Name of Respondent This Report Is: Date of Report Year ...

Name of Respondent This Report Is: Date of Report Year/Period of ReportSouthwestern Electric Power Company (1) xAn Original

(2) A Resubmission(Mo, Da, Yr)

End of 2012/Q4

PUF^CHA$ED POWER Âccount 555)d( nclu ing power exc anges)

1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing ofdebits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges.2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or useacronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller.3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:

RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., thesupplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service mustbe the same as, or second only to, the supplier's service to its own ultimate consumers.

LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted foreconomic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergencyenergy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm servicewhich meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contractdefined as the earliest date that either buyer or seller can unilaterally get out of the contract.

IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but lessthan five years.

SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is oneyear or less.

LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability ofservice, aside from transmission constraints, must match the availability and reliability of the designated unit.

IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" meanslonger than one year but less than five years.

EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc.and any settlements for imbalanced exchanges.

OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as allnon-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the natureof the service in a footnote for each adjustment.

Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)No. (Footnote Affiliations) Classifi-

cationSchedule or

Tariff NumberMonthly BillingDemand (MW)

AverageMonthly NCP Deman

AverageMonthly CP Demand

(a) (b) (c) (d) (e) (f)1 American Electric Power'Service

2 Corporation (AEPSC) (1,2) OS 228 NA NA NA3 AEPSC (3) OS 228 NA NA NA4 AEPSC (3a) OS 228 NA NA NA5 Aquila, Inc. dba Aquila Networks (3,4) OS NA NA NA NA6 Associated Electric Coop Inc (3,4) OS NA NA NA NA7 Board of Public Utilities -

8 - Kansas City (3,4) OS NA NA NA NA9 Cajun Electric Cooperative, Inc. (5) OS NA NA NA NA

10 Calpine Energy Services LP (3) OS NA NA NA NA11 Canadian Wind (8) OS NA NA NA NA12 Citigroup Energy Inc (3) OS NA NA NA NA13 City of Bentonville (6) RQ 126 NA NA NA14 City of Independence (4) OS NA NA NA NA

Total

FERC FORM NO. 1(ED. 12-90) Page 326

200

Name of Respondent This Report Is: Date of Report Year/Period of ReportSouthwestern Electric Power Company ( 1) XAn Original

(2) A Resubmission(Mo, Da, Yr)

End of 2012/Q4

ccou n t (Continued)Including power exchan es)

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

4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriatedesignation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, asidentified in column (b), is provided.5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enterthe monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and theaverage monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). MonthlyNCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demandduring the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f)must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthoursof power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.7. Report demand charges in column (j), energy charges in column (k), and the total of any other types of charges including,out-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column (I). Report in column (m)the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlementamount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I)include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by theagreement, provide an explanatory footnote.8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must bereported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401,line 12. The total amount in column ( i) must be reported as Exchange Delivered on Page 401, line 13.9. Footnote entries as required and provide explanations following all required data.

MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWERLine

Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l) NoReceived Delivered ($) ($) ($) of Settlement ($).

(g) (h) (i) G) (k) (i) (m)

619,08 14,213,61 -1,166,551 13,047,064 21,531 38,44 1 -434 38,014 3

245,88 ( 16,104,85 1 16,104,858 4

6 1,7 -2 1,742 533 9,53 -100 9,433 6

7

1 79 -1 791 8

4,200,000 4,200,000 913,85 323,64 -6,766 316,880 1059,471 1,670,29 1,670,294 11

96 22,53 -471 22,066 12

36,31 13

19 193 14

5,402,097 12, 507,768 115,639,171 22, 787, 507 150, 934,44


201

Name of Respondent This Re ort Is' Date of Report Year/Period of ReportSouthwestern Electric Power Company

(2)(1) X An Original

A Resubmission(Mo, Da, Yr)//

End of 2012/Q4

PURCHASED POWER iAccount 555)l( nc u ing power exc anges)











cationSchedule or


AverageMonthly NCP Demand


(a) (b) (c) (d) (e) (f)1 City of Independence P&L Dept (3) OS NA NA NA NA2 City of Lafayette (4) OS NA NA NA NA3 City of Minden (7) OS NA NA NA NA4 City of Minden (6) RQ NA NA NA NA5 City Utiliities of Springfield (3,4) OS NA NA NA NA6 CLECO Power LLC (3,4) OS NA NA NA NA7 CLECO Trading and Marketing (7) •,,, . ' OS NA NA NA NA8 Constellation Energy

9 Commodities Group, Inc. (3,4) OS NA NA NA NA10 Empire District Power Marketing (3,4) OS NA NA NA NA11 Endure Energy LLC (3) OS NA NA NA NA12 Entergy Power Services Inc (3,4) OS NA NA NA NA13 Electric Reliability Council of

