (b)

Pirkey Cenerating Station, Unit I (b)

Tirrk Cenerating Plant (b)

Total

Lignite

Lignite

4O.2Vo S

5Q.0%

85.9%

13.33Va

Coal

Coal

(in millions)329.7 8 3.7 $t25.1 I 19.6

53 t. r 36,51.641.4 0.9

201.367.9

381. I69.8

$ 2,ó32.9 $ 1ó0.7 $ 720.1

(a) Operated by CLECO. a non-afl-iliated company.

(b) Operated by SWEPCo.

16. çosT REpucTIgN PROGRAM

2014 Díspositíon Plant Severance

Management retired several generation plants or units of plants during 2015. These plant closures resulted in involuntaryseveranc€s. The severance program provides two weeks of base pay for every year of service along with other severance

benefits.

SWEPCo's disposition plant severance âctivity for the year ended Ðecember 31, 2015 is described in the following table:

Balance as ofDecember 3lr20l4

Ëxpense

Allocation from

ÄEPSC Incurred Settled Ädjustments

Remaining

Balance as ofDecember 31,2015

$ 0.1 $ __$.(in millions)

-.$ 0.1 $ -$

SWEPCo recorded charges of $84 thousand to Operation Expenses in 2014 primarily related to employees at thedisposition plants. Management does not expect additional costs to be incurred related to this initiative.

FERC FORM NO. I D 123.75

THIS PÀGE INTENTIONALLY LEFT BLANK

( 2e2,43ã)

Balance of Account 219 at End oi CunentQuarlerl/ear

10

( 3,861,363)Total (lines 7 and 8)ó{ 2,903,58e)

Currenl Quarter^/ear to Ðale Changes in

Fair Value

I( s57,774'

Currenl QlrA/r to Date fìeclassifications

from Acct 219 to Net lncome

3,568,928

Bâ'ance ol Account 21 I at Beginning ofCurrenl Year

63,568,928

Balance of Account 219 at End otPrecedin g Quarter/Year

c( 1,224,2821Total (lines 2 and 3)4

( 286,412',)

Preceding Quarter¡/ear to Oate Changes in

Fair Value

a( e37,870)

Preceding Qtr¡yr to Ðate Reclassifioalions

from Acct 219 to Net lncome

2

4,793,210

Balance of Account 219 at Beginning ofPreceding Year

I

OlherAdjustments

(e)

Foreign GurencyHedges

(d)

Minímum PensionLiability adjuslment

(net amount)(c)

Unrealized Gains andLosses on Available,for-Sale Securities

{b)

llem

(a)

Line

No.

1' Reporl in columns (o),(c),(o) and (e) the amounls of accumulated other comprehensive income items, on a net-of-tax basis, wtrere appropriate"2. Reporl in columns {0 and (g) the amounts of other categories of other cash flow hedges.3. For each category of hedges that have been accounted for as 'fair value hedges', report the açcounts atfected and the related amounts in a footnote.4. Report data on a year-to.date basís.

YeailPeriod of ReportEnd of 2015/Q4

Date of Reoort(Mo, Da, Yi)Soulhwestern Electric Power Company

Original

t2) A Resubmission

FERC FOFM NO. 1 (NEW 06-02) Pags 122a

( e,331,734)( 9,03e,2e9)10

190,¿182,469192,34tt,t80( 1,863,711)1,997,652I8

1,039,8781,997,6527

( 7,468,023)( r 1,036,951)6

( 7,4ô8,023)( 11,006,e51)5

141,U7,&1140,369,257978,144( 64,556)2,266,9824

( 286,412)3

1,2æ,5s6( 64,55ô)2,266,9822

( 8,446,167)04,556( 13,303,933)'l

TotalComprehensive

lncome

(¡)

Net fncome (Carried

Foru¡ard fromPage 1'17, Une 78)

(D

Totals lor eachcategory of items

recorded ln

Accounl 219(h)

Other Cash FlowHedges

tSpecrtyl

(s)

Other Cash FlowHedges

lnlerest Rate Swaps

(0

L¡ne

Nô.

STATEMENTS OFACCUMULATËD COMFREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDQING ACTIVITIES

Year/Period ol fleportÉndof 2011Q4

Dale of Report(Mo, Da, Yi)ttSouthwestem Electric Power Company (2) Resubmlssion

FERC FORrr NO. r (NEW 0C42) Pags 122b

2,828,867,U1Total Accum Prov (equals 14) {æ.263A31,gZ,)3318,043,S76rÕ,urhJ,Y/bAmort ol Plant Acqu¡sition ,4d¡32

Abandonment ol Leases (Natural Gas)3fTotat Held lor Future Use (2S & 29)3û

Amort¡zation29

Depreciation28

Hefd for Future Use27

Total Leased to Others (24 & 25)26

Amorllzation and Deplet¡on2s

Pepreciation24

Leased to Othêrs232,810,823,86¡2,8t0,823,865Total ln Service (18 thru 21)22

23,364,30€23,364,306Amorl of Other Utility Plant21

Amort ol Underground Storage Land/tand Rights20

Amort & Depl ol Prodwing Nat Gas Landlt-and Right't92,787,459,55Í2,787,459,559Deprec¡alioñ18

ln Service:17

Detail of Accum Prov for Depr, Amort & Depl1ô5,832,376,5025,832,376,502Net Utility Flant (13less l4)152,828,867,A412,828,867,841Accum Frov for Depr, Amort, & Depl144,66't,244,3438,661,244,34{tTotalur¡lity Ptant (8 thru 12)13

't8,043,97€'18,048,976Acqulsit¡on Adlustrn ents12744,716,787744,716,Constnrtion Work in Progress11

'l,581,4801,581,480Held for Future Use10

Leased to OthersI7,896,902,1007,896,902,10CTotaÌ(3lhru 7)I

Éxperimental Plant Unolassilied7305,873,r25305,873,125Completed Constnrcllon not Classified6

Plant Purchased or Sold530,092,82530,0s2,625Prop€rly Under Cap¡tal Leâses4

7,560,93ô,A507,560,936,350Plant In Service (Classified)3

ln Service2

Utility Plantf

Ëlectric(c)

ïotal Company lor theCunent YearlQuarter Ended

(b)

Classificalíon

(a)No.

Beport in Column (c)

column (h) commonthe amount for eleclric funclion, in column (d) the amount for gas function, in column (e), (0, and (g) report other (spec¡fy) and in

funclion.

SUMMAFOF ÞEPRECIATION. AMORTIZATION ANÐ DEPLËTION

YearHenoc ot HeportEnd of 2015/Q4

uale of ñefþn(Mo, Da, Yi)tt

Original(2',t A flesubmission

Name or Hesponqent


FEBC FORM NO. 1 (E9.12{9} Pago 2(X,

33

32

3'l

30

29

28

27

2o

25

24

2A

22

21

20

19

t817

t615

14

13

12

11

't0

II7

6

5

4

3

2

1

UneNo.

Common

(h)

Olher ($pecify)

(s)

Olher (Specify)

(f)

Other (Specify)

(e)

Gas

{d}

SUMMARY OF UTILITY PLA¡ITAND ACCUMUTATED PROVISIONSFOH DEPRECIATION. AMORTIZATION ANÐ ÞEFLETION

YearlPer¡od ot ReportEnd of 2015/Q4

Date of Reoort(Mo, Da, Yi)tl

lsrOrigínal

(2) A Resubmission

Name of Flespondent

Soulhwestem Eleotric Power Company

FERC FOFM NO. 1 (ED, 12€9) Pags 20i

THIS PA.GE INTENTIONALLY LEFT BLANK

FOOTNOTE DATA


201VQ4


ttThis Report is:(1) XAn Original{ A Resubmission

Name of Respondent



11

97.975:49€4,071,734.504TOTAL Prod. Plant Iotal lines 45)46706.5581

TOTAL Olher Prod. Plq¡t (Enter Total of l¡nes 37 thru 44)45{347) Asset Flet¡rement Côstq for Other produclion44

690,767{348) Misa. Powér Plant Equipment4344ô,9778,549,516(845) Accessory Ëlectric Equipment42

12.1551(344) Generators41

(34i1) Primg Movers40

(342) Fuel Holders, lroducls, and Accessories3934.86't.303(941) Struclures and lmprovgments38

{3a0) þ¡d and Land Rights37D. Other Produclion Planl36

TOTAL HydIaul¡c Production ptant (Enter Total of tines 27 thru 94)35(337) Âsset Fetirement qqstqfor Hydraulic Production34

and3ri]

{335} Misc. Power Planl Equipment32

(334) Accessory Eleqlric Equlpment31

30

(332) Reservoirs. Dams, ând Waterways2S

(331) Stn¡ctures and lmprovemenls28

(330) Land and Land Rights27

C. Hydraulic Productíon Plant28TôTAL NWlqar Production plãnt (Ënter lotal of lines 18lhru 24)25t326) Asset Rêtírement Costs for Nucle€r ptoduction24

(325) Misc. Power Plan! Ëquipment23

(324) Accessory Electric Equipment2221

(32?) Reactor Plant Êquipmênt2A

(321) St4¡ctures and lmprovements{9(320) Land anC Land Rightst8

,.v.r¿,v t qB, Nuclear Production Plantl7

97TOTAL $team ProdrJct¡on Plant (Enter Total of l¡nes I thru 15)l631.046.217(317) Asset Retirement Costs for Steam Produclionl5

207.181.724147 T213.230,067(91 5) Accessory Eleçtric Êquipmentl3

1f682.279.933(314) Turbogenerator Units12

(313) Ëngines and Engine-Driven Generatorst12,'160.729.359{312) Boiler Plant Ëquipment10

3.181.31662T.040,895(311) qtryclures and lmprovements926,566.313,3f 0) Land and Land RighlsI

Production Planl7

2. PRODUCT]ON PLANT61

,lTOTAL lntangible Plant (Enter Total ol lines 2, 3, and 4)513,528.175Plant4

(302) Franchises and Qonsents312.202(301) Organization2

J.INTANGIB LANT1

BeginnAaco

(a)No.

f . Beport below the oríg¡nal cost of eleotric plant in service according lo lhe prescribed accounts.2. ln addition to Account 10i, E¡ectric plant in gervice {Classified), lhís page and the nen include Account t02, Ëlectric plant purchased or Sold;Account 103, Ëxperímental Electric plant Unclassif ied; and Account I 06, Completed Conslruction Not Classified-Electric.3. lnclude in column (c) or (d), as appropriate, correct¡ons of addit¡ons and retiremenls tor the curent or preceding year,4. For revisions lo the amount of initial assel relirement cosls capitalized, included by primary plant account, increases in cplumn (c) additions andreductions in column (e) adjustments.5. Ënclose in parentheses credit adlustrnents of plant actounts to índicate the negative etfect of such accounls,6. Classity Account 106 according lo prescribed accounls, on an estimated basis il necessary, and ínclude the entries in column (c), Also lo be includedin column (c) ârE entrie,s for reversals of tenìative distributions of pr¡or year reported in column (b). Likewise, lf lhe respondent has a signilicant amountof plant retirements which have not been classified to primary accounts at lhê end of the year, lnctude in column (d) a lenlat¡ve dÍsh¡bution of suchrelirements, on an estimated basis, wilh appropriate contra entry to the account for accumulated depreciation provisíon, lnclude also in column (d)

Year/Period ol ReportEnd of 201S/Q4


This Reoort lsr(f ) fiAn Original(2) ff A Resubm¡ss¡on

Name ol Respondent

Southwestem Electric Power Çompany

FERC FORM NO. 1 {REV.1245} Page 2M

48315.7976.û72.S3617.531 .4{t1

46130.094.481272,073u{ì912,821428.726.705269,7884184.118,713

4t)393834.884.3902,28537't.451.8523635u3,ÍÌ

3231

30

2928

2726

2E

242322

21

201918

'17

164.028.472.821315.79?6.072.93€17.259.358

't561.153.9¿16.072.93614209.9ô4,004I 83,1 79921,1S213219,217.,4õ41.202.17Q

'12687.5.t5.0336.204.70611

102.199.618.4158.610.965I624.034.504't32.618320,325I26.S69.48076

540.695,8213r,525.820440.683.61931.525.8203212,2021

No.

LineBalance atEnd ¡ffearlf)

Translers

{e)

Adjustments

(d)

Retiremenls

diskibutions of these lentative classifications in columns (c) and (dl, including the reversals of lhe prior years tentat¡ve account distribut¡ons of thessâmounls. Careful observance of the above instructions and the texls of Accounts 101 and 106 will avoid ser¡ous omissions of the reporled amount olrespondenl's planl actually ¡n sery¡ce at end ol year.7. Show in column (f) reclassif¡cations or transfers within rnilþ plant accounts. lnclude also in column {f} the addition$ or redrrctions of primary account

arising trorn dislribulkrn ol amounts initially recorded in Account 102, include in column (e) the amounts with respect lo accumulaledprovislon lor depreciallon, acquisition adlusûnents, elc., and show in column (f) only the offset to the debits or credíls d¡stributed in column (f) to prímary

9. For each amounl comprising the reported balance and changes in Accounl 1 02, state the property purchased or sofd, nâme of vendor or purchase,also datêol Acçeunts,

pages.to theseofthesuchclassification of reguiremenlplantconformingaamount statement showingsupplemirsubmsubslantíal inand ¡taccountin onlarythlsincludeduse ol plantthe nature and

the Uniformjoumal entries have been filed wilh the Commission asdate of transâstion. lf

account classifications.8. ForÂccount3gg, státô

and 1I'101ELECTRIC PL

Year/Period of FleportEnd of 201s/O4

Date of Reoort(Mo, Da, Yi)llÂ Rêsubmiss¡on(21

{1

Name of Respondent

Southwest€m Electric Power Company

FEBC FORM NO.1 (REV.12{5} Page A0S

303.315.6803347.642.744.ïQIAL Electric Plant in Serylce {Ent€r Total of tines 100 thru 100)104

(1 03) Expedmental Plant Unslassified103{LessJ (102) Ëlectric Plant Sold (See Instr. 8)'tc2

(102) EleclricPlant Purchased (See lnstr. 8)101903.315.6807.U2.744.834TOTAL (Accounts 101 and 106)100

131IOTA! qgneral Plant (Enter Total of l¡nes 96, 97 and 98)9f¡30.155883,803{a99.]!) ¡CCglE4irement Cosls lor General Plant98588.022.291(399) Other Tangible Prooertv97

229.621.882qqqIOTAL {Enler Toralof lines 86Ihru 95}9648.9152,582,560(398) Mlscellâneous Equipment95

1.806.84463.4dì8.608Communication9494,2272.195.699(396) Power Operated Equ¡pment93

5.375.105(395) Låboratory Equipment921.937.62121,794,778(394) Toofs, Shop and Garage Equ¡pment91

ö;¿.ötq¿-q I s-44l,1?Oâl (ln¡ac F¡r rinmaniÈìe.Pr.¡v..¡ôn4.118.518(392) Transporlatíon Equipment89

104,11411{99Ð Ofice Fumiture and Equipment882.404.69898,903,923390) Strqclqrgs qnd lmprovements87

29A.77417.468.611{389) Land and Land Rishts866. GENERAL PLANT85TOTAL Transmission and Market Operatíon Plant (Total lines 77 thru 83)84

(386) Asset Retirement Costs lor Regional Transmission and Market Oper83

(385) Miscellaneous Regíonal Tqnsmission and Market Operalion plant82

(384) Communicatlon Equipment81

(383) Computer Software80

(382) Computer l-lardwarE79

(381) St4rclqles and lmprovemenls78

(380) land and Land Rishts77

5. REGIONALTRANSMISSION OPERATION PI.ANT761 1 237TOTAL Distribution Plant (Ënter Total of lines 60 thru 74)75

(374) Asset Reliremenl Costs lor D¡slribution Plant741.093.00039,059.264L379) Str€e! Ughting and Signal Systems73

(372) Leased Property on Customer Premises72141.277.133on customer71

11,09.17291.375.456(370) Meters7078.598.866(369) Services69

15.077.f 73355,301.729(368) ljqe Transform ers688.707.509190,863,3281Q9?LU¡QqS{S!¡¡d Conductors and Oevices672.5U.26155.857.662(366) Underground Conduit66

I390.011.s&(365) Overhead Conductors and Devices651 1.682.672387.91 1.428(364) Foles, Towers, and Fixturesu €63) çto4Sg qaïery Equ¡pment6323.368.081(3ô2) Stalion Equípment62

5.232.074(3ô1) Structures and lmprovements6193.2918.787.908(360) Land and tand Rights60

4. DISTRIBUTION PLANT591,300,777,65'lTOTAL Transmission Plant (lqter Total of lines 48 thru 57)58

(359.1) Asset Ret¡rement C,osls for Transmiss¡on Plant57131 ,947(359) Roads and Trails56

255Devices553,700(357) Underground Conduit54

14.492.9S3295,351.953þ56) Overhead Conduclors and Þevices5338.136.220419.801.536(355) Poles and Fixlures52

139.924.204(354) ïowers and Finures5135.3dÌ1.70S460,485,538(353) Stalion Equipment50

5.83010,385.713{352) Structures and lmprovemenls491,836.25674.692.765(350) tand and l¿nd Riqhts48

3. TRANSMISSION PLANT47

Account

(a)

Lrne

No.


Ënd of 2015/Q4Soulhwestern Electric Power CompanyAn OriginalA Flesubmission

Dâ,(2) ll

FERC FORM NO. 1 {REV. 12.05) Pags 206

10458,8686.O72.93685.382.84dr

1û3

t2

101

16.072.Sm85.382.8æ99796,98698

9726.63098235.428.353"1æ.24770,35€95

944.351

9392

gl16.075908988-r89,17S530,23ta7210.1528610.5448584838281

8079

77707582,æ2,6777473426.2U72

41.9,+tl.O10985,129

7019,,180,31(

698t.91s.8072'16.87468366.37ô.5694.002.633

1,142.11758,¡l{11,07910,u4

652.896.039641.672.29663

62270,634.011i.688.4S5612.00601

59583.025.92S57

6613f,947552955453224,706145,4'052457.G35.'t17-2S.684872.9555'l478,736

-r26,0w'1,530,80849Æ7ô.529.û21

47

L¡neNô.

tsâlance:atËno ¡ffear

I fan$tgrc¡

tn

Adjustrnents

le'l

Retiremenls

(d)

Year/Period of ReportËndol 20151Q4

Date ol Beoort(Mo, Da, Yi)lt(2) Resubmission

Name of Respoodent


FEHC FOBM NO. t (REV. 12-05) Page 207

FOOTNOTE DATA

earlPeriod of Report

2015/Q4

ol Report(Mo, Ða, YQ

A Resubmission(1) X An Original

is:ThisName of Fìespondent

Soulhwestern Eleclric Power

Llne

Formula Rate uses 13 month average. Production demand and energy are identifiedby a query CIf plant accounting system.

204 Líne Column:

GSU {Generator Step'up) portion of totaltransmission accounts gS2 & 353 identifiedby a query of the plant accounling system. GSU's serve as a generation componentand are included in rate base for production plant.

Líne No,:50

GSU {Generator Step'up) portion of totaltransmission accounts gSA & 353 identifiedby a query of the plant accounling system. GSU's serve as a generation componentand are included in rate base for production plant.

2A4 Llne 58


75 Column:204 Líne

Formula Hate uses 13 month average

No.:86


204 Llne No.:87 Calumn:

Formula Flate uses 13 month average.

88 Column:


Lîne 89 Column:

Formula Rate uses'13 monlh average.

20i, Line No.:


Lîne No.: 9l

Formula Flate uses 13 month average,

204 No.:92

450.1FOFM NO.1

, FOOTNOTEDATA

Year/Feriod of Report

2016tQ4


tt

This Report is:(1) ! An Original{2} _ A Resubmission

Narne of Flespondent



204 Llne No.:


Llne No.:


244


204 Llne

Formula Rate uses l3 month average.

45A.2NO.

1,581 ,480Total47

46

45

44

43

42

41

N3S

38

37

a6

âÊ

34

.Ít

32

3'l

s0

29

28

27

26

25

24

23

22

Other Property:21

20

1S

18

17

16

15

14

13

12673,762Items under $250,000't1

10

IB

7

6

514,6752016311t14City Lake Substation (T 145)Ê

4393,0,1i,20245l1lO9Cardnell Foad 138KV Substation (1062)â

2

Land and Fighls:1

inUate Qnq¡nallv lnclucled

in îhis Aócount(b)

LinsNo.

1" Fleport separately each property held for luture usê at end ol lhe year having an original cost ot $250,000 or more. Group other items ot property heldfor future use.

2' For property having an original cost of $250,000 or more previously used ín utility operations, now held for luture use, give in column (a), iñ addition loother requ¡red informalion, the date that utility use ol such property $,ìas discontinued, and the date the original cost was transferred to Account 105.

Year/Perlod ot Report

Endof 2015/Q4

This(1)(2) A Resubmission

Dale(Mo,

tl

Name ot Respondenl


FERC FOFM NO.r (ËD.12-96) Page Z1q

THIS PAGE INTENTIONALLY LEFT BLANK

744,71A,787TOTAL4i¡

42

41

40

3930,570,7't4Other Minor Projects Under $1,000,0003fl

1,332,386$s-Cl-Sepco-D Gen Plt979,1ô3,709

FT.CI"SEPCoTX.T AS6ET IMP362,153,174Ed-Ci-Sèpco-O Ast lmp356,æ0,869ET.CI.SEPCeTASSET IMPu

16,078,890WS-CI-SEFCùG PPB33342,714,68AWSH U0 ACI / FF / Chimney32

r,9i3,294WSH Ll3 Turbine Major Capital3'!4,644,774Coal Yard Runoff Surgo ïanksa02,191,520SWEPCoTrans Pre Éng Parent291,263,775/SWEPCO-Ð0Shadow282,460,4t4T/SWEPOOÆransmission Work27

15,281,632T/SWËFCGT)íShadow2629,8¡7,A42T/SWEPCO/Transm ission Work25

1,154,048T/SWEPCO-TVShadow242,251,362T/SWEPCO/Transmission Work2g1,857,292T/SWEPCO-TVShadow223,227,062Work21

20,165,3092039,725,300T/SWEPCO¡r/allianþNW Texarkana1S

2,038,404D/SWDist¡ibution Station Repl18

3,985,402T/SWTransmission Station Repl17

I,989,08rÍ,SWEPCO Meter Converslon16

't,426,839Shreveporl Dlstrict Mtr Conv152,8¿15,13t1

PRK l-andfill141,105,7t6PFIK Area K Landlillf31,148,304High Avall Data ctr-sEP-Q12

1,383,927High Avail Data CIÍ-SEP-D11

2,579,744FLC Purchase Spare GSU't0't,250,552FLC Turbine Conlrols UpgradeI2,076,06SFC Landlill Leachate TreatmentI6,799,920Flint Creek FGD LåndFill7

182,844,949FC UJ DFGÞ w/ FFô

1,024,661SWEPCo Distr Fre Eng Parent5

T,395,724SEP/I-A. Rodessa Sub O-Station4

1,382,401Shreveport Bossier Land Pu¡ch3

1SWEPÇO CIHLc/Pirkey Land AÖq2

1

Descriplion of Project

(a)

Line

No.

1 . Report befow descriptions and balances at end of yeâr of projects in2. Show items relatíng to'reseatch, development, and demonstration.Aöclunt 107 ol lhe Uniform System of Accounls)

process ol construction (i07)projects last, under a captlon Resealch, Þevelopment, and Demonslrating (see

3. Minor proiects (5% of lhe Balancs End of the Year for Account I 07 or gl,Ooo,000, wtrlchever is less) may be groupecl,

Year/Period of ReportEnd of 2O15lQ4


This Reoort ls:(1) fiAn original(2) ¡A Resubmisslon

Name of Respondent

Southwestem Elei;tric Power Company

FEHC FORM NO.1 (ED. 12€? Page 21ô

TOOTNOTEDATA


2015/Q4

Date ol Report(Mo, Ða, YÐ

tl

This Beport is;(I) X An Original(2)

-A Resubmission

Name of Respondent


tPollution Control& Other Production CWIP identified by a query of the ptant

accounting systêm. (Formula Rates)

450,1I

2,787,459,5592,787,459,559TOTAL (tuter Total of lines 20 thru 28)2S

190,936,107190,996,107General2¿

Fìegional Transmlssion and Market Opention2l

690,329,575Distriþülon2e

ß1,n4,500Transmlssion2a

26,126,46525,126,ffiOther Prodtrctlon24

Hydraulic Production-Pumped Storage21,

Hydraulic Prod wtion-Conventkrnal¿¿

Nuclear Prodwtion21

1,419,292,9121,419,29Ì,912Sfeam Prcducüon2t

Sectlon B. Balanees at Ënd ol Year Âceordlng tô Fr¡netlonal Classlfleailon

2,787,459,5542,787,459,55SBalance Ënd of Year (Ënter Totals ol lines '1,

10, '15,'16, and 18)

1S

Book Cost or Asset Retirêmênt Gosts Het¡redl€

17

.539,874Other Debit or Cr. ltems (Describe, details in

footnote):

't€

64,&59,44€64,559,,145TOTAL Net Chrgs. for Planl Ret. (Enter Total

of lines '12 thru 14)

15

9,117,059SalvagE {Çredit)14

19,819,490Cost of Femoval13

53,857,02453,85J,024Book Costof Plant Retiredt¿

Net Charçs lor Plant Retlr€d:11

180,869,874180,863.874TOTAL Deprec. Prov lor Year (Enter Total ollines 3lhru 9)

10

o

1,045,53€OtherAccounts (Speci&, details in footnote)lIOther Clearing Accounts7

ïransportatlon Erpenses-Çlearing6

(413) Exp. of Eleo; Plt. Leas. to Olhersç

825,33C825,333(403.1) Deprecialion Expense for AssetRetirementCosts

4

178,993,00t178,993,0@(403) ûepreciathn Ëxpense3

Deprecialion Provislons for Year, Oharged toI

2,671,695,0042,671,695,004Balance Beglnnlng of Year1

SÊcllon lL Balances and Year

Nq.

1. Explain in a foolnole any imporlant adluslments dudng year.â. Explain in a footnote any difterence between tha amount for book cost of plant relired, Line 11, column (c), and that reported foreleclric plant in servÍce, pages 204-207, column gd), excludíng rotiremenls ol non-depreciable property.3. The provisions of Account 108 in thg Uniform Syslem ol accoqnts requirâ lhal relirements ol depreciable planl be recorded whensuch plant is removed from s€Mce. ll the respondent has a signilicant ämounl ol plant relired at year end which has nol been ¡ecordedand/or classified to the various reserve functional classificatÍons, make prelímínary closing entriê$ to tentatively lunclionalizs the bookcost of the plant relired. ln addition, include âllcosts included ín retiremenl work in progress at year end in the appropriate funclionalclassilicalions.4. Show separately interest credits under a sinking lund or similar method ol depreciatíon accounting.

Year/Period ol ReportËnd of 2015/Q41 Da,

(2) Flesubmlssion tlName of Bespofldent


FERC FORfvl NO.'l (REV.12-05) Pags 2lg

FOOTNOTÊ DATA


2015/Q4


lt

This Report is:(1) X An Original{2) _ A Resubmission

Name of Respondent


219 IVo.;expense c s to account

Sta11 RiderAmort,ize TX & FERC portions of ARO Ash Pond costs in

accoune L823O99Louisiana asbestos ARO depreciation expense classified

Eo accounE 1080013Louisiana ash pond ARO depreciation expense classified

Eo account 1823099

3 ,968,72]-l. of re¿ t

ARO Reserve account 1080013Reclassify investment. for Panhandle assegsReserve for Dolet Hi11s FAS 143 ARO, account L080012

c

58,818*5,093

ra9 ,227

230 ,142

1 04 538

n esg

18, 3 88-14, 833

s-539, 874

219 Lìne ,6 Column: cPRW

Schedule Page:219 Line No.: 14 Calu¡nn¡ cincludes $4,553,6L5 of removal cosE in retirement work in prosress (RWIPSchedule Page: 219 Llne No; '13 Column: c

219 Line No. 25 c


Accumulated Ðepreciation provision of GSU (Generator Step-up) relatedinvestment in accounts 352 and 353 identified by a query of the plant accountingsystem. (Formula Rates)

219 Llne No.:26 Column: c


FERC FORM NO.1 {ED. 12-87t Pase 450.1

2ô,17ô,006TOTALTotal Costof Accounl 123.1 $ I42

41

and Louisiana Order No. U€0975 September 30, 200g40

Arkansas Docket No. O9-055-U O¡der No. 4 December 22,2æ9,39

(3) Commíssion Aulhorizallon contained in the38

37

Order No. I, datêd July 6, 2001,36

Public Service Commísslon ¡n Docket No. 01,146-U35

(2) lnlerim t¡nanc¡ngaulharized by the Áßansasuü\t

Transactlon recorded in 199732

Release No. 35-2651 1 , dated April 26, 1 99631

{1) Aulhodzed by the SËC lri File No, 7&8763;

29

28

27

SUBTOTAL26

Equity in Undtstr¡buted Eamings25

lnveslement24NAou21t15Mutual Energy SWEPCO, LLC23

22f 4,532,293SUBTOTAL21

I,659,502Add¡t¡onal lnveslments (2015 Cash Infusion)2012,872,791lnvesfnentt9

NA1U2gl09Oxbow Lignite Company, LLC (3)18

l711,461,701SUBTOTAL1023,589,735Equity in Undistributed Earnings15

-20,215,155Ðivídends148,087,121lnvestnent13

NA06i/01/2001Dolet Hills Ugnite Cornpany (2)12

11

172,012SUBTOTAL10145,90047 "6Vo ol Equ¡ty ¡n Undistr¡þuted EamingsI-44,800Div¡dends/AdiustmentsI54,912NA07/3t/9678 shares,l997, $10O parvalue clmmon stock {1)716,000NA1AOg47common slock6

The Arklahoma Corporalion, 160 shares, g100 par value5

410,000SUBTOTAL310,000NAß12u28common stock2

SoulhwestArkånsae Utilities Corp. 100 shares, $100 par value1

AmÖunt ol lnvestmÊnt atBeoinnino of Year- (d)-

Dals otuaf¡yitv

Dâte Acquired(b)

Descriplion of lnièst¡r¡ffi(a)

No.

123."1


End of 2A1ilQ4Southwestern Electric Power Company {1)(21 A Resubmission

(Mo;tt

FERC FOFM NO.1 (ED. 12€9) ?age 224

4233,828,7033,866,217

41

Æ3S

38

37

36

35

34

33

32

31

30

29

28

27

26T,946,6032,899

262,8392,839

241,9¡13,764

23

22

2116,375,0r0

203,502,219

1912,872,791

18

17

l615,325,389s,863,688

1527,453,4233,863,688

14.20,215,155

138,087,121

'12

1T

10171,701-310

I145,589-310

I-44,800

754,912

ô16,000

5

4

310,000

210,000

1

LíneNo.ot

Arnounl ot lnvestment atEnd

flYear

Hevenues lor Year

(0

tsqurry rn ÐuosrqnryEaminqs¡f Year

4. For any securities, notes, or accounts that were pledged designate surh securit¡es, notes, or acçounts in a lootnote, and stat6 ths name of pledgeeand purpose of lhe pfedge.

5. ll Commission approval uas required for any advance made or secur¡ty acquired, designate srrch facl in a footnote and give name of Commission,date of authorlzatlon, and case or docket numbêr.6. Report column (f) interest and divkJend revenues form invesünents, including such revenuqs form secur¡tles dlsposed of during the year.7, ln column ft) report for each investment disposed of durlng the year, the gain or loss represented by lhe differençe between costof lhe investment (orthe other amount at wtrich canied in the books of account if diflerence lrom cost) and the selling price thereof, not including ¡nterest ad¡ustment includibleln column (f).

8. Report on Une 42, column {a) the TOTAL cost ôf Account 123.1


Ëndof 2015/Q4Southwestem Electric Power Company(1)(2)

OriginalA Resubmission tl

FERS FOFM NO.1 (89. 12€9) Page 225

Eleclr¡c173,137,00115T,702,408TOTAL Materials and Supplies (Per Balance Sheet)20

t9

18

17

Slores Fxpense Undistributed (Account 163)16

Nuclear Malerials Held tor Sale (Account 157) (Not

applic to Gas Util)

15

Other Materials and Supplies (Account 15ô)14

Merchandise (Account 155)13

73,666,499TOTAL Account 154 (Enter Tolal of lines 5 thru 1 1)12

Electric121,966Assigned to - Other (provide details in tootnote)t1

Regional Transm ission and Market Operation Plant(Estimated)

10

€lectric1,110,05'l95r,121Distribution Plant (Est¡mated)9

Elect¡ic304,802453,781Transmission Plant (Ëstimated)IEleclric39,970,67854,097,574Production Planl (Êstimated)7

Assigned to - Operations and Maintenance6

Êleclrlc29,886,718't8,042,057Assigned to - Construclion tEsl¡mated)5

Plant Materials and Operaling Supplies {Account'154)4

Flesiduals and Extracted Products (Account 1æ)3

Ëlectric2,830,9901,445,837Fuel Stock Ëxpenses Undistributed {Account 152)2

Efectric76,590,072Fuel Stock (Account 151)'I

Department orDepartments which

Use Materíal(d)

BalanceEnd of Year

(c)

BalanceBeginning of Year

(b)

Account

(a)

UneNo.

1. ForAccountlS4, report the amounl of plant materials and operating supplies under lhe primary functional classifications as indicated in column {a);estimates of amounls by lunction are acceptabfe, ln column (d), designate the department or deparlments which use the class of material.2. Give an explanalion of important ¡nvenlory adjustmenls during lhe year (in a footnote) showing general classes of material and supplies and thevarious accounts (operating expensès, clearing accounts, plant, etc.) affected <lebited or credited. Show separately debit or cred¡ts to stores expenseclearing, if appllcable.

MATEÊfALS AND SUPPLIES

Year/Pe¡iod ol Report

End of 2011Q4

Date of Reoort(Mo, Da, Ybtl

This Reoort ls:(l) E:lAn or¡sinal(2) ff A Resubmission

Name of Flespondent

Southwestern Électric Power Company

FEFC FORM NO.1 {FEV.12{5) Paga 227

FOOTNOTE DATA


2015/Q4

Name of Hespondenl

Southwestem Ëlectrio Power Comoanv

lThis Report is: I

l(1) X An Original Ill2\ A Resubmission I


tt

227 Llne No,: 1


227 t

This footnole applies to both current and prior year.

to OEher - Accounts, ri

Formula Rate uses 13 rnonth ãveraEe. Production materia¡s and supplies are identifiedby a query of thê general ledger $ystem.

esNo,:

I 1FERC FORM

Losses4611€Gains45't 1€Net Sales Proceeds (Other)44

Net Sales Proceeds (Assoc. Co,)43Sales:42

41t,161.0(SalancsEnd of Year40

1,16.l.0(Cost ot Sa¡es39Deducl Hetu¡ned by EPA38Add: Withheld by EPA37

1,tô1.0(ol Year36Allowances Wlthhsld (Acct 198.2)

Losses35222,32aGains342nß29l¡gSqþ9 Jroceeds (Other)33

Net $ales Proceeds(Assoc. Co.)32Sales:31

I30

289,2ß.00BalanceEnd ol Year29ô,600.0{Total2A

27

261,400.0(Omaha Fubl'rc Power Dlst255,000.0(Lumínant LLC24

200.0{Board of Publíc Utilitfes29¡(ansas City22Costof21

20Other:19

4ô,708.0(Charges lo Account 60918

tlelinquished Year;17

16

Totaf't514

13

12

11

10

sPurchases/Transfers:I

76

åelumed by EPA536,758.0(36J58.00l¡qgø (Less Withheld Allow)4

¡ggg'led Þuring Yeat32

305,793.00BalanceBeginning ol Year1

NO,(d)

No.(b)

SO2 Allowances lnvenlory(Account 158.1)

(a)

LineNo.

20',t6Current Year


ls:Original

(2) A Flesubmission II Endof 2O1lQ4

Alfowances (Accounts 158.f and 158.2)

1. Report below lhe parliculars (details) called for concerning allowances.2. Report all acquisitions of allowances at cost.3. Report allowances in accordancs wilh a weighted average cost allocatîon method and other accounlíng as prescribed by Generallnslruction No. 2'l in the Uniform System of Accounls.4. Report the allowances transactions by the period they âre first eligible for usê: the cu rrent yeals allowances in columns (b)-(c),allowances lor the rh ree succeeding yeafs tn columns {d)-(i), starting with the following year, and allowances for lhe remainlng

years tn columns {j)-(k)5, Report on line 4 the Environmenlal proteclion Agency (EPA) issued allowances. Rêport $rithheld portions Lines 86-40.

FERC FORi/r NO. I {ED.12-95} Fago 228r'

46

4514(t144r4(31

43

42

41

4060,159,0057;838.0(580.0{s00.00

3St:t42.0458t.0(38

37f,1ô1.0ût,161,0(

3€s7258.0(580.0(580.00

35

942æ,,â2t33,)t,32132

31

30

292,500¿98.001,964,304.0(72,752.ffi72,752.U286,600,00

27

26

2tf ,40q.00

245,000.00

23200.00

22

21

2Q

19

1846,708.00

17

16

15

14

'tg12

1f10

II7

6

5

437¿632.00287,590.0(8,263,008,263.00

3

2

111,676,714.0C64,489.0(64,48S.00

LineNo.Amt.

(m)Na,fl)

Amt.tkì

No.fiì

Amt.{il

No.(h)

Aml.{q}

No"(0

TotalsFulura Years20182017

6, Beport on LÍnes 5 allowances retumed by the EPA. , Report on Line 39 lhe EPA s sates ol the withheld allowances. Report on Lines43-46 the net sales proceeds and ga¡ndlosses resulting from the EPA's sale or auction of the withheld allowances.7, Report on Línes 8-14 the names of vendorsllransferors of allowances acquire and identify assocíated companies (See 'associatedcompany' under'Definitions' in the Uniform System of Accounts).8, Report on Línes 22 - 27 the name of purchaserd lranoferees of allowances disposed ol an idenlify assocíated companies.9, Report the net costs and benelits of hedging lransactions on a separate line under purchaseVtransfers and saledttansfers.10. Report on Lines 32-35 and 4346 lhe net sales proceeds and gains or losses from allowance sales.

Allowances (Accounts 158.1 and 158.2) (Continued)

Y€ar/Period of Report

Endof 2015/Q4(r(2', A Rêsubmíssion tt

Name of Respondent

Soulhwestem Eleclric Power Company

FERC FORM NO,1 {ED. 12-95} Page 229a

Losses46Gains¡+5

Net Sales Proceeds (Other)44Net Sales Proceeds (Assoo. Co.)€Sales:42

41

Balanc*End ol Year40Cost of Sales39Þeduct Retumed by EPA38

Add: Withheld by ÊPA37

BalanceBegínning of Y€ar36

Allor¡rances Withheld (Acct f 58.2)

Losses35

Gains34

Nel Sales Proceeds {Other}33N6t Sales Proceeds{Assoc. Co.)32

Sales:3t30

t5,847.tr16,600.0(BalanceEnd ol Yea¡29Total28

272625

242322

Cost of Sale9Transfers:21

12,005.00CAIR Program by EPA2A

O,lher:19

(),r44.00Charges to Account 50918

Relinquished During Year:17

16285.90C't,700.00Total15

14

't3't2

93,50C500.00Koch Supply & Trading Co.1135,40C200.00Fathom Energy LLC10

157,0m1,000.00Exelon ComIPurchases/Transfers;I

7è

Retumed by EPA515,847.0(42,693.0úlssued (Less Withheld Allow)4

Acquired During Year:32

24,356.mBalance-Beginning of Year't

Amt.(e)

NO.(d)

Amt.{o}

NO.(b)

NOx Allowances lnvenlory(Account 158..1)

(a)

LineNo.

20t6Current Year

1. Fìeport below the parliculars (delails) called lor concerning allowances.2. Report all acquisitions ol allowances al cost.3. Report allowances in accordance wilh a weighted average cost allocation melhod and other accounllng as prescfibed by Generallnstruction No. 21 in lhe Unifom System of Accounts.4' Fleport the allowances lransactions by lhe period they are lirst elígible for use: the current yea/s allowances in columns (b)-(c),allowances for the threa succeeding years in columns (d)-(i), starting with the following yêarr and allowances for the remainingsucceeding years in columns fi)-(k).5. Fleport on line 4 the Environmental Protection Agency (EpA) issued allowances. Report withheld porlions L¡nes 96-40.

Allowances (Accounts 158.1 and 158.2)


End of 2O15/Q4

Dale of Reoort(Mo, Da, Yi)tt

This Reoorl ls:(1) [lAn orisinal(2) flA Eesubmission

Name of Respondent


FERC FORM t{O. 1 {ED.12-9s} Page 228b

46

4644

43

42

41

40

3S

38

97

36

35

u33

32

3ta0

2921,95(32,447.æ

28

27

26

25

24

23

22

21

2012,005.00

19

18263,95(40,1¡14.00

17

16

152&5.90('r,700,0014

't312

1193,50(500.00

1035,40(200.00

I157,00(1,000.00

I7

6

5

458,540.{X)

3

2

1

LíneNo.Amt.

(m)No.{r)

Amt.kl

No,0l

Amt.til

No.(h)

Ami.(q)

NO,(f)

TotalsFuture Years20182017

6, Report on Lines 5 allowances relurned by the EPA. Report on Line 39 the EPA's sales of the withheld allowances. Report on Lines43-46 the nel sales proceeds and gainMosses resulting frorn the EPA's sale or auclion of the withheld allowances.7. Report on Lines 8-14 the names ol vendor$transferors of allowances acquire and identify associaled companies (See 'associatedcompany' under'Definitions'in lhe Uniform System of Accounts).8. Report on Lines 22 - 27 the name of purchasersl lransforeês of allowances disposed of an identify associated companies.9. Report lhe net costs and benefils of hedging lransactions on a sêpaËte lina under purchases/translers and salesy'transfers.10. Report on Lines 32-35 and 43-46lhe net sales proceeds and gains or losses from allowance sales.

Allowances (Accounts 158.'l and 158.2) (Continued)

Year/Per¡od of Report

End of 2O15lQ'4

Date ot Reoort(Mo, Da, Yi)¡t

An(2) A Besubmission

Name of Respondenl


FEFC FORM NO.1 (ED. 12.95) Pago 229þ

43

1823't,$0,020PUCT Ood(et N6. 37'162 and 3861442

Defened Fud Reænc¡lhfm Cð6Erp€nse -41

40{ 360,876)beg¡nning h November 20'1039

No.37i"/2. perif - 3 yean38

Docket ¡lo. 373&f afd åpproved in PUCT Docket37

ollerecqvery of rate case expgÞ$ rehted lo PUCT36

35

8,756,91 1219 1228310,830,463s6,598,930Belleût P€rsion aDd Oher Pæüelirerîent Plans34

1ær190SLn9 !q L5! : empbyen'Áccounting fu Deñned33

322,¿4t,CJU't7,9324031/{1 i IÂa^ llarI â00 tonAset Retire*nent oblþation - Ash Ponds - SrAS 14331

302,902,34123,?70,48344t -44412,18297614¡489,84€Deferal of Flpl Urdenecsrery - Te€g29

281 7s78,213,7015577,489,5651,755,899Defema I of FuelUrdenecovery - Loui$ana27

26

15,792,23544 -4444,557,7'1311,234,522Defenal of Fuel Undeæcovery - Artansas25

24

6,548,027Varior¡s10,88ô,4951,144,367Unrealized GainÂoss on forward Commitnænb23

22

231,7154073231,71âAmortizatin 5 yæns b€ginnim Odober 201021

EnhancemenB (NRECA) IPSC Doc*etNo. U-3135J20

Nali'onal Rural Ëlecüt tooDeßltve Association19

VEMCO - 0efened Relired Ernployee -18

17

r96,7424073r96,742Amdizalim 5 yean beginning 0dober20l016

lnvestnenb - LPSC Doc*et No. U.3135115

VEMCO - DeferredAssetAcqubitbn and Other14

1342S,416198,192593627,600IPSG 0o*et No. U-3135112

VÊMCO - 0efened Due Dilþencakæmo11

f01,327,3424073 I 9231,327,342February 20'llI

Anortization Peù¡d 5 year, beginningIAcqubition IPSC 0ocket No. U-313517

Valfey Êlecfic Membenhip Corpontion (VËMCO)6

54,799,788533,3109m5,333,090SFAS 106 Medlcare Subidy4

3

6,'179,69228312,654,324128,800,883SFAS 109 Defened lnærBTu2

141,950,08216,118,867282128325,389,692132,679,257SFAS 109 Oefered Fede€l lncom€ Tar1

Balancê at end olCunent Quarterffear

(f)

Wdtten off Duriry

the Period Amount

(e)

Writteû ofi During thg

Quarler /Yêar Account

charsed (d)

D€bits

(c)

Balancê at Beginning

of Cunenl

Qualerffær

(b)

Descriplion and Purpose ofOther Regulatory Assets

(â)

Line

No.CREDIT$

1. Reporl below the particulars (detai2. Minor items (5olo of the Balance inby classes,

ls) called for concerning olher regulatory âs$ets, including rate order docket number, if applicable.Account 182.3atendof period, orâmounts lessthan $100,000which everis less), maybe grouped

3. For Regulatory Assets being amorlized, show period of amortization.

Year/Period öf ReportEnd of 2015/Q4Southwestern Êlec'tric Power Company

(1)(2') Resubmission

Date(Mo,

tt

FERC FORltl NO. ll3.Q {REl/.02-0¡l} Page 232

43

42

9,292,5172349,292,517Levelized Fuel Cost41

Ðefered fupense Sellirg Price Varianæ40

39

3,509,2321,619,64ô5065,128,878beqinnino in March 201338

LPSC Dætet No. U-32220 Amortiætion 5 yeârs37

Oefened 2010 Severanæ Cæb Recovery per36

35

3,066,293779,3002,286,993SPP lransmbsion Proiect Exænse34

Delened Shiæ Road- K¡nq Rivef33

32

2.522,486s932,s22,486beginniru January 20'1531

Ooclet No. U-32220 Arnortizatix ot 1 year30

Louisiana Vegetatirn Managemenl ær LPSC2S

28

1 17,7ô01 17,760Excess Refunds27

Louisiana 2009 Formula Rate Phn26

25

748,64't139,284506887,925begínning in March 201324

LPSC Docket No. U-32220 Arnorlíætion S yeârs23

Costs for Carbon Capture Stor"aqe pe¡22

Defened Font Ënd Engineering and Dæhn Study21

2A

1,030,2653,410,628907 & 9082,265.0882,175,805Ëxpenses19

440 - 444Undenecowry of Ênergy Efficiency Prooram18

17

6,841,4231,258,'t04928,::s¡-:i:;ït;099,522startiru ìn Auqust 2015.'t6

and 37162. Recovery throwh a nte rider15

Nos. 42370, 40443, 39708, 386'14, 3777214

rate case upensæ relating to PUCT Docket13

Final Orderon FUCT ÐæketN0. 42370 lo recover12

11

297,814,,i,::ii,, ä,:;.tæ;o-æ1823322,129111,371for collection relald to PUÇT Dæket No. 4237010

Rale case expenses Dend¡nq future PUCT aoorovalIö

3,713,:i*¡'*li::7: -6ô;0JI18234,5557,365,195Docket No. 40443.7

PUCT approval for colleclion relaled lo PUCT6

represents rate case expenses p€ndinq luturB5

(PUCI Dodet No. 40443), 2015 year-end balanc¿4

Nos. 3/364 and 39708), and 2012 Base Rale Caæ3

'Turk Porer PlantCWlp'c¿se (PUCT Docket2

Rate case expense$ relatir8 lo SWEPCo Texas 20111

Balance at end of

Cunent QuarlerlYear

(0

Written off Durirg

he PerkÍ Amount

(e)

ftitten oñ Dr,ring ths

0ûartelYear Accoont

çharged (d)

0ebits

(c)

Bâlance at Beg¡nnifE

olCunent

Qua¡lerYear

(b)

Description and Purpose ofOlher Regulatory Assets

(a)

Line

No.

ÇREDITS

1. Report below the parliculars (details) called for concerning olher regulatory assels, including rate order docket number, if applicable.2. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be groupedby classes.3. For Regulatory Assets being amortized, show period of amortization.

OTHFR REGULATORY ASSËTS (Account 182.3)

Year/Period of ReportEnd of 2015/Q4

Ðate of Report(Mo, Da, Yr)II

of ls:Original

Southwestern Electric Power Compâny(1)(2) Resubmission

FERC FORM NO. 1/3-Q {REV. 02-04} Page 232,1

408,9r9,85ô114,900,442106,387,704417,432,594TOTAL:u43

42

41

40

39

38

37

36

35

34

33

32

31

30

2S

28

27

26

28

24

23

22

21

20

ls18

17

16

15

14

f312

11

10

II7

6

201,844270,939431 I 509405,25567,528Clause - Lor.lisianaR

Undenecqvered Ênv¡ronrnefl tãl Adjustrent4

3

31 1.16531 1,1ô5peroocketNo. 14{80.U2

Defene.d futansas Envionmental Chemical Cæb1

Eahnce at end ofCunent Quarlerffear

(f)

Wr¡tten off During

the Pedod Arnount

(e)

wfittsi oñùulìg lhg

O¡adE ¡Ye¿r Acøunt

clìaged (d)

Debits

{c}

Balancs at B€ginning

of Cunenl

Quarterlfær

(b)

Description and Purpose ofOther Regulatory Assets

{a)

LineNo.

CREDIT$

1. Report below the particulars (details) called2, Minor items (5% of the Balance in Accountby classes.

for conceming olher regulatory assels, including rate order docket number, if applicable.182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped

3. For Regulatory Assets being amortized, show period of amortization.


Date of Report(Mo, Da, Yr)lt

This Reoort ls:(1) E]An orisinãl(2') llA Resubmission

Name of Rêspondent

$outhwestêrn Êlectric Power Company

FERC FORM NO.lr3-Q {REì/.02.04' Page 232,2

FOOTNOTË DATA


20r5/Q4


This Report is:(1) X An OriginalQ) A Resubmission

Name of Respondent


'atumn: c

Overrecovery of rate case expenses related to PUCT Docket No, 37364 and approvedin PUCT Docket No.37772 is now included on Page 232.1, in FinalOrder on PUCÏDocket No. 42370. Approved for recovery through a rate rider starting in August 2015

232 Line No.:42 e

Deferred Fuel Reconciliation Case Expense, PUCT Docket Nos. 37162 and 38614,is now included on Page 232.1, in Final Order on PUCT Docket No. 42370. Approved

for recovery through a rate rider starting in August 2015.

â232"1 Line No.:7

Rate case expenses relating to SWEPCo Texas 2011 Turk Power Plant CWIP caseand 2A12 Base Rate case are now included on this same page below, in Final Orderon PUCT Ðocket No. 42370. Approved for recovery through a rate rider startingin August 2015.

232.1 Llne 0 Column: e

These rate case expenses related to PUCT Docket No.42370 are now included on thissarne page below, in Final Order on PUCT Docket No.42370. Approved forrecovery through a rate rider starting in August 2015.

232.1 Llne No.:16 G

lncludes the rate case expenses detailed above on Page 232 and 232.1, which wereapproved for recovery in PUCT Docket No.42370. Recovery through a rate ríderstarting in August 2015.

FERC FORM NO.1 {EÐ. 12.871 Pase 450.'f

33,836,83'133,493,396TOTAL49

uetered Heguhtory (þmm.Expenses (See paqes 350 . 35,l )

48

Misc. Work in Progress47

464544

4il42

41

4ö39

.3826.61616.172Various42.7AAMÍnor ltems < S100,00037

36434,623181/,13126,749,&7,874through July 2017âÊ

Fees - Amortization pÊr¡oduUnamortí¿ed Local Credit Line\,\'

3211,042,87Ê'13.340.576Dolet Hills Beclamat¡on Advance3f

309,600763,681Various9.60C7â3,681Defened Leased Assets29

2890,s32ß.787151134.31Sproduct¡on27

starts based on un¡ts of26Amort¡zat¡on begins when mininc25

Marshall South Mine Preparalion2423

72,9484Ê72,WDefened Hate Case Expense22

21713,2221,900565556,014't59,108Missouri20

Undenecovery of Transsource19

Defened Expense -1B

17437.928Various353,409r 64,386Ðisposition of Fuel16

Deferred Expenses -15

141 a207.63215132314,572,226starts based on tons mined13

Amorlizalion begins when mining12

Sabine Mine Rusk Preparationl110

593.824259.S1443'l127.954725,784July 2018IAmortization period throuohIUnamortized Credit Une Fees7

6'10.602.482Various10.931.324136.386Billings and Ðelerred FroieclsÃ

¡s!g!!q!ed Business Devetopm ent4

330.183.98426530.246.8052,973,368Receivable2

14U'tUAgency Fees - Factored AccounlsI

Balance atEnd of Year

(f)Amount

(e)

Debits

(o)

Balance atBeginning of Year

(b)

Descriptìon ol MiscellaneousDeferred Debits

(a)

No.ÇRËDITS

'l . Report below the parliculars (details) called for concerning miscellaneous deferred debits.2, For any deferred debit being amortized, show period of amortization in column (a)3' Mínor item (1 % of the Balance at End of Year for Account 1 86 or amounts less than S 100,000, whichever is less) may be grouped byclasses.

YearlPeriod of ReportEnd of 2015/Q4


e

Southweslern Electric Power Com pany(1)(2) A Besubmission

FERC FOFM NO. 1 (ED. 12-94) PagE 233

<Page 234. Line 17, Colu¡nr¡s B & C

Beginninçtof Year End of Year

Chârit.able contribution Carryfonrard - 190.2 s r,o37,a62

5!,L06,21,9

lL,92r,"130',

5,942,914

5 126,087

52.45O,882

t37 ,465

4, 867, 314

SFAS 109 - Rêgulaeory Assetss - 190.3 & 190,4Àccumulated Ðeferred Income Taxes

- Federal - Pension - ocÏÀccumuLated Deferred lncone Taxes

- Federal - Hedging - fnt Rate

Total Line 17 ç56,t64,525 $57, 601, ?49

Notes

180,042,979TOïAL (Acct 190) ftotal of lines 8, 16 and 17)1€

57,601,74tt56,1 64,525Other {Sæcify)1't

TOTAL Gas (Enter Total of lines 101hru 151€

Other1€

14

'ta

t¿

11

1(

Gasc127,491,877r23,878,454TOTÁL Êlectric (Enter Total of l¡n€s 2 thru 7)É

24,122,42719,353,31 1OtherI

13,085,89320,361,902Reg Liab - Mirror AFUDC. l4t19,473,36819,847,856D¡sallowed Costs . Turk Plantr14,182,82114,290,684Accrued Mine Reclamation¿

30,249,79933,730,392NOL Delerred TaxAsset3

26,377,ã79't6,294,309Accrued Book AËlO Expense SFAS 143¿

Electric1

ÞaÞnce, ?1

Þegtntng

tb)

uescfipt¡on ancl Location

(a)

LtneNo.

1. Report lhe inlormation called for below concerning lhe rsspöndent's åccount¡ng lor deferred income taxes.2. At Olher ($pecily), include deferrals relating to olher income and deductions.

Year/Period of HeportEnd of 2015/Q4Soulhwestern Electríc Power Company

An Oa,(2t A Resubmission tt

FERC FORM NO. 1 (ED.12{8} Page 234

\TA

âo'lIDê,,

lç:

Pow€r

Formula Rate üses 13 month âv6râSêi,

4S0.1¡,1O.

l

l

1'

42

41

4A

39

38

37

36

35

34

33

32

31

30

29

28

27

26

25

24

23

22

21

20

19

18

17

16

15

14

13

12

11

10

9

I?

Prefened Stock (Account 204). None6

5

4

7,600,000TOTALCOMMON STOCK3

2

18.007,600,000Common Slock (Account 201)1

Call Price atEnd of Year

(d)

Par or StatedValue per share

(q)

Number of sharesAdhorized by Charter

(b)

Class and Series of Stock andName ol Stock Series

(a)

LineNo.

1. Report below lhe particulars (details) called for concerning common and preferred stock at end of year, distinguishing separatesêries of any general class. Show separate lolals for common and prelerred stock. lf informalion to meet the stock exchanl¡e reportingrequirêment outlined in column (a) is available from the SEC 10"K Report Form liling, a specific reference to reportform (i.e., year and-company title) may bê reporled in column (a) provided the fiscal yearé for both the ió-f report and this report are compai¡ble.2. Entries in column (b) should reptesênt the number of shares authorized by the articles of fncorporation as amended to end ol year.

YearlPeriod of ReportEndof 2015/Q4

(z',) ÊEsubmission ltName of Respondent


FEHC FQRM NO.1 (ED. 12-91) Page 2S0

42

41

40

39

38

37

36

35

34

33

32

3'l

s0

29

28

27

2ô

25

24

23

22

2',1

2Q

't918

17

16

15

14

13

12

11

10

9

I7

6

5

4

3135,659,5207,536,6€2

I135,659,5207,536,ô40

LineNo.

Amountú)

änaros{q)

Amountt0

È'nafas(e)

IN SINKING AND OTHER FUNDSAS REACQUIREÐ STOCK (Account 217)

OUTSTANÐING PER BAIJNCE SHEET(Total amount outstanding withoul reduction

for amounts held by respondent)

HELO BY RESPÕNDENT

3. Give parliculars (details) concernlng shares of any class and series of stock aulhorized to be issued by a regulatory commissionwhich have not yet been issued.4. The identification of each cfass of preferred slock should show lhe dividend rate and whellrer the dividends are cumulalive ornoncumulative5. State in a lootnote if any capital stock which has been nominally issued is nominally outstanding at end of year.Give particulars (details) in column (a) of any nominally issued capital slock, reacquired stock, or slock in sinking and olher lunds whichis pledged, stallng name of pledgee and purposes of pledge.

Year/Pêríod of Report

End of 2015/Q4Dat€ of Beool(Mo, Da, Yi)ttSouthwestem Efectric Poier Company

(2) A Resubmission

FERC FORM NO. 1 (ED.12-SS) Page 251

ô76,550,701TOTAL40

39

38

37

36

35

34

33

32

31

30

29

28

27

26

25

24

23

22

21

20

19

18

674,443,764Subtotal - Account 21 I17

T6

674,443,7UCapital Contribution from Parentf5

Miscellaneous Paid in Capital ( Aocount 211)l413

2,106,937Subtotal- Account2l012

11

6ôf ,4704.2870 Sedes 201010

473,O214^65% Series 2010s

972,4465.007o Series 2010I7

Reacquired Capital Stock (Account 210)6

Gaín on Resale or Cancellation of5

4

Reduclion in Par or Stated Vatue of Capital Stock (Account 209) - None3

2

Donalions Beceived from Stockùolders (Account 208) - NoneI

Af6untLINENo^

Fleport below the balance at the end of the year and the inlormation specilíed below for the respeclive other paid-¡n capilaf accounts. Provide asubheading for each account and show a total lor the account, as well as tolal ol all accounts for reconcilfat¡on wilh balance sheet, Pagê 1 12. Add morecolumns lor any account il deemed necessary. Ëxplain changes made ln any account during lhe year and give the accounting entries eflecting suchchange.(a) Donations Reoeived from Stoclñolders (Account 208þState amount and givå brief explanation ol the orlgin and purpose of eaçh donation.{b} Reduction in Par or Slaled valuo of Capital Stock (Account 209)r Statê amount and give briet explanât¡ofl of lhe capitalchange which gave rise loamounts reported under this capllon includlng ¡dentifícation with the class and series ot slock lo which related.(c) Gaín on Resale or Cancellation of Reacqulred Capital Stock (Account 210): Reporl balance at beginning of year, credits, debits, and balance at endol year with a designation ol lhe nature of each credit and debit identified by lhe class and series of stock to rvhich related.(d) Miscellaneous Paid-in Capital (Account 21 1)-Cfass'rfy amounts lnch¡ded in this account accordÍng to captions r¡/ñich, togelher with þr¡ef explanations,disclose the general nature of the transacl¡ons whioh gave rise lo the reported amounts.

OTHER PAID-IN CAPITAL (Accounts 208-21l, inc.)

Year/Period of Fìeport

Endof 20151Q4Southweslêm €lectr¡c Powêr C,ompany(1)(2) Resubmission

Date(Mo,

n

FERC FOBM NO.1 (ED.12{4 Page 253

27,732,0092,513,700,00CTOTAL3it

504,000 D322,862,789400,000,000Senior Unsecsred Notes Se¡ies G, 6,45%31

301,092,000 D292,158,471300,000,000Senior Unsecured Notes Sedes F,5,875%28

27

Senior Unsecured Notes Series E - 5.55o/o Financial Hedges26

252,347,500 D24

156,778250,000,000Senior Unsecured Notes Series E, 5.55o/o23

22

Pollution Control Revenus Bonds, Series 2006 - 4.95o/o21

544,01781,700,000Sabine River Authority of Texas20

'f9130,500 Dt8

1,06ô,526150,000,000Senior Unsecured Notes Series D - 4.90% (Fetired ZnnAlS]t17

'f697,000 D15

805,375f00,000,000Senior Unsecured Notes Series t - 5.3757o (Retked 4l16l2Ù1í't14

t3FERÇ Authority under ES15-7-000, January 2, 2015l2

398,3f 153,500,000Pollut¡on Revenue Bonds, Series 2010 1.60o/o1'l

Parish of Desoto, Slate ol Lou¡siana,t0Pollution Conhol Revenue Bonds, Ser¡es 2A1A, 3.25"/çI

596,70s53,500,00€Parish of Desoio, Slate of Louisiana,I7

Account 224 - Other Long-Term Debt6

5

Account 223 - Advances fiom Associated Companies - None4

Account 222, Reacqulred Bonds - None3

Account 221, Bonds - None2

1

Total expense,Premium or Discount

(c)

Principal Amount0f Debt issued

(b)

Class and Series of Obligat¡on, Coupon Rate(For new issue, give commission Authorization numbers and dates)

(a)

LineNo.

1. Report by balance sheet account the parliculars (details) concerning long-lenn debt included in Accounts ZZ1,3onds,2ZZ,Reacquired Bonds,223, Advances from Associated Companies, and 224, Other long.Term Debt.2. ln column (a), for new issues, give commission authorizalion numbers and dates"3. For bonds assumed by the respondenl, inelude in column (a) the name of lhe íssuing company as well as a descriptíon of the bonds.4. For advances from Associaled Companies, report separatêly âdvânces on noles and advancês on open accounts. Ðesignalademand notes as such. lnclude ln column (a) names of associated companies lrom which advances were received.5. For receivers, certificates, show in column (a) the name of the court -and dale of court order under which such cer¡¡cales wereissued.6. ln column (b) show lhe princípal amounl ol bonds or other long-term debt originally issued,7. ln column (c) show lhe expense, premium or discount wilh respect to thê amount of bonds or other long-term debt originally issued.8. For column (c) the total êxpenses should be listed first for each issuance, lhen lhe amount of premium (in parentheses) or discount.lndicate the premium or discount with a notation, such as (P) or (D). The expenses, premium or discount should not be netted.9. Furnish in a footnote particulars (details) regarding the trealmeni of unamortized debt expense, premium or discount associated withissues redeemed during the year. Also, give in a tootnolo the date of the Commission's authorization of treatment other than asspecified by the Uniform System of Accounts.

Year/Period ot ReportËnd ol 20l5lQ4Southwestem Electric Power Company

(1 An (Mo, Da,tt(2) A Resubmlssion

FERC FORM NO.1 (ED. t2-96) Pago 256

*]'t't5,690,2442,210,200,000

32

3125,800,000i1,00,000,00(01/15/201906/09/200801/15/201906/09/2008

30

29

28t7,625,000300,000,00(03v01/201å12lA4l2AO703/0t/20181UO4/2007

27

26860,ô59

25

24

2313,875,000250,000,00€ail1512017a111112007011181201701111t2007

22

21

204,044, t5081,700,00c03/01/2018a4nlnoog03/01/2018oN1112008

19

18

173,675,00007touza1506128/200507/a112a1506/2€1200s

16

'15

14't,552,77804/15/201504115t20030411512015o4t15t2AO3

13

12

11853,62253,500,00cu1t2a191tu2015v1l2A191ta2a1E

10

II4,83001/01/2015o3t1u201o01/0t/2019o3l1a201o7

6

5

4

3

2

1

LineNo.Interest for Year

Amount(i)

(,utslanotn(¡ffotal amount oulstanöinq without' reduction for amounts h"eld by

resnl¡5dent)Date To(q)

Date From(f)

Dâtê otMaturity

(e)

Nominal Dateof lssue

{d)

AMORTIZATION PERIÔD

10. ldentify separale undisposed amounts applícable to issues which were redeemed in prior years.11, Explain any debits and credits other than debited to Account 428, Amortization and Ëxpense, or credíted to Account 429, Premiumon Debt - Credit.12. ln â footnote, give explanatory (details) for Accounts 223 and 224 of net changes during lhe year. With respocl to long-termadvances, show for each company: (a) pdncipal advanced during year, (b) interest added to principal amount, and {c) principle repaidduring year. Give Commission authorizatíon numbers and dates.13. lf thê respondent has pledged any of its long-lerm debt securities give particulars (details) in a footnote including name of pledgeeand purpose of the pledge.14. lf the respondent has any long-term debl securities which have been nominally issued and are nominally outstanding at end ofyear, describe such securities in a footnote.15. lf interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interestexpense in column {i). Explain in a footnote any dillerence between the lotal of column (i) and the total of Account 427, lnterest onLong-ïerm Debt and Account 430, lnterest on Debt to Associated Companies.16. Give parlicularc (deta¡ls) concerníng any long-term debt authorized by a regulatory commission but not yet issued.


End of 2O15lQ4Datê of Reoort(Mo, Da, Yi)tt(2) A Resubmission

Name of Flespondent

Soulhwestern Electric Powe¡ Company

FÊRC FORM NO. 1 (ED.12.96) Page 267

27,732,0092,513,700,000TCITAL33

92

31

30

29

28

27

26

25

Associated Çompanies.24

short-term borrowings which are included ¡n Account 293 - Notes Payable to23

Account 430, lnterest on Debl lo Assoaiated Compaoies, relating lo interest on22

NOTE - The inlerest in Column (¡) for the year does not lnctude the amount in21

2027,732,0094513,700,000Total Account 22419

18491,289100,000,000Texas Local Bank Facilily, Variable Rate17

16

3,568,000 ÐFERC Authority ËS'15-7-000, March 26, 20'15153.980,775400,000,000Senior Unsecured Notes Series J, 3.90o/o14

13

Senior Unsecured Notes Series 1,3.55% - Financial Hedges12

11

1,f30,250 D't02,1,15,ô15275,000.000Senior Unsecured Noles $eries l, 3.55%I

I147,000 Þ7

3,509,108350,000,000Senior Unsecured Notes Series H, 6.20%6

5

Account 224 - Other Long-Term Ðebt (Continued)4

3

2

1

Total expensê,Premium or Oiscount

(c)

Principal AmountOf Debt fssued

{b)

Class and Series of Obllgation, Coupon Bate(For new issue, give commission Aulhorizalion numbérs and dates)

(a)

LineNo.

1. Report by balance sheet account the particulars (details) concerning long.lerm debt included in Accounts 221, Bands,222,Fleacquired Bonds, 223, Advances lrom Associated Companies, and 224,Olher long-Term Debt.2. ln column (a), for new issues, give commission authorization numbers and dates.3" For bonds assumed by the respondenl, include in column (a) the name of the issuing company as well as a description of the bonds.4, Fol advances from Associated Companies, repoÍt separalêly advances on nolgs and advãncÊs on open accounts. Designatedemand notês as such. lnclude in colurnn (a) names of associaled companies lrom which advanc€s were received.5. For receivers, cerlificates, show in column (a) thê namê ol the court -ând dats ol court order under which such certificates wereissued.6. ln column (b) show lhe principal amount of bonds or other long-lerm debt originally issued.7. ln column (c) show lhe expense, premíum or discount wilh respect to the amount of bonds or other long-term debt originally issued.8' For column (c) the total expenses should be listed lirst for each issuance, then the amounl oi premium (in parenlheses) or discount.lndicate the premium or discounl with a notation, such as (P) or (D). Tha expenses, premium or discount should not be netted.9. Furnish in a footnote particulars (details) regardfng thê lreatment of unamorlized debt expense, prenrium or discounl associated withissues redeemed during the year. Also, give in a foolnota lhe date of the Commission's authorization of treatment olher lhan asspecífied by the Uniform System of Accounts.


Fnd of 201slQ4Date of Reoort(Mo. Da, Yi)ttSouthwestem €lectríc Power Çompany )

(2') A Resubmission

FEHC FOFM NO. 1 (EÐ. t2-96) Page 25ô.1

331 f5,690,2442,210,200,000

32

3t30

29

28

27

26

25

24

2g

22

21

2A

191'15,690,2442,210,200,00c

'18

171,807,385100,000,00c071111201707111t201407t|'u2a170711,t12014

16

15

1411,916,6€7400,000,00c4nl2A45a261201541112045312612015

13

122,212,653

11

10

I9,762,500275,000,000uI512022ual2a12u15t2022uogl2a12I7

62r,700,000350,000,00003115/2MO0v1ry2010w15/204003/112010

5

4

3

2

1

UneNo.lnterest lor Year

Amounlfi)

vurslanotn(¡ffotal amounl outstand¡nq without' reduclion for amounls h-eld by

resnl¡¡dent)Date To(q)

Date From(0

Ðalo ofMaturity

(e)

Nominal Þaleof lssue

(d)

AMORTIZATION PERIOD

10. ldentify separato undisposed amounts applicable to issues whích were redeemed in prior years.1 1. Explain any debits and credits olher than debited to Account 428, Amortization and Ëxpense, or crediled to Account 429, Premiumon Debt - Credil.12. ln a foolnole, give oxplanatory (details) for Accounls 223 and 224 ol nel changes dudng the year. Wilh respect to long-lermadvances, show lor each company: {a} pdncipal advanced during year, (b) interest added to principal ãmounl, and (c} principle repaidduring year. Give Commission authorizalion numbers and dates,13. lf lhe respondent has pledged any of its long-term debt securities give pañiculars (déta¡ls) in a footnote including name ol plêdgeeand puçose of the pledge.

14. lf the respondent has any long-term debt securities which have been nominally íssued and are nominally outstanding at end ofyear, describe such securilies in a footnote15. lf intêrêst expensê was incurred during the yeär on any obligations retired or reacquired before end of year, include such interestexpense in column {i}. Explain in a loolnote any difference between the total of column (i) and the toÌal of Account 427, intêrest onLong-Term Debt and Account 430, lnterest on Debt lo Associated Companles.16, Give particulars (details) concerning any long-term debt aulhorized by a regulatory commission but not yet issued.

Year/Period of ReportEnd of 2015/Q4) An Original

A Resubmis¡ion(Mo, Da,

tt(2)

Name of Bespondent

Southwest€m Electric Power Company

FERC FOHÍA NO.1 (EÐ.12€6) Page 257.1

44

,13

42

41

40

39

38

37

36

35

34

33

32

31

30

3ee Footnote29

Show Çornputation of Tax:28

61,313,237:ederalTax Net lncome27

26

25

24

23

22

21

2A

Deductions on Retum Not Charged Against Book lncome19

18

17

l615

lncome Recorded on Books Not lncluded in Retum14

t312

11

10

Ðeductions Recorded on Books Not Deducted for Fletums

8

7

6

5

Iaxable lncome Not Fleported on Books4

3

2

192,346,180Net lncome for lhe Year (Page 1 17)1

Amoun¡(b)

Part¡culars (Deta¡ls)LineNo.

1. Report the reconc¡liation ol reported net income for the year with tarable income used in computing Federal income lax accrua¡s and showcomputation of such tax accruals. lnclude in the reconciliation, as far as praclicable, the same detail as furnished on Schedule M.'l of the tax return forthe year. Submil a reconcilialion even though there ís no taxåbfe income for lho year. lndicale clearly the nature ol each reconciling amount.2. lf the utility is a member of a group wtrich files a consolidated Federal tax retum, reconcife reported net income \¡/ith taxable net income as ¡, aseparate retum were to be field, indicating, however, intercompany amounts lo be eliminated in sr¡ch a consolldated retum. State names of groupmember, tax assigned to each group member, and basis ol allocalion, assignment, or sharíng of the consolidatêd tax among thê group members.3. A substitute page, designed to meel a parlioular need of a company, may bê used as Long as lhe dala is conslstent and meets the requirements oflhe above ínstructions. For eleclronic reporting purposes complete Line 27 and provide the substitute Page in lhe context of a footnote.

Year/Period of ReportEndof 20l5lQ4Southwestem Electric Power Company

(1)(2)

An OriginalA Rêsubmission lt

Page 261

FOOTNOTE DATA


2015/Q4



Name ol Respondent


261 Líne No.:29

NeL fncome for the year per Page 117Federal and State Income Taxes

Pretax BoÕk fncomêIncrease {Decrease) in taxable fncome resulting from:Allowance for Funds Used During Conscruct.ion and OEher Þifferences

Between lt.ems Capitalized for Books and Expensed for TaxBook,/Tax Unit of Property AdjCapitalized RelocaEion CostsDeferred Fuel Costs (Net)Disallowed Costs - furk PlantEquily in Earnings of SubsÍdiary CompaniesExcess Tax Vs Book DepreciaEionMark-to-MarketMine ÐevelopmenEMine ReclamationPension Expenses (Net)Premium,/toss on Reacquired Debt (Net)Provision for Revenue RefundRegnrlatory AsselsRegulatory Liabili tiesRemoval CostsSFAS 106 - Post. Retirement Benefit Expense Accrued/Funded (Net)SFAS 112 - Post, Employment Benefit Expense Accrued/Funded (Net)Unbil-led RevenueOther (Net)

Less Currerrl Year Current State Income Tax

Federal Tax Net Income * EsLimaEed Current yeär Taxable Income(Separate ReEurn Basis)

CompuEation of Tax *Federal Income Tax on Current year Taxable Incone (SeparaLe Return

Basis) at the Stat.utory Rate of 35tAdjusÈment due Eo Syst.em Consolidation (aEstimated Tax CurrenEly Payable (bTax CrediL CarryforwardAdjustmenqs of Frior Year,s Ãccruais (NeL)

EstimaLed Current. Federal Income Taxes (NeL)

L92,34682 ,829

275,3_75

{13,269){33,396)

13,g]-2]-23,552( 1, L31)(3,866)

(LL3,2821222

61)9806)4322',)9689)36)65)

(14,31r 1

(5,99

(7 ,50,7o,18,55r4

l_

(2(1

(

(ee4)(4,377')2,r44

5, 911

61",313

2].,46Q(979)

20 ,48L(3s5)

2t 36s4L,4gL

FERC FORM 1 1 45û.'l

FOOTNOTE DATA


2015/Q4


tt

This Report is:(1) X An Original{2\ A Flesubmission

Name of Respondent


(a) Represen¿s the allocation of the estimated current year r¡et operaEing Lax loss ofAmerican Electric Power Company, Inc.

{b) The Company joins ín the filing of a consolidated Federal income tax reLurn with icsaffiliaBed companies in Ehe AEP system. The allocation of the AEP System'sconsolidated Federal income eax Eo Ehe System companies allocaLes the benefit ofcurrent tax losses to the System companies giving rise t.o chem ín determining bheircurrer¡t Lax expense. The t,ax loss of the System parenL company, American ElectricPov¡er Company, Inc. r is allocated ¿o ies subsidiaries with taxable income. With theexcepEion of the loss of the parenl company, Lhe method of allocation approximates aseparate return result for each company in the consolidating group.

INSTRUCTION 2.* The Lax computation above represents an estimate of the Company's allocated portion ofthe System consolidated Federal income tax. The computat.ion of actual 20L5 Syst,ernFederal income taxes will not be available unril Ehe consolidatsed FederaL incorne taxreturn is compleEed and filed by Seplember 20L6. The actual- allocation of the Sysbemconsolidated Federal income tax co the members of the consolidated group will not beavailable unLil after Lhe consolidated Federal income tax rebufn is filed.

FERC FORM NO. f (ED.',,2-871 Page 450.2

130,329,9241ô1,922,296855,41633,785,493TOTAL41

110,43885,81744,782Unemployment - TX 2Ol540

7,549,7429,331,982TX Locål Franchise-zo1 539

5,A32,,8275,832,627TX Gross Receipls - 201538

1,290,569-20'1,6295,416,650lncome31

Texas State Taxes36

35

OK Sales Tax Ucense - 2015u25,3û427,381OK SafeVUseTax-2A1533

5,3694,9036461,112OK Sale${Jse Tax - 20f 432

-816620-f.54íÌlneome31

20,10020,.l00Slate Franch¡sÞ30

{nlnState Ucense Registralion29

28

275,714389,742Oklahoma.Ad Valofem - 201527

287/|æ287,'t66Oklahoma Ad Valorem - 201426

Oklahoma State Tax€s25

24

State License Reg¡slration23

130130Unemploymenl - NE 201522

3,8164,935NE Safegusê " 20152l-766766NE Saleluse - 201420

828lncome't9Nebrâskâ Stätê Tâxês18

3,328"8243,924,996lA SaleVuse - 2O1517

ß7,270-7,7â4445,024LA SaleVuse - 2014f688,9ô0.13,0401æ,000LA lnsp Fees 20'1415

32S,819416,819LA lnsp Fees 201514

7A7AState Ucense Beg¡stration13

12

4,2114,322't,353Unemploynent - LA 20'15t16,3r 1,5357,980,325[A Local Franchísê - 201510

1,?75,89877,77477,7701,775,894l-A Local Franchise - 2014I8'1,35081,350l-{ OccupUcFees-2015I

730,5'14-1,061,3961,684,392lncome7

3,613,49t)3,937,247-323,74t1state Franchise€

State Ucense FeesÂ

4

20,851,70220,852,175Louisiana Ad Valorem - 20153

177,395I 17,29960,096Louisiana Ad Valorem - 20142

Louísiana State Tâxes1

Adjust-ments

(0

Fteoao taxes(lnclude in Account 165)

I axes Accrueo(Account 236)

(b)

Kind of Tax(See instruction 5)

(a)

uneNo.

I ^ Give parliÇulars (delails) of the combined prepaid and accrued tax accounts and show the lolal taxes charged to operations and other accounts duringlhô year. Ðo not inolude gasolino and other sales laxes vvhich have been charged to the açcounts to which the taxed malerial was charged. lf theactual, or estimated amounls ol such laxes are know, show lhe amounls in ä tootnote and d€signatê whêlhêr ettimated or actuãl amounls,2. lnclude on this page, taxes paid dudng the year and charged dlrect lo final accounts, (not charged to prepaid or accrued taxes.)Enter lhe amounts in both columns (d) and (e). 'Ihe balancing of this page is not affected by th€ inclusion of these tåxes.3. lnclude in column (d) taxes charged during thê year, taxes charged to operations and olher accounts through (a) accruafs credited lo laxes accrued,(b)amounls credited lo proportions of prepaid taxes chargeable to cunent year, and {c) taxes paid and charged dkeot to operations or accounts olherthan accrued and prepaid tax accounts.4. Ust the aggregate of each kind of tax ¡n such manner that the total tax tor each State and suM¡vision can readily be ascertained.

Year/Per¡ocl ot ReportEnd of 2011Q4Southwestern Eleclric Power Company

(1)(21 A Resubmission tt

FERC FOFtrt NO. t (ED. 12.9õl Page 262

4126.893,892135,028,404990,30065,512,749

4052,60333,21420,161

399,33r,9821,782,240

385,æ2,627

37-201,62S3,924,452

36

35

34

3327,3814042,481

324,903

31428-1A7

3020,100

2910

28

27389,742114,028

26

25

24

23

22130-1 30

214,9351,119

20-766

19785828

18

173,925,97-651596,172

't6-7,7&15-'13,0'10

't441ô,6f I87,000

1370

12

tl1,2813,0411,4A1

10-77,7708,058,09570,8961,739,686

I77J70I81,350

-'l ,108,679- t 07,518

63,937,247

5

4

â326,05320,526,122473

26,084111,215

'l

LineNo.Other

(t)

AO|USImenIS rO Het.Earnlngs (Account 439)

{k}

Exraord¡nary ltems(Accoulìl4os.3)

Electric(Account 408.1, 409.1)

Prepa¡d ïaxes(lncl. in Account 165)

ffaxes accruedAccolnl 236)

:ND OF YEARBALANçEAT

5. lt any tax (exclude Federal and State inçome laxes)- covers more then one year, show lhe requ¡red information separately for each lax year,

identifying the year in column (a).

6. Enter all adjustments of the accrued and prepaid tax âccounts in column (f) and explain each adjustment in a lootnote. Ðesignate deblt adjustmenlsby parentheses.7. Oo not include on his pags entries with respect to deferred inepme taxes or laxes collected through payroll deductions or othenvise pendingkânsm¡tlal of such laxes lo the taxing authority.8. Beport in columns (i) through (l) how the taxes were distributed. Report in column (l) only lhe amounts charged to Accounts 408.1 and 409.1pertain¡ng to electrlc operations. Beport in column (l) the amounts charged to Accounts 408.1 and 109.1 perlain¡ng to oth€r util¡ty departments andamounts charged to Accounts 408.2 and 409,2, Also shown in column (l) lhe laxes charged to util¡ty plant or other balance sheet accounts.9. For any lax apportìoned to more lhan one ut¡lity departmenl or account, stalo ¡n a foolnole the basis (necessi$) of apportioning such lax.

Year/Period of Reporl

End of 2O16lQ4Name

Southwestern Electrio Power Company(1)(2')


(Mo, Da,tl

FËRC FORM Í\lO. I tED. f 2-96) Page 263

130,329,924161,S22,29€8ä5,4163it,785,493TOTAL41

15s155State Licenss Registration40

919,0003S

-777,0Ø777,000AR Sales Tax - 20143€

5,582,¡t456,256,110AB Use-20.l537

't,040,376309,688730,688AR Use-201436

288,000AR PUC Fees 201535

575,436275,436300,000AB PUCFees201434

AR Local Franchise-20l Iââ108,67386,44532,O57Unemployment - AR 201532

3l13,250,000Arkansas Ad Valorem - 20'153C

¡ 2.5Y5. /U4-¿+,zvor¿row,urJUÀ -t-^-^^^ lr t r^t^-^- ^Â¡

¡ñt Mt lÐqÞ ñu volqtE[t _ ¿v ¡t

28

122,393122,393State Franch¡se27

1,6ô3,921-959,774lncome26

Arkansas State Taxes25

Misc Slate and Local24

4-4State Ucense Begistratlon23

71,2#72,15014,205State Franchise Delawãre22

Delaware State Taxes21

5,9285,928Federal Excise ïax - 20f52A

2,2122,212Federal Ëxc¡se Tâx - 201419

61,21166,07220,728Unemployment - 201518

10,179,35710,181,€01,476,610FlcA - 2015't7

lncome Tax FIN ¿l8't610,263.51941,489.718-15,417,093lncome Tax15

Federal Taxes14

13

5,209,48120,341,f 48Texas Ad Vãlorem - 201512

13,056,220-376,22313,ß2,443Texas Ad Valorem - 20t411

10

1,871j971 ,871 ,1 97TX Local Franchise-2014s

12,51 1,95912,51 1 ,95SITX Use-Audit Provision7

2,3s6,09S2,557,096TX Use-2oï56

398,314-288,996687,310TX Usê-20145

99,13499,134TX Use-20134

Texas Slate Taxes Continued3

440,868TX PUC.zO152

881,735422,165459,570TX PUC.2O141

Adjust-menls

(0

Pfeoalcl laxes(lnclude in Account 165)

Kind of Tax(See instruction 5)

(a)

uneNo.

1. Give particulars (details) of lhe combined prepakl and accrued lax accounts and show the lotal taxes charged to operations and other accounts duringthe year. Do not include gasoline and olher sales taxes wtrich have been charged to lhe âccounts to wñich the laxed material wao charged. lf theaçlual, or estimated amounts ol suçh taxes are know, show the amounls in a lootnote and designate yvhether estimaled or actual amounts,2, Includø on lhis page, taxes pa¡d during the year and charged direct to linal accounts, (nol charged to prepaid or accrued taxes.)Enter lhe amounts ln both cllumns (d) and (e). The balancing of lhis page ls not aflected by lhe inclusion of these laxes.3. lnclude in column (d) taxes charged during the year, taxes charged to operations and other accounts lhrough (a) accruals credited to taxes accrued,(b)amounts credited to proportlons of prepaid taxes chargeablo lo current year, and (c) laxes paid and charged dkect to operations or accounts otherlhan accrued and prepaid tax accounls.4. List the aggregale ol each k¡nd of tax in such manner thal lhe total tax for each State and subdivision can readily be ascertained.

Year/Period of ReportËnd of 2015/Q4

Dal€ ot Beoort(Mo, Da, Yi)

This Reoort ls:(1) E]An or¡sinal{2t TIA Besubmisslon

Name of Flespondent


FËRC FORM NO. I (EÞ. 12.e6) Pagê 262.1

4120,893,892135,028,40¡t990,300ô5,512,749

40155

39919,000

3B

376,256,113ô73,668

36309,688

35288,000288,000

34275,436

3,Í]

3266,54119,9049,829

31

301,189.40012,060,60013,250,000

294,132-8,428

28

27122,393

261,637,747710,147

25

24

234

2272,15015,100

21

205,928

192,212

1817,8W48,26825,589

173,510,6166,670,814't,478,683

16

1s44.862.81315,809,'106

14

13

121,104,00019,237,1,1815,131,667

f1-37ô,223

't0sI12,5r 1,959

7

62,557,096200,997

5-288,996

468,21034,924

3

2440,868440,868

1422,165

LineNo.Olher

(t)

Aotustments to He¡.Eamings (Account 4Í19)

(k)

Efraordinary ltems(Account 409.3),409.1)

Prepa¡d Taxes(lncl. in Account 165)

(Taxes accruedAccoln| 236)

:Nf, C]F YËAR IBALANCE AT

5. lt any tax (excludê Federal and Slate income taxes)- covers mors then one yeår, show the required information separately for each tax year,

ident¡fy¡ng the year in colurnn (a).

6. Enter all adjustmenls ol lhe accrued and prepald lax accounls in column (f) and explain each adjustment in a footnote. Ðesignate debit adjustmentsby parentheses.7. Do not include on this page enkies with respect to defered ¡ncome taxes or taxes collected lhrough payroll deductions or otherwise pending

lransmitlal ol such taxes to the taxing author¡ty.8. Report in columns (i) through (l) how the taxes were dlstributed. Reporl in column (l) only the amounts charged to Accounts 408.1 and 409.1pertaining to electric operations. Fleport ¡n column (l) the amounts chargod to Accounts 408.1 and 109.1 pertaining lo other ulility departments andamounts charged to Accounts 408,2 and 409.2. Also shown in column (l) the taxes charged to ut¡lity plant or other balance sheet accounts"

L For any tax apport¡oned to more than one ut¡lity department or account, state in a lootnote the basis (necessity) of apport¡oning such tax.


Ënd ol 2015/04Date of Heoort(Mo, Da, Yi)ll

This Reoort fs:(1) 5]Rn orisinal(2) nA Resubmission

Nâme of Respondenl

$outhwestern Electric Power Company

FERÖ FÕRM NO. 1 (ED. t2-96) Page 2ô9.1

130,329,924161,922,29Ê855,41ô&3,785,493TOTAL41

40

39

38

37

36

2É

a33

32

3T

30

2g

28

27

2Ê

25

24

22,264Railcar - WY 201523

M,74234,742Railcar'MO 201522

70s709Raifcar - KY 201521

2A

12,099"'t7,37429,473Railcar - WY 2014't93,332-s,2058,537Bailcar - WV 201418

1,600-1,600Railcar - KY 201417

5,686s,686Railcar - CO 201416

I67,5293,8133,716Bailcar - WV 20131A

13

Ad Valorem12

11

'f ,797,0007,497,352State lncome Taxes - FIN 4810

ISlats License Reg¡strationIVirginia Stâte Taxes7

6

66OH CAT Tax - 2015220H CATTax - 20144

lncome Taxa

Oh¡o Slate Taxes2

.1,500,0001,500,000AFI Use " Provision1

AdlusÞments

(f)

'É

1Ffeoaþ taxes

(lnclude ín Account 165)Iaxes Accrued(Account 236)

(b)

Kind ol Tax(See ínstruction 5)

(a)

L¡Nê

No.

1. Give particulars (dela¡ls) ol the combined prepaid and accrued lax accounts and show the lotal laxes charged to operalÍons and other accounts duringlhe year. Þo not include gasolíne and oth€r sales låxes $/hich havø been charged to lhe âccounts to which thê taxed material was charged. lf theactual, or estimated amounts ol st¡ch taxes are know, show the âmounls in a footnote ând designate whelher est¡mated or actual amounts,2. lnclude on lhis page, taxes paid during lhe year and charged direct lo final accounts, (not charged to prepaid or accrued taxes.)Enter lhe amounls in bolh columns (d) and (e), The balancing of this page is not atlected by lhe inclusion of these taxes.3. lnclude in column (d) taxes oharged during the year, lâx€s charged lo operat¡ons and olher aepounts through (a) accruals credited to laxes accrued,(b)amounts credited to proporllons ol prepaid laxes chargeabl€ to current year, and (c) taxes pa¡d and charged d¡rect to operations or accounts otherthan accrued and prepald lax accounts.4. L¡sl the aggregate of each kind of tax in such manner lhat lhe tolal lax for each State and suMivision can readily be ascertained.

Year/Per¡od of FeportEnd ol 2015/Q4

Name Respondent

Southweslem Electric Power Company(1

(2) A Besubmission u

FËRC FOFM NO.1 (EO. 12-96) Page 262.2

4126,893,892135.028,40,1990,30065,5'12,749

40

39

38

37

36

eÊ

a33

32

31

30

29

28

27

26

25

24

2322,26422,264

2234,742

21709

20

19-17,374

18-5,205

T71,800

T65,686

15

143,813

l3l2

'lf101,797,0009,294,352

II7

6

56

42

e

2

I1,500,000

LineNo.Other

(|)

AOtUSImenIS rO rie[.Eamíngs (Account 4il9)

(k)

Extfaord¡nafy ltems(Account 409.3)

Electric(Account 408.'1, 409.1)

Prepa¡d Taxes(lncl. ln

fç¡unt 165)

flaxes accruedAccoTSl 236)

.} ()F YFAR IBALANCE AT

5" lf any tax (exclude Federal and Slatë incomo taxeî)- covers more then one year, show lh€ required informalion separately for each lax year,

ident¡tying the year in column (a).6. Enter all adjustrnenls ôt the accrued and prepaid tax accounts in column (f) and explain each adiustment in a looþ note. Designate debit adiustmentsby parenlheses.7. Do nol include on his pagô entries wíth rêspect to defened incor¡¡e taxes or lãxes collected through payroll deductions or otherwise pending

transmittal of such taxes lo thê taxíng authority.L Report in colurnns (i) through (l) how the laxes were dislributed. Report in column {l) only the amounls charged lo Ac-counls 408.1 and 409.1p€rtaining to electrio op€ratlons. Report in column (f) the amounts charged to Accounts 408.1 and 109.1 pena¡ning t0 other ut¡lity departmenls andamounts charged lo Accounts ,108.2 and 409.2. Also shown in column (l) the laxes charged to utility plant or other balance sheet accounts.9. For any tax âpport¡oned to mors than one util¡ty depañmenl or account, slate ln a footnote the basis (necessity) of apportioning such tax.


Endof 2015/Q4Name of

Souü¡westem Electric Power Company(1)

(2t Flesubmissíon /t

FERC FOBM NO,1 (8D.12€6) Fage 2ô¡,.2

FOOTNOTE DATA


2015/Q4

Date ol RepoÉ(Mo, Da, Yr)

tt


Name of Respondent

Southwegtern Electric Power Company

Cons sts o a prepa:/ment es tax ; aco

4'l

L r L tax. Beg n 2009,262.', Line No; I Calumn: a

Account 4Co 21üt.262 Line No.: Column: I

Non262 No.:19 Co[umn:

Accountfo

æduleFase: 262.1 Líne No.: 15 Column: Iincluded for of report 1 activi

to Non ty AccountFuel Tax Charged to 174 1 504

a1

Consists of a prepayment for sales Lax only; a collect &, remit tax. Beginning in 2009,included for purposes of reporting all prepaid tax acÞiviÈy.

262,1 39 Calumn: a

262.1 26 CoNumn: I

FERC FORM NO. T 1 450.1

48

41

4e

4t44

4{

42

41

4(

39

38

37

36

35

a33

o¿

3t3C

2e

21

2e

oÊ

2A

22

¿z

21

2C

tç1€

1i

I€

1f

,IA

1!

12

11

1(

Other (Ust separatelyand show 37o, 4o/o,7o/o,

10% and TOTAL)

o1,351,9819,830,871TOTALI

6

1,351,98{4'11.49,830,8711Oo/o

4

4a/oâ

s%2

Adiustments

{s)Electric Ut¡lity1

ruf lIiqffl(

,{çIOUNI NO,(e)

Amount{d)

Þalance,I öegnning

(b)

Accountsubdf¡iionsNo. 'lCr rrrerDeferred for Year

Report below information applicable lo Account 255, Wherenonut¡lity operations. Explain by footnote äny corrsction adjuthe average period over which the tax credits are amort¡zed.

appropríatê, segregate the balances and lransâctions by util¡ty andstmenls to the account balance shown in column (g).lnclude in column (i)

YearlPeriod of ReportEnd of 2015/Q4

Date ol Reoort(Mo, Da, Yi)tt

This(1)(2) Resubmission

Name of Respofldent


FEFC FORM NO.1 (ED. 12€9) Page 266

48

47

46

45

44

4{}

42

41

40

39

38

37

3635

343Í!

32

31

30

28

27

26

25

24

23

22

21

20

19

18

17

16

15

14

13

12

11

10

II8,478,88ô

7

6

58,478,886

4

3

2

1

uneNo^

Averaoe Perþool Alfocãtion

lo lncome{it

Balance at Ëndof Year

(hì

ADJUSTMENT ËXPIáNATION

Year/Perlod ot ReportEnd of 2015/Q4

Date of Reoort(Mo, Da, Yi)t/Soulhwestem Eleclr¡c Power Company

ls:Original

(2) A Resubmiosion

FERC FORM NO.1 (ED. t2{9) Page 267

FOOTNOTEDATA


2015/Q4

Name of Flespondent

Southwestem Ëlectric Power Company

lThis Report ¡s: I

l(1) X An Orisinal I

lQ\ -A Resubmission I


tt

5

Remaining amortization period of 't5 years.

I 450.1

22,524,A149,330,409r 1,533,09124,726,696TOTAL47

4ô

45

44

43

42

41

40

39

38

a7

36

35

34

33

32

31

30

88,93487,933160,481Various161 ,482Minor ltems29

28

659.1q3872,7761,057,386107 /'t088¡{3,713Conskuction27

Contribution in Aid of26

25

6,3756,375554,158186554,1 58Associated Business Development24

23

3,687,6081,025,{t0588,8s91231t1433,251,037Oxbow BW-ln L¡abil¡ty22

21

151,36325,1t9242l7ô,552Welsh Unit I20

Environmental Uability -19

18

23,83345623,833Delened Revenue17

NFFI Ënergy Lease -1ô

'15

4,261,4244,148,9223,460,504131 I 1423,573,006Customer Advanc€ Receipts14

13

1,232,5552,640,7602,2s1,758454843,553Pole Attachments12

11

3,253,805117,1733,136,ñ32Ownership DelerrerJ Creclits10

Power Plant JointII7

9,056,3114tì1,0403,39t,061'143't2,016,332Ownership Deferred Credils6

5

4

2,02â4562,O25Security Depos¡ts3

2

126,53ô't7,837232144,373lnsurance Liability - BRÊMCO1

Balance atÊnd of Year

(f)

Credits

(e)

Amount

(d)

ContraAccount

(c)


(b)

Descript¡on and OlherDeferred Credits

(a)

Line

No.

DÉBIÏS

1. Beport below the particulars (details) called for conceming other deferred credits.

2. For any deferred credit being amortized, show the period of amortizalion.

3. Minor items (5% ol the Balance End of Year lor,Account 263 or amounts less lhan S100,000, whichever is grealer) may be grouped by classes,

Year/Period ol ReportEnd ol 2015/Q4Southwestern Electr¡c Power Company tl(2) A Flesubmission

FERC FOBM NO.1 (ED. 12-94) Page 269

FOOTNOTË DATA

Year/Period of Repod

2015/Q4

Dale of Fleport(Mo, Da, Yr)

ltThis Fleport is:(1) X An Originale\ A Resubmission

Name of Respondent

Southrüestern Êlectric Power Company

269

Farmula Rote Uses;

SFP tndependent Power Producers Sysfem Upgrade Credits By FunctíanYEAR 2475

46,339,620

(9,056,311)

{3,253,805)

34,029,504

1,622,024 112,216,976t

3,391,061 (431,040)

{117,173}

5,013,08S (12,825,139)41,841.,558TotalSWEPCOGeneration IPP

Prepayment

56,994,522

t12,016,332)

(3,136,632)

AËP SWEPCO

Generation IPPPrepayment

Joint Owner IPP Credits

Current Portion of JointOwner Credits

Balance atEnd of Year

Generãt¡onDebit Credit

TransmissionDeb¡t Credit

Ealance at8eg of Year

Ðescription

{46,339,520)11,622,A241 12,276,926

llt56,994,522)AEP SWEPCO

Transmission IPP Credits

TOTAL SWEPCoCom

(75,L52,964,l'otal Line 5 & Line B {12,310,116}5,û13,085 {12,825,139}{r,62?,0241 L2,?76,926

269 Llne No.: a

See Line 5 Foot[oee.


NOTES

Local lncome TaxT3

State lnclme Tax12

90,297,640132,æ7,4241,229,044,805Federal lncomeTax11

Class¡ticalion ol TOTALTO

90,297,640132,øA7,4241,229,w,æ5TOTAL Account 282 (€nter Total of lines 5 ìhrus

I7

85,643,588Regulatory Assels - SFAS 1096

90,297,64(132,607,4241,143,44',t,217TOTAL (Ënter Total of lines 2 thru 4)ç

4

Gasâ

90,297,64C132,æ7,4241,143,&1,217Electric¿

Account 2821

Amounts Creditedto Account 4't 1.1

(d)

Amounts Ðebitedto Account 410.1

(c)


(b)

Accounl

(a)

Lins

No.

CHANGES DUBING YEAR

1. Repqrl the information called for below concerning the respondent's accounting for deferred income taxes ratíng tô property nolsubject to accelerated amorlizalion2. For other (Specify),include deferrals relating lo other income and deductíons.

Year/Period of ReportÉnd of 2015/Q4Soulhwestem Electric Power Company {1)

(2',)

AnA Rêsubm¡sslon tt

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

NOTES (Continued)

13

12

1110,374,4â14,004,40(

10

I1,m,724,6Ai10,374,4214,004,40(

I7

692,013,60(10,374,4211823tzild004,40(1823t2æ

51,r85,711,001

4

3

21,185,71 1,001

I

LineNo.

Balanco atEnd of Year

{k)

Amount

û)

AccounlOebited

fi)

Amount

th)

AccountCredited

(s)

Amounts Creditedto Account 411.2

(0

Amounls Ðebfted

to Accounl 410.2

(e)

CreditsDebits

CHANGES DURING YEAH ADJUSTMENTS

3. Use footnoles as required.


End of 2015/Q4Date ot Reoort(Mo, Da, Yi)tt

Thls Reoort ls:(1) fiAn Original(21 f-lA Resubmlssion

Nam€ of Respondent

Southwestern Electric Porver Cæmpany

FERC FORM NO.1 (ED.12-96) Page 275

FOOTNOTE DATA


2015/Q4

Date of Report(Mq Ða, Yr)

tt

This Reporl is:(1) X An Original(2\ A Resubmission

Name ol Respondent

Soulhwestem Electrlc Powêr Company

ft274

Formufa Rale uses 13 month âvêrâgê,

FERC FORilN NO.1 450.'l

NOTES

Local lncome Tax2A

't,663,09€124,148,735Slate lncome Tax22

16,ô03,34€15,823,31 1142,221,022Federal lncome Tax21

Ölassif ication of TÖTAL20

lô,603,34617,,ff'6,40'l266,467J57TOTAL (Acct 283) (€nter Total of lines 9, 17 añd 18)1S

Non Utíl¡ty,SFAS 1og,SFAS 13318

TOTAL Gas (Total of lines 1 1 thru 16)17

16

f5

14

13

12

11

Gas10

I6"603,34617,486,40146,036,411TOTAL Ëlectric ffotal o{ lines 3lhru 8)I10.402,04514,31 1,231-5,181,449OtherI

457,76€113,8382,869,513Rate Case Delerred Charges7

186,ô5€1,866,584SFAS 106 Med Subsidy Reg Assel6

2,087,991869,78311,805,637DFfT on State NOL5

333,9952,43ß,307Loss on Heacqu¡red Ðebt4

3,134,8912,191,54932,242.819Accrued Eook Pension Expense3

Electric2

Aecount 2831

lo Accoidlt 41 l.t0.1

Balancs atBeg¡nning of Year

tbl

Account

(a)

Line

No.

CHANOES DURINGYEAR

'1. Report the informatíon called for below concerning ihe respondenfs accounting lor deferred income taxes relating to amounl$recorded in Account 283.2. For other ($pecify),include defe¡rals relating lo other income and deductions.

Year/PerÌod oÍ ReportEnd ot 2015/Q4

(2) A Resubmission ttName of Respondent


FEFC FORM NO. r (ED.12-e6) Page 27ô

NOTES (Cont¡nued)

23

æ132,284.,4671¿&.324ô,179,692

21'146,95T,89713,315,40€7,804,496

N1925,969,73013,984,188

l8232,316,88825,9ô9.7301829125/.19,984,188182312Fl.

17

16

15

14

13

12

11

10

s4tì,913,4€6

I.1,272,2õg

72,525,585

ô1,679,926

510,587,429

42,099,312

331,299,477

2

1

LineNo.

Balance alËnd of Year

{k)

Âmounr

{fl

ACCOUnIOebited

{¡l

Amoun¡

rhÌcrfflt"d

Amount3 çred¡tedto Account 41 1.2

(fl

Amounts uobiteoto Aacount 410.2

(êl

CreditsDebitsIBING YFÄN('-¡.tÂNGF.q

3. Provide in lhe space below explanations for Paga 276 and 277. lnclude amounts relating to insignificant items listed under Olher.4. Use foolnotes as required.


End of 20151Q4Soulhweslem Eleclric Power Company(1)

{2)

An OriginalA Resubmission tl

FERC FOFM NO.1 (ED.12.9ô) Page ZTT


2015/Q4

CIate of Report(Mo, Da, Yr)

ltThis Report is;(1) XAn Original(2) * A Resubmission

Name of Respondent

Southwestem Eleclric Power Çompany

Page

Non-utilitySFAS 109Total Line 18

IÊalanceBeginof Yêar

L2,4L4220,3t8,|93222O,33L,346

Pebits toAccount

41a.2

Credits toAccount4TL.2

DebiLAdjùst.

BalanceEnd ofYeâr

CreditAdjust.

00

00

0 13,994,199

0 t_2,4L425 ,969 ,730 23,2 ,304, 47 425 ,969 ,'130 232 , 316 , 898

013,984,199.

0

Llne No,: t9276

Formula Bate uses 13 month average.

1 4s0.1FORllJ|

56,71512429,763.90938,050,3847t,001,899TCITAL41

40

Minor llems < $100,00039

38

7.910.7ü8,221,8843il,180440 -141Delened Ovenecovery Fusl Cosls - &kansas37

36

4,901,87f4.904,8735tr¡LFSC Dockel No. U.3222035

Servix Ouality lrnprovemsnt Poorâm (SQIP)uOvenecovery ol Larisiana Vqgehlion33

32

669.0t 12.118,9t€2,0f5,395140-U{535,488Ðocket ñ0.07O82-TFg1

907/908Conservalion and Energy Efñcient Proqiam30

Public Servbe Comrnissbn's Rules fot29

Endorcement Act ol 1 997 and lhê Arlcnsas28

A*ansas Eæqy Conservation27

Cost Fate FiJ€r pußuaÍt to26

Ovenecovery of Ënergy Etliciency25

24

1,170.141,13e07S1,386,m,1Vafu{ß1,724,U709008-U, J I Slall Over-recovery23

G€neration Ræovery Riþr Docket No.22

Ækansas Public Se¡viræ Commission (APSC)21

20

43,8561,528,70(2,040,379593555,529PUCï Dockel No.40{43f9PUCT Dockel No.3736,fT8

Vegetalion Managemenl - Texast7

1ô

37,388,2362,124,50t22,913,133¡ß1 /,14G,t1¿58,17ô,864Agreement 0ocket No. U.æ7t¿'t5Turk Power Plant - LPSC Slipulated14

Refundable Consln ction lntere.st -13

12

408,754114,æl1 4íl / ¡1Ítl5æ,145Ugnite Mining Operation Ccowner oelenal11

10

706,5663.5t9.78¿2,8(.{JAVariûJs30,9r2Unrealized GainÀoss on Fonva¡d Cqnmlmenls9

I2,?59,47672,0m40742,83r,47ôAmodizalion of 44 yearc hginning in May 20107

and oækst No. 22276; PUCT oocket 37364 alllowed6

Commision ol Texas (PUCT) Dockel N0. 299385

Beslruc{urim Leg¡slation . Publh ulility4

Eam¡nqs Sutiect to Refund under Stale ol Texas3

2

5,358,æ9t83,15{,|,148,597

190/2826,623,838SFAS 109 0efe¡rpd Fedenl lncome Tax1

Balance at Endof Cuilent

Quartelffear

0)

tredits

(e)

AmounI

(d)

ACCOUntCredited

(c)

Balance at Beginingof Current

Quarter¡/ear

(b)

Descriplion and Purpose olOther Regulatory Liabil¡ties

(a)

Line

No.