14 Texas (ERCOT) (3,5) OS NA NA NA NA

Total

FERC FORM NO. 1(ED. 12-90) Page 326.1

202

Name of Respondent This Re ort Is: Date of Report Year/Period of ReportSouthwestern Electric Power Company (1) XAn Original

(2) []A Resubmission(Mo, Da, Yr)

End of 2012/Q4

ccou t ( ontinue )nc udin power excganges)


4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriatedesignation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, asidentified in column (b), is provided.5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enterthe monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and theaverage monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). MonthlyNCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demandduring the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f)must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthoursof power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.7. Report demand charges in column (j), energy charges in column (k), and the total of any other types of charges including,out-of-period adjustments, in column ( I). Explain in a footnote all components of the amount shown in column ( I). Report in column (m)the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlementamount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I)include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by theagreement, provide an explanatory footnote.8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must bereported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401,line 12. The total amount in column ( i) must be reported as Exchange Delivered on Page 401, line 13.9. Footnote entries as required and provide explanations following all required data.

MegaWatt Hours POWER EXCHANGES COST/SETTLEMENT OF POWERLine

Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l) No( )

Received Delivered(h) i

($) ($) ($) of Settlement ($) .g ( ) G) (k) (I) (m)

1 2 -1 28 1

1 37 -1 373 23,481 145,95 145,956 34,20 4

1 751 -1 750 5

5 1,94 -3 1,941 6799,65 8,279,856 26,226,04 22,245,375 56,751,275 7

850 14,94 -100 14,840 9

5,71 133,69 -2,775 130,921 10641 14,98 -313 14,667 1171 30,61 -47 30,571 12

1317,45 27,912 1,179.51 61,500 1,268,924 14

5,402,097 12,507,768 115,639,171 22,787,507 150,934,44


203

Name of Respondent This Re ort Is: Date of Report Year/Period of ReportSouthwestern Electric Power Company (1) X[Ân Original

(2) []A Resubmission(Mo, Da, Yr)

LEnd of 2012/Q4

PUICHA$ED POWER (Account 555)l( nc uding power exchanges)


RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i e., thesupplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service mustbe the same as, or second only to, the supplier's service to its own ultimate consumers.








Line Name of Company or Public Authority Statistical FERC Rate Average Actual Demand (MW)

No. (Footnote Affiliations) Classifi-cation

Schedule orTariff Number

Monthly BillingDemand (MW)

AverageMonthly NCP Demand


(a) (b) (c) (d) (e) (f)1 Exelon (3,4) OS NA NA NA NA2 Grand River Dam Authority (3,4) OS NA NA NA NA3 J Aron & Company (3) OS NA NA NA NA4 Kansas City Power

5 and Light Company (3,4) OS NA NA NA NA6 Kansas Energy, LLC (3) OS NA NA NA NA7 Louisiana Energy &

8 Power Authority (3,4) OS NA NA NA NA9 Louisiana Generating, LLC (4) OS NA NA NA NA

10 Majestic Wind Farm (8) OS NA NA NA NA11 Midwest ISO (9) OS NA NA NA NA12 Nebraska Public Power District (3,4) OS NA NA NA NA13 North Texas Electric Cooperative (6) RQ NA NA NA NA14 NRG Power Marketing, Inc. (3,4) OS NA NA NA NA

Total


204

Name of Respondent This Re ort Is: Date of Report Year/Period of ReportSouthwestern Electric Power Company

(1) Ân Original(2) FÂ Resubmission

(Mo, Da, Yr)/ /

End of 2012/Q4

-PURCHAIncluding power ezcîanges)

on inue


4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriatedesignation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, asidentified in column (b), is provided.5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enterthe monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and theaverage monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). MonthlyNCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demandduring the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f)must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthoursof power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.7. Report demand charges in column (j), energy charges in column (k), and the total of any other types of charges, includingout-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column ( I). Report in column (m)the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlementamount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I)include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by theagreement, provide an explanatory footnote.8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must bereported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401,line 12. The total amount in column ( i) must be reported as Exchange Delivered on Page 401, line 13.9. Footnote entries as required and provide explanations following all required data.