DEBITS

1. Beport below the particulars (details) called for conce¡ning olher regulatory liabil¡lies, including rate order docket number, íf applicable.2, Minor items (5ölo of lhê Salance in Accounl 254 at end of period, or amounls less than $100,000 wh¡ch ever is less), may be groupedby classes.3. For Regulatory Uabilities being amortized, show period of amortizat¡on.

Year/Pêr¡od ol Beport

Énd of 2015/Q4Date of Reoort(Mo, Da, Yi)uSouthwestem Electric Power Company

(1)

{2}

OriginalResubmission

FERC FORM NO.1l&Q (REV 02-04) Page 278

1,834,340,8761,799.664,919TOTAL Electr¡c Operating Revenues27

93,307,14295,748.337TOTAL Olher Operating Revenues26

25

(457.2) Miscellaneous Revenues24

(457.1) Hegional Control ServÍce Flevenues23

65,7t4,08971,522,009(456.1) Bevenues from Transmission of Electricity of Others22

10,72ê,il6(456) Other Electric Flevenues21

(455) lnterdeparlrn ental Rents20

9,245,5269,54{',344(454) Rent from Electric Propêrty19

(45Í!) Sales of Water and Water Power18

2,681,834(45'l) Miscellaneous Service Revenues17

4,939,1474,782,909(,L50) Forfeited Discounts't6

Olher Operaling Flevenues't5r,801,033,7341,703,9.t6,582TOTAL Revenues Net of Prov. for Refunds14

-4,97õ,297"36,320,738(Less) (449.1) Provision for ñale Flefunds13

1,7S6,057,4371,667,595,8¿14TOTAL Sales ol Electricity12

376.å01,ôg2?5,584.831(447) Sales lor Resafe11

1,419,258,0831,392,011,013TOTAL Sales to Ultimaie Consumers't0

(448) lnterdepartmental Sales9

(,146) Sales to Railroads and FailwaysI(445) Other $ales to Public Authorities7

8,428,6868,150,658qCa+) Public Street and Highway Ughting6

358,668,767319,325,746large (or lnd.) (See lnslr. 4)5

464,406.939471,085,093Small (or Comm.) (See lnstr. 4)4

(442) Commercial and lndustrial Sales3

587,751,69'l593,449,516(440) Fesidential Sales2

Sales ol Ëlectricity1

Previous yeat (no Quartedy)

RevenuesOperating Fevenues Year

lo Oate QuarlerlylAnnual(b)

Tille of Account

(a)

No.Line

annual vðrsion of th6se pâgos. Do not report quarlêrly dalâ ¡n columns (cl (e), (0, and (g). Unbilled revEnuss and MWH

(f) and (g), on the basis of meters, in addition to lhê numb€r of tlat rats accounts; excêpl thal whgre separetê melêr rgedings arê âddêdbs counted for sach group ol met€rs added. The "average numb€r ol cu$lomêrs msans lh6 avèragê of tvrglve figures at the clos€ ot

4. lf increasês or decreases lrom prevíous períod (columns (c),(e), and (g)), aro nol derived from prevlously repo¡ted fgures, €xplain any lnconsistenciEs tn å footnole.5. Disclosê amounls of $250,000 or gr€ater in a footnots lor accounts 4St , 456, and 4522.

eacb month.lor billing purposos, one customsr should3. Flsport number ol customers, columns

prescribed account, and manufaclured gas revenuos in total.2. Heport below çeralíng revenues lor eachsEparatêly as requked ln tho annual verslon of these pages.related tó unbilled revenuEs need not be rsportod

1. The following ¡nstructions gên€rålly apply to the

ELECÏBIC OPEBATING REVENUES

Year/Period ot ReportEnd of 2015/Q4

Date of Reoort(Mo, Da, Yi)tt(2) nA Resubmission

This Reoort ls:(1) 6]nn orisínalName of Respondent


FERC FOFM NO.1/3.Q .12-Os) Pags 3ü)

Une 12, column {b) includes $Une 12, column (d) includes

-6,?22,100

-147,422

of unbilled revenuês.

MWH relating to unbilled revenu€s

14627,250529,81828,644,88227,269,404

13

12527,25(529,9'lg28,644,88227,269fiO

t11f1310,3s6,'t859,406,788

t0527,23i52S,80518,288,69717,862,612

II7

651€51580,38?80,390

57,0617,0765,900,73'l5,369,988

472,78¿73,1905,996,4456,076,475

3

24æ,872445,W46.311.1340,345,759

'l

UneNo.Previous Ye€r (no Q€rtêrly)

{s)

Curent Year (no Quarlerly)(0

Amounl Pfoviot¡s year (no Quafleíy)

(e)

Year to Dale Q¡aiefy/Annual

(d)

ÂVG.NO. CUSTOMËRS PÊB MONTHMEGAWATT HOURS SOLD

ln afootnole.)7. Sêê pages 108:109, lmpodånt Changes Ðuring Perlod, frcr lmportalt nsur lerilory åddêd and importãnt ral€ lncrgass o¡ decreases.8. For Llnss 2¡,5,ard 6, see Page 304 lor amounìs reladng to unull€d rÞvenus !y åccoünts.9, lnclude unmet€red sales, Prwide detalls of sr¡cfi Sales in a footnote,

Year/Pedod of ReportEnd ol 20'15/Q4(1 (Mo,

(21 A Resubmission ttName ol Bespondent

Southwestem Electrio Power Company

FERC FORûi NO,1/3.O {REV. 1245) Pags 301

TA


20ßta4


ttThis Report is:

t1) X An Original{4 _A Resubmission

Name ol Respondent

Soulhwestem Eleclric Power Company

Customer revenue, conn€cts, reconand olher charges billed to cuslomers. (Applies to current

services

Account 456.0 Other Electric Revenues:

Royalties - Nonaffiliated

Electric Operations - Nonaff iliated

Electric Operatíons Transm ission related - Nonafliliated

3rd Party Plant Operations íncluding overhead related

Other Misc Revênue - ltems < $250,000

Total

2Aß 5

(3,'t 65,745.76) {1,543,074.1 3)

(1,271,276.29) (869,439.12)

(4,217,991.56) (3,991,000.99)

20,615.'t8 (5,597.14)

(10,72ô,546.12) (7,484,519.31)

FORM o.1 450.1

0.077Í((1,392,011,01317,862,612TOTAL,liì0.042i((-6,222,100-147,422Total42

0.o77((€1.398.233.11fTOTAL B¡IIed41

4{

39

38

37

36

35

utr32

3l

3{

0.093714,1 1CM9,O24593,449,5166,335,759TOTAL Resídential Sales2Ê

2¿

-54,684Duplicate Customer Adiustrnent2'l

2e

-1,884,508Flate Reconcillatlon Rider2ê

-609,788Demand Side Managementl RER24

2,080,770Þefened Fuel2l0.0590-1,718,39¡.25,12'tUnbilled Revenue4

0.1285n218,044r.789,28(13,{¿1Res¡dential Ughting PUAL21

0.0686492,5n2ô814,02¡'t2,w7Master Melered Apartments2C

0.091414,774148,587200,860,94!2,195,183RS1S

TEXAS18

17

o.0331-801,40€-24,214Unbilled Revenuef6o.2'12Ê71029,4114,437,99120,875Residential L¡ght¡ng PUAUOL15

4.075/.f ,042,3082e2,043,39€27,10QMaster Meteredu0.089€21,47Ê4€92,3361,031RWH1Í

0.096414,8il2A2,4æ289,867,1453,007,267RS12

LOUISIANA11

1(

-5,685,97€Defened & Oolet Hills Fuelt0.0363-59ô,64€-16,454Unbilled Revenue€

0,21117867,2æ1,199,4{tC5,68€Residential Lighting PUAUOL7

0.0751353,556239,0213,1 82Masler Metered Apartmentse

0.0849't4,09520,45824,479,217288,35iFlectrlc Heating Applianceç

0.0928ß."t2477,41477,Q42,üee30,r42Flesidential Service (RS)4

ARKANSAS

¿

1

'l{üfifiË"olo"'(f)

II ùAItJS

{stomer^wnPer (ofrtevgtìue

(c)

fvlYv'¡ è(Jr(]

(b)

t\utilt,gf a¡t(¡ ¡ il,tt Qt nalt suf le(¡ule

(a)

unsNo.

1. Report below for each rale schedule in etfect during the year the MWH of eleclricity sold, revenue, average number ol customer, aveÉge Kwh percustomer, and average revenue per Kwtr, excluding date for Sales for Resale which is reported on Fages 310-311.2. Provide a subheading ånd total lor each prescribed operatíng revenue acçounl in the sequence lollowed in 'Ëleqtric Operating Revenues,' Page300-301, lf tho sales under any rate schedule are classified in more lhan one revenue âccount, Ust the rate schedule and sales dala under eachapplicable rev€nue account subheading,3" Where the same customers are seryed under more than one rate schedule in the same revenue account class¡fication (suoh as a general res¡denlialschedule and an off peak uater heating schedule), Ìhe entries in column (d) lor the special schedule should denote the duplication ¡n number of reportedcuslomers.4. The average number of customers should be the number of bills rendered duilng the year divided by the number of bill¡ng periods during the year (12if all billings are made monthly).5. For any rate schedule having a fuel adjustrnent cláuse stâte in a footrlote the estimated additional rev6nuo billed pursuant thereto.ô. Report amount of unbilled revenue as of end of year lor each applicable r€venue account subheadlng.

SALES OF ELEQTFICITY BY RATE SCHEDULËS


End ol 2015/Q4Date ol Beoort(Mo, Da, Yi)tl

ïhis Reoort lsr(1) [¡nn origlnal(2) ¡A Resubmissìon

Name of Respondenl


FEñC FOFM NO.1 (EO.12-95) Page 304

0.077€((1,392,011,01Í17,862,811TOTAL43

((.8,W,,10(-147,42iTotal Unbilled Rev.(See lnstr. 6)42((1.398.233.11rTOTÁL B¡II€d41

0.077583,02373,19C471,125,00C6,076,47€TOTAL Comme¡cial Sales4t-35,¡14€ûuplicate Customer Ád¡usünent3ç

3t-1,502,961Rate Recolrcilíation ñidera'¡

-2A0,62ÍÞemand Slde ManaçmenV RER3(

1,942,28tÐeferred Fuel350.0674-1,947,77t.19,99tUnbllled Revenuea0.10702,Q5115,2513,354,81931,36CCommercial Llghting PUAL330.07188,14{6ç40,355562Commercial Lighting CSL\,¿0.078018,26€1,4s02,065,82326,48fMunicipal Service MS310"0605101,49€8r33,76f ,99062,217Muníoipal Pumping MPS300.04{,970,996,00(f3,473,83770,996Ughting & Power Seryice LLPæ0"07a2232/&7,810127,358,4251,81s,514Lighting & PowerService LP280.07011,032,7147506,7847,n9Coüon Gin CG270.067.1s3,17(t3€w2,7174,512Recreational Ughtíng260.097313,29420,37226,339,t61274,834General Seryice GS2â

TEXAS24

230.0268€59,932-13,442Unbilled Flevenue220.'153s2,A3411,9213,73f ,98624,253Commercial Lighting PUAUOL21

0.r23918,86€1,0372,423,9419,567Municipal Sorvice MS2C

0.0692153,16t5706,037,45687,30€Municipal Pumping MPS'lco.u1ê134,00C129,69€1g{lrrlgation Sì/c18

0.0765724,43t2,647141,1 80,1 391,845,143Llghting & PowerSeryice LP11

0;102S49,48r4,2232'1,514,159209,078General Ughthg & Power GLP1€

0.12ôs16,97€r6,52335,602,498280,481General Servlce G$'t€o.105€3,28C382132,47ê1,254Etectric Sígn Service ESS'14

LOUISIANA1e

12

-6,631,882Defered & Dolet Hills Fuel1t0.021€-221,07310,394Unbilled Flevenue1(0.f39s2,12(8,2772,454,94317,54€Commercial Lighting PUAUOLC

0.086412,31(474504,22t5,835Munícipal Servlce MSt0.076453,01{2711,097,92014,36:Munícipal Pumping Servhe MPS0.0685679,51€1,41365,808,1I7960,156Llghtlng & Power Service LFf0.084233,31€95266,5353,16{Becreat¡onal Light¡ngt0.086€23,84r15,19431,452,955362,29€General SeliceGS4

ABKANSAS

COMMERCIALSALES1

Tütffb"ol¿"'(f)

Þatestlomer

ñwnPer (of

ñevenue(c)

fvlvvÍ a ìtolo

{b}

r\uf f ¡uef a¡u r ¡lle ot HaIe scneoule

(a)No.

Name

Southwestem Electric Power Company(2) Resubmission tl Endof ?q1g/44

1. Report below for each rate schedule in effect during the year lhe MWH ol electrlcity sold, revenue, average number of cuslomer, average Kwh percuslomer, and average revenue per Kwh, excluding dale lor Sales for Resale which is reporled on pages 310.91 .1.

2. Provide a subheading and tolal for each prsscriþed operating revenue account in the sequence followed in'Eleclric Operating Revenues,' page30G301. lf lhe sales under any rate scheduls ars classified in morE than one revenuê acrouÍ1, Lisl the rate schedule and sales data under eachapplicable reventrr account subheading.3. Where the sams cuslomers are served under more than one rate schedule in the same revênue account classilication (such as a general residentialschedule and ân ott peak water heating schedule), lhe êntriês in column (d) lor the special schedule shoufd denote the duplicât¡ön in number of reportedcuslomers.4. Theaverage number of customers should be the number of bills rendered during the year divided by the number of billing periods dudng the year (12if all billings are made monthly).

schedule having a fuel adjusùnqnt clause state in a fóotnote the êstimaìed additíonal revenue billed5. For any rate pursuant lhereto.6. Rèport amount of unbilled rcvenuê as of ênd ol yêaf for each aPplicâble fevenue account subheadíng.

FERC FORM NO.1 (ED.12-95) Page 3{,4,1

o.oTtÊ((1,392,01 1,01317,8ô2,61iTOTAL4{'0.0422((-6,222J0A.147,422Total Unbilled Rev.(See lnstr. 6)42o.477Ê((1.398.233.11iTOTAL BiIIEd4t

,10

âô0.0596757,48€7,076s19,325,74C5,35S,S88TOTAL lndustrial Sates38

-3,16SDuplicate Customer Adjustnent37

36

.145,3trCÞemand Side MânagemenV RERâÊ2,695,961Deferred Fuel34

o.0444-941,987-21,æ(Unbilled Bevenus33

0.10202,83€1,18(341,3943,34tlnduslrial Ught¡ng PUALù¿

0.0528'1,988,00c¿209,86C3,S7(As-dvailable Standby Service3t0.0490429,56393€'19,772,92Í,103,36(O¡lf¡eld - Large lndustrial OU3C

0.0595210,666,00C112,U2,434210,66€Steel Mill LSS2E

0.080621,A72,WC11,721,5U21,37tMetal Melling Service MMS - 69kv28

0.06116,991,500€3,418,61155,932Metal Meltlng $ervice MMS2'1

o.072580,502,50C¿1't ,879,60S161,009Backup Mainlenance, AAS2ê

Lighling & Pwr Svc LLP - with2â

0.0481159,336,00Cç38,334,109796,68CLlghting & PowerService LLP24

0.047428,893,3334,112,31286,680lnlemlptible Power Serviceta0.0642547,8042,r0774,150,.t361,1il,224Lighting & Power Service LP¿¿

0.09799,5831,38?1,300,54213,â91General Service G$21

TEXAS2C

19

0.0204-142:l7i-6,9SUnbilled Revenue18

0.15142,293968336,'t7C2,22Clndustrial L¡ghting PUAUOL17

0.05,1{l150,916,00018,'t89,52€1s0,91€Large Ughting & Power LLP16

0.06741,855,32ç45356,638,095840,464L¡ghting & Power Service LP15

0.097058,48€70t4,009,25241,351General Lightlng & Power GLP14

0.135C12,63f861't,469,15410.881Gên€ral Power Services GPS13

LOUISIANA12

11

.6,914,765Deferred & Dolet Hills Fuel1(

0"0r24-ô5,11C-5,2ô1Unbilled Revenue€

0.'t3162,U91,01€381,9012,903lnduslrial Lighting PUAUOL€

0.052€281,975,00C114,884.049281,975Pulp & Pâper Mill P&PMI

0.0523134,469,00C¿14,061,945268,93tLarge Ughting & Power LLP€

0.06382,5ô,302,878882,06,|Ughlhg & Power Service LPF

0.&3183,245364982,39¿1,181General Service GS4

ARKANSASq

INÞUSTRIAL.SALES2

1

Tü7f;91á*{f)

ÞateFstomer

nwnPer (

nevsnue(c)

'vlvvn ùOrq

{b)

t.{uf f t¡Jg¡ öilu I lltt, ul ñale ¡tcf ¡cuutt,

(a)

LtneNo.

1, Heport belo\,y for each rate schedule in eflect during the year the MWH ol electricity sold, revenue, average number ol customer, average Kwtr percuslomer, and average revenue per Kwtr, excluding date lo¡ Sales for Resal€ whlch is reported on Pages 3'10-31 1 .

2. Provide a subheading and total lor each prescribed operaling revenue account in the sequence followed in 'Electric Openting Revenues,' Page30G3Ot. lf the sales under any rale schedule are classified in more lhan ons revenue account, Usl the rate schedule and sales data under eachapplicable revenue account subheading.3. Whe¡e the same customers are served under more lhan one rate schedule in lhe same revenue acöount classiticalion (strch as a general residentialschedule and an oft peak water healing schedule), the entries in column (d) for the special schedule should denote the duplication in number of reportedcustomers,4. The average number of customerc should be lhe number of bills rendered dudng the year divided by lhe nurnber of billing peilods during the year (12il all billings are made monthly).5. For any rate schedulô having a luel adlustrnent clause state in a loofrote lhê estimated additional revenue billed pursuant lhereto.6, Beport amount of unbilled revenuq as ol end ol year lor each applicabla rêvenue account subheâdíng.

{'ALES OF ELEÇTRICITY AY RATE SCI{EDULES

Year/Per¡ci(l ol Fleport

End ot 2O15lQ4Date of Reoort(Mo, Da, Yi)lt

This Reoort ls:(1) 5]en orisinal(21 ¡A Resubmisslon

Name ol Respondenl


FEBC FORM NO,1 (ED. 12.95) Pags 304.2

0.077ç((1,392,011,01t17,862,61'TOTAL{t 0.4422((.6,222JAC-147,4UTotal Unbilled Rev.{See lnstr. 6)42o.o77Ê((1.398:2*1.11t1e.0T0.034TOTAL BiIIEd41

4(

âc

3t

3i36

35

u33

32

31

3C

29

28

21

2Ê

2Í

24

23

22

21

0.101{'r56,09i5158,150,65t80,390TOTAL Public Street & Highuray Ltg2t1€

-3€Rate Reconciliallon RiderI627,814Ðefened Fuel17

0.0757-13,55€"17SUnbilled Flevenue16

o.09?7158,65çß22,822,23528,87eMunicipal Ughting ML't5

TEXAS14

13o.ú77-45e-60Unbilled Revenue120.087s299,59?1343,528,05(40,146Municipal trrghting ML11

LOUISIANA1C

0

-58,29(Delerred & Dolet Hills FuelI0"1 123-13,58€-121Unbilled Flevenue7

0.15855e,93Í't991,858.48i11,728Municipal lJghting ML€

ÂRKANSASI

4

LIGHT¡NG

PUBLIC STFEET & HIGHWAV2

I

ìtate5stomer^YyfiPer (

,w€raqg Numoerof ciå\omers

ñEVef tue

(c)

lvlvYn ÞOtq

(b)

l\umQef anq I m€ oI Hate scneoule

(a)No.

1' Repott below for each ¡ate schedule in efect during thê year the MWH of electricity sotd, revenue, average number of customer, average Kwh percustomer, and averãge revenue per Kwh, excluding date for Sales for Resale which is reported on pagês 910.911.2' Provide a subheading and totallor each prescribed operaling revenue account in lhe sequence followed in 'Elect¡c Operating Revenues,. page30ù'301' It thê sales under any râte schedule ãr€ classified in more than one revenuê âccount, Ust the rate schedule and sales dala under eachapplbable revenue account subheadíng.3' Where the sâmê ôustomers a¡e served under rnore than one rate schedule in the same revenue acÆount classilioation (such as a general residentialschedule and an off peak waler heating schedule), the €ntries in column (d) tor the special schedule should denote the duplication in number of reporledcustomers.4' The average number of customers should be Úre number of bills rendered during the year divided by lhe number of billing periods during the yeat 112if all billlngs are made monthly).5' For any ratè schedule having a fuel adiuslment clausê stale in a footnote lhe estimated additional revenuê billed pursuant thereto.6' Report âmount of unbilled revenue as of ênd ol year for êach applicable rêvenue account subheadlng.

$ALËS OF FLËCTRIC]TY

Year/Period of ReportEnd of 2A15lQ4

Narne

Southwestem Elecl.ic Power Cornpany ) An (Mo, Da,

t/{2) A Besubmission

FeRC FORM NO. t (ED.'12-95) Page 304.3

FOOTNOTE DATA

Year/Period of Heport

2015/Q4


ll

Report is:X An Original

A

revênue billed pursuant to the fuel adjustment ås

mercial

Street &Highway Lighting

Arkansas

$36,470,519.89

$43,797,882.31

ç45,237,757.72

$378,6ô4.69

!ouisiana

$96,361,269.83

$77,408,813.04

$31,960,079.06

$1,262,999.90

Texas

$64,348,563.19

$66,¿187,044.94

$8I,547,245.51

$830,463.70

d

450.1IFËRC FTRM 1

000Total

00cSublotal non-FQ

00cSubtotal HQ

47.247.448120BQof Texas (ERCOT} (1)14

TerJ â - Flânlric Flâliâhilitu COunCil1.3

108.€110.4109.7111RQRayburn Country Ëlectric Coop, lnc(t,2)12

625^ç695,480129RQEIEC/NTËC (1)11

120.C120.C12Q119RQCooperative, lnc (NTEC) (1)10

Northeast Texas Electrico85.71 10.'61.8113RQCoopetalive, lnc (FIEC) {1)8

East Texas Electric7

14.3f 6,€14.8127RQCity of Prescott, Arkansas (1)6

36.C37.€35.6128RQCity of Minden, Louisiana (1)5

56.€58.C58.5125RQCity of Hope, Arkansas (1)4

133.C150.811ç126ÊQ3

2

Requirements Service (RQ)1

AveraoeMonthly CPI)emanc

(f)

l\veraoeMonthly NCË Demanr

(e)

AveraoeMonthly ËillingDemand {MW)

(d)

FERC RateSchedule o¡

Tariff Number(c)

StatisticalClassifi-cAl¡on

(b)

Name of Cornpany or Public Authority

{Foolnote Aff iliations)

(a)

LineNo.

Actual Demand (MW)

1. Report all sales lor resale (i.e., sales to purchasers olher than ultimatö consumer$) transacted on a seltlêment basis olher thanpowêr êxchanges during the year. Do not report exchânges of electricity ( i.ê., transâctions involving a balancing of debits and oreditsfor energy, capac¡ty, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on thePurchased Power schedule (Page 326-327r.2. Enler the name of lhe purchaser in column (a). Do note abbreviate or truncalê lhe name or use âcronyms. Explain in a footnote anyownership interest or afliliation the respondent has with lhe purchaser.3. ln column (b), enter a Slalistical Classilication Code based on the original conlractual lerms and condilions of lhe service as follows:RQ - for requirements service. Requiremenls seru¡ce is service which the supplier plans to provide on an ongoing basis (i.e., thesupplier includes proiected load for this serv¡ce in its systom resouros planning). ln addition, the reliability of reguirements service mustbe the same asf or second only to, thê supplier's servicê lo its own ullimate consumêrs.LF - for tong"lerm service, 'Long-term'means five years or Longer and 'firm' means lhat service cannol be interrupted for economicreasons and is intended to remain reliable even under adverse conditions (e.9., lhe supplier must attêmpt to buy emergency energyfrom third parlies to maintâin deliveries of LF service). This category should ñot be usäà for Long-term firm service whlch meets thedelin¡lion of RQ sen¡íce. For all transactions identified as LF, provide in a footnote the termination dale ol the contract defined as theearliest date that either buyer or selter can un¡laterally get out of lhe contract,lF - for intermediate-term firm service. The same as LF service except that 'intermediate-term' means longer than one year but LeEs

lhan five years.SF - for short-term lirm service. Use lhis caiegory for all firm serv¡ces where the duralion ol each period of commitment for service isone year or less.LU - for Long-term service irom a designated generating unit. 'Long-term' means live years or Longer. The availability and reliability ofservice, aside lrom lransmissíon constiaints, must match thê avâiläb¡l¡ty and reliability of designâted unil.lU - for intermediale-term service from a designated generating unit. The sarne as LU service except that'intermediate-terrn' meansLonger than one year but Less than five years.

Year/Period ol ReporlEnd ot 20151Q4

Date of Reoort(Mo, Da, Yi)IISouthwestem Etectric Power Company

(1) An OrigìnalA Resubmission

FERC FORM ilO. 1 (FD. 12.90) Page 3't0

275,584,8i¡t9,876,872179,743,98585,963,9749,406,78{l

82,711,4ç46,743,27776,008,18703,1 58,295

192,873,3673,173,595103,735,79885,963,9746,248,493

1412,651,s2ç7,558,ô305,092,89€223,209

13

1233,9'1s,7213,049,7il17,2t9,14813,656,825511 ,398

1120,404,3099,306,4221 1.097,8873,otr,370

1024,26ô,91610,678,42'l13,588,495320,081

9

I18,153,8569,770,2258,383,631416,135

7

64,718,80t2,997,1721,721,63887,46't

59,179,47.t123,84'l5,000,4{144,055,202155,486

416,9'16,40110,645,52'l6,270,88C302,107

334,826,61421,ô70,18613,156,428667,51'l

2

1

LineNo.

Toral ($)(h+i+i)

(k)

Other Charges($)(il

Ënergy Charges{s)(Ð

Demand Charges($)(h)

MegaWatt Hours

Sold

(s)

REVÊ,NUE

OS . for other service. use this category only for ihose services which cannot be placed in the above-defined categories, such aç all

non.firm service regardless of the Length of lhe contract and service lrom designaled units of Less than one year. Oescribe the nature

of the service in a footnote.AD . for Out-ol-period adjustment. Use this code for any accounling adjustmenls or'true-ups'lor service provided in prior reportingyears. Provlde an explanation in a foolnote for each adjustment.i. Group requirements RQ sales togelher and report them starting at line number one. After listing all FIQ sales, enter'Subtotal - RQ'in column (a). The remaining sales may then be listed in any order. Ënter'sublotal-Non-RQ' in cofumn (a) after this Listing' Enter'Total" in column (a) as the Last Line o{ lhe schedule. Fìepod subtotals and total for columns (9} through (k)

5, ln Column (c), idintify lhe FERC Rate Schedule or TariÍÍ Number. On separate Lines, List all FERC rate schedules or tarif{s underwhich service, as identified in column (b), is provided.6, For requirements ËìQ sales and any typê of-se¡vice involving demand charges imposed on a monthly (or Longer) basis,.enler the

average nionthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average

monthly coincident peak (CP)demand in column (f). For all other types of service, enter NA ín columns (d), (e) and (f). Monthly NCP demand is the maximum

metered hourly (6o-minute integration) demand ¡n a month. Monthly CP demand is the metered demand during the hour (ôO'minute

integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (l) must be in megawatts'

Footnote any demand not stalêd on a mêgawâtt basis and explain,7. Report in column (g) the megawatt hours shown on bills rendered lo the purchaser.8. Reþort demand charges in column (h), energy charges in column (i), and the lotal of any other types of charges, including

og1"e¡-period adiustments, in column 0). Explain in a footnote all components of the amount shown in column fi). Report in column (k)

the total charge shown on bills rendered to the purchaser.9. The data iñ cofumn {g) through (k) musl be subtotaled based on the RO/Non-RQ grouping (see instructíon 4), and then lotaled on

tha Last .line of the schédule. The 'subtotal - RQ' amount in column (g) must be reported as Requirements Sales For Resale on Page

40'l , line 23. The 'subtotal . Non-RQ' amounl in column (g) musl be reported as Non-Requìrements Sales For Resale on Page

401 ,iine 24.10. Footnote entries as required and provide explanations {ollowing all required dala.

FOR RESALE (ACCOUnI 447)

Year/Period ot Report

Ënd of 2015/Q4Date ol Report(Mo, Da, Yr)

e(1)(2)

An OriginalA ResubmissionSouthwestem Electric Power Com pany

FERC FORM NO. 1 (ED.12-90) Page 311

00(Total

00cSubtotal non-BQ

0ocsubtoral RQ

14

N.ÁNANANASFSPP Merchanl Sales (5)13

NANÁNANAosSoulhwest Power Pool (SPP) ta12

NåNANANAos(ERCOT) (6,8)11

Electric Beliability Council of Texas10

NANÁNA228osAËPSC (3,4)9

NANANA228osAEPSC {3,8}INANANI228OSCorporation (AEPSC) (3)7

American Electrio Power Service6

Non-BQ5

4

3

104.€'119.46C110ROof Texas, lnc. $ex-La) (1)2

Tex- La Electric Cooperaliv€'|

AverâoeMonthly CPTemanc

(0MontniyÑb?beman,

(e)

AveraoeMonthly Ëill¡ngDemand (MW)

(d)

FERC FateSchedule or

Tariff Number(c)

Slat¡sticalClassíli-cation

(b)

Name of Company or Public Aulhority(Footnote Atliliations)

{a}

LineNo.

Actual Demand (MW)

1. Bepon all sales lor resale (i.e., sales to purchasers other than ultimate consumers) transacted on â settlement basis other thanpower exchanges during the year. Do not report exchanges ol electricity ( i.e., transaclions invofving a balancing of debits and creditsfor energy, capacity, etc,) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on thePurchased Power schedule (Page 326-327).2. Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote anyownership interest or atfiliation the respondent has with the purchaser.3. ln column (b), enter a Statistical Classification Code based on the original contractual lerms and cond¡tions of lhe service as follows:RQ - lor requirements seruicê. Requiraments sêrvice ís se¡vice which tho supplier plans to provide on an ongoing basis (i.e., thesupplier includes proJected load for lhis servioe in its system re$ource planning). ln addition, lhe reliability of requirements service mustbe the same as, or second only lo, the supplier's service to its own ultimate consumers.LF - for tong-l€rm service. 'Long-lêrm' means live years or Longer and 'firm' rneans lhat service cannol be interrupled for economicreâsons and is intended to remain reliable even under adverse conditions (e.9., lhe supplier must aïempt to buy emergency enêrgyfrom third parties 1o maintain deliveries of LF service). This category should nol be used for Long-term lirm service which meets thedelinilion of RQ servíce. For all transactions identilied as LF, provide in a lootnote the termination daìe of the contracl delined as theeadiest date that either buyer or setter can unílaterally get out of the contract.lF - lor íntermediate-term firm service. The same as LË service except lhat 'intermediato-term' means longer than onê year but Less

than five years.SF - for short-lerm firm service. Use this câtegory for all lirm services where the duration of each period of commitmenl lor service isone year or less.LU - for Long-term service from a designated generating unit. 'Long-term' means live years or Longer. The availabilig and reliability ofservice, aside from lransmission constraints, must rnatch the availability and reliability of designated unit.lU - lor intermediate-term service lrom a designated generating unit. The same as LU service excepl that'intermediate-term' meansLonger lhan one year but Less than five years.

Year/Period of ReportËnd of 20ts/Q4

Date of Reoort(Mo, Da, Yi)lt

þrt ls:An OriginalA Resubmission

Southwestem Electric Power Company(1)

FERC FORM NO. 1 (ED. 12-90) Page 310.1

275,584,8Í¡19,874,U2'179,7tf¡,98fi85,963,9749,406,788

82,7't1,4646,703,n776,008,18703,158,295

192,873,3673,173,595103,735,79885,963,9746,2ß,493

14

1310,555,23710,s55,23743ít,38f

1271,211,1015,758,15165,452,9502,714,875

1T1, 1 14,1 2t1,1 1 4,1 2€

10

I155,13€155,13€10,039

I79,f97-79,197

7-244,939-244,939

6

5

4

3

217,839,73C8.899.6398,940,091500,735

1

UneNo.

Total($)(h+i+i)

(k)

Other Charges{$)(i)

Energy Charges($)(i)

Demand Charges($)th)

MegaWatt Hours

Sold

(s)

REVENUË

OS - for other service. use this category only for those services which cannot be placed in the above-delined categories, such as all

non-tirm service regardless of the Lengih of ihe contract and service from designated units of Less than one year. Describe the nature

of the service in a lootnote.AD - lor Oul-of.period adjustment. Uss this code for any accounting adjustments or'true-ups'for service provided in prior reporting

years, Provide an explanation in a lootnote lor each adjustment.i. Oroup requkemenìs RQ sales together and reporl them starting at line number one. After lísling all RQ sales, enter'Subtotal ' FIQ'

in columï (ai. fne remaining sales may then ¡e iisted in any order. Enter'subtotal-Non-HQ' in column (a) after this Listing. Enter

'Total" in coiumn (a) as the Last Line of the schedule. Report subtotals and toläl lor columns (9) through (k)

5. ln Column {c), ìd'entify the FFRC Râte Schedule or Tarift Numb'er. On separate Lines, List all FERC rate schedules or tariffs under

which service, as idenlified in column (b), is provided.6. For requirómenls Re sales and any type of-service involving demand charges imposed on a monthly (or Longer) basís,.enter ihe

average nionthly billíng demand in column (d), the averâge monthly noncoincident peak (NCP) demand in column (e), and the average

monthly coincident Peak (CP)demand in column it). for ali other types of seryice, enler NA in columns (d), (e) and (f). MonÌhly NCP demand is the maximum

metered hourly (60-minute integratioñ) demand in a month. Monthly CP demand is the metered demand during the hour (ôO-rninute

integration) in wi.r¡cn the supplier's system reaches ils monlhly peak. Demand reported in cslumns (e) and {l) rnust be in megawatts'

Footnole any demand nol slatêd on a megâwâtl basis and explain.7. Heport in column (g) the megawatl hours shown on bills rendered to the purchaser,

e. Rebort demand cnárges in cälumn (h), energy oharges in column (i), and lhe tolal of any other types of charges, includìng

ou1-s¡-period adjustmenis, in column fi). Explain in â footnole all components of the amount shown in column fi). Heport in column (k)

the total charge shown on bills rendered ìo the purchaser.9. The data ii column (g) lhrough (k) must be iubtotaled based on the RC/Non-RQ grouping (see instruction 4), ând then totaled on

the Last .line of the schedula. The''sublotal - RQ' amount in column (g) must be reported as Requirements Sales For Resale on Page

401, line 23. The 'Subtoìal - Non-RQ' amount in column (g) must be repodod as Non-Requirements Sales For Resale on Page

401,iine 24.10. Footnote entries as required and provide explanations following all required data.


End of 20151Q4Date of Reoort(Mo, Da, Yi)tt

Name{1)

{2}

OriginalSouthwestern Electric Power Company Flesubmission

FERC FOÊM NO.1 tED.12-90) Page 311.1

FOOTNOTE ÞATA


2015tQ4

Date ol Repoft{Mo, Da, Yr)

ttThis Réport is:(1) X An Originalet A Flesubrnission



( 1)

( 2',

( :¡( 4)

( 5)

( 6)

t7t(8)

Includes custgmer charge

Wholesale transmission

Respondent is an affiliaEed company of American Eleccric Power Sêrvice Corporat.ion

Bookout margins, net

Merchant sale

Nel t.rading purchases & sales within the Electric Reliability Council of Texas(ERCOT}

Net tradingr purchases & sales within the Sputhweçt Power Pool (SPP)

Realizatj.on System Integration Àgrêement Sharing

FORM NO.'I 1 4S0.1

TOTAL Power Prodtclion Exoenses-Hvdraulic Power ltot ol lines 50 & 58)59

TOTAL ¡¡laìnlenance (Enter Total ol lines 53 thru 67)58

(5,15) Maintenanca of Miscellaneous Hvdraulic Plant57t544) Maintenanco of Ëlecldc Plant56{543) Maintenance ol Reservoirs. Dams. and Waten¡avs55

(542) Maintenance of Structures&{54T) Malnentance Supervision and Ensineering53

Malntenance52C, Hydraulic Power Generatlon (Contlnued)51

TOTAL Operation tËnter Total ol Unes 44 thru 49)50{540) ffents49{539) Miscellaneous Hydraulic Power Goneration Expenses48

(538) Electric Expenses47

(5371 Hvdraulic Exoenses46

(536) Waler{orPower45{535} Operation Supervfsion and Ênqineerins44Operation.13

C. Hvdraulíc Power Generation42TOTAL Power Prodætion Expenses-N$. Power (Ëntr tol lines 33 & 40)41

TOTAL Maintenanc€ (Enter Total of lines 35 thru 39)40

(532) Maintenance of Miscellaneous Nuclear Plant99{531) Maintenance ol Eleclric Plant38

(530) Maintenance ol Reactor Plant Equ¡pment37

(529) Maintenance ol Stnrctures36{528} Maintenance Suoervision and Enoíneerino35Mainlenance34TOTAL Operation (Enter Totalof línes 24|hru 32)33

(525) Fents32

(524) Miscellaneoug Nuclear Power Ëxoenses31

(523) Efeclric E¡oenses30{Less) {522) Sleam Transferred-Cr.29

(521) Steam lronr Olher Sources28

(520) Steam Expenses27519) Coolants and Water26

{5181 Fuel25{517) Operation Supervision and Enqineerinq24Operation23B. Nuclear Pourér Generalicn22

820.939,316714,801,191Power &21

84.726.69STOTAL Maíntenance (Enter Total ot Lines 15 thru 19)209.228.3797.823.386(514) Maintenance of Míscellaneous Steam Plant19

1s.170.05515,651.ô96(513) Maintenance of Electric Plantt846.742.59746.9f 3.697{512) Maintenånoê ot Boiler Plant17

7.160.0877.126.123(511) Maintenance of Slructures166.427.641(51 0) Malntenance Supervision and Ênqineerinq15

Maintenance't4136,212,617ô31,184,302TOTAL Operalíon (Enter Total of Lines 4 thru 12)13

-73.237190.262(509) Allowances12537.691520,200(507) Rents1'l

15,059,04417.147.3ô9(506) Miscellaneous Steam Power Expenses10

10.47S.823{505) Eleclric ÊxpensesI(Less) (504) Steam Transferred-Cr.I(503) Steam lrom Other Sources7

16.330.31517.790.151{502) Steam Expenses6

679,23I.9{t569,7/0.415(5011 Fuel5

14.647.03816.225.241(500) OoeratÍon Suoervision and Enqineerinq4

OperatíontA. Steåm Power Generation2

1. POWFR PRODUCTION EXPENSÊSI

Amount forPrevious Year

(c)

Accounl

(a)

Line

No,

lf the amount for previous year is not derived from previously reporled figures, êxplain in footnote.


End ol 2015/Q4Southwestem Electric Power Company(1)(2')

An OriginalA Resubmission tt

FEFC FORL NO.1 (ED. 12.93) Page 320

80.472.721s6.781.200TOïALTransmisslon Expe¡ges ffotal ol llnes 99 and 111)1121 11ol lines 101 thru I111

11t.202439,9341f0258657(572) Maintenance of Underground Unes109

6.V29(571) Maintenance of Overhead Unes'tû82.257.9æ(570) Mq!¡lenance of Statlon Equipmenl107

Maintenance Transm1062't.glt&].988(569.3) Måintenance ol Comm¡.rnlcatlon Equípment105

925,982ol104818-155{569.'l} Maintenanqe of Computer Hard'u¡are103

31.630(5Sg) Maintenânce ot qtryqtures'lv¿8142(568) Maintenance Supervision 4qd Ëngineering'101

100)TOTAL Operation {Enter Total ol lines 83 thru gt99

34.52t(567) Flents984.620.7s(566) Miscellaneous Transmissþq Expensess7

'l61(565) Transmission of Electricity by Ohers9622607(564) Undergroulq Unes Ëxpenses95

1 80,799(5ô3) Overhe"æL l::l!es Expenses944&-17793

,|1.065.351and Services92(561.7) General¡on lnlercþnnection Studies91

2g.6) Transmission Studies902to.aAA244.1W(561.5) Reliaþility, ?lanñing and Standards Deyelopment89

10.408.7131't .1 10.852(561.4) Schedullng, $ystq! Control and Dispatch Services88429and87

13.246.960and864,0.o5420.938(561.1) Load85

843.788.f 8l83

Operation822. TBANSMÍSSION EXPENSËS81

1IAL ol lines 21 &80209.775.149137.524.369TOIAL Other Power Supply Exp (Enter of lines 76 thru 78)79

1.055.3994.946.t23(557) Other Expenses7811.827.786(556) System C¡ntrol and Load ÞispatchinqT7

206.760.584130.75C(555) Purchased Power76Power Supply Expenses75

11.981.416tÊ^10.497TOTAL Power Production Expenqqs-Other Power (Enter Ïot of 67 & 79)741.173.458Tolal73

21,122(554) Maintenance ol Miscellañeous Other Power Generation Flant721.152.3{¡6Maintenance and Ëlectric Plant71

(552) Ma¡ntenance of $truclures70and6S

Mainlenance6811 19,324,396TQTAL Operation (E¡ter Tolal of lines 62 thru 66)67

(550) Renls66

(549) Miscq|laqeous Olher Power Generation Expenses65255.713219,20',|,(548) Generation Ëxpenses64

9.t05.195(547) Fuel6ftand62

Operat¡on61

Ð. Other Power Generation60

lf the arnount for is not derived from in lootnote.Account

No.

Year/Perioct of ReportEnd ot 20'15/Q4

Ðate ol Reoort(Mo, Oa, Yi)lt

This Reoort ls:(l) E:lAn or¡s¡nal(21 l-lA Resubmission

Name of Respondent


fEFC FORM NO. r {Er}. 12-93} Page 321

22,60ø.,151r.991TOTAL Customer Accounts Expenses (Iotal of llnes 159 thru 163)16454"44Í56.982(905) Mlscellaneous Customer Accounts Expenses163

451.9S€399,102(904) Uncollecl¡blê Accounts16217.510,07C17.&38.7¡10(903) Customer Rêôords and Collectfon Expenses161

3.888.31¡3.280.258(902) Meter Reading Expenses160699.32'637.909(901) Suoervis¡on159

rperatþn158

5. CUSTOMER ACCOUNTS EXPENSFS15773.291.59't4.126.128TOTAL Distribution Exoenses ffotal ol lines t44 and f 55115647.65/'.04(TOTAL Maintenâncs fÏotål of lines 146 thru 154)f55

286.66C267.69t(598) Maintenance of Miscellan€ous Distr¡bution Plant13152A.gze(597) Maintenance of Melers153253.96Sr96,785(596) Maintenance of Street Uqhtinq and Siqnal Svstems152119.03i1S-ô84(595) Maintenance of L¡nô Transformers151

1,428,62i1.170(594) Maintenance of Underground Lines15043.579.421(593) Maintenance of Oveùead Lines149

1.053.027887,801(592) Maintenanc€ of Stal¡on Êouioment14847,34i4{}.250(591) Maintenance of Struotures147

371,031s20.s89(590) Maintenance SupeMsion and Enqineerinq't46Maintenance14s

25.637.5s'TOTAL Qeralion {Enter Total of lings 134 thru 143)144739.764898.52s{589) Renlsr43

16.¿!05,82€1{588} Miscellaneous Exoenses1421.218.653814.9€(584 Customer lnslãllations Expensês141

896.6S4,7972,129(586) Meter ÊxpensesI ¡l{)405.64t,163,693(585) Street Ughtingand Signal System Expensesr39

1.2ô5.4041.342.958{584) Underqround Line Expenses1381.924.53€1.634.56r(583) Ove¡head Line Expenses137

693.04{(582) Station Expenses't36154.775't36,20C{581) Load DisDalchinq135

1.9¡¡{1.21!'t.684.323{580) Operation Suoerv¡s¡on and Ënoineêrino134

Operationf Stil

4. DI$TRIBUTION EXPENSES1321.533.35€1TOTAL Regional Transmission and Market Op Ëxpns (Total 123 and 130)t31

Total Maintenance (Unes 125 lhru 129)130

(57ô,5) Mainlenance ol Miscellaneous Ma¡ket Qoeration Plant129

(576.4) Maintenance of Communication Ëquipmenl1ä8

(576.3) Maintenance oJ Cornputer Software127{576.2) Maintenance of Computer Hardware126

576.1) Maintenance ot Structures and lmprovements't25Maintenance't24

1.533.35€'t.412,457Total Operatíon (L¡nes 115 thu122)'t23(575,8) Rents1n

'1.533.35€1.412.457(575.Ð Market Facilitation, Monitoring and Compliance Services121{575.6) Market Monilorlnq and Compliance120{575.5) Ancillary Services Market Facilitation'119

(575.4) Capacity Market Facilitation't18{575.3) Transmission Riohts Market Facilitation117

{575.2} Day-Ahead and Real-Îme Market FacililationT18

t575.1) Operatlon Supery¡sion115

Operation114

3. RËGIONAL MARKET *PÊNSÊS113

Amount forPrevious Year

(c)

Amount forCurrenl Year

(b)

AÇcount

(a)

Une

No"

lf the amount for previous year is not derived from previously reported ligures, explain in footnole.

Year/Period ol ReportEnd of 2015/Q4

Date of Fleport(Mo, Da, Yr)u

Narne

Southweslem Electric Power Company(1i(¿',,


FERC FORM NO. t (ErÌ. 12.93) Pâg€ 322

1.308.367.3221.156.139,568TOTAL and 1 I 1 119872.365.699TOTAL Administr4ive & Ge4eral E4¡eqses fiotal of lines 194 and 1 961197

7.473.36€(935) Maintenanoe of General Plant196

Maintenancei9566.122.935Total ol lines 181 lhru194

1.173.7111lS]1) Hentst931.392.1521.1 17.978(930.2) Mlscellaneous Genelal Expenses192

269.699(930.1 ) General Advertising Expenses19'f

(929) (Less) Duplicate Charges-Cr.190867.0681.923.3itg(928) Regulatory Commission Expenses189

(927) Franchise flqqu!¡ementst881

(926) Employee Pensþns and Benefits1874.713.24â4.448.1431862.650-54S(924) Property lnsurance185

10.235.3128.119-825923) Outside Services Empfoyed1845.991.7593.860-28r(Less) (922) Admlrllstrative Fxpenses Transfened-Credit'183'1.337.8212.788.T38(921) Office Supplies and Expenses'182

32.428.41A29.225.816(920) Admlnist¡ative and General Salaries181

Operatlon180

8. GENERAL179163,427TOTAL Sales Expenses (Enter Total ol lines '174 lhru 177)178

(916) Miscellaneous Sales Expenses177

(9t 3) |dvertis¡ng Expensest76ß4.42?f 38.922175

1(911) SupervÍsion174Operation173

7,17215.24ô.4951TOTAL Customer Service and171

1.8454.394ett70871.M4(909) lnlo¡malioqal ând lnstructional Expenses169

9.307.'t6812.084.335(908) Customer Assistance Expenses1685.93't.4826.097.4At(907) Supervision't67

Operation168

6. CUSTOMER SERVICE ANO INFORMATIONAL EXPENSES165

Account

(a)

UneNo.

lf the amount for is not from in footnote.

Year/Period of ReportEndof 2015/Q4

(2') uNamg ol nespondent


FERC FOFM NO.1 (8D.12-93) Page 323

FOOTNOTE DATA


2015/Q4

Name ol Respondent This Fleport is: Date of Report(Mo, Da, Yr)

ltXAn Original

Southweslem Ëlectric Company *A Resubmission

I

Thís footnote appLies tg both current and prior year,

AllocaEeil maint,enance expenses for joint use computer hardware, computer software andcommunication equipmene are det.ermined by usingi various factors, rr¡hich include number ofremote'terminal units, nurnber of radios, nuinber of employees and oLher factors assigmed toeach fun-ction.

NO.1 1 1

Total

14

13

12

11

NANANANAosSnider lndustries (3)10

NANANANAosSouthwest Power Pool (5)INANANANAosMajestic Wind Farm (4)INÁNANANAosFlat Ridge Wind Fam (4)7

N¡NANANAosËRCOT (6)6

N¡NANANAosTexas (ERCOT) (2)5

Electric Reliabll'rg Coun0il of4N¡NANANAOSCLECO Power LLC (113N¡NANANAosCanadian W¡nd (4)2

N¡NANANAos'|

AverageMonthly CP Demanc

(f)

AvefageMonthly NCP Demanr

(e)

AvêragêMonthly BillingDemand (MW)

(d)

FERC RateSchedula or

Tariff Number(c)

Stat¡sticalClassifi-cation

(b)

Name of Company or Public Aulhority(Footnots Atf ¡l¡alions)

(a)

Line

No.

Actual Demand tMW)

'l ' Report all power purchases made during the year. Also report exchanges of etectricity (i.e., transactions involving a bafancing ofdebits and credits for energy, capacity, etc.) and any setllements for imbalanced exchanges.2' Ënter the name of the selfer or other party in an exchange transaction in column (a). Do not abbreviate or lruncale the name or useacronyms. Explain in a footnote any ownership intêresl or affilialion the respondent has with the seller.3' ln column (b), enter a Statistical Classifícation Code based on the original contractual terms and conditions of the service as follows:

RQ - for requírements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., thesupplier includes proiects load for lhis service ¡n its ôy$tem resource plênning). ln addìlion, the reliability of requirement servico mustbe the same as, or second only to, the supptiels servica lo its own ultimate consumers.

LF' for long-term lirm service. 'Long-term'means five years or longer and 'firm' means lhat service cannol be interrupted loreconomic rea6ons and is intended lo remain reliable even under adverse conditions {e.g., the supplier must attempt to buy emergencyenergy from lhird parties to maintain deliveries of LF service), This category should not be used ior longterm lirm servicafirm serv¡cewhich meets lhe delinílion of RQ service. For all transaction identilied as LF, provide in a footnote the teçnination date ol lhe contractdelined as the earliest date that either buyer or seller can unilaterally get out of the contract.

lF'for Íntermediate'term firm service, The same as LF service expect that 'intermediale-lerm' means longer lhan one year but lessthan five years.

$F ' for shod{erm service. Use this category for all iirm seruiees, where the duration of each period of commitment for service is oneyear or less.

LU 'for long'lerm service from a designated generating unit. 'Long-term' means five years or longer. The availability and reliabílity ofserv¡ce, aside from lransmission constraints, must match the availability and reliability of the designated unit.

lU - lor intermediate'term service from a designated generating unit^ The same as LU service expect that 'intermediate-terrn' meanslonger than one year but less lhan livo years.

EX' For exchanges of electicity. Use this category lor transactions involving a balancing of debits and credits for energy, capacity, etcand any settlements for imbalanced exchanges.

OS - lor other service. Use this category only lor lhose services which cannol be placed ín the above-delined categories, such as allnon'firm service regardless of the Length of the contract and service lrom designated units of Less than one year. Describe lhe natureol lhe service in a foolnote lor each âdjustment.

Year/Period ol Fleport

End ol 2O15lQ4Dale of Reoort(Mo, Da, Yi)t/

Name of

Soulhwestern Eleckic Power Company(1)(2')


FERC FORM NO.1 (EÐ. 12-sO) Page 32ô

130,750,46(6,755,4i18119,791 ,2884,243,7U7,638,964

14

13

12

1t

101 '13,1 001 13,f0(5,40(

I66,406,4985,623,84€60,782,ô5(6,01 r,79(

I25,513,89925,513,89!581,84i

7't3,031,58213,031,58i410,57Í

6742,626742,626

53,743,73¿

4

3388,964388,964

220,350,05720,350,057629,34f

14,200,00C4,200,00(

LineNo.Total (¡+k+l)

of Settlement {$)(m)

Other Çhargos($)(t)

hnergy çharges

trr

Demand Charges($)U)

Megawâtt HoufsDelivered

(i)

MegaWatt HoursReceived

(h)

MegaWatt Hours

Purchased

(s)

COST/SETTLEMËN' OF PCIWERPOWER EXCHANGES

AD ' for out'ol'period adjustment. Use this code for any accounting adjustments or'true-ups' for service provided in prior reportingyears. Provide an explanation in a footnote lor each adjustment.

4. ln column (c), identify the FERC Hate Schedule Number or Taríff, or, for non-FERC jurisdictional sellers, include an appropriatedesignalion for the contracl. On separate lines, list all FERC rate schedules, ìarifls or contract designalions under which service, asidentified in column (b), is provided.5. For reguirements RQ purchases and any typê of service involving demand charges imposed on a monnlhly (or longer) basis, enterthe monthly average billing demand in column {d), the averagê monthly non-coincident peak (NCP) demand in column (e), and theaveråge monthly coincident peak (CP) demand in column (f). For all other types of sêrvíce, enter NA in columns (d), (e) and (l). MonthlyNCP demand is the maximum metered hourly (60-minute integralion) demand in a month, Monthly CP demand is the metered demandduring the hour (60-minute integralion) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f)must be in megawatts. Footnote any demand not 6tated on a megawatt basis and explain.6. Report in column (g) the megawatthours shown on bills rendered to the respondenl. Report in columns (h) and (i) lhe megawatthoursof power exchanges received and delivered, used as the basis for settlement. Do not report nel exchange.7. Report demand charges in column (j), energy charges in column (k), and lhe total of any other types ol charges, includingout-of'period adjustments, in column (Í). Explain in a lootnote all components of the amount shown in column (l). Fìeport in column (m)the tolal charge shown on bills received as settlement by the respondenl. For power exchanges, report in column (m) the se¡lementamount for the net receipt of energy. lf more energy was delivered than received, enter a negalive amount, ll the settlement amount {l)include credits or charges other ihan incremental generation sxpenses, or (2) excludes cêrtain credits or charges covered by theagreement, provide an explanatory foolnole.8. The data in column (g) lhrough {m) musi bc totalled on the last line of the schedule. The total âmount in column (g) must bereported as Purchases on Page 401, line 10. The total amount in colurnn (h) must be repoñed as Exchange Received on Page 401 ,line 1 2. The totat amount in column (i) must be reported as Exchange Delivered on Page 401 , line 13.9, Footnote entries as required and provide explanations lollowing all required data.

Year/Perio'd of ReportEnd of 2015/Q4

Date ol Reoort(Mo, Da, Yi)/t

Name Respondent

Southwestem Electric Power Company(1) An Original

A Resubmission

FERC FOHM NO.1 {8D.12-90) Page 927

TTTIS PAGE INTENTIONALLY LBFT BLANK

FOOTNOTE DATA


2015/Q4


tt

This Report is:(I) X An Original(2) * A Resubmission

Name of Respondenl

Southweslern Electric Power Companv

L

(2t

(3)

(4)

(5)

(6)

ca Non-F' rm

Capacity

Cogeneration

Wind Energy

Net Trading Purchases & Sales within Southwesl power pool (Spp)

Net Tradinq Purchases &. Sales wi¿hin ERCOT

1 450.1

TOTAL

s4

33

32

31

30

29

28

27

26

25

24

23

22

21

20

19

18

17

16

l5't4

13

12

1l

'f0

II7

ADVariousVariousSouthwest Power Pool (2,4)6

osVariousVariousSouthwest Power Pool (2,3,7,8)5

OSVariousVariousSnider lndustries (6)4

ADVariousVariousAEPSC (1,2,4)3

osVariousVarious2

American Electric Power Service1

StatisticalClassifi-cation

(d)

Energy Delivered To(Company of Public Authority)

(Footnote Afiiliation)(c)

Energy Received From(Company of Public Authority)

(Footnots AflilÌation)(b)

Payment By(Company of Public Authority)

(Footnote Àff ìliation)(a)

LineNo.

1. Report all transmissîon ol electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities,qualifying facililies, non-tradilional utility suppliers and ultimate customers lor lhe quarter.2. Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).3. Report in column (a) lhe company or public authority lhat paid lor the transmission service. Heport in column (b) lhe company orpublic authority thal lhe energy was received from and in column (c) the company or publ¡c authority thât the energy was delivered to.Provide the full name ol each company or public authority. Ðo not abbreviate or lruncate name or use acronyms. Ëxplain in a footnoteany ownership interest in or aflilialion the respondent has wilh thô entities lisled ¡n columns (a), (b) or (c)4. ln colurnn (d) enler a Slatisticäl Classificalion code based on the original contraclual terms and conditions of the service as tollows:FNO - Firrn Net\¡/ork Service lor Others, FNS - Firm Network Transmiss¡on Service for Self, LFP - 'Long-Term Fírm Point to PointTransmission Service, OLF - Other Long-Term Firm Transmission Service, SFP . Short-Term Firm Poinl lo Poinl TransmissionReservation, NF - non-lirm transrnission service, OS - Other Transmission Service and AD - Ouþof-Period Adjustments. Use this codefor any accounling adjustments or'true-ups'for service provided in prior reporiing periods. Provide an explanation in a lootnole foreach adjustment. See General lnstructíon lor delinilions of codes.

ccounl 4þþ.I)as

IIIANì

Year/Period of ReportÊnd ol 2O1E|Q4

Date of Report(Mo, Da. Yr)tlSouthwesten Electric Power Com pany {1)

(21


FERC FOFM NO. r (ED.12-90) Page 328

(C0

34

33

32

31

30

29

28

n26

25

24

23

22

21

20

19

18

17

16

15

14

'13

12

l1

't0II7

6VariousVarious196

5VariousVarious196

4VariousVariousNA

3VariousVariousNA

2VariousVariousNA

I

LineNo.Megawan nours

Ðelivered0)

Megawatt FloursReceived

(0

BillingDemand

(Mvv)(h)

Point of Delivery(Substation or Olher

Designation)(g)

Point of Receipt(Subsalation or Other

Designation)(fl

FERC RateSchedule ot

Tarifl Number(e)

TRANSFÊR OF ÊNERGY

5. ln co[umn (e), identify the FERC Rate Schedule or Tar¡ft Number, On soparate lines, list all FERC rate schedules or contractdesignalions under which service, as identilied in colurnn (d), is provided.ô. Report receipt and delivery locations lor all single contract path, 'point lo point' lransmissíon service. ln column (f), report thedesignation lor lhe substation, or other appropriaie identilication for where anergy r*as received as specified in lhs contract. ln column(g) report the designât¡on for lhe subslatlon, or other appropriale identification for where energy was delivered as specified in thecontracl.7. Reporl in column (h) lhe numberof megawatts ol billing demand lhat is specilied ín thê lirm transmission service contrâct. Demandreporled in column {h) must be in megawatts. Footnot€ åny dêmand nol slated on â megawâtts basis and explain.8. Fleporl in column (i) and $) lhe total megawatthours receÍved and delivered.

rr 4þor(uonünueo)as

Year/Per¡od of ReporlEnd of 2o15lQ,4

Date of Reoort(Mo, Da, Yi)ltSoulhwestem Electric Power Company

(1)(2)

An OriginalResubmission

FEHC FORM NO. 1 (ED, 12-90) Pägs 929

71,522,ñ971,5e2,00900

u33

92

31

30

29

28

27

26

25

24

23

22

2'l

20

19

18

17

1ô

15

14

13

12

11

10

II7

648,57648,576

556,275,43856,276,438

4840840

e475,V85475,785

2'14,721,37014,721,370

1

FEVENUE orDemand (s)

{s}(k)

($)(t)

($)(m)

(k+l+m) No.(n)

L ln column (k) lhrough (n) report the revênue amounls as shown on bills or vouchers fn column (k), provide fevenues from demandcharges related to the billing demand reporled ln column' (h). ln column (t), provide reven ues from energy charges related to theamounl ol energy lranslerred. ln column (m ), provide the lotal levenues from alÌ other cha rges on bills of vouchers rendered, includíngout ol perlod adjuslmênts. Explain tn a foolnote alf components of the amounl shown tn column (m), Reporl in column (n)

made, enter zero (1101 1)the total

charge shown on bills rendered t0 lhe entity Listed ln column (a). lf no monetary setllement w€ls in column(n). Provide a footnote explaining thê naturê of the non-monetary settlemenl, including the amount and type of ene rgy or servtcerende red.10' The totalamounts in columns (i) and (j) musl be rêportêd as Tranemissíon Received andTransmission Delivered for annual reportpurpose$ only on Page 401, Lines 16 and 17, respêctively"1 l. Footnote entríes and provide explanations following all required data.

uH (,t Htsfttt {llfered lo as \fr¡

Year/Period of ReporlEndot 2015/Q4


ol

Southwestem Êlectric Power Company(1) An Origlnal

HesubmissiÖn

FERC FORM NO, I (8D.12-90' Page 3lXl

FOOTNOTE DATA


2A1sto,4


lt

This Report is:(1) XAn Original{2) _ A Resubmission

Name of Responderrt


Llne No.:

(1) Flespondent is an affiliated company of American Electric Power Servíce Corporation

(2', Network lntegrated Transmission Service {NITS)

(3) Southwest Power Pool Base Plan Funding

{4) Prior Year

(5) Transmission service charge

{6) Open Access Ancillary Service

(7) Ðirect Assignment

(8) Pointto Point Transmission and Ancillary Service

BC FORM NO.1 D.1 ¡150.1

6f,728,320ôr,728,320TOTAL

l6

15

14

T3

12

11

10

9

I

€,835,029ß,835,029osPower Pool (3,7)ô

Soulhwesl5

215,47421s,474AüAEpSC (1,6)4

17,6n,8fir7,6?,817os3

Service Corpration2

American Elecùíc Power1

Total Cost ofrrans¡glission

trnerovCharoës

($r{f)

rua¡garYatt-noufs

Delivered(d)

Magawatt-noufs¡

Received(c)

StatisticalClassificalion

(b)

Name ol Company or PublicAuthorig (Footnote Aff iliations)

(a)

L¡ns

No.ËXPÊNSES FOR TFANSMISSION OF ELECTRICIW BY OTHEHTTRANSFEH OF ËNÊRGI

.l . Report all transmission, i.e, wheeling of electric¡ty prôvided by other electric ulilities, cooperatives, municípalities, other publicauthorities, qual¡fying facìlities, and others for the quarter.2. ln column (a) report each cornpány or public authority that provided transmission sêrvice. Provide the lull name ol the company,abbreviate if necessary, but do not truncatê name or use acronyms. Explain in a footnols any ownership interest in or affiliation with thelransmission seryice provider; Use addilional columns as necessary to report all companies or public authorities lhat providedtransmíssion service for the quarter reported,3, ln column (b) enter a Statistical Classilicalion code based on the original contractual terms and conditions of the service as follows:FNS - Firm Network Transmission Service lor Sell, LFP - Long-Term Firm Po¡nþto-Po¡nt Transmission Reservations. OLF - OtherLong-Term Firm Transmission Service, $FP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non.Firm TransmissionServicê, and OS - Other ïransmission Service. See General lnstructions for definitions of statistical classificalions.4. Fleport in column (c) and (d) the totäl megawatl hours received and delivered by the provider of the transmission service,5. Report in column (e), (l) and (g) expenses as shown on bills or vouchers rendered to the rospondenl. ln column (ê) report thêdemand charges and in column (f) energy charges related lo lhe amount of energy lransferred. On column (g) report the lotal of allother charges on bills or vouchers rendered to the respondeni, including any out of period adjustments. Explain in a foolnote allcomponents of lhe amount shown in column (g), Report in column (h) the tÕtal charge shown on bills rendered to the respondent. lf nomonetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement,including the amount and type of energy or service rendered.6. Enter'TOTAL' in column (a) as lhe last line.7. Footnote entries and provide explanations following all required data.

TRANSMISSION OF ELECTRICITY BY OTHERS (Account s6s)(lncluding lransactions referred to as 'wheeling')

Year/Period of ReportEnd of 20151Q,4

Date ol Report(Mo, Da, Yi)tl

Reoort ls:E]An Or¡ginal

¡A Resubmission

This(1)(z',)

Name of Respondent


FEBC FOFM NO. 1/9-O (REy.02-04) Page 332

FOOTNOTE DATA


201ryQ4


ltThis Report is:(1) X An Original(2\ A Ftresubmission

Name ol Flespondent

Southwestern Eléclríc Power Company

(1) Respondent is an affiliated company of American Electric Power Service Corporation

{2') racility charge

(3) SouttrwesL Power Pool base plan funding

{4) Southwest Power Pool ancillary service schedule 1

(5) Ne¿work Integrated Transmission Service (NITS)

(6) Prior year

(?) Trans¡nission service charge

450.'l

1t1 17,978TOTAL46

45

44

43

42

41

40

39

38

37

36

35

u33

32

31

30

29

28

27

26

25

24

23

45,559Miscelläneôus Minor ltems less than $5,00022

21

23,650Other Coryorate Contributions and Memberships20

19

13,942Software Ma¡ntenance18

17

61,688Custom er Salisfaction Surveys16

15

36,023Chamberof Commsrcs14

l333,754Bank Administratlon Fees'12

11

42,638Companíes Billed to or from Respondent10

AEP Service Corporation and Other AtfiliatedII

a48,933Associated Business Devefopment7

o

Oth Éxpn >=5,000 shon, purpose, reclpienl, amounl. Qroup if < $5,ooo5

39,133Pub & Dist lnlo to Slkåldrs...expn servicing outstanding Securities4

5,53'lOther Experimental and General Research Expenseso

Nuclear Power Research Expenses2

467,127lndustry Association Dues1

Amount(b)

LineNo.

Year/Pefiod ot Repoñ

End of 2015/Q4uate ol Reooft(Mo, Da, Yi)tt

Th¡s Eleoort ls:(1)lxl An Original(2) n A Resubmlssion

Nam6 oÌ HesponoêntSouthwestem Eleclric Power Çompany

FEFC FORM NO.1 (ED.12.94) Pags 335

Line 1, Column D repres€nts amort¡zation of capitalized software development cost over a 5 year life

B. Basis for Amortizat¡on Çharges

190,696,03812,008,664825,333177,862,0ø]l

Common Plant-Electric

TOTAL

1

7,922,85921,3687,901,49'lGeneral Plant10

Regional lansmission and Market OperalionC

50,586,77250,586,772Distribut¡on Planl€

31,768,93031,768,930Transmission Plant

3,023,3883,023,388Other Froduclion Plant€

Hydraulic Prodr.¡ctíon Plant-Pumped StorageF

Hydraulic P¡oduction Plant-Conventionäl4

Nuclear Production Plantâ

85,385,425803,9ô5û4,581,460Steam Production Planta

12,008,66412,008,ôô4lntangible Plant1

Total

(f)

Amortízation ofOlher Electric

Plant (Acc 405)(e)

Amortizalion ofL¡mited TermElectr¡c Plant

(Account 404)(d)

ueoreciauonExpen'se for AssetRet¡rement Costs(Account 4O3.1)

(c)

DeoreciationËxoense

(Account 403)(b)

Functional Çlassif ication

(a)

LineNo.

A, Summary of Depreclat¡on and Amorl¡zat¡on

1. Report in section A for the yeâr the ârnounls for : (b) Deprecialion Expense (Account 403; (ö) Depreciation Expense for.qsset

Retirement Costs (Account 403.1; (d) Amortization of Limited-Term Eleclric Plant (Account 404); and (e) Amortization of Other Efectric

Plant (Account 405).2. Heport in Section I thê rates used to compute amortizat¡on charges for eleclric plant (Accounts 404 and 405). State the basis

compute charges and whether any changes have been made in the basis or rates used lrom the preceding report year.

3. Report all available information called for in Section C every fifth year beginning with report year 197'1, reporting annually only

used to

to columns (c)through (g) from the complete report oi the preceding year.

Unless composite deprecialion accounting lor total depreciable plant is followed, list numerically in column (a) each plant subaccount'

accounl or functionaf classilication, as appropriate, to which a rate is applied. ldentify at the bottom of Section C lhe type of plant

included in any sub-accaunt used,ln column (b) report all depreciable plant balances to which rates are applied showing subtolals by lunctional Classificalions and showing

composile total. lndicate al the bottom of section C the manner in which column balances are obtained. lf average balances, state the

method of averaging used.

For columns (c), {d), and {e) report available information lor each plant subaccount, account or lunctional classilication Listêd in column

(a). lf plant mortality studies are prepared lo assist ¡n êstimâting avëfagê $ervice Lives, çhow in column (f) the type mortâlity curve

sêlected as most appropriate lor the account and in column (g), if availablê, the weighted average remaining lile of surviving plant. lfcomposite depreciation accounting is used, report available information called lor in columns (b) through (g) on this basis.

4. lf provisions for depreciation were made during the year in addition to depreciation provided by application of reported lates, state at

the bottom of section C the amounls and nature ol the provisíons and the planl items lo which related.

ffizATtoN oF EtEcrRlc PLANT (Account 403, 404,,1o5)(Except amortization of aquisition âdiustmenls)

Year/Period ot Beport

End of 2015/Q4Date of Report(Mo, Da, YQ

This Reoort ls:(1) [¡An orisinal(2') ¡A Resubmission

Name ol Respondent

Southwestern Electric Power Cornpany

FERC FOFM NO. r {REV,12{3) Pâge 396

86€3f 2.3-Knoxlee Plpelinè50

6,3f €3lâ.S - Arsenal Hill49

17Ê31?.&ArsenalHilÌ Plpe48

86,92€31 2.3-ArsenalHillStall47

7,&311.3 - Wilkês46

8*31 1.3 - tone Star45

3,8041.3. Uêberman44

7,80(311.3 - lftox Lee43

5,35131'1.3-Arsenal Hill42

53,27Í31'l .3-ArsenalHillstall41

STEAM - GASIOIL40

39

9,254,509IOTAL COAULIGNITE38

22,ßg316 - Welsh97

47,972316 - Turk36

17,S06310 - Pirkey35

5,779316 - Flint Creeku14,957316 - Dolet HillsO!)

33,201315. Welsh32

92,769315 - Turk31

16,687315 - Pirkêy30

ð,322315 - Flint Creek29

10,617315 - Þolet H¡lls28

109,57C314 - Wêlsh27

236,928314 - Turk26

50,932314 - Pirkey25

12,566314 - Flint Creek24

39,745314 - Dolet Hills23

375,985312 - Wolsh22

984,751312 - Turk21

361,12C312 - Plrkey20

61,898312 - Flinl Creek't9209,063912 - Dolet Hillsf8

87,908311 - Welsh17

268,55i311- Turk16

108,14C311 - Plrkey15

24,83ê3l'l - FlinlCreek14

53,88t311 - Dolel Hills't3

STËAM.. COAULIGNITE12

MOrIarrryCu¡vetffi"

ÂPp¡reaDeor. rales(Percent)

Salvaoe(Perce-n$

Avg, $ervice

lcl

uePfecl¿lgtoPlant Base

(ln Thousands)tbì

Account No,

(aìNo.

C. Factors Used in Estimal¡ng Depreciation Charges

Southwestem Electric Power CompanyAn

End ol 2O15lQ4(z',, A u

DEPBECIATION AND AMORTIZATION OF C PLANT (Continued)

FERC FOFlrl NO.1 (FEv.1243) Page gg7

303,27€35650

44ð,00!3s549

39,69f36448

494,77435347

10,3923524€

73,Ul350 {Rights)45

TRANSi,|ISS'ON44

43

128,461TOTAL OTHEF42

7434e - Matl¡son4t

8,727845 - Mattison40

M,107344 - Mattison39

34,88434'l - Mattsion38

OTHERGËNERATION37

36

662,520TOTALGAS/OIL35

7,S403't6.3 - Wilkesu20331ô.3 - Lone Star33

1,9't€316.3 - Ueberman32

1,805316.3 - Knox Lee31

3,903316.ð - Arsenal Hill30

u,75231 6.3-ArsenalFlillStall29

9,053315.3 - W¡lkes28

83(315.3 - Lone Star27

2,571315.3 - Ueberman2ô

3,7143'15.3 - Knox Lee25

1,1 1€315.3 - Arsenal H¡ll24

40,52Ê31 5.3-ArsenalHillStall23

34,341314.3 - Wilkes22

2,512314.3 - Lone Star21

10,52C314.3 - Lieberman20

19,85231 4,3 - Knox Lee19

4,498314.3 - ArsenalHill18

165,67€31 4,3-ArsenalHillStaltt7

39,e00312.3 - Wilkesf6

1783'l 2.s-Wilkes Pipeline't5

4,05S312"ô - Lone Star14

17,101312.3 - Ueb€men13

32,6733'12.3 - Knox Lee12

.¡{vefageFlemaining

{o)

MOrrarrryCurveÏ¿ç*

¡\PPileaDoor. râtes(Pe,rynt)

Salvaoe(Perce-nt)

trsIrmaIeoAvg. Service

{cl

uepreclaotePlant Base

(ln Thousands)Itìì

Account No.

laì

L¡NE

No.

C. Factors Used in Estimating Depreciation Charges

DËPHECIATION AND AMORTIZATION OF ELECTRIC PLANT (Conlinued)

Year/Perlod ol ReportEnd of 2015/Q4(1)

(2| A Resubmission ttName of Respondent

Southwestêm Electric Power Company

FERC FOFM NO,1 (nEV. 12{3) Page 337.1

50

49

48

47

48

45

ÐEPRECIÀBLE SUM44

{ì2I5,686TOTALGENFNAL PI.ANT42

2,60ss9841

65,14239740

39639

5,37539538

22,68't39437

2,ß139336

4,f 1S392âç

,l{11391.11u10,172391âà

140,2439032

GENËHAL PLANT3't

30

i,947,093rOTAL DÍSTRIBUTION29

37328

41,81S37127

84,80€37026

81,49€36925

366,33C36824

197,77Ê36723

58,26136622

401,84136521

396,95C36420

269,29536219

5,40C36118

3,487360 {Rights)17

ÞISTRIBUTION16

15

1,364,612TOTAL TRANSMISSION14

1323s9't3435712

rìverageRemainino

Lifelq)

Mqfra¡rtyCurvetlr"

APpreoDepr. rales(Fercen0

Salvaoe(P€rceñt)

c\'uf f raleoAvo. Servlce- Life

lc)

ueprecraorePlant 8as6

(ln Thoæands)Account No.

lalNo.

DEPR ÂNÞ AMORTIZATIQN OF PIANT (Continued)

C. Faclors Used in Eslimating Depreciation Charges

Yéar/Period of FleportËnd ol 2O15lQ4

Date of Reoort(Mo, Da, Yi)lt

This Report ls:(1) ffiAn Original(2) ¡A Resubmìssion

Name ot Flespondent

Soulhwestem Electric Powef Company

FERC FORM NO.1 (REV. 12{3} Pago 3¡,7.2

FOOTNQTEDATA

lYear/Period of Fìeport

Lo,u,ooDate of Report

(Mo, Da, Yr)tt

This Report is:(1) XAn Original{2\ A Resubmission

Name of Respondent


deprec e ant s t company

450.1FERC

8,125,7101,923,30S1,890,96632,37eTOTÂL46

45168,634168;634Miscellaneous Minor ltems44

4Íì33,87€33,879Expenses relåted to Formula rate case42

41ß,45243,ß2Expenses related lo 2014Te)€s rate case40

39127,8s(127,85âårpenses t€lated to Texas Fuel Factor38

s7227,281227,281PUCT Ðocket No. 4208936

Recovery Faotorfrom Te)€s Reta¡l Cuslomers35

Expenses incurred related to Transm¡ss¡on Costu33

31,7&91,7#Cost Flecovery Faclors32

Expenses incurred relaled lo Energy Ëficiency3l30

1,258,10¿1,258,104starting in August 201529

and 37162. Flecovéry through a rate rider28

Dockef Nos. 42A7A,4049,39708, AB6i4, gZZg27

recover rate case exp€nses relating lo PUCT26

Final Orderon PUCT Docket No. 42370 lo26

241,000,02cPUCT Docket Nos. 37162 and 3861423

Defenêd Fuêl Reconciliation Case expenses22

21111,371PUCT approval lor collection20

belore lhe PUCT Docket No.42370, pending19

Defened expenses incurred in rate case review18

177,365,19¡PUCï Öocket No. 404¡l{t't6

future PUCI approval for collection relaled lo15

balance represent€ rate case expenses pending't4Cas€ (PUCT Docket No.,î0,l4ir). 2015 year.end13

Nos. 37364 and 39708), and 2012 Base Bale12

'Turk Power Plant CWIP' case (PUCT Docket1tRaìe cãse expenses relat¡ng to Texas 20I110

I-350,87€3 years beginning November 20108

Docket No. 37772. Amo¡lization period -7

Docket No.37364 and approved in PUCT6

Pub¡ic Utility Conmission of Texas (PUCT) -5

Ovenecovery of rate case expênses related to4

332,37332,373Assessment2

Federat Ënergy Regulalory Commission Annual1

ue¡errêdin Account

g"g¡18fr831v""..

TolalËxoense forCuirent Yeâr

(¡),å,(o)

Expensesof

Ulility(c)

Assessed bvReoulatorv'Corñmissión

(b)

Description(Fumish name of regulatory commission or bodv lhe

docket or case number and.a descriplion of lhe case)(a)

No,

1" Report parliculars (details) ol regulatory commission expenses incurred during the current year (or incurred in previous years, ifbeing amorlized) relatíng lo lormal cases þeforq a regulãtory body, or cases in which such a body was â party.2, Report in columns (b) and (c), only the currenl yôa/s expenses lhal aro not deferred and the currênt year's amortization of âmounlsdeferred in previous years,

REGULA l Y TJUMMIÞÞIUN e^yÈNlth,5

Year/Per¡od of Fleport

End of 20t5/Q4Date of Reoort(Mo, Da, Yi)llSoulhwestem Eleotric Power Company )

is:Qríginal

(2) A Resubmission

FERC FOFM NO.1 (ED. 12.*i) Pâg€ 350

467,1¡13,0101,258,104276,404665,235

45

44168,634s28Electric

A3

4233,87ç928Electrlo

4l4043,452928Ëlectric

39

38127,85C928Elætr¡c37

3ô227,287928Eleclric

&5

34

33

3231,7il928Electrtic

31

30

296,8,/.'r,4X1,258,1049,288,09{¡,527928Éleclric

28

27

26

25

24

23-1,000,020928Eleclric

22

21

20297,87¿186,5G928Electric

19

18

'17

16s,7'r1-7,361,4tt'928Ëlectríc

't5't4t312

't1

10

II350,876928Electric

7

6

5

4

3

232,373,928Eleclric1

UneNo.

Amount

k)

ConlraAccount

(i)

Defened loAccount 182.3

(¡l

,tfIt(Jufll(hl

r\çñBut¡r

(q)

uepanmenl

tfl

CURRIAMORTIZED DURING YEAREXPENSES INCUffRED DURING YEAR

3. Show in cofumn (k) any expenses incurred in prior years which are being amorlized. List in column (a) the period of amortization4. List in column (f)' (g), and (h) expenses incurred during year whích were charged currently to incomê, plant, or oth€r accounts.5. Minor items (less than $25,000) may be grouped.

Year/Per¡od of ReportEnd of 2015/Q4

Dale of Report(Mo, Da, Yi)tl

This Reoort ls:(1) ÉAn orisinal(21 nA Re$ubmission

Name ot Flespondenl


FEEC FOFM NO. r (ED.12-96) Page gS1

38

37

3ô

35

34

33

32

3l30

2S

28

27

A. (4 Tolal Cost lncuned lntemally26

25

24

23DTC Walnut Test Facil¡tyA. (6)9 Research General22

21

Metering Test Bed DeyelopmentA. (6)f Melering20

J9

't817

4 ltems < S50,000A. {6) Olher'16

15

3 llems < $50,000A. (5) Environmental {other than equipment)l413

Dislribution Program ManagementA. (3) Dístribution12

t12 llems < $50,000A. (2) Transmissionf0

II

3ltems < $50,000(e) Unconvenlional Generation7

Þ

3 ltems < $50,0005Program Management4

Generation Asset Managoment(b) Fossil-luel Steam3

A. (1) Generalion2

1

Þescriptlon(b)

Classilication(a)

LineNo.

'1. Describe and show below costs incuned änd accounls charged during the year for lechnological research, development, and demenslralion (R, D &D) groiect initiated, continued or concl¡¡ded du¡ing the yeâr. Report also support given to olhers during the year for ¡oíntly-sponsored projects.(ldentityrecipienl regardless of afliliation,) For any R, D & D work carried wilh others, show separately the respondent's cost tor thê year and cost chargeable toolhers (See delinition of research, d€velopment, and demonstration in Unilorm System of Accounts).2. lndicate in column (a) the applicable classificat¡on, as shown below:

ClassifbationsrA. Electric R, D & D Perlormed lntemalfy:

{1) Genêraliona. hydroelectrici. Recreation lish and wildlife¡i Other hydroelectric

b. Fossil-fuel steamc. lntemal combust¡on or gas turbined, Nucleare. Unconvent¡onal generationL Siting and heât rejection

(2) Transmission

a, Overheadb. Underground

(3) D¡stribution(4) Begional Transmission and Market Operation(5) Environment (other than equipment)(6) Other (Classity and include items in excess of $SO,0OO.)

{7) Total Cost lncurredB, Electric, R, D & D Performed Ëxtemally:('l) Research Support to lhe eleclrical Reseârch Õouncil or the Electric

Power Research lnstitute

Year/Period ot Fìepoft

End of 2O15lQ4Soulhwestem Eleclric Power Company(1)(2t A Resubmission

(Mo'tt

FERC FORM NO. I (EÞ. 12-84 Page 952

38

.5t

36

35

34

33

32

31

30

29

28

27

26286.97(286,970

25

24

23402588402

2226€566266

21

20193588193

't91813,563588r 3,563

174,4735664,473

1614,97150614,97',|

15

1425,17Ê50625.179

t3t25,03C5885.030

l't't04,7915664,797

II2.2295882,229

756"t506561

6

517,71250617,712

41 97,594506197,594

3

2

1

LineNo.

UnamorlizedAccumulation

{s)Amount

{0Account

(e)

Costs Incurred ExternallyCurrent Year

{d)

cosls lncurfed lnternallyCurre¿tYear

AMOUNTS CHARGED IN CURRENT YËAR

(2) Research Support to Edison Electric lnslitule(3) Research Support to Nuclear Power GÍoups(4) Research Support to Others {Classify)(5) Total Cost lncurred

3. lnclude in column (c) all R, D & Ð items performed intemally and in colúmn (d) those items performed outside the company costing $50,000 or more,

brÌefly describing the specilic area of Fl, D & Þ (such as salely, conosion control, pollution, automation, measuremenl, insulalion, type of appliance, etc,).

Group items under $50,000 by classificalions and indicate the number of items grouped. Under Other, (A (6) and I (4)) classify ilems by type of R, D &

D activity.4. Show in column (e) the account number charged with expenses during the year or the account lo urhich amounts were cap¡tali¿ed during the year,

list¡ng Account 107, Construction Work in Progress, lirst. Show in column (l) the amounts related tô lhe åccounl charged in column (e)

5. Show ín column (g) the total unamortized accumulaling of costs ol projects. This total must equal lhe balance in Account'188, Research,

Development, and Demonstralion Expênditures, Outslanding at the end of lhe year.

6. lt costs have not been segregalèd for R, D &D activities or pro¡ects, submit estimales lor columns ic), (d), and (t) with such amounts identifìed by"Est,"7, Reporl separately research and relaled testing faciliìies operated by the respondent.

\¡ AC t lvl I IES (L;onl¡nuecRESEARCH, DEVELOPMENT, AND DEMONSTRATIC


End of 2015/Q4Date of Reoort(Mo, Da, Yi)il

This Reoorl ls:(f ) [¡An Orisinal(21 [-lA Resubmission

Name of Respondent

Soulhwestern Eleclric Power Company

FERC FOBM NO. I (EO.12€7) Pâge 353

38

s7

36

35

94

33

32

3r

30

æ28

27

26

25

24

23

Tolal22

21

20

B. (5) lolal Cost lncuned Êxtemally19

18

17

16

15

14

28 ltêms < $50,00013

12

11

10

EPÊl Fesearch Portfolioo

8

EPRI Env¡ronmental Sc¡ence proiects7

6

ËPRl Environmental Controls pro¡eclsB. {1) Electric Power Research lnstitute5

4

3

2

6 ltems < $50,000B. Electric R&D Ëxternal1

Description

(b)

Classification(a)

LineNo.

1, Describe and show below cosls incurred and accounts charged during lhe year for technological fesearch, development, and demonstration (R, O &D) pro¡ect initiated, cont¡nued or concludêd during the year. Fleporl also support given to others during the year for ioin¡y-sponsored proiects"{ldentltyrecípient regardless ol atliliation.) For any R, D & Þ work caried with olhers, show separatëly the respondent's cost for üe year and cost chargeable toohers (See definilion of research, development, and demonstration in Uniform System of Accounts).2. lndicate in column (a) the appl¡cable classilication, as shorvr¡ below:

Classif ical¡ons:A. Êlectric Ê, D & D Performed lntemally:

(1)Generationa. hydroelectric

i. Recreatíon lish and wildl¡feii Other hydroelectric

b. Fossil-fuel steamc. lnlernal combustion or gas turbined. Nuclearê. Unconventional generationl. Siting and heat rejec-tíon

(2) Transmission

a. ôverheadb. Underground

(3) Distribution(4) Regional Transmission and Market Operation(5) Environment (other than equipment)(6) Other (Classify and includ€ ¡tems in excess of SS0,000.)(7) Total Cost lncuned

B. Electdo, R, D & D Perfo'rmed Extemally:(1) Research Suppod to the electrical Research Council or the ãleÇlric

Power Reseârch lnstitute


End of 2015/Q4Date ot Reoort(Mo, Ða, Yi)tfSoulhwestem Electric Power Company

1)ls:Original

l2', A Resubmission

FEñC FOFM NO. I (ED. 12€7) Page 352.1

38

s7

36

35

34

33

32

3t30

æ28

27

26

25

24

23

221,860,9671,573,997286,970

21

20

't91,573,9971,57S.997

18

17

16

1547,85(58847,850

18,97t56618,973

13130,92i506130,922

12

tl31,4535883r,453t0136,703566136,703

I120,953s06120,953

I7668,924506668.924

6

5380,084506980,084

4

322,95558822,955

28,07fcÞos,073

ITJAV5067,107

LlneNo.

Unamortized

Accumulalion(s)

Account(e)

Cosls lncuned ExtemallyCurrent Year

(d)

Costs lncurred lnternallycurreËlYeat

AMOUNTS CHARGED IN CURRENT YEAR

(2) Research Support lo Edison Electric lnslitute

{3) Reseârch Support tô Nuclear Pourcr Groups(4) Resêarch Support lo Others (Glassify)(5) Tolal Cost lnqJrred

3. lnclude in column (c) all R, D & û items performed intemally and ¡n column (d) lhose llems pelormed outs¡ds the company cosling $50,000 or more,brielly describing the specillc area of R, D & 0 {such as salety, corrosion control, pollution, automatíon, measuroment, lnsulation, typo of appltance, etc.).Group ltems under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify ilems by type of R, D &D activity.4. Show in column (e) lhe accaunt number charged with expenses during the year or lhe acclunt lo which amounts we¡e caFilãlizÈd during th€ year,listing Account 107, Gonstructíon Work ¡n Progress, firsl. Show in column (Q the amounts relaled to the accûunl charged in column (e)

5. Show in column (g) lhe tolal unãmortized accumulating of costs of projecls. Th¡s totaf musl equal the balancs in Account 188, Research,Oevelopment, and Demonsfation Expendifures, Outstanding at the end of the year.

6. lf costs have not been segregated lor R, D &D activities or pro¡écts, submit estimates for columns (c), {d), and (0 with such amounts identiñed by"Esl;'7. Reporl sepa¡atsly r€seârch and relätêd lssting faÇilitigs op€rated by the r€spondent.

wrruiluw


Ënd of 2015/04Date of Reoort(Mo, Da, Yi)tt

This Beoort ls:(l) fiAn Original(2) ¡A Resubmission

Name of Flespondent

So{¡thwestern Electric Power Company

FEHC FoRM NO. r {ED. 12{7} Page 353.1

Transmission47

Slorage, LNG Terminaling and Processing46

Olher Gas Supply,15

Prodr¡ction-Nalural Gas and44

Productbn-Manuf actured Gas43

Maintenance42

IOTAL Operation (ËnterTolal of lines gi thru,lO)41

and General40

Sales39

Customer Seryice and lnlormational3S

Customer Accounts37

DlslributionJO

Transmlssion35

Slorage, tNG Terminalíng and Processing34

Olher Gas SupplystGas (lncluding Expl, and Dev.)32

Prodrctl¡n-Manufactured Gas3lOperation30

Gas2992,133,2834,æ7,77187,565,512AL Oper. and Maint. {Total of lines 20|hru 27}28

5,361,375and General Total of lines 10 and 'l27

Sales {Trânscribe from line 9}262,561,475Cuslomer Service and lnformational (franscribê trom line B)25s,383,860CustomerAccounts (Transcdbe trom line 7)24

Distribution (EnterTotal of lines ô and 16)23

R€g¡ona¡ Markel (Enter Total of Unes 5 and 1S)n3.07,774Transmission (EnterTotal of lines 4 and 14)21

41,U2,715Productlon (Enter Total ot lines 3 and 13)æTotal Op€ratíon and Ma¡ntenanceT9

33,666,,135TOTAL Maintenance (Total ol lines 13 thru 17)18

't,512,091Adm¡nístrative and General17

13,599,109Þlstribution16

Regional MarketT5

1,351,138Transmissíon1417,2Q4.O97Production13

Maintenance12

53.899,077TOTAL Operation {EnterTotal ol lines 3 thru 10}11

3,849,284Adminlstrative and General't0Sales9

2,961,475Customer Sêrv¡ce and lnformationa¡85,383,860Customer Accounts7

14,909,204D¡6tribution6

Regional Market52.156.636Transmission4

24,608.618Production3

Operalion2

Elect¡ic1

Total

(d)

Direct PavrollDistributíon

(b)

Classification

{a)

LineNo.

Report below ihe distribution of total salaries and wages for lhe year. Segregate amounts originally charged to clearing âccounts toUlil¡ty Depårtmênts, Construction, Planl Removals, and Other AccorJnts, and enler such amounls in the appropriate lines and columnsprovided. ln determining lhis segregalion of salaries and wâges orig¡nally charged lo clearing accounts, a method of approxirnationgivíng substantially correct results may be used,

ÐISTBIBUTION OF SAI.ARIES ANÐ WA(ih$

Year/Period of FeportEnd of 2O15lQ4

Date of Reoort(fr¡lo, Da, Yi)lt

This Reoort ls:(1) fiAn Original(2') [A Fesubm¡ss¡on

Name ot Respondent

Southwestem Electric Power Çompany

FEBC FOBM NO. 1 {ED.12-88} Page 354

138,789.4t8138,789,418ÏOTAL SAIARIE$ ÁND WAGES985,266.629-6,619,77411,880,403TOTAL O,ther Accounts95

94

93

92

91

90

-65,468.6s¡68¡156 - Other Electric Fìevenue89237,652237,6ã2426 - Politícal Activities88

8288284O1 - Operating Expênse - Nonassociated8719,87719,877242 - MíscCurrent & Accrued Uab86

-568-568188 - Êesearch & Ðevelopment85

169,192f69,192186 - Misc Oelened Debits&1¡16,168146,168185 - ODOTemporary Fac¡lilies83

-3,352,0953,352,095184 - Cl€aring Accounts82

-2,2772,2n183 - Prelím Survey8J

-3.265,4023,265,4t)2163 - Stores Exp€nge Undlstributed804,307,2624,307,262I52 - Fuel Stock Undislributed79

45t,ô8645f ,686151 - FuelStock78

Other Acco¡nts (Specrfy, provide details ín lootnote):n7,il7,8287,173,623TOTAL Plant Rernoval (Total of lines 73 thru 75)76

Other (provide details in lootnote):75

Gas Plant747,547,828374,2057,179,623Electdc Phnt73

Plant Romoval (By Utilþ Departmenls)72

33,841.6781,677,79832,16iÍt,880TOIAL Construction ffot,al ol lines 68 thru 70)7'l

Other (provide details in footnote)t70

Gâs Plãnt6S

33,841,6781,677,79832,163,880Electdc Plantô8

Construclion (By Utilþ Ðepartments)67

Ut¡lity Planl66

92,133,2834,æ7,n',\87,565,512TOTALAII Ulility Dept. {Total of lines 28, 62, and ô4)65

Operation and Maintenance6,4

Othgr Util¡ty Departments63

TOTAL Oæration and Maint. (Total ol lines 62 thru 61)62

Administralive and General (Lines 4O and 49)61

Sales (Line39)60

Customer Service and lnformational (Line 38)59

Customer Accounts (Une 37)58

D¡stributlon (Lines 36 and 48)57

Transmission (Unes 35 and 47)56

Storags, LNG Terminalins and Prooesôinq {lolal ol lines 3t thru55

Other Gas Supply (Enter Total ol lines 33 and 45)5,4

Produclion-Natural Gas (lncluding Ëxpl. and Dev.) (Total lines 32,53

Produclion-Manufactured Gas (EnterTotal of lines 31 and 43)52

Tolaf Operalion and Maintenance5't

TOTAL Maint. (Enter Total of lines 43 thru 49)50

Administralive and Generâl49

D¡stribution48

Total

(d)

Direcl PavrollDislribtJtÍon

tbl

Classilication

(a)

LineNo.

DISTRIBUTION QF SALARIES AN0 WAGËS (Continued)


End ot 2011Q4Dat€ of ReDort(Mo, Da, Yi)tl

Name

Southwestem Eleclric Power Companyl2:) A Flesubmission

FERC FORM NO. r (ED. 12.88) Page 355

FOOTNOTEDATA


201ryQ4


tt

This Report is:(1) XAn Original(2\ A Resubmission

Name,of Respondent

SouthWestem Ëleclríc Po.rver Company

Determined by a query of thê general ledger. (Formula Rates)

450.'l11FERC

( 15,514,880)TOTAL46

.+5

44

ß42

41

40

39

38

37

36

35

34

33

32

31

30

29

28

27

26

26

24

23

22

21

20

f918

17

16

15

14

13

12

11

7.843.42CTransmission Losses10

( 18.,188.429.)Transmission Conqestion RevenueI{ 1.648.625)Operatino Reservest

10.34{1.938Conqeslion7

Othêr ltems llísl separatelvlþ

2-¡ÍôO.66êAncillary Servíces5

Transmission Blqhts4

( 78.288.875)N€t Sales (Account 447)362.321.025Net Purchases {Account 555}2

Enerqy1

Balance at End ofYear(e)

Balance ât End ofQuarter 3

(d)

tsalance at h.nd olQuarter 2

(c)

Balance at End otQuarter 1

(b)

Descriplion ot llem(s)

(a)

Line

No,

1" The r€spondent shall report belo$r the details called for conceming amounls it recorded ín Account 555, Purchase Power, and Account 447, Sales forResale, fot ltems shown on ISO/RTO Setllement Statements. Transactions should be separalely netled for each ISO/RTO administered energy marketfor purposes ol determining wtrelher an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used äs th€ basis for determlningwhether a net purchase or sale has occuned. ln each monthly reporting pêriod, the hourly sale and purchase net amounts aré to b€ âggregated andseparately reported in Accounl 447, $ales for Resale, or Accounl 555, Purchased Power, respectively.

AMOUNTS INCLUDED IN ISO/RTO SÊTTLEMENÎ STATEMENTS

Year/Per¡od of ReportEnd of 2O15lQ4


This Reoort ls:(1) fiAn Original(2) TIA Re$ubm¡ssion

Name of Responclent


FERC FORM NO. 1/3-O {NEW.12{5) Pago 397

Tolal Yeeflo

Date¡Yeâ¡

i7

Tolal lor Ouarler416

Dec€{hber15

November14

Ocloðer13

ITolal lorQ¡ala312

Sedêmbêr11

Arjgrrst10

Julyo

TTotal for Ouarler2IJune7

May6

April

Tolal forOrrarterl4

Mardra

Febn¡ary"

ir.'....¡è;¡¡¿¿ïi -if irJanuaryI

Other

Service

(')

Short-Term Firm

Point to-point

Reservation

(i)

O'ther Long.

Term Firm

Service

(h)

Long-Term Finn

Po¡nt-tepo¡nl

Êeservations

(s)

Firm Network

Sewice lor

Olhers

(r)

Firm Nelwo¡k

Service for Sell

(e)

Hour ol

Monthly

Peak

(d)

Dayol

Monthþ

Peak

(c)

Monthly PeakMW - Tolal

(b)

Month

(a)

LineNo,

NAME OF SYSTEM

(1) Report the monthly peak load on lhe respondent's transmission system. lt the respondent hås tu¿o or more power systems which arê not physicallyinlegrated, furnish the rgquired informalion for each non-¡ntegrated system"(2) Report on Column (b) by monlh lhs tfansmission system's peak load.(3) Report on Columns (c ) and {d) the specified inlo¡malion lor each monthly kansmiss¡on - system peak load reported on Column (b).(4) Report on Columns (e) through (l) by month the syslem' monthly maximum megawall load by statislical classifications. See General lnstruction for thedelinition of each stalisl¡cal classificalion.

Yeat/Period of Report

End ot 2015/Q4Dale of Report(Mo, Da, Yr)lt

(1 An OriginalA Resubmission(2)

Name of Flespondent


FERC FORM NO. rl3-Q{NEW.07-04} Page 400

FOOTNOTE ÐATA


2015/Q4


ltThis Fleport is:


- A Resubmission

Name of ñespondent

gouthwestem Electrlc Power Cort¡panv

'Southwestern Electric Power Company's transmission serv¡ce is administered through aRegionalTransmission Organization (RTO) and requested information is not available on anindividual company basis.

450.11FERC

27,905,50(TOTAL (Ënter Total of lines 9, 10, 14, 18

and 1 9)

2A

Transmission By Others Losses1S

Nel Transmission for Olher (Line 16 minus

lÍne 17)

f8

Delivered17

Rece¡ved16

Transmission For Other (Wheeling)15

Net Exchanges (Line 12 minus line 13)14

0elivered't3

27,905,50€TOTAL (Enter Total of Lines 22 Through

27) (MUST EOUAL LrNË 20)

28

Rece¡ved12

Power Exchanges:1t

528,65SIolal Ënergy Losses277,638,964Purchases't0

107,441Ënergy Used by the Company (Electric

Dept Only, Ëxcluding Station Use)

2620,266,53€Net Generation (Enter Total of lÌnes 3

through 8)

o

Fnergy Furnished W¡thout Charge25Less Energy for PumpingI

3,158,295Non-Requirements Sales lor Flesale (See

inslruction 4, page 31 1.)

24

24,487Other7

Hydro-Pumped Storage6

6,248,493Requirements Sales for Resale (See

inslruclion 4, page 31I.)

23

Hydro-Conventíonal5

Nuclear4

17,862,612Sales to Ult¡mate Consumers (lncluding

lnterdeparùnental Sales)

22

20,242,04(Steama

Generation (Excluding Station Use):2

DISPOSITION OF ENERGY21SOURCES OF ENERGYI

MegaWatt Hours

(b)

Item

(a)

UneNo.

MegaWatt Hours

(b)

Item

(a)

LineNo.

Report below the inlormation called for conceming lhe disposition of electric energy generated, purchased, exchanged and wheeled during the year

ELECTRIC ENERGY ACEO

Year/Period of ReportEnd of 2015/Q4(f)

tztAnA Resubmission tt

Name of Respondent


FcRC FORM t¡O. I (EÞ. 12-90) Page 401a

3,212,39227,905,500TOTAL41

080033,46S194,4352,040,s1c0ecember4{

08002S3,38188,5191,755,20CNovember39

1700123,S2858,5391,873,150October38

1600I4,643305,6452,533,087Septembor37

'1700105,149210,6602,738,572August3(

1700275,023327,4552,96s,197JulyQC

1700244,664320,7252,584,&3Junea1700273,708-18,3072,045,404May3i170073,1473',t8,8221,862,42rApril32

070064,389342,5272,253,43¡March31

0800274,24461 ,8882,&1,441February3(

080084,748601,4842,824,734JanuaryD'

Hour

(f)

Day of Month(e)

Megawatls (Seelnstr.4)(d)

Monlhly Non-RequirmentsSales for Resale &Associaled Losses

(c)

Total Monthly Energy

(b)

Month

(a)

Line

No.

MONTHLY PEAK

NAME OF SYSTËM:

1. Report the monthly peak load and energy output. lf lhe respondent has tì^¡o or more power wtrich are not physically integrated, furnish the reguiredinlormation lor each non- Integrated system"2. Report ¡n column (b) by month lhe system's oulput ¡n Megawatt hours tor each monlh.3. Feport in column (c) by month the non-requirements sales for resale. lnclude in the monthly amounts any energy losses associated w¡th thê sales,4. Beport in column (d) by month the system's monthly maximum megawatt load (ôO minute integration) associated with the system.5. Beport in column (e) and (f) ths specified information for each monûrly peak load reported in column (d).

Year/Period ol ReportEnd of 2015/44

Date ot Reoort(Mo, Da, Yi)tt

e

Southwestem Electric Power Company(1) An Original

A Flesubmission

FERC FORM NO. 't {8D.12-90} Page 401b

'I 1601.00010267.0001 1 601.0000.0000.0007156,000Average BTU per KWh Net Generation44

0.0000.1 200.0400.0000.0000.020Average Cost of Fuel Surned per KWh Net Gen430.0001 1.2303.1400.0000.0003.140Average Cost of Fuel Bumed per Million BTU42

0.00065.9903.1 700.0000.0003.2tûAverage Cost ol Fuel per Unit Bumed41

0.000ô5.9903.1700.0000.0003.210Avg Cost ol Fuel/unit, as Delvd f.o.b'. during year400140000101 1001023Avg Heat Cont - Fuel Bumed (btdindicate ¡t ñuclear)390-2657 18390025291454Quanlity (Unils) of Fuel Bumed3B

BBLSMCFMÇFtJñit (Coal"tÒnVOil-barreVGas-mcflNuclear-indicale)37

coMPostTotLGASGASFuel: Kind (Coal, Gas, Oil, or Nuclear)36

0.1 1 150.02ô3Expenses per Net KWh355559475952ø6774Total Production Expenses34

43558890561Ma¡ntenance ol Misq $team (or Nuclear) Plant33

801753125713Maíntenance of Electric Plant32

8-q6281.32859.3-jMaintenânce of Boiler {or reactor! Planl31

1 2631 I958654Maintenance of Structures30

1 ô3687455679Maintenance Supervision and Engineering29

.27-25243Allowances28128192946Rents27

1 61 4428r 000971Misc Steam (or Nuclear) Power Expenses26530S281 836706Ëlectric Ëxpenses25

00Steam Transferred (Cr)2400Steam From Other Sources23

1301352268sSteam Expenses220Coolants and Water (Nuclear Plants Only)21

18143508I4151 88Fuel2A

2183612206981Productíon Expenses: Oper, Supv, & Engr19

't 34.1697614.5128Cost per KW ol lnstalled Capacity (line 17l5) lncluding18

37241243453510479Total Cost17

1263344507714Asset Belirement CostsI6321 0971 I394007343Equipmenl Costs't5

380415458624624Structures and lm provements14

24026370798Cost of Plant: Land and Land Flights13

49841 000361619300CNel Generalion, Exclusive of Plant Use - KWh12

2626Average Number of Employees1'l

242621When Limited by CondenserWaler10

0When Not Limited by Condenser Water9

00Nel Continuous Plant Capability {Megawatts}I86r7975Plant Hours Connected lo Load7

196623Nel Peak Demand on Plant - MW (60 minutes)o

277.27738.00Iotal lnstalled Cap (Max Gen Name Plaie Batings.MW)5

1 95S201 0Year Lasl Unit was lnstalled419471960Year Originally Constructed3

Outdoor BoilerOutdoor BoilerType of Conslr (Conventional, Ouldoor, åoiler, etc)2

$leam$teamKind of Plant (lnternal Comb, Gas Turb, NuclearI

PlantNamel lieþerman

(c)

Item

{a)

LineNo.

'L Repon data for plant in Service only. 2. Large plants are s'team planls with installed capacity (name plate rating) of 25,000 Kw or more. Report inthis page gas-lurbine and internal combustion plants ol 10,000 Kw or more, and nuclear plants. 3. lndicate by a footnote any plant leased or operatedas a ioint lacil¡ty, 4. lf net peak demand for 60 minutes is not available, give data which is available, specifying period. 5^ lf any employees attendmore than one plant, report on line 11 lhe âpproximate average number of employees assignable lo each plant. 6. lf gas is used and purchased on atherm basis report the Btu content or the gas and the quantity ol fuel burned converted to Mct. 7. Quantities of fuel bumed (Line 38) and average coslper unit of fuel burned (L¡ne 41) must be cons¡stent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20. 8. lf more than onefuel is burned in a plant furnish only the composite heat rale lor all fuels burned.