MegaWatt HoursPOWER EXCHANGES COST/SETTLEMENT OF POWER

LinePurchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total Q+k+l) No.Received Delivered ($) ($) ($) of Settlement ($)

(g) (h) (i) U) (k) ( i) (m)601 14,04 -294 13,755 1

4 4,03 - 1 4,034 2

92 21,65 -453 21,20 3

4

1,661 39,05 -751 38,29 51 29 -6 287 6

7

21 -1 209 812,76 408,05 408,052 9

466,22 20,906,68 20,906,680 10

19,15 19,153 1110 3,29 -5 3,290 12

1,636,494 13

59 13,991 -240 13,751 14

5,402,097 12, 507,768 115,639,171 22,787,507 150,934,44


205

Name of Respondent This Re ort Is:(1) XÂn Original

Date of Report(Mo Da Yr)

Year/Period of ReportSouthwestern Electric Power Company

(2) []A Resubmission, ,

End of 2012/Q4

PU5CHA$ED POWER (Account 555)ncluding power exchanges)



LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted foreconomic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergencyenergy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm servicewhich meets the definition of RQ service. For all transaction identified as.LF, provide in a footnote the termination date of the contractdefined as the earliest date that either buyer or seller can unilaterally get out of the contract.








cationSchedule or


AverageMonthly NCP Deman


(a) (b) (c) (d) (e) (f)1 Oklahoma Gas and Electric Company(3,4) OS NA NA NA NA2 Oklahoma Municipal Power Authority (3) OS NA NA NA NA3 Omaha Public Power District (3,4) OS NA NA NA NA4 Rainbow Energy

5 Marketing Corporation (3) OS NA NA NA NA6 Rayburn County Electric Cooperative(6) RQ NA NA NA NA7 South Mississippi

8 Power Association (3,4) OS NA NA NA NA9 Southwest Power Pool (3,4,10) OS NA NA NA NA

10 Southwestern Power Administration(3,4) OS NA NA NA NA11 Southwestern Public Service Co (3,4) OS NA NA NA NA12 Sunflower Electric Power Corp (3,4) OS NA NA NA NA13 Snider Industries ( 11) OS NA NA NA NA14 Tenaska Power Service Company (3) OS NA NA NA NA

Total


206

Name of Respondent This Re ort Is: Date of Report Year/Period of ReportSouthwestern Electric Power Company

An Original(1) X (Mo, Da, Yr)End of 2012/Q4

(2) A Resubmission / /( ccou t 55 (Continue

Including power excîanges)


4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriatedesignation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, asidentified in column (b), is provided.5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enterthe monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and theaverage monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). MonthlyNCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demandduring the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f)must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthoursof power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.7. Report demand charges in column 0), energy charges in column (k), and the total of any other types of charges, includingout-of-period adjustments, in column ( I). Explain in a footnote all components of the amount shown in column (I). Report in column (m)the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlementamount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (1)include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by theagreement, provide an explanatory footnote.8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must bereported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401,line 12. The total amount in column (i) must be reported as Exchange Delivered on Page 401, line 13.9. Footnote entries as required and provide explanations following all required data.

MegaWatt HoursPOWER EXCHANGES COST/SETTLEMENT OF POWER

LinePurchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l) NoReceived Delivered ( $) ($) ($) of Settlement ($) .

(g) (h) (i) Q) (k) (I) (m)241 5,43 - 12 5,422 1

1 29 -6 28 22,36 55,92 -1,121 54,804 3

475,58 1,765,96 -36,920 1,729,046 5

2,79 6

7

4 1,66 -2 1,661 81,238,77 29,667,80 1,747,561 31,415,36 9

3 1,38 -2 1,387 10184 5,97 -12 5,965 1141 1,291 -8 1,283 12

6,02 188,80 188,803 1328,79 672,75 -14,065 658,691 14 ,

5,402, 097 12, 507,768 115,639,171 22,787,507 150,934,44


207

Name of Respondent

S thThis Re ort Is: Date of Report(1) XÂn Original (Mo Da Yr)

Year/Period of Reportou western Electric Power Company , ,

(2) r_J A Resubmission End of 2012/Q4

PUICHA$ED POWER (Account 555)l d( nc u ing power exchanges)

1. Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing ofdebits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges.2. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or useacronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller .3. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows:


LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interru ted fp oreconomic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergencyenergy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm servicewhich meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contractdefined as the earliest date that either buyer or seller can unilaterally get out of the contract.





EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity etc.,and any settlements for imbalanced exchanges.