STEAM-ELECTRIC GENEBATING PLANT SIATISTICS (Large Plants)


End of 2O15/Q4

Date of Beport(Mo, Oa, Yr)

This Reoort ls:(1) fiRn original(2) ¡ A Besubmission

Name of Respondent

Southwestern Electric Power Com pany

FERC FORM NO.1 {REV. r2-03) PagE 402

4412142.W12000.00012142.0000.0000.000266't't.&)Of 2799.0000.00012799.0004it0.0000.1500.0400.0000.0000.0800.0000.0000.040420.000'12.6&3.1700.0000.0003.1300.0000.0002.810

410.00074.4803.2700.0000.0003.S300.0000"0ö02.900400.00074.4803.2700.0000.0003.9300.0000.0002.90039014000010300012õ4001ûæ380167827682005U2A00126925337BBLSMCFMCFBELSMCF36COMPOSITÊorLGASGASCOMPOSITEotLGAS350.05250.099?0.094234348346&t551576s657129331025386946767283222839901051967293

g12ß72A783651't539+7730870972841346673529385379293É1&4Q44

2867109923072717061ô526342656014ô736124327ß25883885ô1255628102400029000221022176493891546078210002025útæ721018936915171960359453972688760

't8115.0875174.034ô'138.309517101,1518S'870172969085618

't610q395112359220366081592.1491047626702591059t51474651 1589294{t78{¡,91413443729584{t7102781

1266379700055310001024{17000

1l34029JO875504ô9s000I000767793621 128

686449s55588t.5250,00499.504197119541974319641954"r9502Outdoor SoilerOutdoor Bo¡lerOutdoÕr Boiler1SteamSteamSteam

No.

LinePlantName: W/kes

(0

PlantName: Lone 91ar

(e)

PlantName: Knoxlee

(d)

Items under Cost of Plant are based on U. S. ol A, Accounts. Production expenses do not include Purchased Power, $ystern Control andDispatching, and Other Ëxpenses Classified as Olher Power Supply Expenses. '10. For lC and GT plants, report Operating Expenses, Account Nos.

and Sg on Une 25 'Electrio Expenses,' and Maintenance Accounl Nos. 553 and 554 on Une 32, 'Maintenance of Electríc Planl.' lndicate plantsfor peak load service. Designato aulomatically operated plants. I L For a plant equipped with combinations of lossil fuol sleam, nuclear

hydro, inlemal combustion or gas-turblne equipmenl, report each as a sepâratè plant. However, if a gâs-lurbine unil lunctions in a combined

for the various components of fuel cost; and (c) any other informatlve dâta concerning plant typê fuel used, fuel enrichment type and quantity for the

any excess cost unitstypesdevelopment;andtocoslspowef of(b)researchattributedgenerated includingoffor cosÌaccounting method(a)power byplant, briellygeneratinglfasteam plant.wilh thesteãmd explainnuclear2.the gas-turbineunit, includeconvenllonalw¡thoperalion

and and

STÉAM-ELECTRIC GËNËFATING PLANT STATISTICS (Large Flants) (Co ntínued)

Year/Períod ot Reporl

Ënd of 2015/Q4

Date of ReDort(Mo, Da, Yi)tt

Th¡s(1)(2|

ReDort ls:[lAn Original

üA Besubmission

Name of Bespondent


FERC FOBM NO.1 (FEV. 12{}) Pagê 403

r0307.00010765.00010307.0001 1 159.0001't 176.0001 1 159.000Average BTU per KWh Net Generation44

0.0000.1700.0200.0000.1600.020Average Cost of Fuel Bumed per KWh ñet Gen4Ít

0.00015.5001.8500.00013.9602.140Average Cost of Fuel Bumed per Million BTU42

0.00099.69030.9600.oo082.1 1036.g20Average Cosl ol Fuel per Unit Bumed41

0.00067.46031.0100.00071.88037.WAvg Cost ol Fuellunit, as Delvd l.o.b. during year40

01531718369014000û8607Avs Hoat Cont " Fuel Bumed {btr./¡ndícate if nuclear}39

029039331500308643963834of Fuel Bumed38

EBLSTONSBBLSTÕNSUnít (Coal-tons/Oil-barreUGas-mcl/Nuclear-indicate)37

coMpostTotLCOALcoMPosrrorLCOALFuel: Kind (Coal, Gas, Oil, or Nuclear)36

0.02630.0300årpenses per Net KWh35

4007561818375?338Total Production Expensesu97750294841 rMaintenance of Misc Steam (or Nuclear) Plant33

6825235723191Maintenance of Electric Plant32

eatÊ,aaF,.r0858822Maíntcnance ol Boiler for roanlnrl Planl31

6'l ô617534S85Ma¡ntenancs of Stnrtures30

274.54-1607878MaÍntenance Supewision and Engineering29

8414104743Allowances28

39094157578Rents27

?59638518r956Misc Steam (or Nuclear) Power Expenses26

582828282C15õElectric Expenses25

00Steam Translened (Cr)a00Steam From Other Sources23

7414053501 147Steâm Expenses2200Coolants and Water (Nuclear Plants Only)21

30673166149583675Fuel2A

1294405373ø802Production Expenses: Oper, Supv, & Engr't9470.9877395.5478Cost per KW of lnstalled Capacity (line t7l5) lncluding18

131405555662147058Total Cost17

74030761900626¡Asset Retiremenl Costs16

95r29856551978354Equipment Costsl525s0769889266962Structures and lmprovements14

336,1925189U74of Plant: Land and Land13

'1s209840006f30770000Net Generation, Exclusive of Plant Use - KWhl¿

90133Average Number of Employees1l2641562When Umited by Condenser Water10

00When Not Limited by CondenserWalero00Net Continuous Pfant Capability (Megawatts)8

73647452Planl Hours Connected lo Load7

2651535Net Peak Dèmând on Plant " MW (60 minutes)6

279.0A'1674.0ûlnslalled Gen Namê Plate

19781982Year Last Unit was lnstalled4

19781977Year Originally Qonstructed0

Outdoor BoilerOutdoor BoilerType of Constr (óonventional, Outdoor, Boiler, etc)2

SleamSteamKind of Plant {lnternal Comb. Gas Turb, Nuclear1

PlantName: :üti.€F.ffiffiffi

PlantNamel Welsf¡

(b)

Item

(a)

Line

No,

1. Beport dala for plant in ServÌce only. 2. Large plants are steam plants with installed capacity {name plate rating) of 25,000 Kw or more. Fleport inthis page gas-turbine and intemal combustion planls of 10,000 Kw or more, and nuclear plants. 3. lndicate by a footnote any plant leased or operatedas a ¡oint fac¡lity. 4. ¡f nel peak demand tor 60 minutes is not available, give data which ls ava¡lable, specifying period, 5, lf any employees åttendmore than one plant, report on line 1'l the apploximale average number of employees assignable to each plant. 6. lf gas is used and purchased on atherm basis report the Btu content or lhe gas and the quantity oÍ fuel bumed converted to Mct. 7. Quantities of fuel bumed (Une 38) and average costper unit of fuel bumed {Line 41) must be cons¡slent w¡th charges to expense accounts 501 and 547 (Une 42) as show on Une 20. L lf more than onefuel is bumed in a plant lurnish only the composite heat rate tor all fuels burned.

STEAM"ELECTRIC GENËRATING PLANT STATISTICS (t-arge Plants) (Continued)


End of 2015/Q4

Date ol Reoort(Mo, Da, Y.r)

Th¡s(1)

l2l

Report ls:fiAn Oríginal

nA Resubmission

Name of Flespondent

Southwestem Electríc Power Company

FERC FOHM NO. r {REV. 12-03} Pags 402.1

440.0000.00012409.0001 1495.000't1721.0001 1494.00010658.000f0667.00010658,000

ß0.0000.0000_3700.0000.0400.0500.0000.ô300.030

4:2t.0000.00029.9700.0003.4243.S400.0002.8103.280

410.0000.00030.2500.0003.59053.ô200.0002^84042.390

400.0000.00030.2s00.0003.59056.0300.0002.W443.2A

390010090104868070101264ô6

38003010320782851499538090232326t200

37MCFMCFTONSMCFTONS

36GASCOMPOSITEGÅSLIGNITËCÛMPOSITEGÀSLIGNITË

350.43230.05620.0429

341058660310021753417V290217

336519957581891512

32f 173480262672993582

310830387111405422

3009335771058666

291 17337754961267't57

28103425034348?

27045833101934

26ô07427928112160321

25219200741 9301175922

24000

23000220286027841239fi21000

20sl0644981398100t4223S659

'19ô7982'1104705383460t18382.æ081146.2266923.68{i}17130094481s3239424757211't593

16025296571061791 I1593758238274479212447510468

1434884í19153874763108140185

131451852r510615584Íì029

12244870041 7&318100039ô5867000

1150109

l02A4257580

s000

I000

710687607357

6362270586

Ê34t).00289.9961S.3t¡

4200719861985

320071 9861985

2No BoilerÕutdoor BoilerOutdoor Boller

1Gas TurbineSteamSteam

LineNo.

PlantName: l/arryÐ Matlíson

{0

PlantNarne:

Plant

Name:

L ltems under Cost of Plant are based on U. S. ol A. Accounts, Production expenses do not include Purchased Power, Syslem Control and LoadDispatching, and Other Expenses Classilied as Other Power Supply Éxpenses. '10" For lC and GT plants, report Operaling Expenses, Account Nos.547 and 549 on Line 25'Electric Ëxpenses,'and Mainlenance Account Nos. 553 and 554 on Line 32, 'Maintenance of Electric Plant.' lndícale plantsdesigned lor peak load service. Designate automaticålly operated plants, 'l 1. For ä plant equipped with combinations ol fossil fuel steam, nuclearsleam, hydro, lntemal combustion or gas-turbine eguipment, report each as a separate plant However, it a gas"turbine unit tunclions in a combinedcycle operation with a convent¡onal steam unil, include the gas-turbine with the steam plant. 12. lf a nuclear power generating plant, briefly explain bylootnote (a) accounl¡ng method lor cost of power generated including any excess cosls attributed lo research and development; ib) types ol cost unitsused lor lhe various components of fuel cosl; and (c) any other lnformative data concemlng plant Vpe fuel used, luel enrichment type and guantity lor thereport period and othe¡ physical and operating characteristios of plant.

ÊTEAM- ÉLECTRIC G EN ERATI NG PLANT STATI STI CS (Large Plants) {Confrnued)

Year/Period ot Report

End ol 2015/Q4

Oate of Report(Mo, Da, Yr)tt

This Reoort ls:(1) filen originat(2) ¡]A Resubmission

Name of Respondent


FËRC FOFM NO. r (REV. 12-03) Pâg€ 403.1

[email protected] BTU per KWh Net Generatlon440.0000.0000.0000.0000.0300.020Average Cost ol Fuel Bumed per KWh Net Gen4{'0.0000,0000.0,000.0003.1802.270Average Cost of Fuel Bumed per Millíon BTU420.0000.0000.0000.0003.30040.460Cost of Fuel per Unit Eumed410.0000.0000.0000.0003,30041,û40Avg Cost of as Delvd f.o.b. during yearN000010408905Heat Cont - Fuel Bumed it39o00045&tS1230591Quanlity (Units) of Fuel Bumed38

MCFTONSUnit {Coal-tons/Oil-banel/Gas-mcf/Irluclear-indicate)?:7

COMPOSITGASCOALFuel: Kind (Çoal, Gas, Oil, or Nrælear)360.00000.0310Expenses per Net KWh35

074479371Total Production Expenses3401868830Maíntenancs of Misc Steam (or Nuclear) Plant3301531249Maintenance of Electric Plant32U+t I t+44Mâlnlênân.a nf Flnilc¡ /^r raâ^l^rl Þlâñì3!015s0187Maintenance of Structures3001984459Maintenance and290-137ô4Allowances28061774Renls2702563142Misc Steam (or Nuclear) Power Ëxpenses26090¡1289Electric Expenses2500Steam Transfered (cr)2400Steam From Other Sources2303792904Steam2200Coolants and Water (Ntrclear Plants Only)21053102309Fuel2Q024r6566P¡oduction Expenses: Oper, Supv, & Engr't903149.3231qog! p9r KW of lnstalled Capacity (line 17l5) lnctudingl801 648985553Total CÖst1705093955Asset Retirement Cosls1601361918240Êquipment Costs150268617742Structures and lmprovements14013355616Cost of Plant: Land and tand Rights1302403398000Generation, Exclusíve of Flant Use - KWh120112Average Number of Employees't104-r7When Limited by Condenser Water1000When Not Limited by Condenser WaterI00hlet Cont¡nuous Plant Câpability (Megawatts)I06589Plant Hours Connected to Load70479Net Peak Demand on Plânt - MW (60 mínutes)6

0.00523.60lnstalled Gen Name Plate52012Year Last Unit was lnstalled42012Year Originally Constructed3

Outdoor Boilerïype of Constr {Conventional, Outdoor, Eoiler, etc}2SteamKind ol Plant (lnternal Comb, Gas Turb, Nuclear

,|

PlantNamg;

(c)

PlantNamer

Item

(a)

Une

No.

STEAM.ELECTRIC GENEBATING PI.ANT STATISTÍ CS Planls\ (Continued)1. Report data lor plant rn Service only, 2. Large plants are steam planls with installed capacity (name plate rating) of 25, or more. Report tnthis page gas-turbine and inlernal combustion plants ol 1 0,000 Kw or more, and nuclear plants. 3. lndicate by a footnote any plant leased or operatedas a joint facility" 4. net peak demand lor ô0 m inutes ts not available, give däta which is available, specifying period. 5. It any employees atlendmole than one plant, report on line 1

,| lhe approximaie average numbef ol employees assignable lo each plãnt. 6. tf gaô ¡s used and purchased on âtherm basis report lhe Btu contenl or lhe gas and the quantity ol luel bumed converted lo Mct. 7. Quantities ol luel bumed (Une 38) and average costper unít of fuel bumed (Line 41) must be cons¡stent wilh charges to expense accounts 501 and 547 (Line 42) as show on Line 20. L lf more than oneluel is bumed in a plant furnish only lhe composit€ heat rate for all fuels bumed.

YearlPeriod ol Report

Ënd of 2O15lQ4


This Reoort ls:(1) E:lAn Oris¡nal(2) nA Besubmission

Name of Respondent

Southwestem Ëfectric Power Company

FERC FOFM NO.'t {FEV. 12{3) Page 492.2

FOOTNOTE DATA


2015/Q4


tt

This Repod is:(1) X An Original(2) _ A Resubmission

Name of Hespondent


Arsenal ltill Unit 6 (J. Lamar Sta1l Unit), a naEural gas-fired combusbion turbine co¡nbinedcycle generatj-ng uniL, became operational in June 2010. Uni¡ 6 consists of 2 combust.ionturbines feeding one steam Lurbine.

Flint Power StaL on s n percentages shown

Southwestern Eleclric Power CompanyArkansas Electric Cooperative Corporation

TotaI

s0850t

100t

402 -l

4A2.1 Column: c

1 Llne No.: -l Column: d(2) P Polrer

SouLhwestern Electric Power CompanyNorLheast Texas Electric Cooperativeoklahoma Municipal Power AuthoriEy

Total

percentages shown ow

85.936811. ?2ût2.344*

100. 000t

I Ê-íne No,: eDolee L s Power StaL on S

Southsresbern Electric Þower ComI¡anyCentral Louisiana Elect.ric CompanyNortheasE Texas Electric Coor¡erativeOklahoma Municípal Power Authority

percentages shown O1.r:

40 "234*50.000s5.860r3.9068

402.2 No.: -l Column: b100.00

Tur P1ant, a 600l"fV'l Ultra* un t, opera

(4) Turk Power Station is jointly owned in the percentages shown below:

E December 012

Southwestern Electric Power CompanyArkansas Elect.ric Cooperative CorporationEasU Texas Electric CooperatíveOklahoma Muni-cipal Power Authority

Total

73 .33tLL.6748.33t6.67t

1.00 .000t

FERC FORM NO.1 (ED. 12-87t Page 450.1

317t03"4{t4,0r9,0,(I(]IAL36

I46.4t3"46.45345.00345.0(Sotjthwest Shreveport9G005 DianaaÊ

g-24,6u124,7,z{.15345,00345.0(90004 D¡ana33

3.6.19.)¿

I0.476.3{2.0.11345.00345.0(Pirkev9S003 Lebrock3l30

126.4{3.28-4345.00345.0(Entergy Grimes90{02 Crockett2S

345 kV ln TX28

27

1ô1.5?Subtotal 345 kV in OK26

2â

181.571-61.57345.00345.0{Clarksville 3¡1590-00'l Chamber SprÍngs24

345 kV in OK23

¿¿

¡7.5097.7(Subtolal 345 kV ¡n LA21

2ô13.ffi-3.06345.0(Wilkês9O-013 Longtflood19

'|19.021-19.û2345.0(Southwest Shreveport90-012 Lonswood1€

(lnterconnect)17

'|37.722-37.72345.00345.0(Enlergy El Ðorado9&011 Longt¡,ood16

ntercïnnect)15

,|34.6{3€4.ô345.00345.0(CLECO Dolet H¡lls9G008 Southwest Shreveport14

13

,|7.503.303-3.3345.00345.0{Southwest Shreveport90405 Diana't2

345 kV ¡n LA11

10

€75.83Subtotal 34.5 kV ín ARo

I114.40114.4345.00345.0(Ship6 RoadT1344 Fl¡nt Creek7

122.152.n.15345.0(NW TexarkanaTL327 Turk {AB}6

1I 1.531 -f 1.5267345.00345.0(Tontitown90023 Chambers SpringÁ

117.923-r7.92345.00345.0(CUS Brookline (lnterconnect90-010 Fl¡nt Creek4

13.042-3.04345,00345.0(GFDA GRDA 1 (lnterconnect)9O'0Og Fllnt Creek2I6^851.6.85345.00345.0(Clarksville 345SO-001 Chamber Springs¿

345 kV in AR1

Number

otChcu¡ts

(h)

rJn ùIrucluresof Aoother

Lrnê(s)

wft Þof

Desi

Type ol

Supporting

Stn¡cturete)

Ðesigned

(d)

Operaling(c)

To(b)

From(a)

LineNo.

LENGTH lPole rniles)(ln the èase.ofunoeforound ltnes

report õircuit miles)

Uts.sI(ìNAI IQN

'1. Report infonnation concerfling transmission lines, cost of lines, and expenses for year. List ëach lransm¡ssion line having nomina¡ vollage of 132kilovolts or greater. Êeport lransmission lines below lhess vollages in group totals only for each voltage.2. lransmission lines include all lines covefed by the definition of l¡ansmiss'ron system plant as given in the Un¡lorm Syslem of Ac¡ounls. Do not reportsubslatlon costs and exp€nses on this page.3. Beport data by índividual lines lor all voltages if so required by a State commission.4. Exclude from hls page any transm¡ssion lines for wtrich plant costs are included in Account ,l21, Nonutility Property.5. lndicate whether the type of supporting structurs reported in column {e) is: {1) single pole uood or steel; (2) H-frame $/ood, or steel polesi (3) towecor (4) underground construction lf a transmission line has môre than one þe of supporting structure, ¡ndicate lhe mileage of each type of constructíonby lhe use of brackets and e)dra lines. Minor port¡ons of a transmission line of a different type ol conslruclion need not be distinguished from theremainder of the line.6, Beport in columns (0 and (g) the total pole miles of each lransmlssion line, Show in column (fl the pole miles ol line on $lructures the cosl of which isreporled for the llne designated; conversely, show in column (g) the pole miles of linê on structures lhe cost of which ¡s reported for anolher line. Reporlpole miles of line on leased or partly owned structures in column (g). ln a footnote, explaÍn the basis ol such occupancy and state lvhether expenses withfespeot to such slructures arê included in tñe expenses reporled lor the line designated

TRANSMISSION LINE STATISTICS


End of 2015/Q4Dato ot ReDort(Mo, Da, Yi)

Thls(1)

(2) A Flesubmission

Name of Responcfent

Southwes¡em Eleckic Power Company

FERC FOFM NO.1 (ED. r2€4 Page 422

388,9r 1,57i6,730,r67181,406880,132,24{806,499,35373,632,89r

35¿f5ô.0 AcsB

34

391x1024.0 ACAR

32¡x1272.0 ACSR

31hrû24.0 AcÀÊ

30

ælxlû24.0 ACAB

28

27

28

26

241x795.0 ACSR

23

æ.

21

n't92x1024.0 ACAR

182x795.0 ACSR

17

t62x1024.0 ACAÊ

t5

142ts6.0 AcsR

J3¡x795.0 ACSR

12¿t5ô.0 ACSR

t1

r0

II7¡x954.0 ACSB

6)54.0 ACSR

51x795.0 ACSÊ

4lr5€.0 AcsR

3lxl4ill"0 ACSR

21x795.0 AC$R

'|

No.

TotalEæ,31ses

Rents

{o}

i¿ìaintenanceExoenses'(n)

OperationExpenses

(m)

Total Cost

(l)

Conskuclion andOther Cosls

{k}

Land

CI)

Size olConductor

and Malerial(i)

EXPENSES, EXCËPT DEPRECÍATION AND TAXE$Ç()tt I ul- LrNh (lncruoe in çolumn (,) Land,

Land rights, and clearing right-otway)

7. Do not report the same lransmission line struclure twice. Beport Lower voltage Lines and higher voltage lines as one line. Designate in a tootnote ityou do not include Lower voltage lines with higher voltage lines. lf two or more lransm¡ssion line structures support lines ol the same voltage, report thepole miles ol the primary struclure in column (f) and the pole miles of the olh€r line(s) in column (g)

8. Designate any transmission l¡ne or port¡on thereol lor which the respondent is not the sole owner. ll such property is leased lrom another company,give name of lessor, date and lerms of Lease, and amount ol rent for year. For any transmíssion line olher lhan a leased line, or portion thereof, forwhìch the respóndent is not the sole owner but which the respondent op€rates or shares in the operation ol, lumísh a succinct slaternent explaining thearângemenl and giving particulars (details) of such matlers as p€rcent ownership by respondent in the line, name of co€wlìer, basis ol sharingexpenses of lhe Line, and how thê expenses bome by the respondenl are accounted for, and âccounts aíectêd. Specity whether lessor, cGowÍìer, orother parly is an associated company.9. Designate any transm¡ssion line leased to another company and give name of Lessee, dale and terms of lease, annual rent for year, and howdetermined. Specify whether lessee is an associated company.10. Base the plant cost fígures called for in cotumns 0) lo (l) on the book cost at end of year.

Year/Pêriod of Fleport

End ot 2015/Q4e

Southwestem Electric Power Company(1)

t2)An Dâ,A Resubmission

FERC FORM NO. | (ËO.12-84 Page 423

317103.484,019,04IO TAL36

35

19.18t-9.18I61.00t61.0(East Rogers83-006 East Centertonu24.333

113.9Sr.9.4916r.00161.0{Hyland83'005 Dyess32

31

2-0.87883C

17.091.6.207161.00161.0{Tontitown83-004 Dyess29

t'13.422.13.42't61.00161.0(East Rogers83-0O3 Dyess28

2-16.4527

116.821.0.3716r.00I ôf .0{South Fayetleville83-002 Chamber Sprinss26

2.1 1.5325

I0.641 1.ô1r{.08161.00161.0(Tontitown83-00i Õhamber Springs24

.161 kV in AR23

222820.0571 l.63Total 345 kV SWEPCO21

2A

1612.55476.53Subtotal 345 kV in TXI9T8

17.æ2-7.43345.00345.0(NW TexarkanaTL328 Turk (TX)f'l1tô.003-16.0345.00345.0(Montlcello75000 {TL199) Welsh't€

1.0,766w/tap to NW Texarkana15

187.263-86.492345.00345.0(PSO Valliant (lnterconnect)90-905 Welsh1A

13130,tr3-30.63345.00345.0(Tenaska Rusk County90-022 Lebrock12

2{.911

16.111-5.2'345.00345.0(Plrftey90-019 Lebrockt0167.14367.14345.00345.0(Tenaska Rusk County90-018 Crocketto

II30.6{3.30.63345.00345.0(Wilkes90-O17 Welsh7

t{.7836

Ir2.0844.323-4li¡.54345.00345.0(W€lsh9O-015 Northwest Texa¡kana510.4€34.48345.00345.0(Welsh DC90-014 Welsh4

135.343-35.34345.00345.0(Wilkes90-0'13 Longwoodâ123.6C3-23.6345.00345.0(Welsh9O-007 Diana¿

123.6S3-23.69345.00345.0(Welsh90-006 Dlana1

Number

otCircuits

(h)

Lrn òlruclUresol Another

Ltne(s)

Type ol

Supporting

Struclure(e)

Designed

(d)

Operating(c)

To(b)

From(a)

LineNo.

LENGTH lPole milesl(ln the òase.olunoeforound lrnesreporl öircuit miles)60 3

Ub,SI(JNAT¡ON

l. Report information concerning transmission l¡nês, cost of lines, and exp€nses lor yeâr. List each lransmission line having nomínal voltage of 132kilovolts or greater. Heport transmission lines below these voltages ¡n group lotals only for each voltago.2. lransmission lines ínclude all lines covered by the dofinilion of transmission system plant as given in the Uniform System of Accounts. Do not reportsubstation costs and expenses on this pagg.3. Report data by individual lines lor all voltages if so required by a State commission.4. Exclude from this page any transm iesion lines lor wirlch plant costs are included in Account 1 21 , ñonutil¡ty Property.5. lndicate whelher the type of supporting stnrcture reported in column (e) is: (f ) sfnglê polê wood or steel; (2) H-frame wood, or steel poles; (g) tower;or (4) underground construction lf a lransmission line has more than one type ol supportíng stmcture, ìndioatê the mileage of each type of conslructionby the use of brackets and extra lines. Minor portions of a transmission line ot a differenl type of construction need not bê dist¡nguished from theremainder of the line.

6. Report in columns (f) and (g) the total pole m¡les ol each transmission line. Show in column (f) the pole miles of line on slruclures lhe cosl of which isreporled for lhe line designated; conversely, show in columñ (g) the pole miles of line on structures thê cosl ol which i$ reported for another line. Reporlpole miles of line on leased or parlly owned structures ln column (g). ln a footnote, explain the basis of such occupancy and state lvhether expenses wilhr€specl to such slructures are included ln the expenses reporied for the line designated.


YearlPeriod of ReportEnd ol 20151Q4

Date of Reoort(Mo, Da, Yi)

This Beoort ls:(1) $Rn Originat(2) f-lA Resubmission

Name of Respondent

Southwestern Êlectric Power Company

FERC FORM NO.1 (ED. 12-84 Page 422.1

366811,67r6J30,161.l81,406

880,r32¿{t806,499,35373,ôæ89f

35r590.0 ACSB

341272.0 ACSF

331x397.0 ACSR

32t272.0 A C31rß97.0 ACSR

30r15ôO ACSB

æ1272.0 ACSF

28168.0 ACSR

272x397.0 ACSR

2612720 ACSR

2,¿166.0 ACSR

24t0200 Accc/rw23

a21

20

t9t817)54.0 ACSR

t6lt56ÅcsR

t51156.0 AcsR

14tf560 ACSR

t31x1272.0 ACSR

121x1024.0 ACAR

l1102x1272.0 ACSR

Ià1024,0 ACAR

I¿x795.0 ACSR

72rs6.0 ACSR

ô2r5ô.0 ACSR

61156.0 ACSH

41156.0 ACSR

31x1024.0 ACAR

21156.0 ACSß

J1t56,0 ACSR

No.

TotalExR,3lses

Rents

(o)

Ma¡ntenanceExpenses

(n)

OperationExpenses

(m)

Total Cost

(l)

Construction andone¿*tosts

Land

û)

Size ofConductor

ând Material

tÐ

ÊXPËNSËS, EXCËPI ÞEPRECIATION ANÞ TAXESço$ I oF LlNh. llnc¡uds in Golumn {.1) þnd,Land rights, and clearing right-of-way)

7. Do not repod the same t¡ansmission line slructure twice. Report [ower voltage Lines and higher voltage lines as ane line. Designate in a footnote ifyou do not include Lower voltage lines with higher vollâge lines. lf üo or more lransmission líne stnrctures support lines of lhe same voltage, reporl thepole miles of the prlmary structure ¡n column (f) and the pole miles of lho other line(s) in column (g)

8. Designate any transmission l¡ne or porlion thereof lor which tha respondent is not the sole owner. lf such property ls leased from another company,give name of lessor, date and terms of Lease, and amount of rent for year. For any transmlsslon llne other than a leased llne, or portlon tiereof, lôrwhich the respondent fs not lhe sole owner but which the respondent operates or shares in the operat¡on of, fumish a suçcinct stalement explaining thearrangement and giving parliculars (details) of euch matters as percenl ownership by respondenl in the line, name ol coowner, basis of sharingexpenses ol the Une, and how the expenses bome by the respondent âre acclunted for, and accounls atfected. Specify whether lessor, co-owrìer, orother party is an associated company.9, Designale any transm¡ssion line leased lo anolher company anä give name of Lessee, date and terms of lease, annual rent for year, and howdetermined. Specify whether lessee is an associated company.10. Base the plant cost ligures called tor in columns (Ð to (l) on the book cost al end of year.

TRANSMISSION LINE STATISTICII


End of 2O'l5lQ4gouthweslem Electdc Power Company(1)(z',,

(Mo,

ttÞa,

A Resubmission

FERC FORf'lt NO. I {En.12-87' PagE 423.1

31710s.4€4,0r9.04TOTAL30

14.6Ct-4.6181.00r8't,0{Rogers83430 East Flogers35

'|4.441"4.416r.00r61.0(Roqers83-029 Lowêllu1rf.2{t-"t't2161.00f61.0(fontilown83û28 Low€ll33

2-t0.59432

10.40ß.4t.ã.629161.00r61.0(fonütown83€27 Flint Creêk31

2.10.337r30

114.3¡14.013816t.00161.0(Flint Cre€k89025 Chamber Springs29

17.441"7.44161.001ô1.0(fonlitown83{26 DyEss28

113.96't-t3.9616T.00161.0(ffest Boonevillê83-û22 North Magazine27

I2.9€r.2.96181.00161.0(Southeast Fayettevillo83421 South Fayetlôv¡lle26

0nterconnect)25

I2.06¿-2,6't6t.00161.0(GRDA Siloam Springs83-020 Slþam Springs24

I8.8C2{.8161,00161.fivBr(oG&Ë)83-018 North Maoazinez3125.95r':25.94821ô1.00101.0(Danville83{17 North Maqaz¡nenI19.61f-19.61161.0018'l.0(West Booneville8S016 North Huntinston21

20

(lntêrc,onnecl)19

113.1S2.13.192i161.0016T.0(OGE FortSmith8$015 Nodh Huntington18

12.811.2.811ô1.00161.0(Southeast Fayetteville83{14 Hfand17

2-1.ô75416

12.æ7.11t6.437S161.001ô1.0(Siloam Sprinos83-013 Flint Creek15

14

10.03e.0.03161.0016t.0(EDE Decatur South83-012 Flint Creek13

(lnterconnect)12

t1.252-125161.0016f.0(SWPATabIê Rock83-011 Eurel€ Springs11

24.4(lnterconnect)10

15.34t.0.94161.0016t.0(Entergy,.laßison83-010 Eurelø SpringsI(lnterconnect)8

11.2s2-125r6t.00161.0(SWPA BeaverOam8dì-0O9 Êureka Springs7

(lnlerconnect)6

1't6.812-16.81161.00t6'f .0(SWPA Beaver Dam83-008 East Rooers5

14.1(r4.104

3

15.2814.9Í1.14.985181.00lôr.0(Fl¡nt Creek&3-007 East Centerton2I1.9f1.1.96161.00f 61.üCenlertonTL'|80 Easl Centerton1

Number

otCircuits

(h)

vft ùtructufesot tother

(s)

¡çturqinerated

unùof

Dêsi

Type ol

Supporling

Stncturs(e)

Designed

(d)

Op€rating(c)

To(b)

From(a)

LineNo.

LENGTH (Pole miles)(ln th6 òas6.ofunoerotouno lines

report õircuit miles)

ub.iilLiNA I ¡(JN

1. Report information conc€ming transm¡s$ion lines, cost ol lines, and expenses lor year. L¡sl each lransm¡ss¡on line havíng nom¡nal voltägê oi 132kilovolts or greater. Report transmission lines below these voltages in group lotals only for each voltage.2. Transmission lines include all lines côvered by the delinition of lransmission system plant as given in the Uniform System of Accounts. Do not ieportsubstation costs and expenses on this page.3. Heport data by individual lines for all vollages if so required by a State commission.4. Exclude lrom ttris page any t¡ansmission lines for which plant costs are included ¡n AcÆount 12f , Nonutility Property.5. lndlcate uÀelher tha type of supporting slructure report€d in column (e) is: {l) single pole wood or steel; (2) H.frame wood, or steêl poles; (3) tower;or (4) underground constnrclion ll a lransmission line has mors than one type ol supporting stn¡cture, indicalê the mileago of each type ol constructionby thë use of brackêts ând extra lines. Minor portions ol a transmission line of a ditferenl type of construcl¡on need not be dislinguished trom lhoremainderof the line.6. Beport in columns (0 and (g) lhe total pole miles of each lransmission llne. Show ln column (f) the pole miles of line on structures the cost ol which isreponed for the line deslgnated; conversely, show ln column (g) the pole miles of lins on structures the cost of which ¡s reporlgd for another line. Fleportpole miles ol line on leased or partly owned structures in column (g). ln a foolnote, explain the basis of such occupancy and state !ìrheher expenses wilhrespect to such structures are included in the expenses reported for the line designated.

Yeaf/Pef¡od of ReportËndol 2015/Q4

Date of Reoorl(Mo, Da, Yi)lt

This{1)(2,

Reoort ls:

fiAn Original

[lA Resubmission

Nam€ o1 Flssponclent


FERC FOFM NO. I (EÞ. 12{7) Taga 422.2

366,91 1,57Í6J30,r6t181,406880,132,24{806,499,35373,632,89!

351272.0 AcsRc41590.0 AcsR

sÌ15903 ACSR

32l¡697.0 ÂCSR

3l1156.0 ACSB

30lßì7.0 AcsR2St272.0 ACSR

28lt5ô.0 AcsÂ27t97.0 AcsB261x397,0 ACSR

25

24b697.0 AcsR

23Ì50.0 cw*,1272.0 AcsH21t97.0 ACSR

N¡9s.0 ACSß

'19397.0 ACSB

l81272.0 ACSB

172x397.0 ACSR

16

152x397.0 ACSÊ

l4ts/95.0 AcsR

't2

11/s5.0 ACSB

10

sì66.0 ACSR

8

7¡95.0 ACSn

6

5166.0 ACSR

4¡156.0 ACSR

3r590.0 AcsR21020.0 AccoTW1lr5ô.0 AcsR

No.

TotalExn6lses

Rents

(o)

MaintenanceExpenseg

(n)

0perationExpenses

(m)

Total Cost

(t)

Conslruction andOther Costs

(k)

Land

ü)

Size olConductol

and Material(¡)

EXPENSES, EXCÊPT DEPREÇIATION AND TAXESÇ(Jtir oF LtNh (tnctude in Çotumn 0) tånd,

Land rights, and clearing right{f-way)

7. Do not report lhe sâme transmission linê structure tw¡ce. Report Lower voltage Unes and higher vollagê lines as one líne. Designate in a foolnote ifyou do not include Lower voltage lines with higher voltage lines, lf two or more transmission line structures support lines of the same voltage, report thêpole m¡les of the primary slructure in column (f) and the pole miles of the other line(s) in column (g)

8. Designate any lransmission line or portion thereol for wñich the respondent is nol the sole oumer. It such property ¡s leased from another company,give name of leqsoc date and terms of Lease, and amount ol renl for year. For any transmissbn line other than a leased line, or port¡on lhereof, lorwhich the respondent is not lhe sole oüner but w?rich he respondent operates or shares in the operat¡on of, lumish a sr.¡ccinct statement explaining thearrangement and giving part¡culars (details) of sr¡ch matters as percent ownershlp by respondent in the line, name of co{wner, basis of sharinge¡penses of the Une, and how the expensEs bomô by the respondent ars accounted lor, and accounts aflected. Specify whether lessor, co.owner, orother party ¡s ån assoc¡ated company.9. Designate any transmission line leased to anolher cpmpany and give name of Lessee, date and terms of lease, annual reni for year, and howdetsrmined. Specify whðther lessee is an associated company.10. Base the planl cost figures called lor ln cnlumns () to {l) m the þook cost at end of year.


Year/Period of ReportEnd ot 2015/Q4Southwestem Ëleckic Power Company

(1)(z',)

AnDate(Mo,

ttResubmission

FERC FOBM NO. t {ÉD. r2{7) Page 423,2

317103.484,019.04TOTAL36

3514.ßf-4.10138.00115.0(HopeTL3t5 Turk34

,|26.741.28.14r38.00t38.0(TurkTL330 SETexerkänâ33

121.7(1.21.7013f¡.00138.0(Turk81-086 Sugar Hilt32

(lnterconnect)31

128.A128.22138.00138.0(PSO Craig Jct.81.84å Menâ30

'I0.3€f 4.384138.00138.üSoutheast Texarkana8't{72 Bann29

(lnterconnect)28119.542.19.54138.00138.0(Entergy South Murlreesboro81-062 South Nashville27

26

2511.6423.422-25.06138.00ræ.0(South Nashvilief i -055 Païerson24

2.30.0623132.1.2.28138.00138.0(South Dierks81-054 Patterson22I0.7t1{.78138.00138.0(Sugar Hill81 -050 Northwest Texarkana21

I8.2628.26t38.00138.0(Patterson81 -049 Northwest Texarkana202{.4811(lnterconnect)1g

126.951.26.470513{t.00t38.0(PSO Craig Jct.81-847 Patterson18

17118.452.18.45Ì38.m138.üPatterson81-044 North New Boston16

1517.492-7.49138.00t38.0(PSO Craig Jct.81-009 Dequeen14

'138 kV in AB13

't2378.61297.38Total '161 kV SWEPCO1'l

f0378.61297.38Subtotal 161 kV in ARI

I¿1.6.|t -f .61161.00161.0(Osburn TapTL360 Osbum Tap713.35l-3.35161.00161.0(Shipe RoadTL343 East Centerton6I1.98t-1.98'r6f .00181.0(South Fayetteville83-036 Fayettev¡lle5

I4.ltt4.1839161.001ô1.0(Van Asche83-035 Favetleville4

15.9tl-5.551ô 1.00161.0(Van Asche83-034 Oyess3

17.5(1-7.5625161.00161.0(Siloam Springs83-033 Chamber Spríngs2

10.2¡1.0.234fì161.00l6t.0(ïontitown83-032 Mattison Plant1

Number

ofCircuits

(h)

\Jft ùltuGLUresof Another

Llne(s)

Type of

Supporting

Structure(e)

Deslgned

(d)

Operating(c)

To(b)

From(a)

LineNo.

LENGTH lPole milesì(lß the òase.of

unqerorouno lrnesreport õircuit miles)

UC.öItiNAI I()N

1. Report inlormåtion conceming transmission lines, cost of lines, and expenses for year. Ust eâch lransmissíon line having nominal voltage of 132kilovolts or greater. Fleport transmission lines below these vollages in group totals only tor each voltage.2. Transmission lines include all lines covered by the definition of transm¡ss¡on system plant as gíven in the Unitorm System of Accounts. Do not reporisubstation cosls and expenses on this page.3. Report data by individual l¡nes úor all vollages il so required by a State commission.4. Exclude from thís page any kansmlssion lines lor which plant cosls are included in Account 121 , Nonutility Property.5. lndicate whelher the type of supportíng structure reported in column (e) is: (1) single pole wood or steel; (2) H-lrame wood, or steel poles; (g) tower;or (4) undêrground construct¡on ll a transmission line has more lhan one type oi support¡ng structure, indicate the m¡leagê of each type ol constructionby the use of brackets and èxtra lines. Minor portions of a fansmission line of a different typê ot conslruction need not be distinguí$hed lrom lhgremainder of the líne.

6. Report in columns (0 and (g) the ìotal pole m¡les of each transmission líne. Show in column (f) the pole miles of line on structures the cost ol wtrich isreported for the line designated; conversely, show in column (g) lhe pole miles ol line on structures the cost of which ls reported for another l¡ne. Reportpole miles of line on leased or partly owned slructures in column (gl. ln a footnote, explain the basis of such occupancy and state whether expenses wilhrespect to such structures are included in the expenses reported for the line designated.


Year/Períod of ReportEnd ol 2015/Q4


This Reoort ls:(1) SAn Original(2', ¡lA Resubmission

Name of Respondent


FERC FOFM NO.1 {8D.12{Ð Pagø 422,3

36681r,57fô,730,f6118t,406880,13234€806,499,35373,632,895

35

ut590 ACSR

331590 ACSR

&2t590 AcsR

3t

30¡95.0 ACSR

æ12720 ACSR

28mcu 19n

ni272.0 ACSR

26!0cu f9/1

25ßô.4ACSR

241272,0 AcsR

23t97.0 AcsR

arr3s7.0 ACSR

211272.0 ACSR

2At024.0 ACAR

t9t8t272.0 ACSR

17lô6,0 ÂcsB

t62¿03.2 AcsR

15

14]97.0 AcsR

't3

12

t1

10

II7t272.0 ACSR

6¿156 ACSR

51s90.0 AcsR

4t590.0 ACSR

31590.0 ACSR

2r590.0 AcsÊ

I¡x1590.0 ACSR

No.

TotalExr6;ses

Rents

(o)

Ma¡nt€nanceÉçenses

(n)

OperationExoenses'(m)

Total Cost

(t)

Construct'on andOther C,osts

(k)

Lând

ü)

Size ofConductor

and Material(i)

EXPENSES, EXCEPT DEPRECIATION AND TAXESÇ()¡i I (JF LtNts {rnctuoe rn uorumn u) råno,

tånd rights, and cleaíng right-of-way)

7. Do nol .eport the sams lransm¡ssion líne slructure twice. Reporl Lower voltage Unes and higher voltage llnes as one llne. Designate in a footnote if

you do nol include Lower voltage lines with higher voltago lines, lf t\¡ro or more transmission llne structures support lines of the same voltage, report the

pole miles of the primary structure in column (f) and lhe pole miles of the other line(s) in column (g)

8. Designale any transmlssion line or portion thereof for wlrlch the respondent is not the sole owner. tf sttch property is leased from another company,

give name ol lessor, date and terms of Lease, and amount of rent for year. For any transm¡ss¡on l¡ne other Û¡an a leased line, or port¡on thereof, lorwtrich lhe respondent is not the sole owner but whlch lhe respondent operates or shares in {he operation of, lumish a succinct statement explainlng lhe

anangement and giving particulars (details) of Euch matlers as percent ownership by respondent in the line, name of co'owner, basis of sharing

expenses of the Line, and how lhe expenses bomo by thË respoñdent arê accounted for, and accounts atfected. Specity wheher lessor, co.owner, or

other party is an âssoc¡ated company.9, Designate any lransmission line leased to another company and give name of Lessee, date and terms of lease, annual rent for year, and how

delermined. Specify whether lessee ¡s ân associated company.10, Base thê plant cost figures called for in columns (J) to (l) on th€ book cost at end of year.

NE STATISTICS


End ot 2015/Q4Dale of Beport(Mo, Da, Yr)

uThis Reoort ls:(1) 6.¡en originat(2) ¡A Resubmission

Name ol Respondent

Southwestem Électric Power Company

FERC FORM NO.1 {ED. f2€4 Page 423.3

317103.484,01S.04TOTAL36

35

,1

6.861-6.86138.00t38.0(Whitêhurst81-060 Red PointuI3.882-3.88r38.00138.0(Scottsville8I-039 Lonswood33

32

1n.911.2..51138.00138.0(Slonewal¡8f-034 Logansport31

14.3824.3813t.00138.0(Logansport8'l-033 Carthage POD30

29

2-0.2628

19.nt€,96138.00138.üSouthwest Shreveport8l-032 Unrilood27

2{..17Cedar Grove26

12.651-2.48138.00't38.0(South Shreveporl wltap to8l-031 Un'dood25

24.8ü224

19.6fI -1.826138.0013{t.0(Longwood81-030 Lieberman23

2-24.1722

13it.5:1.9.4138.00138.0(Red Polnt81-O29 Lieberman21

2-6.482017.2(1.0,72f3fì.00r38.0(Lieberman81-O19 IPC Jefferson1g

2-3.0618

I4.41.1.28138.00r38.0(Southwest Shreveport81-016 Gèneral Motors17

110.6if..l0.62138.00r38.0(South Shreveport81-01 5 Fort Hurnbug16

11222.2.n13800t38.0(Longu,ood81-014 Floumoy15

2-0.9814

,f1,561-0.58138.00t38.0(General Motors81-O'13 FloumÖy13

10.6c1{.ôI38.00138.0(-ogansport81-007 Cenler12

34.841I118.422'15.58138.00138.0(Longwood81-004 Arsenal Hill10

I1s.06l-5.059t138.00138.0(Linwood8l-003 Arsenal H¡llI

l -1.1 07

11.0321.002"f9.90138.00138.0(Lieberman81-002 Arsenal Hill6

5

2{.53Trichel Street4

15.0614.53138.00138.0(Fort Humbug w/tap to81-001 Arsenat H¡ll3

138 kV in Li\2

131.64218.31Subtota¡ 138 kV in AR1

Number

ofCircuits

(h)

uI I ùlI UCtUf eSot Another

Line(s)

vft ùof

Desi

Type of

Supporting

Structure(e)

Ðesigned

(d)

Operaling(c)

To(b)

From(a)

LineNo.

LENGTH (PoIE m¡Iesì(ln the Òase.olundetoround lrnes

report ëircuit miles)

IJh,SIGNA IION

1. Fleport ¡nformat¡on conceming lransmission lines, co$t of lines, and expenses lor year, List each transm¡ssion line having nom¡nal voltage ol 132kilovolls or gfeater. Heport transmission lines below these voltages in group totals only for each voltage.2. Transmisslon línes ¡nclude all lines covered by the delinition ol transmission syst€m plant as given in lhe Uniform System of Accounts. Do nol reportsubstatlon costs and expenses on this page.3. Heport data by individual lines for all voltages íl so required by a Stale commission.4. Excludelromth¡spageanykansmissionlínesforwhichplantcostsareincludedinAccount'l2l,NonutilityProperty.5. lndicate whether thÊ type of supporling struclure reported ln column (e) is: (1) single pole wood or steel; {2) H-frame wood, or steel poles; (3) tower;or (4) underground con$lruclion lf a transmission line has more lhan one iype of supporting structure, indicate lhe mileage of each type of constructionby the use of brackets and exlrâ lines. Minor portions of a transmission line of a different typê of construclion neêd not be d¡stinguished lrom theremainder of the llne.6. Report in columns {f) and (g) the total pole miles ol each ttansmission line. Show in column (0 the pole miles of line on structures the cost of which isreported for lhe line designated; conversely, show in column (g) the polê miles of l¡ne on struciures the cost of which is reported for another line. Reportpole miles of line on leased or partly owned structures in column (g). ln a lootrrote, explain the basís of such occupancy and state whether expenses withrespect to such structures are included in the expenses reported for the line designaled.



End of 2015/Q4Date ot Reoort(Mo, Da, Y'r)

This Fleoort ls:(1) []An Orisinal(e) f-lA Besubmission

Name of Flespondent


FERC FORM NO,1 (ED.12-8Ð Page 422.4

3ôô,9't1,57r0,730,16ìr81,4{X880,192¿4¡806,499,35373,03¿391

35]97.0 AcsR

u¡r3s7.0 ACSR

trtbß97.0 ACSR

32195.0 AcsR

tl12720 AcsR

30155.0 ACAR

n17030 AoAR

281272.0 ACSR

271272.0 AÂc

26154.0 AcsR

25397.0 ACSR

242É66.8 ÀCSR

2321563 AqSR

2.2ß7.0 ACSR

2t1272.0 ACSB

Nß6:4 AGSR

1gx56¡ ACSR

18¡953 ACSR

17i68.0 ACSR

16t272.0 MCt56.0 ACSB

t4/95.0 ACSR

'lgrô60 AcsR

12¡55.0 ACAR

1tb¿ô6.8 ACSR

101024.0 ACAR

I1272.û ACSR

I1272.û AAC

7lss ÂcsR

62¿60.8 AÇSR

52x997.0 AQSR

41272.0 SO54/19

3tl5û ACSR

2

I

JneNo.

TolalExo,g¡ses

R€nts

(o)

MaintenanceExpenses

(n)

OperationExpenses

(m)

ïotal Cost

(t)

Constructiôn ândother Costs

(t0

Land

0)

Size olConduclor

and Material(i)

ÊXPENSES, EXCEPT ÞEPRECIATION AND TAXESrvlJ5 l LJF LlNtr (¡nCtUAe ln r/Olumn U, LanA,

!ånd rights, and clearing dghtof-way)

7, Da nol reportths samê transmission line slructure twicê, Rêport Lower voltage Unes and higher voltage lines as one line" Þes¡gnale in a foolnote ifyou do not include Lower voltage lines with higher voltage lines, lt ¡¡ro or more lransmlsslon llne str¡Jctures support Iines of the same voltage, report thepole miles of the primary struclure in column (f) and the pole miles of lhe other line(s) in column (g)

8. Oeslgnate any transmlssion llne or porlion thereol Íor which lhe respondent is nat the sole owner. lf slþh properly is leased from another company,give name ol lessor, date and te¡ms ol Lease, and amount of renl for year. For any transmlssion line olher than a leased line, or portion lhereof, forwtich the respondent is not the sole owner but which lhe respondent operales or shares in lhe operation of, fumish a succincl statement explaining lheanangemenÌ and giv¡ng parllculars (deta¡ls) of swh matlers as percent ownershlp by respondent ín the line, name of coowner, basls ol sharingexpeñsos ol üro Line, and how the expenses bome by the respondenl arê accounted lor, and aocounts åffècted. Spec¡fy whêther lessor, cæwner, oroüer parly is an associatêd company.9. Designate any transmission line leased to anofher company and give name ol Lessêe, dalê ând terms of lease, annual rent lor yéal and howdetermined. Specify whether lessee is an associated company.10" Bas6lhe plant cast t¡gures called for in columns 0) to (l) on the book cost at end of year.

TFANSMISSION LINE STAT}STICS


Ëndof 2015/Q4Date of BeDort(rrlo, Da, Yi)tt

This Report ls:(1) fiAn origlnal(2) f-lA Fesubmlssion

Name of Respoîdent

Southwestem Electrlc Power Company

FERC FOñil NO. r (FD. 12€4 Page 423.4

317.t03.48

4,0t9.04TOTAL36

138 kV in TX35

34337.nsubtoral 138 kv h oK33

32

(lnlerconnect)31

1't7.82t'17.82'r38.00138.0(PSO Craig Jct.81-848 Mena30

(lnterconnect)29I9.441-9.4407138.00I38.0(PSO Craiq Jct.81-847 Patlerson28

(lntêrconnect)27I10.012-'t0.0t138.00f 38.0rPSO Craig Jct.81-009 Dequeen26

138 kV in OK25

24323.4S284.84Subtotal 138 kV ln LA23

22I3,17t-3.17138.00r38.0(Benteler #2TL365 Port Robson2',i.

14.tc14.098138.00r38.0(Benleler #lTL3M Po¡t Robson20f!f.302.f L30'r3{t.00138.0(HauqhtonTL33¡ McDade19

I2.952-2.95r38.0013f1.0(RedpointTL335 Haughton18

7.872-7.87138.00138.trMcDadeTL331 Caplls17

12.3810.341.10.339138.00138.0(Southwest ShrevepÖrt81-084 South ShrevepÕrt16

'|0.082.92p.g2't38.00138.0(Caplis81-083 Bean15

I'f .æ1.1.2938138.00138.frPort Flobson81-082 Beant415.60'l-5.5962f38.00ræ.0(Wallace l¡ke81-081 Port Robson13

(lnterconnect)12

'I6.8t2{.86138.00138.0(CLECO IPC Mansfield8l-067 Wallace Lake11

14.5114.51138.00138.0(Whitehurst8l-066 Trlchel Street10

24.18StonewallI112.321€.14138.00138.0(Westem Electric Wtap to81 -065 Soúthwest Shreveport8

2-5.U7

15.441{.1138.00138.üWestem Electric81-064 South Shreveport6

1rLtf2-1 1.18138.0013{t.0(Wallace Lâke81-0æ South Shreveport4

2-l 1.4333

1t3,81t-2.3763138.00138.üSouthwest Shreveport8l-061 Rock Hill2

1

Number

ofCircuils

{h)

UN SIruCIUTESof Another

Ltne(s)

rcIUfEnerated

lJn ìrrof

Desi

Type ol

Supporting

Slructure(e)

Designed

(d)

Operalíng(c)

To(b)

From(a)

LineNo.

VOLTAGE (KVìllndicate wtierdòther lhan60 cvclê.3 ohase)

utsstLiNA f t9N

1. Report ¡nfomation conceming transmiss¡on l¡nes, cost of l¡nes, and expenses for year. List each transmission line having nom¡nâl voltagê of t92kilovolts or greater. Beport kansmission lines below these voltages in group totals only for each voltage.2. Transmission lines include all lines covered by the definition of lransmission system plant as given in the Unifonn System of Áccounts. Do not reporlsubslation costs and expenses on this page,3. Feport data by individual lines for all voftages il so required by a State commission.4. Exclude lrom this page any transmission lines for which plant costs arê included in Account 121, Nonutility Property.5. lndicate whether thê type of supporting slructure reported in column (e) is: (1) single pole wood or steel; (2) H"frame wood, or steel poles; {3) tower;or (4) underground conslruction lf a transmlssion line has moÍe lhan one type of supporling structurê, indicate the mileage ol each type of construotionby lhe use of brackels and extra lines. Minor portions of a trânsm¡ssion line of ä different type of canslruclion n€ed not be distinguished lrom theremalnder of lhe line.6. Report ín columns (t) and (g) the total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which isreported lor lhe line.designated; conversely, show in column (g) thê pole miles ol line on struclures the cost of which is reported for another line. Reporlpole míles ol line on leased oÍ partly owìed slructures in column (g). ln a footnole, explain the basis of such occupancy and state whelher expenses w¡threspect 1o such structur€s are included in the expenses reported for the line designated,



Endof 2015/Q4Name of

Soulhwestern Electric Power Company(2)


FERC FOFM NO,1 (ED.12€4 Page 422.5

366,9.l1,57t6,730,16i18f ,40t880,132,24¡806,499,35373,632,895

35

34

33

32

317950 ACSR

3021397,0 ACSR

æ¡95.0 ACSR

2&1272.0 ACSR

27

28t97.0 ACSR

25

24

23

u.211533 ACSR

20rs33 ACSR

1g{/0 ACSR

t8r590.0 AcsR

17

tg1272.0 AcsR

151590.0 ACSR

141590.0 AcsR

r3rs90.0 AcsR

12

1tt66.0 ÁcsR

101x397.0 ACSR

I1x795.0 ACSR

81272.0 ACSR

7

€rr397.0 ACSR

5rs5.0 AcsR

4t66.0 ACSR

3397.0 AcsR

2t590.0 AcsR

I

UneNo,

TotalËxn(eJlses

Flenls

(o)

MaintenanceExpenses

(n)

OperationExoenses

'(m)

Total Cost

(t)

Construction andOther Costs

(k)

Land

(i)

Slze ofConductof

and Material(i)

EXPENSES, EXCEPT ÐÉPBECIATION AND TAXEScosï OF L|NE (lncrucre in (þlumn (J) Land,

Land rights, and clearing righþof-way)

7. Oo not report the same lransmission line structure twice. Report Lower vollage Lines and higher vollage lines as one line. Þesignâte in a footnote ifyou do not include Lower voltage lines with higher voltage lines. ll two or more transmission line structures support lines of the same voltage, report thepole miles of the primary structure ¡n column (f) and the polê m¡les of thê other l¡nets) in column (g)

8. Designate any transmission line or portion thereof for wtrich lhe respondent ¡s not the sole owner. ll such property is leased from another company,give name of lessor, date and lerms of Lease, and amount of rent tor year. For any transmission line other than a leased line, or portion thereol. lorwñich the respondent ls nol the sol€ owner but which the respondent operales or shares in the operation of, fumish a succinct statement explaining lhearrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharingexpeñses of lho Líne, and how lhe expenses bome by the respondent are accounted lor, and accounts aflected. Specify whether lessor, co{wner, orother party is an associaled company.9, Oesignate any lransmission line leased to another company and give name of Lessee, date and terms of lease, annual renl for year, and howdetermined. Spec¡fy whether lessee is ån âssociated company.10. Ease the plant cost figures called for in columns (il to (l) on lhe book cost at end of year.

TRANSMISSION LIN E STATISTICS

YearlPeriod of ReportEnd of 2O15lQ4

Name

Southwestem Électric Power Company(1)(2)

An OriginalA Resubmlssion

(Mo,tt

Da,

FERC FOBM NO.1 {ED.12-87) Page 423.5

317103.484019.0,(IOTAL36

1'17.6jïfl.47138.00138.0(Pittsburg81-035 Lone Star South35

z-17.7834I40.s8t-2 .2f38.00138.fiLogansÞort8l-033 Cadhase POD33

32r6.4i24.47138.00138.0(South T€)râs Eastman81'028 tûox L€êgt

2-12.3500I15.0,(r-2.69138.00t38.0(Rock Hill81-027 Knox Lee29113¿!¿-13.49138.00138.0(Plrkey81{26 tt¡ox Lee28I23,S1f -23.91138.00r38,0(Overton8'l-025 l(nox Leê27

l-10,7826117.8€tt.tT38.00r38.0(Northwest Hendelson81-024 !ftox Lêê25

,|I 1.1(¿-1 ,l.1

138.00138.0(W¡lk€s81 -023 Jeflerson Switching24116.6(2-t6,6r38.00138.0(Marshall 1388 1 -022 Jefferson Switchinq23Iu.,9tt-2,.98138.0t138.filake lamond81'û2T Dfana22I1.121-1.42138.00138.0(Jefferson Switching81-020 IPC Jeflerson21

20Its.8t2-f9.8138.m138.0(L¡ebermân81-019 IPC Jetferson19

18

a-n.08City17

124.41.2.78T38.00f 38.0(Perdue w/lap to Liberty81-018 Ha¡rison Road16

15

12.5012.812-12.87f38.00138.0(Knox Leg81-017 Ha¡rison Road14

13

2.11.86't2I3.2314.281¿.42138.00138.0(Pliler Road \ry1tap to NGPL81-012 D¡ana1II21.8Í211.85138.00138.0(Perdue81-011Diana10

I2-12.t18

112,6214..12138.00138.0(Lone Star South81-010 Diana7

1t1.t€1 -1't.16130.00138.0(Tenaha8l-008 Center6

5

I1.U4.521-5.9574't38.00r38.0(Northwest Te¡<a¡kana81-006 Bann4

3I16.3€1.16.38f 38.00t38.0(Logansport81-007 Center2111.312-11.31r38.00138.0(IPC Domino81-005 Bann1

Number

ofCircuíts

(h)

un ùIfttclufesof ADother

unê(s)

¡çIUf9

å1"¿

lJn ùuofl

Desic(1

Type ol

Supporting

Structure(e)

Designed

(d)

Opêrâtíng

{c)

To(b)

From(a)

UneNo.

utssluNAil()N

1. Report infornation concemíng lransmisslon lines, cost ol lines, and expenses for year. Ust each transmission line having nom¡nal voltage of 132kilovolts or greater. Beport transm¡ssion lines below these voltages in group totals only for each vollage.2. Transmlssion línes include all lines covered by the delinition of tÍansmission system plant as given in the Uniform Syslem of Accounts. Do not reportsubstation costs and expensês on lhis pags.3. Report data by individul lines for all voltages if so required by a State cornmisslon.4. Exclude from this page any lransmlssion lines for which plant costs are included in Account l2f , Nonutllity Properly.5. lndlcate whether the typ€ of eupporling structure reported in column (e) ls: (1) singfe pole uood or steel; (2) H-trame wood, or sleel poles; (3) tower;or (4) underground constructíon lf a transmission line has more than one type of supporting structure, indicate the mlleage ol each type of constn¡ctionby the usê of braÖkets ånd exlra lines. Minor portions of a hansmíssion line of a diflerent type ol ûonstruclion need not be d¡stinguíshed from theremaínder ol the line.6. Feport in colun¡ns (Q and (g) the total pole miles ol each transmission line. Show in column (f) the polo miles of line on slructures the cost of wfrich isreporled lor the line designatedl conversely, show in column (g) the pole miles ol líne on struclur€s the cost of wlìich ís reported for another line. Reportpole miles of line on leased or partly owned structures in column (g). ln a footnote, explain lhe basis of such occupancy and state wñethe. expenses withrêspêct to such struolures are included ín the expenses reported forlhe line designated.

TRAN$MISSION UNE STATISTICS

Year/Period ot ReportEnd ol 2O15lQ4

Date ol Reoort(Mo, Da, Yi)tt

This(1)(2) A Flesubmission

Name of Respondent


FERC FORr/r NO.1 (ED.12-34 Page 422.6

366,911,57iô,730,.l67181,40f880,13¿¿4€80t,499,353?3,632,895

35t590.0 AcsB

u/55.0 ACAR

ca1272.0 ACSR

3a¿x795.0 ACSR

3T¿1338.0 ACSR

30/95.0 ACSR

2St66.0 ACSB

281x1033.5 ÂCSR

271x397.0 ACSH

2e¿r3S7.0 ACSR

231272.0 ÀcsR

241024.0 AcîR

nIt24.0 ACAR

21590.0 ACSR

21¡950 ACSR

N197.0AcsÊ

lg]3ô.4 ACSR

'18t97.0 ACSR

t7¿ß97.0 ACSR

t61272.0 ACSR

t5lß97.0 ACSR

t4t272.0 AcsR

13136.4 ACSR

121133ô.0&397.0 Ac$

J112720 ACSR

101x397.0 ACSR

I2x7S5.0 ACSB

I¡(660.0&795.0 ACS

72xgÌ6.0&397.0 ACS

6¡95.0 ÁcsR

5]97.0 A0sR

41156.0 ACSB

3

2155.0 ACAB

'|rû24.0 ACAR

No.

TotalExn¡¡ses

Rênls

{o}

MaintenanceExpenses

(n)

OperalionExpenses

(m)

Total Cost

(t)

onstruction andOther Costs

(k)

Land

0)

Size ofCondrctor

and Material(i)

EXPENSËS, ÊXCEPT OÊPRSCIATION ANP TAXESU()li I Uþ LINE, (lncluoe rn çorumn u) Lano,

l-and rights, and clearing right-of-way)

7" Ðo not report ths same transmission line structurê twicg. Report Lower vollage Línes and higher voltage lÌnês as one line. Des¡gnate in a footnote ifyou do not include Lower voltagË lines with higher vollage lines. lf lwc or more lransmisslon lfne structures support lines of thê same voltage, report thepole miles of the primary structure in column {f} and the pole miles of the other line(s} in column (g}

L Designate any transmission l¡ne or port¡on thereot lor whlch lhe respondent is not the sole owner, lf such property is leased lrom another company,give name of lessor, date and terms of Lease, and amount of rent for year. For any transmlssion line other than a leased line, or portion thôreof, for

rvirich the respondent ls nol the sole omer but which the respondent operates or shares in the operation ol, fumish a succ¡nct statement explaining lheanangement and giving particulars (delails) ol such matters as percent ownership by respondent in the linê, name of co-owner, basis of shadng

expenses ol lhe Line, and how the expenses böme by the respondent are accounled for, and accounts affecled. Specify whethgr lössor, co{Ìvnerr or

other party ls an associated company.9. Ðesignate any transmission line leased to anolher company and give name of Lessee, datâ and terms of lease, annual rent lor year, and how

determlned. Specity whether lessee is an associated company.'10. Basê thê plant cost f¡gurês câllêd for in columns (il lo {l) on the book cost at end of year.

TRANSMISS¡ON LINE STATISTIÇS 1

Year/Per¡od of ñeportEndof 2015/Q4

Date of Reoort(Mo, Da, Yi)tl(2) A Resubmission

Name of Responclenl


FERC FORIjl NO.1 (ED. 12{Ð Page 423.6

3f?103.484CI19.04TOTAL36

123,312-25.9121138.00138.0(Southwest Shreveport81-061 Fock Hill351t5.532"r5.53138.00138.0(Whilney81-059 Pi¡key34

g,2-1732

117.41t.0,48138.00r38.0(Scottsville8l-058 Pirkey31

't34.08134.08138.00r38.0(Wilkes81-057 Pettv3015.56t-5.58138.00138.0(PetU8l-05ô Ca¡np County29110.34t.10.34138.00t38.0(Susar Hill8l -050 Norllrwest Te)€rkana28

3{,S27¿-6.551726

t7.ilt-0,t859138.00r38.0(Patlerson81 -049 Northwest Texarkana25¿-5.9624

1t3.f81"72.'t38.00138.0(Overton81 -O¿18 Northwest Henderson2322.45Stalion22

15.76l-927I38.00f38.0(Whitney81 -047 Eastex Slr/itchinq2',1

0.15e-.1520J4ô.7f2-46.79138.00r3t¡.0(Wilkes81-045 North New Boston19

15¿12-5.41't38.00138.0(Paüerson8t-044 North Nêw Boslon18

17

2-03NW Texarkana16

I17.8!1-17.59138.00138.0(North New Boston dtap to81 -04i' BannT5

1-2.125514

l{.371813

1t9.3€2-16.88138.00138.0(North Mineola8'l-042 Brady (Þo<on Mob¡l)12

(lnlerconnect)11

I18.1¡l-18.r26rr38.00r38,0(RCEC Canton Tap81-041 No¡th Mineola10

I2.32ô.532{.53138.m138.0(Pirkey81-040 Mar6hallI1t2.t€2-12.19138.00138.0(Scottsville81-039 Lonoü,oodI

7

2-9.766

1t2.9St€.23138.00r38.0(Whitney81-037 Pliler FloadR

4

2-10.87â110.9S'l{.f2't38.00138.0(Wilkes8'l -036 Lone Star South2

1

Number

otCírcuits

(h)

Lr¡t ùUuctute¡tof

Tother(s)

.¡(.,{u{cinerated

\JTI ùot

Desi

ïype of

Supporting

Structure(e)

Designed

(d)

Operalfng(c)

TO

(b)From(a)

LineNo.

NGTI'I lPole milos)llD lhe èase.olìoeforouno lrnesrort õircuit miles)

Utsù'IUNA I IUN

1. Report information corrcerning lransmission linos, cosl of lí¡es, and expenses for year. Ust each lransmission line having nominal voltage of 102kilovolts or greåter. Report lrânsmission lines belovv these voltages in group tatals only for each vollage.2. Transmisslon línes include all lines covered by the delinition of l¡ansmission system plant as given in lhe Uniform System of Accounts. Oo not reportsubstation costs and Expenses dÌ th's page.3. ñeport data by individual línes for all voltages il so reoulred by a State commisslon.4. Exclude lrom lhis page any transmiesion lines for whlch plant costs are included ¡n Accounl '121 , Nonutil¡ty Property.5. lndicate w¡eher the typ€ ol supporting structure reported ln column (e) is: {1) single pole $,ood or steel; (2) H-lrame wood, or steel poles; (3} tower;or (4) underground construction lf a lransmisslon line has moÍe lhan one type of supporling structure, lndlcate the mileage ol each type of constructionby lhg us€ of brackets and oxtra lines, Minor portions of a transmission line of a ditlerent type of construction need nol be distinguiçhed from theremainder of thê lins.6. Report in columns (0 and (g) the total pole miles ol each lransmlssion line, Show in column (f) the pole miles of line on structures the cost of which isrepoñed fof thê l¡nq designated; @nversêly, show Ín column (g) the pole miles of line on stnrctures the cosl ol which is reported lor another line. Reportpole miles ol line on leased or partly owned structures ln column (g). ln a footnote, explain the basis of such occupancy and stat6 wheth€r expenses withrespect lo sr¡ch slructures are included in lhe expenses reported for lhe line designated.

TRA NS MI SS I ON LI N E STTT I STICS

Yeaf/Period ot FleportEnd of 2015/Q4

Name of Flespondent

Southwestern Electric Power Company(1)(21

An OriginalA Flesubmission u

FERC FORM NO.1 (ÊD.12€Ð Page 422.7

36681r,57Íô,730,16i181,40f88t,132p4¡806,499,35373,632,895

35197.0 AcsR

34lxlCt33.5 ACSB

g'L477.0 ACSR

322x397.0 ACSR

31t272.0 ACSR

30

æ1272.0 ACSR

28t272.0 ACSR

271156.0 ACSR

281272.0 SD54/19

25tû24.0 ACAR

24

23l¡397.0 ACSß

n2x795.0 ACSB

211x336.0 ACSß

2A195.0 ACSR

t9ì66.0 ACSR

t8t66.0 ACSF

17f7.0AcsR

16lx47l.0 ACSR

l5!156.0 ACSR

T4lr3f)7.0 ACSñ

t31272.0 ACSR

12r$97.0 ACSR

1t'95.0 ACSF

t0272.0 ACSB

I2x1033.5 ACSR

I2ß97.0 ACSR

72x397.0 ACSR

62x336.0&397.0 ACS

51272.0 ACSR

4

31x795.0 ACSÊ

2lxô66.0&795.0 ACS

1

No.

TotalExoenses'(p)

Rents

(o)

MaintenanceExpenses

(n)

OperatlonExpenses

(m)

Total Cost

(t)

Construction andOther Cosls

(k)

Land

0)

Sfze ofConductor

and Materlal(i)

EXPENSÊS, ËXCFPT DEPRECIATION AND TAXESuuS r ur L|NE (trìc¡uge ,n uþtumn u, L¿¡no,

Land rights, and clearing dght-of-way)

7. Do not reporl the same transmission line structure twice, Report Lower voltage Unes and higher vollage lines as ons line. Dêsignate ¡n a lootnot€ ¡tyou do not include Lower voltage lines wìth higher voltage lines. ll two or more transmission l¡ne ôtruotures support lines of tho same voltage, report thepole miles of lhe primary sfucture in column {Q and lhe pole miles of ihe other line(s) in column (g}

8. Designate any lransmission line or portlon lhereof lor whlch the respondent is not the sole onner. lf such propely is leased from another company,give name of lessor, date and le¡ms of Lease, and arnount of renl lor year. For any transmission líne other lhan a leased line, or porlion thereof, forwñich the rêspondent is not ths sol€ owner but which the respondent operates or shares in the operatlon of, fumish a succinct statement explainlng lheanangement and gíving partlculärs (detâils) ol such matters as percenÌ ownership by respondent in the line, name ol cæwner, basis of sharingexpenses ol lha Une, and how the sxpenses borne by the respondent aro accounted lor, and accounts atfected. Specity whether lessor, co-ovvnêr, orother party is an associated company.9. Designate any transmlssion line leased to anolher company and give name of Lessee, date and terms of lease, annual rent lor year, and howdetermined, Specify whether lesseg ls an associated company.10. Base the plant cost figures called for ln columns 0 to (l) on the book cost at end ol year.

Continued)TIìANSMISSIQN LINE S|ATISTIçS i

Year/Period ot ReportEndol 2015/Q4

Date of Report(Mo, Da, Yr)1t

Th¡s Rêoort ls:(1) 6]An orisinat(2) ¡A Resubmission

Name of Respondent


FERC FOFM NO.1 (ED.12-84 Page 423.7

317103.4ð4,019.04IUIAL36

44t.92Subtotal 115 kV in AR35

u(lnterconnect)(lnterconnect)33

I7.1{2-7,11r5.00'115.0(Entergy Palmos81'053 AECC Fulton Planta2

I19.31f.1g.3t138.00r 15.0(Patterson8l-052 Okây31

1t5.5t'l.15.5138.0úr t 5.0(Hope81-051 Okåy30

29

10.0124.0r115.00115.0(AËCC Fulton Plant81"038 Hops28

115 kV ¡n AR27

26

10(f 5.511412.UTotal 138 kV SWEPCO25

24

5210.38875.5€subtotâl 138 kv in TX23

22

135.14â-35.14138.00138.0(Wesl Childress81-901 (21085) Lake Pauline21

2-51.3520

156¿i14.92f 38.00'r38,0(West Childress81 -900 {2r 0,€) Shamrock19

2-r0.30818

,-1.62't7112.æl-0.3598138.00f38.0(Perdue81-085 Brady {Ê¡o<on Mobil}1€

128.14f ¿5.14138.00138.0(Winnsboro81{80 North Mineoh15

1Á.4¿-'t4.2r38.00138.0(WFEC Bussell (lnterconnect)81-845 Lake Pauline14

10.8920.3'1.20.32r38.00138.0(Winnsboro81479 Pittsburs<a

14.34t.4.3419138.00't88.0(Pittsburg81-078 Camp Countv12

Station11

10.8f2-0.8307r38.00138,0(Soulh Te¡øs Ëastman8'l-076 Eastex Switchinq10

StationII9.5?f-s.57r38.00138.0(Harrison Road81 "073 Eastex Switch¡noI11 1.341.t 1.941138.00t38.0(Southeast Texarkana81{72 Bann7

I9.521-9.522rr38.00138,0(Rock Hill81-070 Carthaoe POD6

2-18.255

I24.41-5.79138.00138.0(West Atlanta w/tap to IPC81-069 IPC Domlno4

2-31.683

I32.03t{.35138.00138.0(Wilkes8f -068 West Atlanta2

I

Number

olCircuits

(h)

\JIt Èrtfuutute:¡of Another

une(s)

Type of

Supporting

Structure(€)

Designed

(d)

Operat¡ng(c)

To(b)

From(a)

UneNo.

LENGTH (Pole milesllln the òâsê.of

uncferorouno ltnesreport ðircuit miles)

utsÞttiNÄ I r(JN

1, Rêport informat¡on concem¡ng transm¡ssion llnes, cost of lines, and expenses for year. Ust each lransm¡ss¡on line having nominal vollage of 132kilovolts or grealêr. Rspod lrânsmíssion lines below lhese voltages in group totals only for each voltage.2. Transmission lines include all lines covered by the delinition of lransmission system plant as given in the Uniform $ystem of Äccounts. Ðo not reportsubstation costs and expenses on lhis page.3. Feport data by lndividuel lines for all voltages il so required by a Slate commlss¡on.4. Exclude trom th¡s page any transmission lines lor which planl costs are included in Acclunt '121 , Nonutility Property.5. lndicate wtrelher the type of supporting structure reported in column (e) is: (1) single pote wcod or steel; (2) H-lrame'¡,ood, or sleel poles; (3) tower;or (4) underground constn¡clion lf a lransmlssion line has more lhan one lyp€ of supporting structure, indlcate the mileage ol each type of constructlonby thè use of þrackets and extra lines. Minor portions ol a transmíssion line of a different type of conslnrclion need not be d¡stinguished kom theremainder of the linê.6. Report in columns (f) and {g) lhe total pole miles ol each lransmission line. Show in column (f) the pole miles of line on sln¡ctures lhe cosl of wfrich isreported for the line designated; conversely, show in column (g) the pole miles of l¡ns on struclures the cost of which is reported for another line. Reportpole miles of line on leäsed or partly owned structures in column (g). ln a footnote, expla¡n the basis of such occupancy and stale whether expenses withrespect lo such structures are included in the expenses reported for the line designated.

TRANSMISSTON LINE STATISTIC$


End of zO15lQ4Date ot Reoort(Mo, Da, YÐ

ttTh¡s Reoort ls:(1) 5]nn original(2) ¡A Resubmission

Name ol Respondent


FEHC FORM NO.1 (EÐ.12€4 Page 422.8

s6Ê,9r r,57(ô,730,16?181,40€880,132,24{800¡99,35373,632,895

35

34

33ì68.0 ACSR

32t2720 ACSR

311590ACSR

301591 ACSR

æ1272.0 AcsB

281272,0 AAC

27

26

25

24

23

221¡r¡.0 ACSR

2A

l91T7.0 ACSR

t811397.0 ACSB

171x397.0 ACSR

l61272.0 ACSR

15t590 ACSR

14rT7.0 AcsR

13i590 ACSR

121272.0 AcsR

11

102x7950 ACSR

II1272.0 ACSR

7t272.0 AcsR

6t272.0 AcsÊ5197.0 ACSR

4¡024.0 ACAR

3ìô6.0 ACSR

21024.0 ACÂR

I

LineNo.

TotalExnglses

Ëlents

(o)

MaintenanceExoenses'(n)

OperationExpenses

(m)

Total Cost

{t)

Constrrclion andOther Cosls

(k)

Land

(¡)

Size ofConductor

and Material(i)

EXPENSËS, EXCËPT ÞFPRËCIATION ANÐ TAXFScosT ot- L|NE (lncrude in column {J) Land,

lånd rights, and clearing right-ol-way)

7. Þo not report the same transmission line structure twice. Fleport Lower voltage Lines and higher voltage lines as one line. Designale in a footnotê ifyou do not include Lower voltage lines with higher voltage lines. lf t'¡o or more lransm¡ssion line slrrrctur€s support lines of lhe same voltago, report thepole miles of the pr¡mary struoture in column (0 and the pole miles of the olher line(s) in oolumn {g)8. Designate any transm¡ssion llne or portion thereol lor which the respondent ls not lhe sole ovører. lt such property ls leased lrom another company,giv€ name of lessor, dale and terms of Le¿s6, and amounl of rent lor year, For any lransmission line ott¡er than a leased line, or portion lhereof, lorwl¡ích the respondent is not the sole owner but which the respondont operales or shares in lhe operation of, fumísh a succinct stalem€nt explafning lhearangemenl and giving particulars (delails) of such matters as percent ownership by respondent in th6 line, name of co-owner, basis of sharingexpenses of thê L¡nö, and how the expenses bome by the respondent are accounted for, and accounls atfected. Speciñy whether lessor, co{wner, orother pãrty is an associated compâny.9, Designate any transmission line leased to another company and give name ol Lessee, date and lerms of lease, annual rent lor year, and how'dêtsrmin€d, Spæi$ whether less€e is an associaled company.10. Base the plant cost figures called for in cÒlumns (il to (l) on the book cosi al end of year,


Year/Per¡od of Reporl

End ot 2O15lQ49ouhwestem Eleclric Power Company ) {Mo, Da,tt(2) Resubmission

FERC FORM NO.'r (ED. 12-87) Page 423.8

3r7103.484,0rs,0¡IOIAL36

140.6(l-10.2969.00ôs,0(Mena w/lap to US Motors66-036 Dierks35

¿"37.7Fo¡emanu139.2rI1.5869.m6S.{XPatlerson wltap to Magnolla66-035 Dequeen33

2.28.7532

'|28.7!1.0.046S.006S.fiNashv¡lle6&034 Dequêèn31

244.6230

'I1.7840.1ft-5.6369,0069.0(Mena66-033 Dequeen29I2.At-2.6469,006S.0(West Boonev¡llê66-019 Boonaville28112.111-12.1163.0069.0(OGE Branch (lnt€rconnect)66-018 Booneville27

2.'t8.4StPc26119.8'1-1.3Í,69.0069.0(Texarkana Plant dtap to66-017 Bloomburg25

23.45& Texas Eastem24

18.951{.569.0069.0(Hosston wltaps to Rodesså66-016 Bloomburg23

to Red L¡ck & Sugâr Hill22

10.630.0i1-0.0769.006S.0{Thirty Ninth Street wltaps66-012 Bann2',l.

10.204.241{23669.0069.0(Te¡<a¡kana Plant66-01 I Sor¡theast Texarkana2A

10.252{.2569,006S.0(Bloomburg66-007 Allanta19

18

24.7Sugar Hill & Nêkoosa17

120.511-1S.8169.0069.0(Tweltth Street w/taps to66-006 Ashdowr16

24.C415

I1.1 51.0.8163.0069.0(Patterson66{05 Ashdown14

69 kV in AF13

12

€56.t0Total 115 kV SWEPCO11

10

114,24iubtotal '115 kv in TXII

114.241.14.24f 15.00115.0(SPS Nichols (lnterconnect)81 -902 (2I t49) Shamrock7

115 kV in fi6

10.ô,qSubtotal 115 kV ¡n l-AÊ

4

'|0.641 t5.00115.0(Jetd-WenTL357 lnt€rconnecl3

115 kV ín l-A2

1

Number

ofCircuits

(h)

\.rn ÞIfl¡crutesof Aoolher

une(s)

Type of

Supporting

Slruclure(e)

Designed

(d)

Operaling(c)

To(b)

From(a)

LineNo.

LENGTH fPole milesì(ln th6 èase.ofunooforound lrnes

report õircuil miles)

UhSIGNAIION

1 . Report information conceming lransmission lines, cost of lines, and expenses tor year. Ust each lransmission line havíng nominal voltage ol 132kilovolts or greater, Heport transmission l¡nes below lhese voltages in group totals only for each voltage.2. Transmission lines include all lines covered by the delinitlon of lransmission system plant â6 given in the Uniform Syslem of Accounts. Do not rêportsubstatlon costs and expenses on lhis page;3. Report data by indlvidml lin€s for all voltages if so requked by a State commission.4. Excludelromthispageanytransmissionlineslorwhichplanlcostsareinch¡dedinAccountl2l,NonutilityProperty.5. lndicate whether the type of support¡ng structure reported in column (e) is: (1) single pole uood or steel; (2) H"frame wood, or sleel poles; (3) lower;or (4) underground conslructíon lf a transmission line has more lhan one type of supporting structure, indicate the mileage of each Çpe of construct¡onby the us€ of brackets and êxlra lines, Minor portions ol a transmission line of a diflerent type ol construction need nÕt bê d¡st¡nguished from theremalnder o, the llne.6. Report in columns (0 and (S) the lotal pole miles of each transmission line. Show in column (f) the pole miles of line on struatures the cost ol which isreported for lhe line designated; conversely, show in column (g) the polê mlles of line on struclurês the cosl of yvhich is reported for anolher line. Reportpole mifes of line on leased or parlly orvned struclures in column (g). ln a footnote, explaln lhe basis of such occupancy and statê whether expênses withrespeçt lo such struclures are included in the expenses reported for ths line designated.

TRANSMISSION UNE STATISTICS

Year/Period of ReportEndof 2015/Q4

Dat€ of Beport(Mo, Da, Yi)ltSouthwestem Electríc Power Company

This(1)(2) A Flesubmission

FERC FORt¡t NO, 1 (ED. t2{4 PagE 422.9

366,9r'1,57Í6,730,16j181,40t880,132¿4{806,499,35373,632,89f

35197.0 ACSR

3d¡10 AcsR

33v0 AcsR

32

3t]/0 AcsR

30

æ'95.0 ACSR

28r/0 AcsR

27t0 AcsR

26t/0 AcsR

25266.8 ACSF

24

23¡66.8 ACSS

2.21t272.0 ACSR

I1272.0 ACSR

't9ì970 AcsR

18)97.0 ACSR

17lx3S7O ACSR

161272.0 AcsR

t5

142x397.0 ACSR

13

't2t1

10

II7YO ACSH

6

5

4

3ß6.4 kcM ÂcsR

2

1

Line

No.

TotalËxn(edJses

Renls

(o)


Operation*r,P;*'

Totat Cost

(t)

Construclion andOther Costs

(k)

Land

0)

Size otConductor

and Malerial(i)

EXPENSES, EXCFPT DEPRECIATION AND TAXEScos I oF LINE (lnclude ¡n Çolumn (j) Land,

Land rights, and clearing rightoËway)

7. Do not report lhe same transmission line structure lwice. Reporl Lowêr voltage Lines and higher voltage lines âs one line. Designate in a foohote ifyou do not include Lower voltage lines wilh higher voltage lines, lf two or more transmission líne structures support lines of th6 same voltage, feport lhepale miles ot the primary slructure in column (t) and thê pole miles ol the other line(s) in column (g)

8. Designaìe any transmission line or portion th€reot for which the respondent is not the sole owner. lf such property is leased from another company,give name ol lessor, dale and terms of Lease, and amount of rent for year. For any lransmiesion line other than a leased line, or portion thereof, lorwhìch the respondent ¡s not the sole owner but which lhe respondent operates or shares in the operat¡on of, fumish a succ¡nct slatement exPlaining the

arangemenl ând gíving particulars (details) of such matters as percent ownership by respondont in the line, name of c*ovvner, basis of sharingexpenses ot lhe L¡ne, and how the expênses bome by the respondent are accounted for, and accounts atfected. Specify whether lessor, Ëo'owner, ofother party is an associated company.L Designale any transmission line leased lo another company and give name of Lessee, date and terms ol lease. annual rent for year, and how

determ¡ned. Specifywhether lessee is an assoc¡ated company.10. Basê the plant cost flgures called for in columns ü) to (l) on lhe book cost at end ol year.

TFANSMISSION LINE STAT'STIÇS


Endot 2015/44Date of Reoort(Mo, Da, Yi)II

Name Respondent

Southwestern Eleclrlc Power Company(1)(z) FÌesubmíssion

FERC FOFM NO. f (ED. 12-84 Page 423.9

31i103.484,019,04TOTAL36

10.042.0.u69.0069,üOGE VBI (lnterconnect)66-131Ít AECC Vgl North35

(lnterconnect)34I2.44t2.uô9.0069.0(OGE Helberg {lnterconnecl}6&129 AECC Filzhugh33

2-3.8737(lnterconnect)32Iô,7C1-2.8275ô9.006S.0(SWPA Naro$ß Darn6ô.1 27 Murf reesboro West3t

s0

CoopEr Tire2914.9{1.4,94ô9.0069.0(Iwenh Street w/tâp to6&126 T€xârkanâ Plant28

10.2c14.269.0069.0(fexarkana Plant6&124 Taylor Street27

PSO Red Oak (lnterconnect)26

I7.0c2-769.0069.0(OGE Howe {lnterconnec$ .6&12I Midland25

I5.0€1.5.03138,00ô9.0(Nekoosa Fdwards6&'lt4 Petlerson24

2-10:t257lvlurlreesboro Uptovrn23112.7ôr-2.038169.môs.0(Nashvill€ øtap to66-1 05 Mudreesboro West22

21

2.!..76Excelior2A

I14.2{1-9.4469.008S.0(North Huntinqton w/tap tot6-098 M¡dlãnd19

Sefor18

241.51(lnterconnect) w/taÞ to17

143.8S1.2.3869.0069.0(AECC VBI North66-063 Greenland16

24.42't5I4.414.,?,69.0069.0(South Fayetlevilfe6&062 Greenland14

'|0.528.042{.0469.0069.0(Prairie Grove6S061 Greenland13

11.951.1.9569.0069.frNorth Rogers66-043 East Rosers12

11

Centertonl0I9.C0f -s.9069.00ô9.0(North Rogers wltap lo66-042 East CentertonoI2.032.2.0369.m69"0(Springdale6ô041 Dyess8

7

15.40l-5.469.0069.0{Springdäl€66-039 Dyess6

Ê

118:t71.18.n69.0069.0(West Murfreesboro66-038 Dierks4

2-0.6f3

1I.861.12569.0069.0(South Dierks66-037 Dlerks2

2-30.311

Number

ofCircuits

(h)

vn-ÞIructuÍesot Anothe¡

Lrne(s)

Type of

Supporting

Structure(e)

Designed

(d)

Operating(o)

To(b)

From(a)

LlneNo.

LENGTH lPole m¡lêsìlln the òase.of

uncferofound linesreport õircuit miles)

DESIGNATION

1 . Report infomation conceming tiañsmission lines, cost of lines, and expenses for year. Ust each trañsmission line having nominal voltage of 132kilovolts or grealer. Fleport lransmission lines below these voltages in group lotals only for each vôltag6.2. Transmisslon lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Þo not reportsubslation costs and expenses on this pagg,3. Report data by individual lines lor all voltages if so required by a Slate commlssion.4. E(clude trom lhls page any transmissbn lines lor whlch pfant costs are ínclt¡ded in Account 121, Nonutitity Property.5, lndícate whelñer the type of supPort¡ng structure reported in column (e) is: (1) sfngle pole wood or steel; (2) H.frame wood, or steel poles; (O) tower;or (4) undergroud construct¡on ll a lransmissíon line has more than one type of supporling structure, índícate the milêâge of each typê of conslruct¡onby the use ol brackets and exlra lines. Minor portfons of a transmission line of a different type ol conslnrtion need nol be dist¡nguished lrom theremainder of üe llne,6. Report in columns (f) and (g) the total pole miles of each lransmission line. Show in column (0 the pole miles ol line on struotures lhe cost of which isreporled ror lhe lÍne designated; conversely, show ín column (g) the pole miles of line on struclur€s lhe cost of which is r€ported for anolher line. Reporlpole miles of line on leased or partly owned struclures in column (g). ln a footnote, explain lhe basis of such occupancy and stale \^ñether expenses withrespecl to such structures are included ¡n the expenses reported lor the line designated.


Year/Period ol ReportEnd of 2A15/Q4Southwestem Electric Power Company

(1)(2)

An OriginalA Resubmission tt

FERC FORM NO, 1 (ED.12€n Page 422.'lO

366i911,57i6,730,16i181,4ü880.1æ34t806,499,35373,632,89¡

35]36.4 ACSR

34

33195.0 ACSR

32MACSB

3fx16.4 ACSH

30IrþÅCSR

29ms7.0 ÂcsR

28¿x336.0 ACSR

27t272.0 AcsB

26

25!oAcsR

24t272.0 ACSR

23r/0 AcsR

nl0 acsR

21r/0 AcsR

2Ar233.t ACSR

19v0AcsR

t8177.0 ACSR

17)36.4 ACSR

16z0AcsF

15

14ß6.4 ACSR

13177.0 ACSR

122)ß97.0 ACSR

11136.4 ACSR

101272.0 ACSR

I1272.0 ÂAC

I¡r397O ACSB

7ì66.0 ACSR

6|36.4 ACSR

5

4166.8 ACSR

3

2197.0 ACSR

1+77.0 ACSR

LineNo,

TotalExoenses'(p)

Flenls

(o)


Operat¡onExpenses

(m)

Tolal Cosl

(1)

Conslrtrction andOther Costs

(k)

Land

()

Size otConductor

ând Material(i)

EXPENSES, EXCEPT DEPRECIATION AND TAXESuu$ r uF uNe (rncruoe rn uorumn u, Lano,

Land rights, and clear¡ng rightof-way)

7. Do not rêport the same lransmission line slructure h^rice. Bepon Lower voltâgê Unes and higher voltage lines as one line. Designale ln a tootnote ¡f

you do not include Lower voltage lines wilh higher voltage lines. lf two or moro transmission line stn¡ctu¡es support lines of the sama voltage, report thepole miles of the primary stnrture in column (f) and the pole milos of the other llne(s) in column (g)

8. Deslgnate any transmission line or portion lhereof lor which the respondent is not lhe sole owner. lf srctl property ís leased lrom another company,give name ol lessor, date and terms ol Lease, and amount ol rent for year. For any transmission line oûler than a leased l¡ne, or portion thereof, foÍwhich the respondent is not ths solê owner but whìch the respondent op€rates or shares in the operation of, lumish a sucr¡nct statemeñt explaining lhearrângement and glving particulars (details) of such màttêrs as përc€nt ownership by respondent in the line, name of coowner, basis ol shar¡ng

expens6s of thê L¡ne, and how the expenses bome by the respondent aro äc@unted for* and accounts aflected. Specify whether lessor, co-owner, orother party is an associated company.9, Des¡gnate any transmlssion line leased lo another çlmpany and give name of Lessee, date and lerms ol lease, annual rent for year, and howdetermined. Specify whethêr lessee is an associaled company.10. Basô the planl cost llgures called for in cnlumns (Ð to (l) on the book cost at end of year.

TFIANSMISIiION LINh, S I A ¡ IA I IÇt'


Endot 2015/Q4Date of Reoort(Mo, Da, Yi)t¡

This Reoort ls:(1) 6]¡en orisinat

{2'l ¡A Besubmission

Name of Eespondent


FËRC FORM NO. t (ED. 12-84 Page 423.10

gt7103.48{,0t9,04TOTAL3€

2{.55& Midvalley05

I4.971-0"9769.0069.0(Woodlawn dtaps to Kamack66-056 Floumoya2-8.t4American Pump & Woolnorlh33

I9.2tln.8369.0069.0(Summer Grove dtaps to6S055 Floumov32

2-13731

t't0.14,8.n6S.00ô9.0(Hardy Slreet66-054 Floumoys0

FoÒinq Boad23

I2.81t-2.8169.0069.0(South Shreveport w/lap lo66-047 ÊlleÈe Road28

1303l-3.0369.0089.0(Lucas66-046 Ellerbe Road27

12.31l-2.3769.00ô9.0(Fem slrêet66-045 Ellerbe Road26

2{.2125

Jû.560.89t-0.6869.006S.0(Fort Humbuq66-0,14 Edwards Street24

24.4523

I1.7ût.02169.0063.0(North Marketô&024 Brownlee Road22

14.3i24.576S.0069.0{Minden Road66-023 Brownlee Road21

10.8.l2{.8169.0069.0(Eduards Street66-022 Brooks Street20

12.731.74l-1.74û469.0069.0(Fem Str€et6È021 Broadmoor19

I0.161.58t-1.576669.0069.0(Fort Humbuq6ô020 Broadmoor18

& Texas Eastôm17

I12.002-1269.0069.0(Hosston Wlaps to Fodessa66-016 Bloomburg16

2{r.9915

I2.21t{.7969.00ô9.0(Shed Road66-003 Ars€nal H¡ll14

I2.551-2. 52789.0069.0(Waterì,ì¡orks66-@4Arsenal Hill13

t2.2(1-2.203169.0069.0(Norlh Market6S002 Arsenal Hill12

I1.n1.1.n69.006S.0(Brooks Streetô6-00l Aßenal Hill11

ô9 kV ín LA10

Iâc.l0.07{t1.8'Subtotal 69 kV in ARI

7

Iô,9414.21l-142169.0069.üWaldron (N.O.)66-640 North Huntinston6

2.1S.375

120.561.1.1969.0069.0(Siloam Sprinos66-218 Prairie Grove4

118.53f-18.5369.0069.0(Waldron66-208 North Huntington3

114.132-14.1369.m69.0(Okay66"206 Nashvills2

(lnterconnecl)1

Number

otCircuits

(h)

\Jfl ù[tUGluresof Anolherune

{s}

vft Þof

Desi

Type of

Supportlng

Slructure(e)

Designed

(d)

Operating(o)

ïo(b)

From

{a)

[JneNo.

LENGTH {Pole milesllln the òase.of

unõeforouno lrnesreportðlrcuit miles)

uÞùüq¡NA I tvN

t. R€portinformationconcerningtransmissionlines,costollines,andexpensesforyear. Llsteachtransm¡ssionlinehavingnominal voltageotlS2k¡lovolts or greater. Report transmission lines b€low thesê völtages in group totals only lor each voltâgê,2. Transmission lines include all lines covered by lhe definilion of lransmission system plant as g¡ven in the Uniform Syslem ot Accounts. Do not reportsubstation cosß and expenses on this page.3. Report data by lndtuldual llnes for all voltages if sô required by a Slate commission.4. Exclude from this page any lransmiss¡on lines for wfrich plant cosls aré lncluded [n Account 121 , Nonutility Property.5. Indicalê whether the þe of supporling structure reported in column (e) isl (1) síngle pole wood or steel; (2) H"lrame wood, or sleel poles; (3) tower;or (4) underground conslfuct¡on lf a t¡ansmission line has more lhan one typê of support¡ng structure, indicate the mileage ol 6ach type of clnstructlonby the use ol brackets and oxtra lines. Minor podions of a transmission line ol a diflerent type of constructlon need not be distingulshed from theremainder of lhe line.6. Report in columns (fl and (g) the total pole miles of each transmission line. Show in column (f) the pofe miles of l¡nÊ on structures lhe cost of which isrêported for the line designated; conversely, show in column (g) tbe pole miles of line on structures the cost ol which is reporled for anothe¡ line. Reportpole mlles of line on leased or partly owned structures in column (g). ln a lootnote, explain the basis ol such occupancy and state whether expenses withrespect lo such slructures are included in lhe expenses reporled for the line designated.

THANSMISSION LINE STAT¡STIÇS

Year/Psriod of Report

End of 2015/Q4Date ol Report(Mo, Da, Yi)II

Th¡s Reoort ls:(1) ElAn original(2) ¡A Besubmission

Name of Bêspondent

Soulhwestem Electrb Power Company

FERC FORM NO.1(8D.12€4 Pagø 422.11

366,911,s7Íô,730,16?181,406880,132,24{806,499,35373,ô32,8S5

35i/û AcsB

uÌ97.0 ACSR

33197.0 ACSR

32r/0 AcsR

31

30197.0 ACSR

æì66.0 ACSR

28n6.4 ACSR

27197.0 ACSR

26tß97.0 AcsR

25

24ì66.0 ÀCSR

231233.0 ACSR

2.2p032 ACSB

21i66.0 ACSR

20i68.0 ACSR

19166.8 ACSR

18i66.0 ÅcsR

17

16266.8 ACSR

15¡x397.0 ACSR

t41500.0 cu

t31272.0 ACSR

121272.0 ACSR

ft1x397.0 ACSR

l0II7

Ilr.0 AcsR

5

4177.0 ACSR

3177.0 AcsR

2159.0 ACAR

I

!ineNo.

TotalËxoenses'(p)

Flents

(o)


ÕperationExpenses

(m)

ToÌal Cost

(l)

ôonstruclion andOther Costs

(k)

Land

(,)

Size ofConductor

and Material(i)

EXPËNSËS, EXCEPT DFPRECIATION AND TAXESuos I oF LINE (lnclude rn uorumn 0) Lano,

Land rights, and clearing righþof-way)

7, Ðo not report the same lransmission line structure twice. Report Lowervoltage Lines and higher vollage lines as one line. Designate in a footnole if

you do not include Lower voltage lines with higher voltago lines. lf two or more transmission line structures support lines of the same vollage, report thepole miles of the primary struclure in column (f) and the pole miles of the other line(s) in column (g)

8, Designate any transmission line or portion thereof for which the respondent is not the sole owner. lf such property is leased from another companyrgive name of lessor, dale and lerms of Lease, and amount of renl lor year. For any kansmlssion line other lhan a leased line, or port¡on hereol, forwhich the respondent is not the sole owner but whfch lhe respondent operates or shares in lhe operation ol, fumish a succinct statement explaining lhearangement and giving parliculârs (details) ol sr¡ch matters as percent ovnership by respondenl in the line, name of co-olvner. basis of sharing

expenses of the Line, and how the expens€s bome by the respondent are accounted for, and accounts atlecled. Specify v^/hether lessor, co€wner, or

other party is an associated company.L Designate any transm¡ss¡on line leased to another company and give name of Lessee, date and terms of lease, annual rent fôr year, and howdetermined, Specify whether lessee is an associated company.'10. Base the plant cost ligures called for in columns 0) to (l) on the book cost at end of year.

TRANSMISSION LINE STATISTICS (Continued)

Year/Period of ßeport

Endof 2015/Q4Date of Reporl(Mo, Da, Y0

This Reoort ls:(1) fiRn Original(2) nA Resubmission

Name of Respondent


FERC FORM NO.1 (ED. 1244 Page 423.11

317'r03.484,019.04f (JTAL36

406.28330.4(subtotal 69 kv in LAâÊ

34

9.0(69.0069.0(KíngslonTL354 Bayou-Pieneââ16.4269.0013.8(VerdäTL355 lnterconnect32

116.3€69,0069.0(HicksTLUT e Leesville31

12.5(69,0069.0(N Leesv¡llêTL348 E Leesville30

,tf3.0€6S.0069.fiN LeesvilleTL352 Hombeck29

1.l2.83

69.0069.0(NegreetTL350 Many28

118.8C69.0069.0(NobleTL351 Many27

19.0c69.006S.0(MarthavilleTL349 Belmont26

110.3869.006S.0(ManyTL349 Eelmont25

f4.2414.2469.0069.0{Red Po¡nt66-332 Calumet24

113.162-13.1669.0069.0{Norlh Market66-331 Blanchard23

22

'I4.961.4.9ô69.0069.0(LS #12457 w/täp 10 JD Ward66-321 Calumet21

112.051.12.0569.0069.0(BellevusWtap to Do$þod6G320 Bed Point20

11.707.1.769.0069"0(Shed Road66-100 Minden Road19

't82-3.9Shreveport17

112. t9t{.æô9.0069.0(Summer Grove Mtap to South66-099 Midway16

'|8.26t{.2669.0069.0(RobelineTL358 Marthaville15

¿.0.4{t6314

12.65s.781-5.288969.0069.0(Wallace Lake w/tap to Finne66-092 Lucas'f3

,l0.186.821'6.8269.006S.0(Stanley (PHEC)66-086 Logansport12

13.4(2-3.469.0069.0(Superior66-O76 Jeflersont1

2-3.8f0110.4:I€.6569.0069.0(Superior66-072 HosstonI

I114.9t2-14.9869.0069.0(Super¡or w/tap to Belcher66-071 Hosston7

6

Ã

4

I27.71't-27.7369.0069.0(North Benton w/tap to Mott66-070 Hosston2I1.0.0069,00ô9.0(Wateruorks66-067 Hardy Street2

I1.1il -1.1 769.0069.0(Midway66-065 Hardy Street1

Number

ofCircuits

(h)

(Jn òIrucIUresof Another

Line(s)

unÒof

Desi

Type of

Supporling

Structure{e)

Designed

(d)

Operating(c)

To(b)

From(a)

LineNo.

LENGTH lPole miles)lln the òase-of

unoeforound ltnesreport õircuit miles)

VULIALiE (KV){lndicate wtìerdòther than6O cvcle. 3 ohaseì

t]ESIGNATION

1. Rêportinformat¡onconcemingtransmissionlines,costof lines,andexpensêsforyear. L¡steâchlransmissionlinehavingnom¡näl voltâgeof 132kilovolts or greater. Seport transmission lines below lhese voltages ¡n group totals only for each voltage.2. Transmíssion lines ínclude all lines covered by the delinition of kansm¡ssion system plant as g¡ven in the Uniform gystem of Accounts. Do not reportsubstation cosls and expenses on lhis page.

3. Report dala by individml lines for all voltages if so required by a State commission.4. Exclude lrom this page any lransm lssion lines for which plant cosls are included in Account 1 21 , Nonutility Property.5. lndicate whelhêr the type of supporting structure rcported in column (e) is: (.l) single pole wood or sleel; (2) H.frame wood, or steel poles; (3) tower;or (4) underground constructíon lf a lransmission line has more lhan one type of supporting structure, indicate lhe mileâge of each type of construct¡onby the use of brâckets and exlra l¡nes. Minor portions of a transmiss¡on linê of a d¡tferent gpe of construction need not be dislinguished from theremainder ol the line.6. tleport in columns (f) and (g) lhe total pole miles of each transmisslon line. Show in column (f) the pole miles of line on structures the cost of which ¡sreported for the line designated; conversely, show in column (g) the pole miles of line on struclures the cost of which is reported for anolher line. Reportpole miles of line on leased or partly owned struclures in column (g). ¡n a footnote, explain lhe basis of such occupancy and state whelher expenses wilhrespect to such struclures are included ín lhe expenses reported lor lhe l¡ne deslgnated.

TFANSMISSION LINE STATISTICS

Year/Period ot ReportEnd of 2015/Q4


t¡Name

Southwestem Electric Power CompanyOrigínal

(2\ A Resubmission

FERC FORM NO.1 (ED. 12-84 Page 422.12

3ôt,911,57f6,730,I6?f81,40t880,132,24880û,499,35iì73,632,89t

35

34

3$

32336.4 kCM ACSR

3t]36tkcMAcsR

30136.4 kcM AcsB

æxrô.4 kcM AcsR

28¡9stcMACSR

27/95 kCM ACSR

26¡36.4 kCM ACSS

25r95 kcM AcsR

24166.8 ACSR

23t77.0 AcsR

22166.8ACSR

21v0 AcsR

N}/0 AcsR

1gàß97.0 AcsB

T8795.0ACSB

17¡660 ACSR

16tz.o ACSR

15l3E.4ACSR

14s7.0 AcsR

13v0Acs8

12t/0AcsR

l1¡60.8 ACSR

10r/0AcsR

I136.4 AcsR

Ir/0ÂcsR

7¿66.8 ACSR

6r/0 AcsR

5197.0 AcsH

4¿6ô.8 ACSH

3179 ACSR

2!6ô.0 ACSR

Iì66.0 ÀCSR

LineNo.

TotalËxt6ses

Rentg

(o)

Ma¡ntenanceExoenses'(n)

Op€rationExoenses'(m)

Total Cost

(r)

Constnjclion andOlher Cosls

(k)

Land

(¡)

Size otConduclor

and Material(Ð

EXPENSES, EXçEPT ÐËPHECIATION ANÞ TAXESc;gs I (Jf, L|NE (tncruoe tn çorumn u) Lano,

Land righls, and cleåring rightol-way)

7. Do nol report the same lransm¡ssion l¡ne slructure twice. Report Low€r voltage Lines and higher voltag€ l¡nes as one line. Dêsignate in a tootñote ¡l

you do not include Lower voltage lines with higher vollage lines, lf two or more transmission line slructures support lines of the same voltage, report lhepole miles ol the primary structure in column (f) and the pole miles of the other line(s) in column (g)

8. Deslgnate any lfansmlsslon lino or portlon thereof for which lhe respondent ¡s not the sole own6r. lf such property is leased from anolher company,give name ol lessor, date and tems of Lease, and amounl of r€nt for year, For any transmission linE other ü¡an a leased line, or porlion ther€of, torwhich the respondent is nol the sole own€r but wtrich the respondent operates or shares in the operation of, fumish a succinct stalem€nt explafning thearrangement and gíving particulars (details) ol such matters as perêentownership by respondsnl in the líne, name of co-ownêr, basis of sharing

expenses of the Lino, and how the êxpeoses borne by the rêspondent are accounted for, and accounts affected. Specify whelher lessor, coownor, orolh€r party is an âssociated compâny.g. Oes¡gnate any transmission line leâsed to another company and give namo of Lôssee, date and lerms of lease, annual r€nt for year, and how

delermined, Specify whether lessee ¡s an associated company.10. Base lhe planl cost figures called for in columns (i) to (l) on lh€ book cost at end ot year.

TRANSMISSION L1NE STATISTIçS

Year/Psriod ot R€portËnct of 2015/Q4

Date of Reoort(Mo, Da, Y;)tt

This Rêmrt ls:(1) [¡Anoriginat(2) nA Resubmission

Nams of Responclent

Sguthwe¡ten Eleclric Power Company

FERC FORM NO.1 (ED. 12{n Page 423.12

3t7r03.484,0f 9.04TOTALs6

2-14.2535I't7.nt-2.s86S.0069.0(Mount Pleasant66-032 Däínserfield34

33

Lone Star & Air Products32

I15.51t-15.5169.0069.0(Hughes Springs w/tap to66-031 Daingertield31

2-0.ô530I6.9it6.3269.0069.0(Perdue66-030 Clarksville29

I7,X,ç7n6t.0069.0(Pêrdue66-029 Clerksvllle28

2.7.11Plpeline27I8.9tt.1"85ô9.0069.0(Sablne wltap to Service66-028 Chrksville26

& Texoma2E

18.4s1.8.4969.0069,0(Greggton dtaps tc MidVally66-027 Clarksville24I2.{2.2.69.0069.0(LA. Pacilic66-028 Carlhaqe23

2.10.487ô22I11.4214.932769.0069,qRock Hilt66-025 Carthage21

rPc20

11.64f.r.6469.0069.0{Texarkana Plant wltap to6&017 Bloomburg19

& Texâs Eastemt811.8ttn"8069.0069.0(Hosston øtaps to Rodessa6&01ô gloomburgt714.1C2"4"169.0069.0(Rock Hillô6-015 Beckv¡lle1ô

2'18.4315

I0.6324.01r.5.5869.0069.0(Poyrìler66-0f 4 Beckv¡llê1:4

tô.602€.669.0069.üL,A. Pacific66-013 Beckville13

12

2-1.2to Red uck & suqar Hill1T

110.57t'9"3769.0069.0(Thirty Ninth Street Wlaps66-012 Bann10

16,43t-6.4369.0069.0(Texarkana Operations Center66-010 BannI€

Star and Red River7116.8(f-f6,85969.006e.fiNew toslon w/tap to Lone66-009 Bann6

2-12.5Atlanta5

113.{f1.0.9969.0069.0(L¡nden Wtap to West66-00g Atlanla417.722-7.7569.0069.0(Bloomburg66-007 Atlantae

69 kV io TX2

1

Numbe¡

ofCircuits

(h)

vil Ðtfuçlufgsof Another

Lrnê(s)

K,turl,neratêdDe31

Type o!

Supporting

Structure(e)

Designed

(d)

Operating(c)

To(b)

From(a)

LlneNo.

rn

UtsÈ'IUNAIIUN

1. Report inlormation conceming lrânsmission lines, cost ol li¡es, and expenses for year. Ust each transmíssion line having nominal vollage of 132kilovolts or greater. Report lransmlssion lines below lhese voltages in group totals only for each voltage,2. Transmission lines include all lines covered by the defínition of transmission syslem plant as given in lhe Unllorm $ystem of Accounts. Do not reportsubslation cosls and expensês on thls page.3. Report data by lndivtdual linss lo¡ all voltages il so required by a SÞte commission.4. Exclude lrom this page any transmission lines for wtrich plant costs are included in Acoount '12I, Nonutility Property,5. lndicate whelher lhe type ol support¡ng stn¡cture reported in column (e) is: (1) single pote uood or steel; (2) H"rrâme $,aod, or steel poles; (3) tower;or (4) underground conslruction ll a transmission line has more lhan one type of supporting structure, indicate the mileage of each type of constructionby the use oJ brâckel$ ând extra lin€$. Minor portiqns of a tänsm¡$sion lins of a different typê of conskuctiôn need not bo distinguished lrom theremainder of lhe line.6. Beport in columns (f) and (g) lhe total pole miles of each transmission line. Show in column f) the pole miles of l¡ne on sln¡ctures the cosl of which isreported for the line designated; conversely, show ¡n column (g) üe pole m¡fes of l¡n€ on structures the c.ost ol whích is reported for anolher line. Reportpole miles of line on leased or partly owned structures in column (g). ln a footnote, explain the basis ot such occupancy and slate whether expenses withrespect to such struclures are included in lh6 exp€nses reported for the líne designaled.

Year/Period of R€portEnd of 20151Q4Southwest€m Eleclric Power Company

(1)(2)

OriginalDate(Mo,

tt

FEBC FOBM NO.1(ED.1244 Pagø 422.19

360,911,57(ô,730,16?t 81,40(880,13224€806,499,35373,032,89Í

35

u¡97.0 ACSB

33¡/0AcsR

32ß7.0 ACSR

31xr6.4 ACSR

30

æbß97.0 ACSR

28177.0 AcsF

27197.0 ÂcsR

26|/0 ÂcsR

251553 ACAB

24r/0AcsB

23t97.0 ACSR

n2133ô"4 ACSR

nl9tloAcsR

l8l7l2 CU (7 Slrand)

iô160.0 AcsB

15¡/0 AcsF

14x)7.0 ACSR

I3197.0 ACSR

12177,0 AcsR

'Itrß97.0 ACSR

r01272.0 AcsR

I166.0 ACSB

I177.0 ACSR

1ß7.0 ÁcsR

6/0 AcsR

5

4]97,0 ACSR

3t97.0 ACSR

2

t

JneNo.

TotalExpenses'(p)

Rents

(o)

Ma¡ntenanceExpenses

(n)

OperationExpenses

(m)

lolâl Cost

(t)


{k}

Land

û)

Size ofConductor

and Mate¡ial(i)

ÊXPENSES, ÊXCÊPT OËPåÊCIATION AND TAXËSuol' l ul- LlNh (lncluoe ln f.þlumn ul Lânq,

Land rights, and clearing right-of-way)

7. Do not report the same kansmission line struclure tw¡cë. Êeport Lower voltage Unes and higher voltage lines as one line. Designate in a foolnole ilyou do not inclr¡de Lower voltage lines with highêr voltage lines. lf t$,o or more transmission line structures supporl l¡nes of the same vollage, report lhepole miles of the primary structu¡e in column (0 and the pole miles ol lhê other line(s) in column (g)

L Designate any transmission line or porl¡on ìhereof lor which the respondent is not the sole owner. lf such prop€rty is leased f¡om another company,give narne ol lessor, date and terms of Lease, ând amount of rent lor year, For any transmlsslon llne olher lhan a leased line, or portion thereof, forwhich the respondent is not the sole owner but wtìich the respondent operates or shares in the operation of, fumish a succinct statoment explaining heanangement and giving partlculars (d€ta¡ls) of such matt€rs as percent ownershlp by respondent ln the llne, name of co-owner, basis of sharingaxpenseÊ of lhe Une, and how lhe expenses bome by the respondent are acÆounted lor, and accounts afected. Specity whather lessor, co-owner, or

other party is an associaled compâny;I. Designate any transmission line leased to another company and give name of Lessee, date and lerms of lease, annual rent tor year, and howdetermined. Specify whether fessee is an associated company.'¡0. Base the plant cûsl tigures câlled lor in columns {l) to (l) on the book cost at end of year,

TRANSMISSION LINF STATISTIÇS

Year/Period of Flepoft

End ol 2015/Q4Date of Reoort(Mo, Da, Yi)ttSouthwestem Êlectric Power Company

An Odginal

12) Resubmission

FERC FOBM r.lo. r (ED. f 2{7} Page 423.13

317103.484,0t9,0{TOTAL36

35

f5.87t-5.8769.0069.0(Southeast Lonqview66-080 Knox Lee34

2-7.433

I0.04f 6.341.8.93569.0069.0(Whitney66-079 Kilqorè32

22.1231

'|0.705.61t-3.4969.0069.0(Sabine66-078 Kilgore30

2.7.729

10.0712.4214:t269.0069.0(Overton6S077 Kilgors28

Ir8.3(2-'t8.363.0069.0(Superior66-076 Jeffe.son27

Woodlawn26

113.652-'l3.6s69.0069.0(Norlh Marshall Wlap to66-075 Jeflerson25

Air Products24

I8.381-8.3869.0069.0(Lone Star Soulh øtap to6S074 Hughes Springs23

2.15.4522

115.70t{.2569.00ô9.0(Linden66-073 Hughes Springs21

110.901-,l0.969.0069.0(Perdue66-069 Hawkins20

2.17.6619

I18.90t-l.u69.0069.ffM¡neola66-068 Hawkins18

I2.66r-2.6663.0069.0(Lake tamond66-064 Greoqton17

16

15

14

I25.011.25.0169.006S.0(Quitman wltap to Alba66-060 Grand Saline13

I6.996.8r1.6.813269.0069.0(Mineola66-059 Grand Saline12

Fitlsburq Steel11

124.471-24,4769.0069.0(P¡ttsburq Mlap to66-058 Gilmer10

111.44f-11.4469.006S.0(Perdue66-057 Gilmer9

I7

2{.35& M¡dvalley6

t33.s',i1.33.2269.0069.üWoodlawn Vtaps to Kamack66-056 FloumoyE

Pump & North Laneville4

114.8!f.r4.8969.0069.0(Sawmill øtaps to Sohio66-050 Fvenside3

I3.6€'t€.66ô9.0069.0(Poynter66-049 Ev€ns¡de2

1ô.4{r€.469.m69.0(Northwest Henderson66-ort8 Evenside1

Number

ofCircuits

(h)

un ùrtuclur€sol Arlolher

Lrne(s)

Type ol

Support¡ng

Structure{e)

Designed

(d)

Operating(c)

To(b)

From(a)

LineNo.

{GTH fPole miles)ln the èase.ofrderotound ltnesrcrt õircuit mites)

IJEùI{:NI\ I IUN

1, Report informalion conceming trånsmiss¡on lines, cost of lines, and expenses for year. L¡st eâch lransmission line having nominal voltage of 132

kilovolts or greater, Heport kansmission lines below lhese voltages in group totals only for each voltage.2. Transmission lines include all lines covered by the deiinition of transmission syslem plant as given in the Uniform Syslem of Accounts. Do not reportsubstat¡on costs and expenses on this page.3. Report dala by individual lines for all voltages if so required by a State commiss¡on.4. Exclude lrom lhis page any transm¡ssion lines for which plant costs are included Ín Account '121, Nonutility Property.5. lndicate whether lhe type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) lower;or (4) underground construction lf a lransmission line has more lhan one type of supporting struclure, indfcate the mileage ol each type ol constructionby the use ol b¡ackels and extra lines. Mínor portlons of ä lransm¡ss¡on lins of a different type ol construction need not be distinguished from lheremainder of the line.6. Repod in columns (0 and (g) tho total pole miles of each transmission line, Show in column (f) the pole miles of linê on slructures the cosl of which isreported for the line designated; conversely, show in column (g) the pole miles ol l¡ne on slructures the cost ol which is reported for another line. Reportpole miles of line on leased or partly owned structures in column (g). ]n a footnote, explain lhe basis of such occupancy and state whether expenses withrespect to such structures are included in the expenses reported for the line designated.

TRANSMISSION LI NE STATISTICS

Year/Period of ReportEnd of 20151Q4


This Reoort ls:(1) 6]An orisinal(2', ¡A Resubmission

Name of Respondent


FERC FORm NO.1 (ED.12-84 ?age 422.14

366,9t I,57f9,730,167181,40'688{t,13¿,24t806,49S,1ã373,692,895

352x795.0 ACSÊ

u1x477.0 ACSR

33

3Í!ßô.4 ACSR

3t

30r/0 AcsB

29¡2.0 ACSR

ßßô.4 ACSR

27166.8 ACSF

2A

25¿66.8 ACSñ

24]97.0 ACSR

23t{}6.4 ACSR

n2t197.0 ACSR

20177.0 ACSR

19

18fr.0 AcsR

171272 ACSR

t6195.0 ÀcsR

15t7.0AcsR14197.0 ACSR

13l3ô.4 ACSB

12r/0AcsRlt338.4 ACSR

t0¿0AcsR

d397.0 ACSR

Ir/0ACSB

7ß6.4ACSR

62nACSF

5f2CU0Srand)4266.8 ACSR

3z0 AcsR

2177.0 AcsR

f]97.0 ACSH

ineNo.

TotalExoenses'(p)

Rents

(o)

MâintenancêËxpenses

(n)

OperalìonExoenses'(m)

Total Cost

(t)


(k)

Land

0)

Size ofConductor

and Material(i)

EXPENSÉS, EXCEPT DEPRËCIATION ANO TAXESuus l ur" LrNts (rncluoe rn Lþrumn u) Land,

Land rights, and cleäring right-of-way)

7. Do not report lhê same lransm¡ssion line structurê twice. Reporl Lower vollage Lines and higher vollage linês as one lÍne, Þesignate in a footnole ifyou do not include Lower voltage lines with higher voltage lines. lf two or morê l.ansmission line struclures support lines of thé same voltage, report thepole miles ol the primary structure in column (f) and the pole miles of the other line(s) in column (g)

8. Designate any transmisslon l¡ne or portlon thereol for which üe respondent is not the sole oumer. lf such property ís teased from anolher company,give name ol lessor, datê and terms of Lease, and amount of rent lor year. For any transm¡ssion line other lhan a leased line, or portion thereof, lorwhich ths respondent fs not ihe sofe owner but wt¡ich the respondenl operatæ or shares ¡n the operat¡on of, lumish a strclnct statement explaining thearangement and giving parliculars (details) of srch matters as percent ownèrship by respondent in lhe line, name of coowner, basis of sharingexpenseg ol lhe Une, and how he exp6nses þomê by the respondênt are ac.counted for, and açcounl$ affected, Specify whether lessor, ço-owner, orolher party is an associated company.9. Designate any transmission line leased to another company and give name of Lessee, date and terms of lease, annual rent lor year, and howdetermined. Specify whether lessee ís an associated company.10. Base thã plant cost flgures called for ¡n columns [) to (l) on the book cost al end of year.

TRANEMISSION L¡NE STATISTICS

Year/Feriod of ReportEnd o! 2015/Q4

of

Southwestem Electric Power CompanyOriginal (Mo, Da,

tl(2t Resubmission

FERC FOFM NO. 1 (ED.12{7) Page 423.14

317103,484,019.04TOTAL36

eÊ12.411.2.469.0069.0(Thirty Nínth Street66-f25 Taylor Street34

12.8t1.2.8669.0069.0(Texarkana Plant6&124 Taylor Street33

12.9(1-2.96ô9.0069.0(Texarkana Operations Center66-123 Taylor Street32

3't

30

14.6f1-4.6869.0069.0(Whitney w/lap to Letoureau66-122 Soulheast Longview29

W€st Mount Pleasânt28

2{.67Winfield, Mount Vemon &27

1r6.3¡1-15.6669.0069.0(Pilgrim's Pride øtaps to66-116 Petty26

West Mount Pleasant25

Winfield, Mount Vemon &24

11.55I-1.5569.0069.0(Pilgrim's Pride dtaps lo6&115 PetW23

11.301-1.369.0069.0(North New Boslon66-107 New Boslon22

21

244.75& Cookv¡llê20

155.241.10.4969.0069.üNew Boslon dtaÞs to Naples6&102 Mount Pleâsânt19

2-0.6851t8I0.682.Xt -1.605669.0069.0(North Mineolâ66-101 Mineola17

16

I0.æ,l8,14l-18, t469.0069.0{Rock Hill Wtap to Blocker6ô095 Marshall15

13.4t2-3.4969.0069.0(North Marshall66-094 Marshall't4

12t.0I1-21.04769.0069.0(Marshall 6966-093 Lonw¡ew He¡ghlsf3t4. t€14.1869.0069.0(Wh¡tney66-090 Longview Heights12

¡1

12.59't-2.5969.006S.0(Whitney66-088 Longv¡ew10

Plânte

10.730.9014.96S.0069.frLone Star South66-087 Lone Star PôwerI7

12.707.16I-7.1669.0069.dLongview Heights66-083 Lâke Lamond6

Big Three5

18.6tt-8.6669.0069.0(Southeast Longview w/lap to66-082 Lake Lamond4

3

13.t4t-3.1469.00ô9.0(Longview66-081 take Lamond2

1

Number

ofCircuits

(h)

utt ùtt wluf ësof Another

unê(s)

L,rft ì>of

Desi

Typê ol

Supporting

Structurê(e)

Designed

(d)

Operating(c)

To(b)

From(a)

LineNo.

LENGTH lPole rniles)(ln lhe òase,ofundeforouno linesreport õircuit miles)

V()LIAGts, ÍKVI(lndicate wtìere'òther than6O cvcle. 3 ohaseì

utss¡uNAilUN

1, Report information concem¡ng kansmission lines, cost of lines, and expenses for year. List each lransmission line having nominal voltäge of 132kilovolts or greaier. Reporl transmission lines belor¿\, these voltages in group totals only for each voltage.2. Iransmission lines include all lines covered by the delinition ol lransmission system planl as given in lhe Unifonn Syslem ol Accounts. Do not reportsubslation costs and €xpenses on lhis page.3. Report dala by individual lines lor all voltages il so reguired by a State commission.4. Exclude from this page any lransmission lines lor which plant costs are included in Accounl 121, Nonutility Property.5. lndicate whether tho type of supporting structure reporìed ín column (e) ¡s: (1) single pole \,vood or steel; (2) H-frame wood, or steel poles; {3) tower;or (4) underground constnrtion It a lransmission line has more lhan one $pe of supporting structure, indicate the mileage ol each type of construclionby tbe use ol brackets añd extra lines. Minor porlions ol a transmis$ion line of a ditferent type of construclíon need not be distinguished from theremainder of lhe line.6. Report in columns (f) and (g) fhe total pole miles of each transmission line. Show in column (f) the pole miles of line on structures the cost of which isreported for the line designated; conversely, show ín column (g) the pole miles of line on struclures the cost of which is reported lor another l¡né. Reportpole miles ol line on leased or partly owned skuctures in column (g). ln a loohote, explain the basis of such occupancy and stale whethêr expenses withrespect to such structures are included in the expenses reported for the line designated,



End ot 2015/Q4Date ol Reoorl(Mo, Da, Yi)ttSouthwestem Ëlectric Power Company

(2)An OriginalA Resubmission

FERC FOR¡it NO. 1 (ED.12{4 Page 422.15

386,9t 1,57iô¡730,1ô?181,406880,t32,24{80f,49{¡,35373,632,89€

35

34¿x397.0 ACSR

331272.0 ACSR

32i66.0 ACSR

3llx7S5.0 ACSB

30v0 AcsR

ærr24,0 ACAB

28177.0 ACSR

27r/0ACSR

%t272.0 AAC

25

24

231272.0 þ'AC

uì66.0 ACSR

21r/0 ACSR

2Aì97.0 ACSR

19166.8 ACSR

18

17177.0 ACSR

16¡97.0AoSR

151272.0 ACSB

1412720 ACSR

t3r/0ACSB

12t68.0 AcsR

1I¡rd970 ACSR

102ræô.0 ACSR

II197.0 ACSR

7195.0 ACSR

6177.0 AcsR

5]97.0 ACSff

4¿1336.0&397.0 ACS

3

2¡55.0 ÂCAR

1

No.

TotalËxoenses'(p)

Rents

(o)


OperationExpenses

(m)

Iotal Cost

(t)

Constrrction andOther Costs

(k)

Land

(¡)

Size olConductor

and Material(i)

EXPENSES, EXCEPT ÐFPBEÇIATION ANÞ TAXESuuu r ur. LrNts (rncruoe tn L;otumn 0) Lano,

Land rights, and clearing right-of-way)

7. Do not report lhê same trânsmission line structure twice. Reporl Lower voltagê Llnes and higher voltagê l¡næ as one linê. Oesignale in a lootnote ifyou do not include Lower voltage lines wilh higher vollage lines, ll tr¡vo or morê transmission líne slruotures support lines of the same vollage, report thepole mlles of lhe primary structure in column (f) and the pole miles of the other line(s) in column (g)

L Designate any transmlssion line or portion thereof for wh¡ch lhe respondent is nol the sole owrtêr. lf st¡ch property is leased from another company,give name ol lessor, date and terms of Lease, and arnount of rent for year. For any transmission line other than a leased line. or porlion thereof, forwhich the respondent is nol the solo owner br¡l wlrich the respondent operates or shares ln the operation of lumish a succinct stiatement explaining theanangement and giving particulars (details) of such matters as percent ownersh¡p by respondent in the line, name of ccowner, basis of sharingexpenses ol the Une, and how lhe expen$es bome by the respondenl aro accounted for, and accounls afected. Specify whether lessor, Ga{wner, orolher party is an associated campany.9. Designate any transmiasion line leased lo another company and give name of Lessee, dat€ and terms of lease, annual rent for year, and howdetermined. Specifu whether lessee ís an associated compâny.'10. Bas€ the plant cost figures called for in columns {J} to (l) on the book cost at end of yeâr.

TRANSMISSION UNE SÏATISTICS

Yea¡/Period ol Report

Ëndof 20161Q4Southwestem Eleclrio Power Company(1)(?)

Original (Mo,tt

Da,

A ReSubmission

FERC FORü NO.1 (ED. 12€4 Page 423.15

st7f03.4€4,019.04TOTAL36

35

34

Total shown in Column i-ptransmlsslon line.33

available individualLlne Cosls and expenses are32

31

14659.31I,54f .l!Totat 69 kVSWEPCO30

297142"9618.91Subtotal 69 kV ln TX28

27125.8C1-25.869.0069.ffNorthwest Memphls66-806 {21508) Clarendon26

2.fô.9f5lnterconnect)25f17.0C1{.8569.0069.0(SPS Mag¡c C¡tv66-804 i2120O) Shamrock2414.3424.U69.0069.0{WFEC Russell (lnterconnecl)66-80g (21176) Vemon Main23118.721-18.7269.00ô9.0(Jericho66-802 (21 047) Clarendon22

2.0.8AmocrMemphis21

134.61r.33.8169.0069.0(West Chlldress øtap to66-800 (21046) Northwest2010.11t-0.1 13669.0069.0(Marshall 6966-633 Maßhall 138't917,191-7.1969.00ô9.0(Frederick Jct.66-624 Vemon Ma¡n Street18

17

11.352.621-2.6269.0069.0rMurvaul REC66-330 Carthaqe16

MagnoliaT5

I15.7211,741-11.7469.00ô9.0(Wlnnsboro øtap to Quitman66-2'19 Quitrnan14

Lâke13

'|0.9323.17t-23.r68069.006S.0(Winnsboro Wtap to Femdale66-217 Pittsburg12

2-2.2711

18^æ1-6.m69.006S-0(Tumertown66-213 Overton10

2.0.ô3II3.2¡l-2.õ269.0069.0(Povnter66-21 2 Norlhwest HendersonI19.4269.0069.0(Ouitmân66-210 Norlh Mineola7

I3.04r-3.04138.0069.0(West Mounl FleasantTL212 Mount Pleasant6

12.0et-2-0ô69.0069.0(66-203 Mount Pleâsant4

4

2n2.8976Vemon & Texoma212.713t.5S1.18.694169.m69.0(W¡nnsboro dtaps to Mount66-128 Winlield2

1

Number

otÇi¡cuits

(h)

\Jn ùrtuctuÍesof Another

Lrnê(s)

\Jft Þof

Desi

Type ol

Supporting

Slructure(e)

Designed

(d)

Operatíng(c)

To(b)

From(a)

LíneNo.

LENGTH fPole miles)lln the òase.of

unoefofound lrnesreport õircuit miles)

uhStGNAt toN

1. Rêport informalion concern¡ng lransmission lines, cost ol lines, and expens€s for year. List each transm¡ssion line having nom¡nal voltage of 132kilovolts or greater, Report transmission lines below these voltages in group totals only for each vollage,2. Transmission lines include all lines covered by lhe definition of transm¡ssion syslem plant as given in lhe Uniform System of Accounts. Do not reportsubstat¡on costs and expenses on this page,3. Report data by individual lines ficr all voltages ll so required by a State commission.4. Exclude trom this pago any transmission lines for which plant costs are included in Account 121, Nonulility Property.5. lndicale vvhelher the type ol supporting slructuré reported in column (e) is: (1) single pole wood or steel; (2) H-frame urood, or steel poles; (3) tower;or (4) underground construction lf a transmission line has more lhan one type of supporting structure, indicate the mileage ol each type ol construct¡onby the use of brackels and exira lines. Minor porlions of a kansmíssion line of a different type of çonslruclion need nol be d¡çtlnguished trom lheremainder of the line.6. Report in columns {f} and (g) the total pole miles of each lransmission line. Show in column (f) lhe pole miles of line on slructures the cost of which lsreported for the line designated; conversely, show in column (g) the polê miles ol l¡ne on struclures the cost of which is reported for another line. Reportpole miles of line on leased or partly owned structures in column (g). ln a footrote, explain the basis of such occupancy and state whether expenses w¡lhrespect to such slruclures are included in lhe expenses reporled for the line designated,

TFAN{



This Reoort ls:(1) [¡en orlsinal(2'l ¡ A Resubmission

Name of Respondenl


FERC FOBM NO. r (ED.12-8Ð Page 422.16

368,9'tf ,57f6,730,16it8t,406880,132348800,¡f99,35373,632,89r

35

34

33

326,91 1,57í6,730,167181,40€880,13¿,24€

31

30

N28

27

26,38.4 ACSR

25

24,OACSR

23rn.o ACSF

22,36.4 ACSR

21r/0 AcsR

20ßô.4 ACSR

t9,J1212.A A C

l8138.9 ACSR

't7,97.0 Âcsn

't6)36.4 ACSR

15r7.0 ACSR

14r/ûAcsB

t3rr.0 AcsR

t2266.8 AßRJI

10,OACSR

(

I]970 ACSH

7t272.0 ACSR

61533.3 ACSB

5¡55.0 AcÀB

4177.0 ACSR

3]3ô.4 ACSR

2t0 AcsR

I

No.

Totâ¡exnS;ses

Rents

(o)

Mai¡tenanceExpenses

(n)

OperationExpenses

(m)

Tolâl Cost

(t)

Construction andglher Çosts

(k)

Land

ú)

Size ofConductor

and Måter¡al

{i)

EXPENSES, EXCEPT ÞEPRECIATION ANO TAXESu(Js I ot, LlNb. (lnclude ¡n column 0) Land,

Land rights, and clearíng right-ol-way)

7. Do nol report lhe same transmission line struclure twice. Beport Lower voltage Unes and highêr vollage lines as one line. Designate in a footnote ifyou do not include Lower voltage lines wjth hlgher voltage llnes. lf t\¡\ro or more lransmission line stnrtures support lines of tho same voltage, report thepole miles ol the prímary structure in column (f) and the pole rniles of lhe other line(s) in column (g)

8. Designate any transmlsslon line or portion thereof lor wt¡ich the respondenl is not the sole owner. ll snch property is leased from another compâny,give name ol lessor, date and terms of Lease, and arnount ol rent for year. For any lransmisslon line other than a leased line, or portlon lhereof, forwhich the respondenl is not lhe sole owner but wfrlch lhe respondent operates or shares in the opemtion of, furnish a succ¡nct statement explaining theaßangement and giving particulars (delails) ol such matters as percent ownership by rsspondent in the line, name of co{wner, basis of sharingexpenses ol the Une, and how he expensss bomê by the respondent are accounted for, and accounts atlected. Speciþ whether lessôr, co-o\¡rner, orofter parly is an associated company.9. tesignale any lransmission line leased to anolher company and give name of Lessee, date and terms of lease, annual rent lor year, and howdetermined, Speclfy wñether lessee is an associaled company.10. Base the plant cost figures called for in columns û) to (l) on lhe book cost at end of year.

TRANSMISSION LINE STATIST¡CS

Year/Period of Repod

Endof 2015/Q4Southwestem Electric Power Company(1)(2t

An OriginalA Flesubmission

{Mo, Da,tt

FERC FORM NO.1 (8D.12-8Ð Page 423.16

TOTAL44

4€

42

41

40

eo

3€

37

36

35

34

3¡

32

3t

30

29

28

27

2â

tÉ24

23

¿¿

2l2A

19

18

17

16

t6

14

13

12

fit0

ô

I7

6

I

4

a

2

NO LINESADDED1

Ultimate

(s)

Pres€nt

0)

^YËt6UgNumbeíperMilss(e)

Type

(d)

l.llt,Lengh

tnMiles

(c)

to

(b)

From

(a)

UneNo.

r-r ùr l ttuuIUHult{çut I tt t,tsSUPPILINÈ UEì

1. Report below the inlormalion called for concerning T¡ansmission lines added or allered during lhê year. lt is not necessary to reporlminor revisions of lines.

2. Provide $eparale subheadings for overhead and underground construclion and show each transmíssion line separately. lf actualcosls ol competed conslruction ârè not readily available for reportlng columns (l) lo (o), it is permissible to report in lhese columns lhe

TRANSMISSION LINES ADDED DUF'NG YEAR

Year/Period of Flepori

End of 2015/Q4Date of Report(Mo, Da, Yi)tt

This Reoort ls:(1) EIAn orisinal(2) ¡A Resubmission

Name ot Responctent


FERC FOFM NO.1 (REV. t2{3} Pags 424

44

43

42

4'l

40

39

38

37

36

35

u33

32

31

30

29

2e

21

2e,

2a

24

23

22

21

2Õ

19

18

17

1€

15

14

13

12

11

10

II7

6

Ã

A

¿

1

LineNo.Total

(p)

AssetFtet¡re. Costs

(o)

Conductorsand Ðev¡ces

(n)

Poles, Towersand Fixtures

{m)

Land andLand,Rights

VoltageKV

(opï6tins)Conliourationand Spacing

(¡)

Specilication

{i)

Size

{h)

LINE COSTV(JNUUU I lrñÞ

costs. Designale, however, if êslímatêd amoünls arê reported. lnclude costs of Clearing Land and Rights-olWay, and Roads andTrails, in column (l) with appropriate foolnote, and costs of Underground Conduit in column (m).

3. lf design vollage diflers frorn opêrating voltage, indicate such fact by footnote; also wher€ line is other lhan 60 cycle, 3 phase,

indicate such othêr characledslic.

Continued)TNANSMISSION LINES ADDEÐ DURING YEAR


End ol 2O15lQ4Date of Reoort(Mo, Da, Yi)u

This Reoort ls:(1) 5]nn Original

{21 ¡A Besubmission

Name ol Rospondent


FERC FORM NO. r {FEV. 12-03} Page 425

12.5069.0(DBRQOKS STREET (SW). LA40

12.0(DBHOOKSSTREET (SW) - r-A39

12.UDBFOADMOOR. LÅ38

13.0969.0CDBHOADMOOH - T.A97

12.5069.0(DEFIOADMOOR - LA3612.4769.0(DBOSSTERCTTY- l-A35

12.5069.0CDBOONEVII.I.E.AR34

34.5CTBONANZA.AR33

12.4734.5{TBONANZA. AB82

34.501ô1.0(TBONANZA. AB3T

12.47138.0CDBODCAU ROAD. LA3012.æÐBLOOMBURq.AR29

r3.ü¡69.0CDBLANCHARD - I.A28

12.æ69.0CDBLANCHARD. LA27

'13.0969.0CDBrG SANÐY {SW),Ð(26

'13.2069.0CDBELMONT(SEP). LA25

12.0069.0CDBELLEWE OIL FIELD. I.A24

12.4769.0CDBELLEWE.I.A2g

'12.0069.0CoBELCHER. LA22

13.0S69.0CDBECKVILLE - TX2't

12.0CDBEÂN " I.Â20

't2.47138.0CDBEAN. LA19

13,2069.00DBAYOU PIERRË - LA18

12.0072.60r38.00TBANN. TX17

72,OO138.mTBANN. TX16

12.0069.00DBALDWIN -TX15

12.00E}ATLANÏA.TX14

12.4769.00DÁTUNTÄ'TX13

12.0069.000ASHDOWN 6911â - AH12

138.00TABSENALHILL. LA,11138.0(TARSENALHILL. LAf0

12.0(TAFSENALHILL- I¡I12.0069.0CrARSENALHÍLL. lj8

12,4770.50138.0CTARSENAL Hf LL - I.A7

13.80't38.0cDALUMAX'TX6

12.0069.0CDALSA.fX5

12.5069.0CDAIRLINE.ÏX4

12.4769.0cDAIÊLINÊ.TX3

12.0069.0CDArR PRODUCTS (SW) -TX2

't2.4734.5CDABBOTT - ARI

Tertiary(e)

Secondary(d)

Primary{c}

Character ol $ubstation

(b)

Name and Locatlon ol Substatíon

(a)

Line

No.

VOLTAGE (ln MVa)

1. Report below the information called lor concerning subslations of the respondent as of lhe end ol the year.2. Substations which serve only one industrial or street railway customer should not be listed below.3. Substalions with capacities of Less lhan 10 MVa except those serving customers with energy for resale, may be grouped accordingto funclional character, but the number ol such substaiions must be shown.4. lndicate in column (b) the tunctional character of each substation, designating whether transmissíon or distribution and whetherattended or unattended. At tho end of the paga, summarize according lo lunction the capacilies reported for the individual stations incolurnn (f).

Year/Per¡od of ReportEndof 20151Q4

Date of Reoort(Mo, Da, Yi)ttSouthwestem Electric Power Company ) An Original

A Besubmission

FERC FOnil NO.1 (ED.12-96) Page 420

¡10240

394'lSTATCAF

386ISTATCAF

37125

3612Q

3527û"54

240

33f1STATCAF

3231

:J1I12

30240

29I2

28125

27219

261o

25114

2415

23I13

'¿2Iô

2116

'¿a'ìISTATCAF

t9140

18t7

17I133

161133

1527

1461STATCAF

132ô6

1222tt13Air Cqre Fleaclor

1043JSTATCAP

I61STATCAP

I284

72400

o240

5'I5

4120

3120

z17

11a

LíneNo.Total capacity

(ln MVa)(k)

Number of Unils

fit

Type ot Equipment

li)

NumberofSpare

Traneformers

{hl

NumberotTransformers

ln Service

{o)

Capacity of Substat'r¡n

(ln SeMce) (ln MVa)

{fì

CONVÊRSION APFABATUS ANÐ SPECIAL EQUIPMENT

5. Show in columns {l), (i), and (k) special equipment such as rotary oonverters, rectifiers, condensers, etc. and auxilíary equipment lorincreasing capacity,6. Designate substations or major itêms of equipment leassd from olhers, iointly owned w¡th others, or operated othen¡/iss than byreâson of sole ownershíp by the respondent. For any substation or equipment operated under lease, give name of lessor, dale andperiod of lease, and annual rent. For any substation or equipment operated olherlhan by reason of sole ownership or leass, gívê nameof co-owner or olher party, explain basis ol sharing expenses or other accounting between the parties, and state amounls and accounlsatfected ïn respondent's books of account. Specify in each case whether lessor, co-owner, or olher party ¡s an associated compåny.

Year/Period oÍ FleporlEnd of 2O15lQ4

Datê of Reoort(Mo, Da, Yi)tt

(1)(2)

An OriginalFlesubmission

Namê ot Respondent


FERC FORü NO.1 {ED.12-s6) Page 427

12.4769.mTDEQUEEN. AR40

72.æ138.00TÞEQUEEN. AR39

12,00DDEKALB - TX38

12.4769,00ÞDEKALE - TXa7

12.0069.00DDËKALB. TX36

12.47138.00DDEËN POINT. LA35

12.4769.00DDAINGERFIËLD. TXu13.8C138.003¿+5.00ïCBOÕKETT.TX33

12.5C138.00345.mTCROCKETT. TX32

13,2034.50DCRËSTON. LA31

12,0069.00DcooKvrLLE tsl^¡) -Tx30

12,5069.00ÞCI.ABKSVILLE. TX29

12.08ÐCI.ABKSVILLE.TX28

69.0(DCLARENDON -TX27

7.5669.00ÐCI.ARENDON.TX26

't3.096S.0(DCITY I.AKE SUB. TX25

7.62TcHTLDRESS WEST (SEP). TX24

TCHTLDRESS WEST (SEP) - TX23

12.4769.00't38.0cTÇHTLDRESS WEST (SEP). TX22

2.&69.0CDCHILDRESS AMOCO.TX21

1S.0S69,0CCHILDRESS AIHPOBT PRISON - TX20

r3.801ô1.00345.0(TCHAMBËFS SPÊING. AR19

12.47161.0(DCENTERTON.AR"t8

12.47138.0CDCENTER.fX17

138.0CDCENTER.TX16

12.0CDCENTER.TX15

138.0CD0EDAR GROVE (SW) - r.A14

12.00DCARTHAGE. Ð(13

'12.5069.00DCARTHAGE. TX12

13.2034.50ÐoARHOLL (SEP) - l-A11

7.2069.0CDCAREY - TX10

36.20138.00DCAPLIS.I.AI12.47138.00DCAPLIS - LAI't3.2034.5CDCANE RrVER (SEP). LA7

13.20115.0(DCANE RIVER (SEP). LA6

13.2034.5CDCAMPTI. LA5

12.0069.0CDCALUMET " LA4

12.47't38.0cTBRYANS MILL " IX3

34.0069.0CÐBROWNLEE.I.A2

12.0069.0CDBROWNLEE.I.A1

Terliary{e)

Secondary(d)

Primary(c)

Characler ol Substation

(þ)

Name and Location of Subslation

(a)

L¡ne

No.VOLTAGE (ln MVa)

.1. Report below the informalion called for concem¡ng subslations ol tha respondent as of the end Õl thê year.2. Substations which serve only one industrial or street railway customer should not bs listed below.3. Substations with capacities of Less than 10 MVa except lhose serving customers wlth energy for resale, may be grouped accordingto functional character, but the number of such substations must be shown.4. lndicate in column (b) the lunctional characler of each subslation, designating whether transmission or distribulion and whetheratlended or unattEnded. At the end of thE pagê, summarize according lo lunction thê capacities reported lor the individual stations incolumn (f).

,BSTATIONS

Year/Period of ReportEnd of 20'15/Q4

Oate of Reoort(Mo, Da, Yi)lt

Name Flespondent

Southwestern Electric Power Company(1)(2)

An OriglnalA Resuþmission

FEFC FOFM NO.l (ED. 12-96) Page 426.1

40133

391133

38(ISTATCAF

,,t71I

361I35245

aa4242

3i¡,l300

321300

31'l7

301r'¿9240

28I2STATCAF

2741STATCAF

267

25¿50

2413,312Alr Core Reactor

236,60C1STATCAF

22150

211I2932

l91600

l81

17284

l6311STATCAF

15€1STATCAF

'145€1STAÏCAF

131t2STATCAF

12,40

1114

't032

I130

I125

717

6253

5114

4I€

3IIz114

T22â

UneNo.Totâl

(lnCapacityMVa){k)

Numberol Un¡ts

ti)

fype of Equiprnenl

(i)

Number ofSpare

T¡ansformers

{h}

Number ofTranslormefs

ln Servlce(q)

Capacity ot Subslalion(ln Service) (fn MVâ)

(f)

CONVÉRSION APPASATUS ANÐ SPECIAL EQUIPMENT

5. Show in columns (l), (j), and (k) special equipment such as rotary converters, reclifiers, condensers, etc. and auxiliary equipment lorincreasing capacity,6. Designate substalions or major items ol equipment leased lrom others, jointly owned w¡th others, or operated otherwíse than byreason ol sole ownership by the respondent. For any substation or equípment operated under lease, give name of lessor, date andpedod of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownershìp or lease, give nameof co-owner or other party, explain basis ol sharing expenses or other accounting between the parties, and slate amounts and accountsaf{ected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party is an associated cornpany"


End ot 2015/04Datê of Reoort(Mo, Da, Yi)tlSouthwestem Electdc Power Company

(1)(2)

AnA Resubmission

FERC FORM NO.1 (EO. 12.96) Pags 427.1

13.80't81.00345.00TFLINT CBEEK SUB " AR¡¡012.0069.mDFINNEY. LÀ3$'

12.0CDFINNEY.LA38

12.0469.00ÐFINNEY. LAs7

r2.0069.mDFËRNDALE LAKE. TX36

12.50DFERN STREET " T.A35

12.00DFERN STREET- I.Åu12.00t)FAYETTEVTLLE (SW) . AR33

12.4]161.00DFAYEÍTSfiLLE (8$ - An32

12.41181.00DFARMINGTON.AR3ff 2.00DEVENSIÐE. TX30

12.506S.00DEVENSIDE- 1)(29

34.50't6!.0(TEUREKA SPHINGS 1ô1KV. AR28

34.50161.0(TEUREI(^ SPFINGS 161KV. AR27

1S.0S69.0(DESTELL¡NE.'D(26

r2.00DELLERBE ROAD. LA25

12.4769.0(DELLERBE ROAD - LA24

12.5069.0(DEDWARDS STBÊ T. LA23

69.00161.0(TEAST ROGERS. AR22

69.0CTEAST ROGEHS. AR2'l

69.0CTEASTCENTEHTON - AR2A

12.41ô9.001ôt.0cTÊASTCENTERîON - ARt97.2069,0O161.0CTÊASTCENTERTON. ARt87.6i69.00't6't.0cTDYESS . AR,7

12.0069.0{TDYESS. ARI669.0CTDYESS. AR't5

13.0969.0úÐDOGWOOD -TAÎ412.4769.00DDOGWOOD -LAT3

1S.0S161 ,00DÐIXIEI-AND. AR't212.5069,00oÐIXIEI.AND. AÊ1t12.4769.00DDIXIEI.AND. AN10

12.4769.00ÐDIERKS.ARI7.62DDIËRKS.ARI

13.8C138.00345.00TDIANA. TX7

13.8C138.00345.0(TDIANA. TXô

13.2034.5(DÐËRRY " LÀ5

69.0(IÐEQUEEÍ,¡ - AR4

12.&TDEQUEEN. AB3

34.508S.0CTDEQUEFN. AR2

12.5069.0{TDEQUEËN. AÊ1

Tertlary{e}

Secondary(d)

Primâry(c)

Character ol Substâtion

(b)

Name and Location ol Substalion

(a)

UneNo,

VOLTAGE (ln MVa)

1. Report below the information called for conceming subslations of the respondent as of lhe end of lhe year.2. Substation$ which serue only one industrial or street railway customer should not be listed below.3. Substations with capacities of Less lhan 10 MVa except those serving customers with energy fol resals, may be grouped accordingto functional character, but the nurnber ol such substaiions must be shown.4. lndicate in column (b) lhe lunctional characler ol each substation, deslgnating whelher transmission or distribution and whetherattended or unattended. At the end ol tho page, summarize according tó lunction lhe capacities reported for lhe indivldual stations incolumn fl).

Year/Period ol ReportEnd of 2O15lQ4

Datê of Reoort(Mo, Da, Yi)ttSouthwestsm Electric Power Company

(1)(2t


FEBC FORM NO.1 (EÞ. 12-96) Page 426.2

402800

3912

3E11STATCAF

3735

3612

35240

34t1STATCAF

3¡tl¿¿STATCAP

32280

3112Q

30€1STATCAF

2924A

2&'|2Q

27120

2ö32

2561STATCAF

z+256

23120

?21133

21431STATÇAF

20431STATçAF

1S'l130

181130

173265

16219

154fISTATCAF

'141I1311'l

12125

11120

10133

Ie32

8q'lSTATCAP

7tt1050

I1300

5f11

4221STATCAF

36tSÏATCAF

2111

1133

LineNo.Total Capacity

(lnùlVa)Number ol Unäs

riÌ

Type of Ëquipmént

(¡)

Number ofSpare

Transformers

ft)

Number ofTransformers

ln Service(o)

Capacity ol Subtation(ln Service) (ln MVa)

(f)

CONVËRSION APPAHATUS AND SPECIAL ËQUIPMÉNT

5. Show in columns (l), fi), and (k) special equipment such as rotary converters, rectifiers, condensers, etc. and auxiliary equipmenl forincreasing capacity.6. Designate substâtions or major items of equipmenl leased from others, jointly owned with olhers, or operated olhen¡rise than byreason of sole ownership by the respondent, For any substallon or equipment operaled under lease, give name of lessor, dale andperiod of lease, and annual rent. For any substation or equipment operated other than by reason of sole ownership ot lease, give nameol co-owner or other party, explain basis ol sharing expenses or other accounting between the pârl¡es, and stale amounts and accountsaffected in respondent's books of accounl, Specify in each case whether lessor, co-olvner, or other party is an associaled company.

SUBST

Year/Period ot ReportEndol 2015/Q4

Dats of Reoort(Mo, Da, Yi)ttSouthweslen Electric Power Çompany

(r) An OdginalFìesubmission

FEFC FORri NO. I (EÐ. 12-96) Page 427,2

24,9069.0CDHORNBECK. L{40

12.00ô9.0cDHOOK$. TX39

12.4769.0CDHOLOX. AR38

13.2069.0CDHlcKs'1,{37

12.5069.0(DHEDLEY. TX36

12.4769.0CÐHAWKINS.TX35

13.09138.0CDHAUGHTON - I.Au12.47138.0CDHAUGHTON . LA33

DHAFTS ISI.AND. TA32

34.50138.mÐHARTS ISI.AND.I-A31

34.50138.0cÐHABRISON ROAD.TX30

12.00DHARDY STREET. lÁ29

13.0969.0CDHALLSVILLE. TX28

12.5069.0CDGREGGTON.TX27

't2.0069.00DGREGGTON.TX26

12.47161.00DGFEGG STREET. AR25

12.0034.50DGREENWOOD.AR24

12.0034.50DGREENWOOD. AF23

12.4769.00tGRËENI.AND. AR22

12.0O6S.00DGREENL{ND. AR21

26.4069.00ÞGFAVEL POINT. tá2A

12.00DGFAND SALINE. TX19

12.W69.0óDGRAND SAL¡NE. TX18

13.20s4.s(DGRAND ECORE. LA17

12.5069.0CÐGILMER.lX16

12.0069.0(DGILUAM.IÁ15

12.47r38.0cDGEORGTAFACTF|C (SW) - LA14

13.80138.0cDGENERAL MOTORS. I-A13

12.5069.0cÞGATES -Ð(12

13.2034.5{ÞGAIIAGAN - I.At1

12.47.t38.0cDFBIARS SWITCH . TX10

12.0CTFORT HUMBUG.I.Aô12.0069.00TFORT HUMBUG.I.AI

13.0€70.50138.mTFORT HUMBUG . LA7

2.ß69.0CDFORMAN.MAGNCILIA. AB6

12.0069.00DFOREMAN. Añ5

12.5069.00DFORD.L{4

12.0069.00DFORBING ROAD. I-A3

7.2C63.00138.0(TFLOUñNOY - LA2

12,5069.0CTFLOURNOY - I.AI

Tertiary(e)

Secondary(d)

Primary{c)

Character of Subslation

(b)

Name and Locaiion of Substallon

(a)

UneNo.

VOLTAGE (ln MVa)

1. Report below the ínformation called for concerning subslât¡ons of the respondent as of thê end of lhe year.2, Substalionswhich serve only one induslrial or street railway customer should not bo listed below.3. Substatlonswith capacities of Less than 10 MVâ excêpt those sewing cuslomêrs w¡th energy for resâle, may be grouped accord¡ngto functional character, but the number of such substations must be shown.4. lndicate in column (b) the functional characler of each subslation, designating whether transmiss¡on or distribution and whetheraltended or unattended. At ths end of lhe pag€, summadze according to function the capacities reported for the individual stations fncolumn (l).


Endof 2O15lQ4Datê ol RêÐort(Mo, Da, Yi)ttSoulhwestem Electric Power Company

(1) AnA

FERC FORM NO.1 (ED. 12-96) Page 426.3

40I28

iJ9221

381Iðt114

3632

35a2â

'J4I25

trtT'tl

321€2STATCAF

312100

302133

z9227

2A250

272.10

2615

25,|M2414

23311

221tl21ts

21)1lill961STATCAF

16219

17114

1ô2415.,|

5

14I7

13290

1'¿120

t'l111

't0228

IfISTÄTCAF

I219

71130

6,|7

52s

4240

31I21f33

12&

LlneNo.Total Capac¡ty

(lnlvlVa)Number ol Units

lit

Type of Equipment

ril

Numb€r otSpare

Transformers

thì


ln Service

{ol

Capacity of Substation(ln $ewice) (ln MVa)

tfr

CONVERSION APPARATUS AND SFECIAL EQUIPMENT

5, Show in columns {l), fi), and (k) special equípment such as rotary convêrters, fectiliers, condensers, etc, and auxiliary êquipment forincreasing capacity.6. Designate substations or maJor items of equipment leased lrom others, jointl¡¡ owned vJ¡th othêrs, or operaled othen¡rise than byreason of sole o$lneiship by the respondent. For an¡¡ substation or equlpment operatêd under lease, give name of lessor, date andpe¡iod ol lEase, and annual rênl. For any substalion or equipment opôrated olher than by reason ol sola ownership or lease, give nameol co-owner or other party, explain basîs of sharing e)penses or other accounting between the parties, and stala amounts and accounlsallected in respondent's books of account. Specify in each case whether lessor, co-owner, or olher party is an associalêd company.

Year/Period of ReportEn<t of 20"lVQ4

Date ot Reporl(Mo, Da, Yi)tl(2)

An OriginalA Besubmlssiôn

Name of Respondent

Southwestem El€ctric Powg¡ Company

FERC FOFM NO.1 (ED. t2-90) Page 427'3

12.47t38.00DLTNWOOD(8W). r-A,lo13.09138.00DLINTON ROAO.Iâ39

12.00ô9.0(DUNDEN. TX3812.0069.0CDLIEBERMAN 12KV. LA37

13.006S.00138.0CTLIEBEHMAN.I.436

12.5069.00138.0(TLIEBERMAN T LA35

12.47138.0(DLIBERTY CITY.TXu12.47138.0CDLEVERETTS CHAPEL. TX3i¡

12.4769.0(DLETOURNÊAU 69/12. TX32

14.4069.00t38.0(Tr-AKË PÁUUNE {SËP}- TX31

12.m69.0CDIAKE LAMOND -TX30

12.47ô9.0(DI.AKE I-AMONO.TX29

13.8069.00'1s8.00CII.AKEÎjMOND.TX28

12.00DI.AKE LÁMOND.TX27

t9.2434.5CDKURTHWOOD - ¡.A26

6S.0CTKNOX LEE.TX23

69.00TKNOX tEE. TX24

24.9069.0CDKINGSTON. ¡á20

12.5069.0CDKINGS HIOHWAY - TX22

12.$DKILGORE.TX21

,12.5069.0CDKILGORÊ.ÏX20

12.4769.0(DKILGORE.TX1g

4.1626.0CDJW GATHERTNG (SEP) - LA18

8.3069.001 't5.0cTJERICHO.TX17

7.2A34.5CÐJENNY LIND. AR16

7.2034.5CDJENNY LIND - AH15

4.18t 16.0cDJELD.WÉN P¡JNT.I.A14

12.0069.0CoJEFFERSON - TX"t312.47138.0CDIPC-JEFFEBSON. TX12

12.47138.mDtPc-DoMtNo -Tx1t

13.2069.mDIPC ôgKV " IX10

12.00DHYI..AND " ARI't2.41161.00DHY1ÀND. ARI34.5069.00THUNTINGTON . AR7

13.0969.00THUNTTNGTON " AR6

4.1€12.0069.00DHUGHES SPRINGS - TX5

12.00DHOWELL,TX4

12.476S.00DHOWELL.TX3

12"0069.00DHOWELL-TX2

13.0969.0(DHOSSTON-t-A1

Tertlary(e)

Secondary(d)

Primary(c)

Character of Substat¡on

(b)

Name and Location of Subslation

(a)

LineNo.

VOLTAGE (ln MVa)

1. Report below the information called lor concerning subsiations of the respondent as of the end of the year.2, Substations which serve only one industrial or street railway customer should nol be listed below.3. Substations w¡th capacities ol Less lhân 10 MVa except those serving customêrs with energy for resale, may be grouped accordinglo functional character, but the number ol such substâtions must be shown.4. lndicate in column (b) the functional character of each subslation, designating whether transmission or distribution and whelherattended or unattended. At the end of the page, summa¡izê according lo function the capacilies reported for the individual stalÍons incolurnn {f}.

¡UBSTATIONS

Year/Per¡od of FeporlEndof 2015/Q4

Date of Reoort(Mo, Oa, Yi)tt

Name of Respondent

Southwestem Electric Fower Company(1)

{z',)

An OriginalA Êesubmission

FEFC FOFM NO. r (8D.12.96) Page 426'4

40266

392¿10

38213

37214

36150

35250

ö4611

3T'1I32125

3'l163

30120

29240

26'l133

2712ISTATCAF

2613

251STATCAF

?41133

23,t28

22¿40

21(2STATCÂF

2U120

192&18228

17J42

1612

1512

14128

T321g

12220

't117

1017

I61STATCAP

I133

7117

6I6

5221

4t1STATCAF

3,l33

z120

1113

LineNo.Toìal Capacity

(ln MVa)k)

Number ol Units

{iì

Type of Equipment

ti)

NumberolSþre

Transformers

fh'l

NumbêrofTransformers

ln Service

lol

Capac¡ty of Subslation(ln Service) (ln MVa)

tfr

CONVERSION APPARATUS AND SPECIAL EQUIPMENT

5. Show in columns (l), (j), and (k) special âguipment such as rotary conve¡lers, rectifiers, condensers, etc. and auxiliary equ¡pment forincreasing capacity,6. Designate substations or major ilems of equipment leased from others, jointly owned w¡th others, or operated otherw¡se than byreason of sole ownership by the respondent. For any subslation or equípment operated under leasê, give name of lessor, date andperiod of lease, and annual rent. For any subslation or equipment operated other than by reason of sole ownership or leasô, give nameof co-or¡/ner or other party, explain basis of sharing expens€s or other accounting between lhe parties, and stale amounls and accountsatfected in respondent's books of âcoount. Specify in each case whether lessor, co-owner, or other parly is an associaled company.

Year/Pe¡iod ot Report

Endol 2015/Q4Date of Fleoort(Mo, Da, Yi)tt

(1)(2)

OriginalA Flesubmisslon

Name ol Resporìdent


FERC FoRM NO.r (ED.12.96) Pagø 427.4

12.4769.00TMENA. AR40

TMEMPHIS NW. TX39

13.0069,0CDMEMPHÍS. TX38

69.00DMËMPHIS. TX?7

12.00DMCWILUE STRETT. lá36

't2.4713å.0CDMCWILLIESTREET- LA35

12.47138.00DMCOADE.I.As4

12.4769.00DMABTTN (SW)-Iá33

12.0034.5€DMABTTN (SW) - r-A32

13.2069"00DMARTHAVILLÊ- lj31

12.00ÐMÂRSHATI. 69KV - TX30

13,0€63.00DMÂFSHALL 69KV. TX29

12.Ø69"00DMABSHAII.69KV. TX28

13.0(69.00138.0€TMARSHAII. 138KV. TX27

7.2C69.00138.00TMAFSHATI- 138KV. TX26

13.2069.00DMANY- I.A25

13.2034.50DMANSFI€LÐ. lj24

13.0969.00CILUCAS.I.A23

12.00DLUCAS.I.A22

12.47161.0(DLOWETL(SËP) - AR21

12.5069.0(DLOUISIANA PACIFIC. TX20

13.8C138.00s45.0(TLONGWOOÞ (SW) - l-A19

12.0{TLONGWOOD (SW)- rÁ18

13.8C138.00345.0CTLONGWOOD(SW) - LA17

12.il138.00345.0CTLONGWOOD (SVV). LA16

12.47138.0CDLONGVIEW HEIGHTS -TX15

12.0CDLONGVIEW HËIGHTS. TX14

12.UDLONGVIËW.TX13

't3.0s09.0cDLONGVIEW.TX12

12.5069,0CDLONGVIFW.TX1t12.5C69.00138.0{TLONE STÂF SOUTH . ÏX10

12.m69.0€DLONE STAR SHETL ORDNANCE . TXI13.0969.mTLONE STAB {SEP).TXI12.4?t38.00DLONDON (SW). TX7

13.0969.00TLOGANSPORT. LA6

't2.00ô9.00TLOGANSPORT. LA539.84ô9.00138.00TLOGANSPORT. t.A4

13.80ô9.00138.0(TLOGANSPORT. t.Â\'12.O069.frÐLOçKESBURG (NEW) -AR2

1DLTNWOOD(SW) - rá1

Tertiary(e)

Secudary(d)

Primary(c)

Characler of Substation

(b)

Name and Location ol Substatíon

{a)

Line

No.

VOLTAGE (ln MVa)

1. Report below the information called for concerning substations of the respondent as of thê end of lhe year.2. Subslalions which serve only one industrial or slreet railway customer should not be lisled below.3. Substations with capacities of Less than 10 MVa except those serving oustomêrs with energy lor rêsale, may be grouped accordingto functional character, but the number of such substations must be shown.4. lndicale in column (b) the funetional character ol each substation, designating whelher transmissíon or distribution and whetherattended or unattended. At thê end of the pâge, summarize according to funclion the câpâcities reported lor the indívidual stations incolumn (f).

Year/Period of ReportEndot 2015/01

Date of Report(Mo, Da, Yi)ttSouthweslem Electric Power Company

(1)(2t

An OriginalA Flesubmission

FERC FORM NO.1 (8O.12-96) Page 426.5

402

3961STATCAP

tð313

3741STATCAP

3gqI$ÏATCAP

35266

34231

3ß113

32'l€

elJ14

304tSTAîCAF

2912A

282l4

271133

261133

25128

2415

2,240

22¡ISTATCAF

21250

20240

191143

185(2REACTOF

171149

162298

152N"14€1STATCAF

l3I1STATCAF

12125

11120

t01133

I210

E16

7228

€113

5,|7

4133

3156

221

't€1STATCAP

LineNo.Total Capacity

(ln MVa){k)

Number of Units

(i)

Type of Equlpment

fi)

Number ofSpare

Transformers

ft)

Numb€r otTransformers

ln Service(q)

Capaclty of Substatlon(ln Service) (n MVa)

{f}

CONVERSION APPARATUS AND SPFCIAL EQUIPMËNT

5, Show in columns (l), fi), and (k) special equipment suoh as rotary convsrters, reclif¡ers, condensêrs, etc. and auxiliary equipment lorincreasing capacity.6, Designate substations or major items of equipment leased lrom others, jointly owned with othêrs, or opêrâled otherw¡se lhan byreason of sole ownership by the respondent. For any substatlon or equipment operated undêr leasê, give name of lessor, date andpèriod ol lease, and annual rent. For any subslation or equipment operated other than by reason ol sole ownership or lease, give name

ol co-owner oroth€r party, explaîn basis of sharing expenses or other accounting between the partiês, and stalê amounts and accounts

affected in respondent's books ol account. Specify in each case whether lessor, co-owner, oF other party ís an associated company.

SUBS


Endol 2015/Q4Dalo ot R€port(Mo, Da, Yr)tt

(1)(2t

An OrlginalA Resubmlssion

Name of Respondent

Southwestem Elecl¡io Power Company

FEFC FOBII NO.1 {ED. 12-96} Paga 427.á

12.47138.0CDNEW GI.AÐEWATER - TX4012.0CDNEW GI-4ÐEWATER. TX39

12.0CÐNEW BOSTON.TX38r2.5069.0CDNËW BOSTON. T(3?

2.4069.0CDNETTLETQN . TXs624.9069.0CoNEGRËET" LA35

69.0CDNA$HVILLE 69KV . AR3436.2969.0CDNASHVILIË 69KV. AF3336.0069.00DNASHVILLË 69KV. AR3212.O069.00DNASHVILLË 69KV. AR31

12.47138.00DNASH.Ð(3012.4769.00oNAPLES -TX2912.0069.CtoDNAPLES.TX2813.0969.00DMURFBEESBORO WEST. AR2712.0C69.00DMURFREESBOROWEST. Añ2612.0069.00ÞMURFREESEORO UPTOWN - AR2512.0069.00DMUHFREESBORO UPTOWN - AR2412.O069.00DMOUNTVERNON (SW) "TX23

7.62DMOUNT PLËASANT - TX?2

't3.0969.00DMOUNT PLEASANT -TX21

13.0069.00DMOUNT PLEASÀNT.TX2012.4769.00DMOUNT PLEASÂNT. TX19

24-9069.00ÞMOTr-lj18

1â@26.00DMOrt-u17

12.0026.00DMOTT.tAt612.0026.00DMOTT.I-A't512.0069.frDMONROECORNERS -TX14

69,0(oMINEOLA-TX13

13.0969.0(DMINEOI.A.TX12

12.00DMINDEN BOAD - I-A11

12.0069,0{DMINDEN HOAD - LAf012.4769.00ÐMIDWAY {SW) - LAI12.0069.0CDMTDWAY (SW) - LAI2.ß69,0CDMID.VALLËY LONGVIEW - TX7

2.N69.0CDMID-VALLEY,TX6

't 2.0069.0CDMror-AND (SW) - AR569.0(TMENA. AR4

f 2.0cTMENA.ARa69.00138.0CTMEÑA.AR2

34.5069.0CTMENA.AR1

Tertíary(e)

Secondary(d)

Primary

tc)

Characler of $ubstatíon

(b)

Name and Location ot Substation

(a)

No;VOLTAGË (ln MVa)

1. Report below lhe information called for concerning substations of lhe respondent as of thå end of the yeâr.2. Substations which serve only one industrial or street railway oustomer should not be listed below.3. Substations with capacities of Less than 10 MVa except lhose serving customers with energy for resale, may be grouped accordingto lunctional character, but the number of such substations must be shown.4. lndicate in column (b) the lunctional character of each substation, designaling whelher transmission or distribution and whetherattended or unattended. At lhe end of the pags, summarize according lo funclion the capacities reported for tho individual stalions incolumn (f).

YearlPer¡od of RçportEnd of 2015/Q4

Dalê of Reoort(Mo, Da, Yi)tt

Name s:

Southwestem Electric Power Çompany(l )(2)

An OriginalA Besubmission

FERC FOFM NO.1 {E[r. 12-9ô) Page 428.6

4013it

3961STATCAF

3E61STATCAF

3724A

3613

35114

u2t2STATCAP

i,lr¿6

321e

31219

30250

29I6

2A'lÉ

?7Io

2611

2512

2436

23228

222

21114

20t13

ts114

18I14

1766

161'l

1511

14I7

13221STATCAP

1212A

t1€ISTAÏCAP

102,10

g266

8228

717

61I51I461STATCAP

3€,tSTATCAP

2183

1't14

UneNo.Capac¡ty

MVa)(kt

Total(ln

Numberof Units

{i)

Type of Equlpment

(i)

Number ofSpare

Transformers

{h}

Number olïransformers

ln Service(q)

Capacity of Substation(ln Service) (ln MVa)

(f)

CONVERSION APPARATUS ANÐ SPECIAL EOUIPMENT

5. Show in columns (l), fi), and (k) special oquipment such as rotary converters, rectifiers, condênsers, etc. and auxiliary equiprnent forincreasing capacity,6. Designale substations or major ilems of equipment leased from others, jointly owned with others, or oporaled otherwise than byreason of sole ownership by the respondent. For any substation or equipment operated under lease, givê nâme of lessor, dats andperiod of lease, and annual rent. For any substation or equipment operated other lhan by reason of sole ownershlp or leâse, give nameof co-owner or other party, explain basis ol sharing expens€s or other accounting between the parties, and stale amounts and accountsaflected in respondent's books of accounl. Speciþ in each case whether lessor, co-owner, or olher party ís an associated company.

Year/Period ot Reporl

Endol 2015/Q4Date ot ReDort(Mo, Da, Yi)tt

An Orlg¡nalA Besubmission

(1)

{2)Southweslen Electric Power Company

Page 427.6FEFC FORM NO. I (ED.12-96)

12.47138.0CDPIERRÊMONT. L{40

r2.0069.0(TPËTTY - TX39

69.001S8.0(TPETW.T(38

138.0CTPEBDUE.TX37

't3.0€70.50108.0cTPERDUE.TX36

r38.0eTPATTERSON.AR3513.0€70.50r38.0(TPATTSRSON.AR34

7.2C69.00138.0CTPATTERSON. AR33

12.5C69.00138.OCTOVERTON. TX32

't38.0cTOVEffTON. TX31

13.09161.0CDOSBURN.AR30

34.006S.0CTOKAY.AR29

{, ôôAO tYTOKAY. AB28

19.0!70.50138.0CTOKAY.AR27

t2-0069.0CDotlclry-LA26

12.0{TNCIRTHWEST TÐ(ARKANA - TX25

138.00345.0CTNORTHWËST TEXARKANA. TX2413.2069.00138.OCTNORTHWEST HENDERSON . TX23

12.0CDNORTH ROGERS - ARÐ"12.5069.0tDNORTH ROGERS - AR21

13.2072.60138.0(TNOÊTH NEW BOSTON - TX2A

69.0013{t.0cTNORTH NEl¡' BOSTON.TX't912.0069.0CTNORTH MINEOI.A -ÏX18

6S.00138.0CTNORTH MINEOLA.TX17

63.00TNORTH MINEOIA -TX16

12.00DNOBTH MARSHALL. TX15

12.47ô9.00DNORTH i'ARSHALL. TX14

12.0069.00DNOBTH MARSHALL. TX13

12,5069,00DNORTH MARKTT. LA"12

24.9069.00DNORTH LEESVILLE. L.A11

34.5069.00DNORTH LANEVILLE. TXTO

12.00ô9.00161.00TNORTH HUNTINGTON - ARs69.00161.00TNORTH HUNTINGTON. AHI

69.0(TNORTH HUNTINGTON. AR7

12.00138,0(TNORTH BENTON.I.A6

13.2C69.00138.0(TNORTH BËNTON - I.A5

12.47138.0(TNORTH BÉNTON. LA426.4469,0(ÞNOBLE (SEP) - LA324.9Q69,0cDNOBLE (SEP) - r-A2

'12.4769.0CDNEW HOPE (SW) " TX'|

Tërtiary(e)

Secondåry(d)

Primary(c)

Character ol Substalion

{b)

Name and Location of Substation

(a)

Líne

No.VOLTAGE (ln MVa)

1, Report below lhe information called for conceming substat¡ons ol the respondent as of the end of lhe year.2. $ubetalions which serve only one industrial or slreet railway customer should not be lísted below.3. Substations with capac¡ties of Less than 't 0 MVa except those serving customers with energy for resale, may be grouped accordingto functional character, but the nurnber of such substations must be shown.4. lndicate in column (b) lhe functional character of each substalion, designating whether transmission or dist¡ibution and whetherattended or unattended. At the end ol thg page, summarize according to lunclion the capacities reported for the individual stations incolumn (f).


Ënd ol 2015/Q4Date ol Reoort(Mo, Da, Yi)lt

e

Southwestem Electrlc Power Company )Resubmission

FEBC FORil NO.1 (ED. 12-96) Page 42õ.7

r¡o1s

39z19

{rð2267

37381STATCAF

3ô'l't30

3ã5€1STATCAF

341130

&3183

322a31311STATCAP

301,10

2916

2812

27I90

26I7

252â1BEACTOF

2421200

232f66

?261STATCAP

21266

20183

19'l42

181I17113Íì

t6221STATCAF

1561STATCAF

14114

13'l14

12240

11125

10tq

II83

6'l83

7zt1STATCAP

6114

5I42

4114

3t25

2228

'|2f9

LineNo.Total

(lnCapacityMVa)(k)

Number of Units

fi)

Type ol Equipment

(i)

Number ofSpare

Transformers

lht


ln Service(o)

Capacity o{ Substation(ln $ervice) (ln MVa)

(fr

CONVERSION APPARATUS AND SFECIAL ËOU'PMFNT

5. Show in columns (l), (j}, and (k) special equipment such as rotary converlers, rêctifiers, condensers, etc. and auxiliary equipment forincreasing capacity.6. Designate substations or rnajor ilems ol equipment leased from others, jointly owned with others, or operated othenaise than byreason ol sole ownership by the respondenl. For any substalion or equipment operated und6r leasef give name ol lessor, dats andpedod of lease, and annual rsnt. For any substation or equipment operaled olher than by reason of sole ownership or lease, give nameol co-ownsr or oth€r parly, explain basis of sharing expenses or other accounting between the parlies, and state amounts and accounlsalfected in respondent's books of account. Specily in each case whether lessor, co-owner, or other party is an associated company,


End of 2A15lQ4Soulhwestem Ëlectric Power Company(1) An

Date(Mo,ttA rssþn

FERC FORM NO.'r (EÞ. 12-96) Page 427.7

12.U.DROGEHS.AR40

12,0069.0(DROOESSA. L{39

13.0s70.50138.0(TROCK HILI- TX38

2.3069.0(ïROCK HILL. ï(s7ts.0s69.0(DROBEUNE. I.A36

12,50DRIçHMOND ROAD "TX35

12,4169.0{DRICHMONO ROAD.TX&13.09161.0CDREEVES ROAD - AR33

34.50161.0(DREEVES ROAD. AH32

13.09't61.0cDREEVES ROAD. AR31

12.4769.0(DREÐ FIVER AFSENAL. TX30

T2.0069.0CDREÐ BIVER ARSENAL. TX2s

'!38'0(TREÐ POINT - LA2813.2ø72.60138.0CrREÐ POINÍ - I¡27

13.8066.001S8.0{TFED POINT - LA26

't3.0s138.0C1HED POINÍ. LA25

13.2034.5CDRED OAK (SËP) . r-A24

12.ü,ÞRAINES - I.A23

13.201J5,0CDPROVENCAL- LA22

13.0969.0CDPRAIRIE GROVE. AR2'l12.UÞPOYNTËR- TX20

12.0069.0CDPOYNTER. TX19

13.2034.5CDPOWHATAN (SEP) -LÂ18

12.üDPOWELL STFEET ' I-A17

12.47138.0€DPOWËLLSTREET. L.A16

12.47138.mDPORT ROBSON. I.A15

34.50138.00DPLILER FOAÐ. TX14

13.0SDPLÊASANT HILL. AR't313.0969.00ÐPI-AIN DEALING. L{12

12.0069.00ÐPLÂIN DEALING - LÂ't1

12.OO69.00DPITTSBURG STEEL. TX10

12.5069.00TPTTTSBURG (SW) -TX9

72.60138.00TPTTTSEURG (SW) - TXI34.50138.00345.0(TPIRKEY. TX7

13.80138.00345.0(TPIBKEY. TXo

12.5069.0(DPINËS ROAO .I.A5

12.4769.0(ÞPINES HOAD.Iá4

12.5069.fiDPILGRIMS PRIDE . TX3

12.0CÐP¡ERREMONT.I.A2

34.50138.0CDPIERREMONT - I.AI

Têrtiary(e)

Secondary(d)

Primary(c)

Character of Substat¡on

þ)

Name and Location ol Substation

(a)

LineNo.

VOLTAGE (ln MVa)

l. Report below the information called for conceming substâtions of lhe respondent as oi thê ênd of ths yêar.2. Substations which serve only one industrial or street railway customer should not be lisled below.3. Substations with capacities of Less than 10 MVa except lhose serving customers with energy lor resale, may be grouped accordingto functional characler, bul the number ol such substations must be shown.4. lndicate in column (b) the lunctional character of each substation, designating whethor transmission or dist¡ibution and whetheratlended or unattended; Ât the end of the pâge, summadze according to lunction lhe capacilies repoûed for the individual stations incolumn (f).

Year/Feriod of ReporlEnd of .. 2015/Q4

Date of Reoort(Mo, Da, Yi)ttSouthwestem Electric Power Company

(1) OriginalBesubmission

FERC FORM NO.1 (ED.12.96) Page 426.8

rx]e1STATCAF

3911

382180

37'|

38II95Iæ34133

33II'ðz12A

g11s

301J3

29113

2A431STATCAF

z7142

26160

2612â

24I7

23€1STATCÁF

22256

21't26

?o€1STATCAF

19e3S

1E26

1741STATCAP

16266

15126

142100

1316

't21I

1t111

10'l6

I2¿lo

Et133

71675

6't600

512A

412Q

324A

21$TATCAP

1I50

LineNo.Tolal

{fnCapacityMVa)lk)

Number of Units

t¡t

Type ol Eguipment

ti)

NumþerofSpare

Transformers

fh)

Number otlransformers

In Service

{q)

Capacity of Substation(ln SeMce) (ln MVa)

(n

CONVEHSION APPARATUS AND SPECIAL ËQUIPMËNT

5. Show in columns (l), fi), and (k) special equipment such as rotary converters, rectiliers, condensers, etc. and auxiliary equíprnent forincreasing capacity"6. Designate subslations or major items of equlprnent leased from olhers, jolntly owned with others, or operated otherwise than byreason ol sole ownership by the respondent. For any substation or equipmenl operated under lease¡ give name ol lessor, date andpedod ol lease, and annual renl. For any substation or equiprnent operated other lhan by reason of sole ownership or lease, glve nameof co-owner or other party, explain basis of sharing expênses or other accounting beWeen the parties, and state amounts and accountsaffected in respondent's books ol account. Specify in each case whelher lessor, co-owner, or other party is an associated company,

Year/Period ol ReportEnd oi 2015/Q4

Dale ot Reoort(Mo, Da, Yi)llSoulhwestem Ëleclric Power Company

(1) An QriginalA Resubmission

FEFC FOBM NO. I {ËD. 12-gô) ?age 427.8

13.8C138.00345.0(TSOUTHWEST SHREVEPORT. I.A40

34.5tTSOUTHWË$T SHREVEPORT . I.A3934.5C138.0€345.0(TSOUTHWÊST SHREVEPOBT. I.A38

13.2C72.80138.0CTSOUTHA{STTÐ(ÂRKANA. ARa7

12.47138.0CDSOUfiËAST MARSHALL. TX36

12.50ô9.0cDSOUT}IEAST LONGVIEW - TX35

12.4769.0CDSOUTHEA9T LONGVIEW - Ð(u12,47161.0CÐSOUTHEAST FAYETTEVILLE - AB33

12.50161.0cDSOUTHEAST FAYETTEVILLE . AR32

12.50161.0CDSOUTH SPRINGDALE. AR3'f

12.47161.0{ÞSOUTH SPRINGDALE. ÀR30

12,47t3B.0cTSOUTH SHREVEPORÏ.I.A29

69.00138.0CTSOUÏH SHREVEPORT. I.A28

12.0CTSOUTH $HREVEPORT. LA27

12.47138.0CDSOUÎH NASHVILLE . AF26

69.0CDSOUTH NASHVILLE. AR25

12.4769.00161.0CTSOUTH FAYETTEVILLE. AR24

69.mTSOUTH FAYETTEVILLE - AR23

161.mTSOUTH FAYETTEVILLE. AR22

12.mTSOUTH FAYETTEVILLE. AR21

12.47161.mTSOUTH FAYETTEVILLE - AR2Q

69.0016'1.00TSOUTH FAYETTEVILLE. AR19

72.60138.0CTSOUTH DIERKS.AR18

2.N69.00DSOFIIO. TX17

69.0CTSILOAM SPFIINGS 16IKV. AR16

7.6269.00161.00TSILOAM SPRINGS 161KV - AR15

f 3.8C1ô1.00345.0CTSHIFE ROAÐ. AÊ14

12.0CDSHËD HOAD. L.Al313.09ô9.0cDSHËD HOAD. LAtr2

12.0069.0CDSHED ROAD. LA't1

TSHAMBOCK (SEP) -TXl0't3.0969.0CTsr-rAMBocK (sEP) "rx0

6.1069.00138.0CTSHAMBOCK (SEP) - TXIÁ.4A69.00115,00TSHAMROCK (SEP) . TX7

2.4469.00DSERVICE PIPELINË - TX6

12.47138.00DscoTTsvrLLE (sw) . TX5

12.00DSASINË - TX4

12.47ô9,00DSABINE. TX3

12.0069,00DROSEOROUGH " TX2

12.47161.00DROGEFS.AH1

Tertiary(e)

Secondary(d)

Pdmary(c)

Character of Substal¡on

(b)

Name and Localion of Substalion

{a)

[¡neNo.

VOLTAGE (ln MVa)

1. Report below the information called for concemíng substations of lhe respondent as ol ths end of tha year.2. Substations which serve only one induslrial or strêet railway customer should not be lÍÊled below.3. Substalions w¡th capacíties of Less than 10 MVa except those serving customêrs with energy for resale, may be grouped accordingto functional character, but the number ol such substatíons must be shown.4. lndicate in column (b) iho functional character of each subslation, designaling whelher transmission or disldbution and whetherattended or unatlended. At the end of the page, summarize according to function ths capacities reporled lor the individual stations incolumn (f).

SUBSTATIONS

Yeaf/Period ot f¡eport

Ënd ot 2015/Q4Date of Reoort(Mo, Da, Yi)tt

(1)(2\


Name of Respondent

Soulhwesl€m Electric Power Company

FEFC FORIU NO.1 (EÐ. 12-96) Page 426.9

401600

3S233Air Core Reactol

3821350

371139

s6266

35142

:34J42

3i,140

32I33

3l133

30133

2C¿45

2E¿166

27t1STATCAF

26¿40

251STATCAP

241't33

234f1STATCAP

225¡1STATCAF

21tTSTATCAP

2A275

191134

1A183

t7I2

1ö4¿1STATCAF

151133

14,l675

13€1STATCAF

12114

11114

101C1STATCAP

9311

I163

7163

613

5240

441STATCAF

3120

212

1280

LinêNo.Total Capacity

(ln MVa){k}

Number of Units

{iì

Type of Ëquipment

til

Numþer ofSpare

Transtormers(hl

Number ofTransfonners

ln Service

lo)

Capacity ol Substation(ln Service) (ln MVal

{n

CONVERSION APPARATUS AND SPËCIAL ËQUIPMENT

5. Show in columns (l), fi), and (k) special equipment such as rotary convert€rs, rectifiers, condênsers, etc. and auxiliary equipmenl lorincreasing capacig.6. Designate substations or major items of equipment leased from others, joíntly owned wilh others, or operated otheruise than byreason of sole ownership by the respondenl. For any substation or equipment operaled under lease, give name of lessor, date andperiod of lease, and annual rent, For any subsiation or equipmenl operated other lhan by reason of sole ownership or leasa, give nameof co-owner or othêr party, explain basís of sharing expènses or olher accounling between the parlies, and state amounts and accountsâffected in respondent's books of account. Specify in each case whether lessor, co-owner, or other party ís an associated company.

YearlPerÍocl ol Reporl

End ot 20151Q4Date ol Reoort(Mo, Da, Yi)II

(1)(2)

An OriginalÂ Besubmlssion

Name of Respondent


FERC FORM NO. f (ED. 12-96) Page 427.9

13.00ô9.00138.0CTWALI.ACE I.AKE.I¡40

12.00DWALÞRON. AR39

12.0063.0€DWALDFON. AR3t!

12.00DVIVIAN.I-A37

12.47161"0€DVAN ASCHE.AR3ô

4.1669.mBU.S. MOTORS. AR35

12.5069.00DTWELFTH STREET (SW) - AR34

12,0069,mDruRNERTOWN.TX33

34.5(138.003,1€t.00TruRK.AR32

.l3.2(1't6.00TTURK " ÀR31

115.00138.0CTTURK. ÀR30

12.00DTRICHËLSTREET - I.A29

19.09138.00DTFICHELSTFEET- lj28

12.47138.00DTFICHEL STREET. IÁ27

13.8C161.00345.00TTONTITOWN. AF26

't3.8C161.00345.00TTONTITOWN.AH25

12.00DTHIRTY.NINTH STBEET. TX24

12.5069.00DTHIRry-NINTH STREET.TX23

t2.4769.00DTHIRTY.NINTH STREET . TX22

2.30DTEXAS E.ASTEFN.TX2l12.5009.0cDTEXARISNA PLANT. ÂR2A

12.0CDTEXARKANÀ OPÉRATIONS CENTER . TXT9

12.5069.0CDTEXARKANA OPERATIONS CENTER . TXT8

12.47Df EXARI(ANA OPERATIONS CENTER . TX17

12.47138.0CÐTENAHA.TX16

138.0CDTENAHA.TXt512.mDïAYLOÊ STREET. fi14

12.4769.0CDTAYLOÊ STREET.Ð(13

't2.47136.mDTATUM -ÏX12

12.0069.00DsuPERroB (sw) - LA11

12.00DSUMMEñ GHOVE.I.Al07,2A12.0069.00DSUMMERGROVE. LAI

12.0069.00DSUMMERGROVÊ.I.AI12.47138.00TSUGAR H|LL (SW) . AR7

?.2072.60138.00TSUGAR HrLL (SW) - AR6

34.00r38.00DSTONÊI¡/ALL.I.A5

12.47138"0CoSPRINGHILL. TX4

12.0CDSPRINGDALE " AR3

12.4769.0CDSPRINGÛALE. AR2

12.0069.0CDSPRINGDALE. AR1

Tedlary(e)

Secondary{d)

Primary(c)

Cha¡acter ol Substâtion

þ)

Nâmê and Location ol Substation

(a)

LineNo.

VOLTAGE (ln MV:)

1. Report below the informalion called forconcerning substations of lhê respondent as of thê end of the year.2. Substalions which serve only one ¡ndustrial or street railway customer should not be listed below.3. Substalions with capaoities of Less than 10 MVa excepl lhose serving customers with energy lor resale, may be grouped accordingto functional character, but the number ol such substations must be shown.d lndicate in column {b) the functional character of each substalíon, designating whelher transmission or distribution and whetherattended or unattended. At lhe end ol the pâgê, summarize according to lunclion the capacities rêporled for the ¡ndividual stations incolumn (f).

iUtsI'TATIONIi

Year/Period of ReportEnd of 2011Q4

Date ol Reoort(Mo, Da, Yi)II

{1 Ân OriginalA Flesubmission(2)

Name of Respondent


FEHC FOFM NO.1 {ED. rz-s€} Page 42ô.10

.lo183

39€1STATCAF

3E2'tg

37219

36280

3517

34240

3tt214

32I675

31t1ô7

301166

2941STATCÀP

28140

27t42

26167ã

251675

7+(1STATCAF

23I20

22103

2l2I2026ô

'¡9€1STATCAF

f812Q

17I28

T6III531

,|STATCAP

141STATCAF

132

121s

11¿2',1

10Ê1STATCAP

I17

I17

7I20

61133

512û

4122

31STATCAP

2142

1133

LinêNo.Total

(lnCapacityMVa)(k)

Numberof Unils

(i)

Type ol Equipment

fil

NumÞer olSpare

Transfomers

{h)

Numbêr ofTransformers

ln Servic€

{q}

Capacity of Subtation(ln Sewice) (ln MVa)

(n

CONVERSION APPARATUS ANÞ SPËCIAL ËQUIPMENT

5. Show in columns (l), (j), and (k) special equipment such as rÕtary converters, rectifiers, condensers, etc. and auxiliary equipment lorincreasing capacity.6. Deslgnate substalions or major items ol equipment leased from others, joinlly owned with others, or operated otherwise than byreason of sole ownership by the respondent. For any subslation or equipment operated under lease, give name ol lessor, date andperiod of leaso, and annual rent. For any substation or equipment operaled othêr lhan by reason of sole ownership or lease, give nameol co-owner or othêr party, expla¡n baeis of sharing expenses or olher accounting between the parties, and state amounts and accounlsaflected in respondent's books of account. Specily in each case whether lessor, co-owner, or other party is an associated company.


Endof 2015/Q4Date ot ReDort(lvto, Da, Yi)ttSouthweslem Êlectric Power Company

(1)

(z','An OriginalA Resubm¡ss¡on-

FEHC FORM NO. I tED. 12-96) Page 427.10

40

39

38

37

't2.0069.0CDwooor-AwN (sw). TX36

12.0CÞWINNSEORO-TX35

12.4770.50138.0CDWINNSBORO.TXu12.5069.0{DWINNSBORO.TX33

12.0069.0CDWINNSBORO.TX32

12.0069.0CDW]NFIELD- TX31

13.8C138.00345.0CTWIIKES. TX30

13.8C138.00345.0CTW'LKES. TX29

J2.0{TW'IKES. TX28

69.0CTWHITNtr-TX27

12.0CTWHITNEY. TX26

12.4769.0CTWHITNEY- TX25

12.0t72.æ138.0CTWHITNEY- TX24

12.0{69.00138.0CTWHITNEY. TX23

12.0€DWHITEHURST.I.A22

34.50138.00DWHITEHURST. LA2'l

12-47138.00oWHITEHURST. LA20

13.0969.00DWESTWOOD-TX19

34.50f 38.00DWESTERN ELECTRIC, LA18

12.47r38.00DWESTERN ELECTFIC. t.A17

34.50138.00DWESTÊRN ELECTRIC. LA16

34.5(DWÊSTERN ELECTRIC.I.A15

12.0CDWESTERN ELECTRIC.I.A14

12.0CDWESTMOUNT PLËASANT.TX13

12.0069.0CDWESTMOUNT PLEASANT - T)(12

0s.00161.0(TWÉST BOONEVILLE. AR11

12.5069.00TWESTATT.ANTA - TX10

69.806S.80345.0CTWËLSH HVDC CONVËRTEB. TXo69.0069.80345,0CTWËLSH HVDC CONVERTER - TXI

69.00345.mTWËLSH IIVDC CONVERTER . -rX7

7.56138.00DWËLLINGTON - TX6

12.00DWATERWOHKS (SW) - LA5

r2.5069.00ÞWATERWORKS (SW). LA4

12.0069"00ÞWATERWORK$ (SW) - LA3

19.096S"00ÐWASKOM-TX2

34.50138.00TWALI.ACE LAKË.I-AI

Tert¡âry(e)

$econdary(d)

Primary(c)

Character of Substation

(b)

Name and Location of Substalion

(a)

Line

No.

VOLTAGÊ (ln MVa)

1. Beport befow the information called for concerning substatlons of lha raspondent as of the end of tha year.2. Substations which serve only one industríal or stréet railway customer should not be listed below.3, Substatíons with capacities of Less than 10 MVa except those serving customers with energy for resals, may be grouped accordingto functional character, but the number of such substations must be shown.4. lnd¡catê in column (b) lhe functional character of each substatíon, designating whether transmission or distribution and whelherattended or unattended. At the end of the page, summarize according to function the capacities report€d tor the individual slalions incolumn (f).

Year/Period of BeportÊnd of 20'15/Q4

Date of Reoort(Mo, Da, Yi)tÍ

(1)(2'

An OriginalA Resuþmission

Name ot Respondent

Southweslem €leolric Power Company

FEBC FORM NO.1 (EO. f2€6) Page 426.11

4s9

38

37

361o

35e1STATCAF

341130

3f,120

32I20

312I30ã447

2S1149

2A50¿REACTOF

27431STATCAT

2g61STATCAF

25360

24I133

231133

2,€ISTATCAf

212122

?g12A

191IIE144

1724t6'l50

t51€¿STATCÁP

14I1STATCAF

TS€tSTATCAf

1Z'|I11167

't0283

I41020

ö12æ

71296

6314

561STATCAF

4240

s114

2234

1130

LineNo.Tolal Capacity

(ln MVa)(kì

Number of Units

{it

Type of Equipment

(il

Number olSpare

Transformers

{h}

Number otTranslormers

ln Service

{q)

Capacity ol Substation(ln Servioe) tln MVa)

(f)

CONVERSION APPARATUS AND SPËCIAL ËQU]PMENT

5. Show in columns (l), fi), and (k) special eguipment such as rotary converters, rect¡fiers, condensers, etc. and auxíliary equipment forincreasing câpacity.6. Designate substations or major items of equipment leased from others, iointly owned with others, or operated otherwise than byreason of sole ownership by lhe respondent. For any substation or equipmenl operated under lease, give name of lessor, date andpêriod of lease, and annual rent. For any substation or equipmen! operated other than by reason of sole ownership or lease, give nameof co-owner or other parly, explain basis of sharing exponses ôr olhor accounting between the parlies, and stats amounts and accounlsaflected in respondenl's books of account. Specily in each case whether lessor, co-owner, or olher party ¡s an associatêd company.

Year/Period of Heport

End ot 2011Q4Date ot Reporl(Mo, Da, Yr)ttSouthwest€m Electric Power Company ) An Original

(2) Besubmiss¡on

FERC FORM NO. I {ED.12€6) Page 427.1f

42

4',|

4Q

39

38

37

36

35

523,959Various (16)PSORail Car Maintenanceg270JA1184r&MFlail Car Maintenanceó!t

642,259l5'lPSOFlail Car Lease32

111 t9,Z1Zlclt&MFlail ô¡r I o:cae1

350,244f5tAPCoRail Car Lease30

393,153456APCoOther Operating Revenues29

782,509154PSOMateríals and Supplies28

390,2041gAEPTCMateríals and Supplies27

653,079Various {15)AEFTCHVDC East Transmission Tie2ô

736,1 13VariousAPCoFleet and Vehicle Charges25

335,755VariousAÉPSCFleet and Vehicle Charges24

703,100Various {14)PSOCentral Maintenance Facility23

'| ,561,8704UAEPSCBuilding and Property Leases22

446,483107,108PSOAssets and Other Debits - Utif¡ty Plant2l

Non-power Goods or Servfces Provlded for Afllllate2A

835,928VariousAPCoFleet and Vehicle Charges19

2,857,052426.5AEP Credit, lnc.Factored Customer A/R Expenses18

4,152,978426.5AEP Credit, lnc.Factored Customer AIR Bad Debts17

544,043920AEPSCEnvironmental Services16

2,443,879Various (4)AEPSCDistr¡bution Expenses - Operation15

506,561920AEPSCCustomer and Distribulion Services14

11,222,799901-904AEPSCCustomer Accounts Expenses - Operalion13

575,308920AEPSCCorporate Safety and Health12

2,022,925920AEPSCCorporale Plann¡ng & Budget¡ng11

626,770920AEPSCCorporale Communications't04,001,246920AEPSCCorporate Accounting9

49,828,947107,.t 08AEFSCConskuclion Serv¡cesI628,935Various (3)AEPSCCivil & Political Activilies & Other Services7

848,'.t47Various (2)APCoCentral Machine Shop6

1,547,160920AEPSCAudit Services5

604,690107,108PSOAssets and Other Debits " Utility Plant4

9,327,887AEPSCAdminisl¡ative and General Expenses - Operation3

2,177,977935Adminislrative and General Expenses - Maintenance2

Non-power Goods or Servlces Provlded by Aílllatedf

AmounlCharged or

Credited

AccountCharged or

Credited(c)

Name ofAssocialedlÂtf iliated

Company(b)

Descriplion of the Non-Power Good or Service(a)

LineNo,

I2.

3.

Year/Period ol ReportEnd ot 2O16lQ4


This Reoort ls:(1) fiAn Original(21 f1A Resubmíssion

Name of Respond€nt


FERC FORM NO.1 {Nêw)FERC FORM No.l-F (New)

Page 429

42

41

40

39

38

37

36

35

34

33

32

31

30

29

28

27

28

25

24

23

22

21

Non-power Goodg or Servlc€s Provlded for Afllllale20

2,025,769510-514AËPSCSteam Power Generation - Ma¡ntenance19

529,320g¿0ÀËpscSecur¡tì/ and Aviat¡on18

575,776920AEPSCRÍsk and Strategic lnitialives17

2,341,255Various {10)AEPSCResearch and Other Services't6

2,042,546920AEPSCRegulatory $ervicesf5

902,975920,923AEPSCÊêâl Ëstats and Workplace Services14

2,824,5't3151AEGCôFla¡l Car Maintenance13

602.832186PSORail Car Lease12

1,763,271186t&MRa¡l Car Lease11

6,149,455555-557AEPSCOther Power Supply Expenses10

1,882,139Various (9)PSOMaterial and SuppliesI323,073Various (8)OPCoMaterial and SuppliesB

æ7,674Varíous (7)AËPTNMaterial and Supplies7

909,98sVarious (6)AEPTCMaterial and Supplieso

3,719,454920AEPSCLegal General Counsel / Adm¡nistrat¡on5

3,673,581920,923AEPSClnformation Technology4

2,033,895920,923AEPSCHuman Flesources3

7,324,554Various (5)AEPSCFuel &, Storeroom Serv¡ces2

Non-power Goode or Servlces ProvldEd by Afllllated1

AmountCharged or

Credited(d)

AccountCharged or

Credited(c)

Name ofAssociated/Atf il¡ated

Company(b)

Description of the Non-Power Good or Serv¡ce(a)

LineNo.

2.

3.

WITH

YearlPeriod of FleporlEnd ol 2015/Q4


Southwestern Efectric Power Company {1)

{z',)


FERC FORM NO.1 {New)FER0 FOFM NO. 1-F (New)

Page 429.1

42

41

40

39

38

37

36

35

34

3Í¡

32

ùr

s0

29

28

27

26

25

24

23

22

21

Non-power Goods or Servlces Provlded for Ælllfate20

19

f8

17

16

'ls14

13

12

11

l0

II

357,802107AEPTCWelsh Power Planl HVDC Te7

486,063920AEPSCTreasury and lnvestor Relations6

306,123560,566PSOTransmission Êxpenses . Ope¡al¡on5

8,429,789Various (13)AËPSCTransmission Expenses - Operation4

1,578,&9Various (12)AEPSCTransmission Expenses . Maintenance3

13,421,742Various (l'l)ÂEPSCSteam Power Generation - Operation2

Non-power Goode or Servlcês Prôvlded by Aíll¡at€dI

Amour¡tCharged or

Creditedor

Name olAssociated/Atf iliated

Company(b)

Descriptíon ol the Nôn-Power Good or Service(a)

UneNo.

1.2.

3,

ATED) COMPANTES

Year/Period of ReportËnd of 2O1E|Q4


This Reoort ls:(t) fiRn Originat(21 ¡A Resubmission

Name of Respondent

Soulhwestern Eleckic Power Company

FERC FORM NO.1FERC FORM NO.1

(New)-F (New)

Page 429"2

FOOTNOTÉ DATA


2015/Q4


ttThís Report is:(1) X An OriginalQ\ A Fìesubmission

Name of Respondent


b

Affiliated Companies shown in Column I B ):AEGCo - AEP Generating CompanyAEP Credit, lnc. - AEP Credit, lnc.AEPSC - American Electric Power Service CorporationAEPTC - AEP Texas Central CompanyAEPTN - AEP Texas North CompanyAPCo " Appalachian Power Companyl&M - lndÍana Michigan Power CompanyPSO - Public Service Company of Oklahoma

AEPSC Allocations@ndprofessionalservicesprovidedbyAEPSCareallocatedamongmultiple affiliates. The costs of the services are billed on a direct-charge basis, wheneverpossible. Costs incurred to perform services that benefit more than one company areallocated to the benefiting companies using one of 80 FERC accepted allocation factors.The allocation factors used to bill for services performed by AEPSC are based uponformulae that consider factors such as numbei of cuetome'rs, number of employèes,number of transmission pole miles, number of invoices and other faclors. The data uponwhich these formulae are based is updated monthly, quarterly, semi-annually or annually,depending on the particular factor and its volatility. The billings for services are madeat cost and include no compensation for a return on investment.

FLEET Allocations {VariousìCosts related to AEP's fleet vehicles are allocated in the same manner as the labor of eachdepartment utilizing the vehicles. To the extent a department provides service to anotheralfiliate company, an applicable share of their lleet costs are also assigned to thatalfiliate company.

NO. r 450.1FEHC

DATA


2A15/Q4

Date of Report(Mo, Da, Y$

lt


Name of Respondent


3 c

Various Account Listingsas Provided Column c FERC Accounls:

920,921 926,929,930.1,930.2,931107,108,512,513426 "1,426,3,426.4,426 "ã580,581,592,593,594,596,599151,'152,163147,154,570,571,5921 t7,1 54,570,593,595,597,593,594107,154,560,571,9351 07, 1 54, 1 63,1 94,51 ?,51 3,51 4,570,935"t 82.3, 1 93,1 94,'l 96, 1 gg500,501,502,505,506,509568,569,569. 1,569.2,569.3, 570,57 1,57 2,57 3560,561 .'1,561 .2,561 .3,56I .5,561 .6,562,563,564,566107,f 09,512,5131 86,56 1 . 3,562,570, 922,924,925151,163,194,419

Various (1)Various (2)Various (3)Various (4)VariousVariousVariousVariousVariousVariousVarÍousVariousVariousVarious

(5)(6)

{7){8){e){r0}(1 1)(12)(13)

{14)Various {15)Various (16)

RC FORM NO.1 I d50.2

Schedule Pêge No,

Àccrued and prepaid taxes .

Àccumulaied Ðeferred Inco¡ne Taxeg .

262-263,... 234272-277

Accumulated provisions for depreciaeion ofcotlfBon utilily plaot . . . .... 356utility Þl-anu . ., 219

..... 2po-201uEiliÈy plant (sun¡nary) ....Àalvances

from assgciated companiês ....... ....256-251..., 228-229l\llowances

Àmortizaiionmiscellaneous ,..,of nuclear fuel .

.... 3d0202-201118-119Àpproprietions of, Retained Earnings

Àssociated Companies.

advances fro¡n .,..... .... 256-25:1corporations con¿rol.1ed by respondent .. ,.control ovêr respondenÈ .

interest on debt Eo ...ÀttestaE.ion,.;,,¡,Balance sheet

compar4ti.ve

103

102. 2s6-257....... t

notes toSonds .

Capital Stock .

expense

110*113L22-123236-257

"... 25L.... 254

premiums 25225Lreacquired

subscr.ibed: ::: ::: ::: ... ;;;-::xCaqh flows, statenenc of

Changesimportane during yeär .... "

constructionwork in progress - conmon utility pl.anè '......356

.. ".., - 216

.. . 200-201

work in progrêss - elect,ric ....work in prôgresa - other utility departmeûts

Controlcorporations control"led by respondent. . , r...;, ... 103

... 102over respondenÈ ...Cor¡roration

controlled by ,....lncorj)orated .. ......".101

CPÀ, background informâÈion on ... 101CPA Certification, this re!¡ort for¡n ,

INDEX

FËRC FQEM NO. r (ËO.12-9S) lndex 'l

ScheduleDef erred

credits, other.debibs, miscellaneous ...lncome lâxês accumulaÈed - acceleratedamortization property

Paqe No.

inco¡ne Èaxes accuJnul.aeed - other property ........ 272-273.... 274-275.... 276-277........ 234........ iii

incone Laxes accunulaleil - oèher .

inco¡ne taxes accumulated - pollution controL facilitíeSDefinitions, this report form ,

Deprecialíon and a¡norEizalionof com¡non uti15.ty plant ..,of electric planE .

.,. 356,.. 27933 6-3 37

... 105

256-257354-3s5118-119118-119... 401

DirêclorsÐiscount - premium on long-terrn debU

DisEribution of salaries and wages ..Dividend appropriations ..Earnings, RetainedElectric energry account.Expensês

el.ectric operation and mainCenanceelect,ric operaÈion and mainEenance,unâ¡nôrtized debt .

Extraordinary propêrty losses

su¡nmary .,. 320-323..... 323.... " 256..... 230

FiLing requírernenEs¡ this r€porE forrnGeneral informalionfnsEructions for filing the FERC Fortn 1

..... 101

"... i*ivGenerating plant, staEiÊtics

hydroeLectric {large}pumped storage {1arge}sma11 plants .,.,sEeam-elecEric (1arge)

406-4a7408-409410-411402-403406-407

"... 101

1 08-109

Hydro-electric generauing plant statistícs ....IdenEificacion ....Important changes durlng year .

Incomescatêmenc of, by departrnentsstatemenE of, for the year (see also revenues)deductions, miscellaneous a¡nortization ...,..,deductions, other income deductiondeductions, other interesl charges

fncorporation informa¡ion . .

114-11?114*11?

.... 340

.... 340

....340

....101

INDEX {continued)

FeRC FORM NO.1 (EO. 12-95) lnder 2

Schedule Paqe No.

Interestchargeç, paid on long-term debÈ, advances, etc

Invèslmencsnonut.ilily properÈysubsidiary conpanies

InveÊÈrneIrt tax credíls, accumulat.ed deferred ,...,Law, excerpts applicable bo Èhis repofè form . . . , "f,isL of schedules, this rêporE fqnn .

256-257

221

. 224-225

. 266-267,..,.. iv..,,, 2-4. 256*257Long-eêñn debb

Lo6ses-Exç.raordinary proper tyMaEerials and suppl.ies r r.. !. i

230227

335Mi6cellaneous general expênses ....Notes

to balance sheet t22-t23122-r23122-t23t22-123

....22L202-203442-403

.... 104

tg statement of changes in financial position ..to Ètatenent of i.nco¡ne

to statenent of retained earningsNonutllity propereyNuclear fuel materialsNuclear genêrating p1ant, stablsticsOffÍcers and officers, salari,esOperating

e:çenses -electrice:r¡lenSes-elecuric { su¡nmary)

Otherpaid-in capitaldonaEions received from stockholders ,

gains on resale or cancell"ation of reacquired

' ?s3

" 253

caplÈal stock -,.,, 253253253232

278401

mj.scellaneous paid-in capiÈalreductl.on in par or staEed vaLue of Capítal stockregmlatóry assetsregnr).atory 1iabilities

Pêaks, nontshly, and outpuÈP1ant, Co¡nmon utí1ity

accu¡nulaÈeð provision f,or depreciation .. 356

.¡ 356acquisitlon âdJustrnentsallocated to ubil-iÈ.y departnenEscornpleced conseructioû not classtfied ,.construction work in progresEexpensesheld for future use ..

.......3s6, .. -... 3s6

....,... 356

.. 356... 356.. 356.. 356

in çervlceleased to olhers

Plant data . -.. . .336*33740L-429

lNÐEX (continued)

FERC FORM NO.1 (ED. t2,95) lndex I

SchedulePlanÈ - electric

accumulaEed provlsion for depreciation .

conslruccion wo¡k in progressheld for future use . "

in serviceleased t'o others

PlanE - uLility and accurnulated provisions for depreciabionamorllzaciôn and depleÈion (suffnary) ....

Pollution control fâciliEies, accumulated deferredincome t.axes .

Po!¡rer Exchanges ..Premiurn and discount on long-t.erm debtPremium on capital stock .

Prepaid laxes .

Property - losses, extraordinaty ...Pumped storage generâging planc statisbics .

Purchased power (iûcluding power exchanges)Reacquired capital seock .

Reacquired long-Eêrm debt .......Receivers' certificates ......,. "

Paqe Nq.

.... 2L9,. ", 2L6... . 2t4204-207

1t 2

20t

..... 26r

."... 233

.350*351

.352-351

110

118-119118-119118-1193 00-3 01

. ".. ".. . 234

.... 326*327

.,..... . 256

........251

. . .. 262-261

...".... 230

.... 408-409

.... 326-327

....... . 250

.... 256-25?

..., 256-257ReconciliaCion of reported neE inco¡ne v¡ith taxable income

from Federal income Èaxes .

Reg'uLatory commission expenses deferredRe$ll.aEory cornmission expenses for yeårResearch, development. and dernonst.ralion acEiviçiesRet.ained Earnings

amottization reserve Federalappropriated .. ..statement of, for the yearunappropriaEed ..

Revenues - elecÈrj.c operaEingSalaries and wages

dlrectors fees ,

distlibution of .

of ficêrs 'Sal-es of electricity by raEe schedulesSäles - for resaleSaLvage - nuclear fuel .

Schedules, this reporE form ..Securities

exchange registracion ....Statemenl of Cash Flows .

statemene of j-ncome for Èhe year ,

SEaEemenÈ of reÈained earnings for the yearSE.eam-e1ecÈric generating planE statisEics ..substaEionsSupplies - materials a¡d ..

."..... 105

... 354-355

....... 104

,...... 304

... 310-311

... 202-203

......,2-4

250-25L120-t2t1t4-LL?1 1 8-1194 02-403... 426

,., 227

INDEX {continued)

FEFC FORM NO.1 (ED, r2.9O) lndsx 4

Schedule Paçe No.Tðxes

accrued ànd prepaidchargeð durlng year .

262-263.. 262-263

on l-ncone, defeËred and accumulateð ... .-..234272-277

.... 26L

.... 429

reconciliauion of ne! íncome r.¡ith taxable income for ..TrArlsforl0ei,s, line - electricT¡ansmlssion

Lineg added during yêar .

lines scatist,ics .

of electricity for ochers

,.. " 424_425.. -. 422-423.... 328-330

óf êlècEricity by otlrers ... 332UnamorLized

debt. discoune ,.... 256-257236-257256-257... 230

dèbÈ expense ,

preniqm on debE

Unrecovered PlAnl and Regulatory SEudy Costs

INDEX (continued)

FERC FORM ¡¡O, r (8O.12€O) lndsx 5

Major Electric Utilities, Licensees - APSC

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