Line Name of Company or Public Authority StatisticalCl if

FERC Rate Average Actual Demand (MW)No. (Footnote Affiliations) ass i- Schedule or Monthly Billing Average verage

(a)cation

bTariff Number Demand (MW) Monthly NCP Deman d Monthly CP Demand

( ) (c) (d) (e) (f)

1 Tex-La Electric Cooperative

2 of Texas Inc (6) RQ NA NA NA NA3 The Energy Authority (3,4) QS NA NA NA NA4 Union Electric Company (3) OS NA NA NA NA5 Union Power Partners LP (3) OS NA NA NA NA6 Western Area Power Administration

7 (WAPA) - Upper Plains Region (3,4) OS NA NA NA NA8 Wester Energy Inc (3,4) OS NA NA NA NA9 Western Farmers Electric Coop (3,4) OS NA NA NA NA

10

11

12

13

14

Total


208

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

Southwestern Electric Power Company(1) XÂn Original(2) MA Resubmission

(Mo, Da, Yr) End of 2012/04

ccou t 555 (continued )Inc uding power excîanges)


4. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriatedesignation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, asidentified in column (b), is provided.5. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enterthe monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and theaverage monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). MonthlyNCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demandduring the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f)must be in megawatts. Footnote any demand not stated on a megawatt basis and explain.6. Report in column (g) the megawatthours shown on bills rendered to the respondent. Report in columns (h) and (i) the megawatthoursof power exchanges received and delivered, used as the basis for settlement. Do not report net exchange.7. Report demand charges in column Q), energy charges in column (k), and the total of any other types of charges, includingout-of-period adjustments, in column (I). Explain in a footnote all components of the amount shown in column ( I). Report in column (m)the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (m) the settlementamount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (I)include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by theagreement, provide an explanatory footnote.8. The data in column (g) through (m) must be totalled on the last line of the schedule. The total amount in column (g) must bereported as Purchases on Page 401, line 10. The total amount in column (h) must be reported as Exchange Received on Page 401,line 12. The total amount in column ( i) must be reported as Exchange Delivered on Page 401, line 13.9. Footnote entries as required and provide explanations following all required data.

MegaWatt HoursPOWER EXCHANGES COST/SETTLEMENT OF POWER Line

Purchased MegaWatt Hours MegaWatt Hours Demand Charges Energy Charges Other Charges Total (j+k+l) No.Received Delivered ($) ($ ($) of Settlement ($)

(g) (h) 0) (j) (k^ (I) (m)

44,87 2

60,63 1,416,73 -29,618 1,387,115 3

2 58 -12 573 4

10 2,49 -52 2,442 5

6

16 5.201 -10 5,191 7

11,64 274,13 -5,628 268,506 8

32 7,75 -144 7,608 9

10

11

12

13

14

5,402,097 12,507,768 115,639,171 22, 787, 507 150,934,44


209

THIS PAGE INTENTIONALLY LEFT BLANK

210

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

Southwestern Electric Power Company 2 A Resubmission // 2012/Q4

FOOTNOTE DATA

Schedule Page: 326 Line No.: I Column: a__

( 1) Respondent is an affiliated company of American Electric Power Service Corporation

( 2) Economy energy and pool energy

( 3) Respondent portion of participation in purchases through AEP Economic Dispatch

(3a) Prior year participation in purchases through AEP Economic Dispatch due toInterchange Cost Restruction correction for February 01, 2007 throughDecember 31, 2010

( 4) Dedicated non-firm purchases

( 5) Capacity commitment

( 6) Power exchange

( 7) Dedicated firm purchases

( 8) Wind Energy

( 9) Congestion

(10) Imbalance Energy Purchase Settlement

(11) Cogeneration

scneaule Page: 326.1 Line No.: 7 Column: a

Formula rate excludes purchases associated with the CLECO PSA (Purchase and SalesAgreement) through 2014.

FERC FORM NO. I ( ED. 12-87) Page 450.1

211

Name of Respondent

Southwestern Electric Power CompanyThis Re ort Is:(1) X[]An Original(2) A Resubmission

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

Year/Period of ReportEnd of 2012/Q4

Account 4 56 . 1)(Including transactions referred to as 'wheelin g ')

1. Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities,qualifying facilities, non-traditional utility suppliers and ultimate customers for the 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) the company or public authority that paid for the transmission service. Report in column (b) the company orpublic authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to.Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnoteany ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c)4. In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to PointTransmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point TransmissionReservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this codefor any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote foreach adjustment. See General Instruction for definitions of codes.

LineNo.

Payment By(Company of Public Authority)

(Footnote Affiliation)(a)

Energy Received From(Company of Public Authority)

(Footnote Affiliation)(b)

Energy Delivered To(Company of Public Authority)

(Footnote Affiliation)(c)

StatisticalClassifi-cation(d)

1 American Electric Power Service

2 Corpora6on (AEPSi;) (1,2,3)' Various Various OS3 AEPSC ( 1,2,4) Various Various AD4 Kansas City Power & Light (5) Various Various OS5 City of Lafayette (5) Southwest Power Administration City of Lafayette LFP6

7 Snider Industries (6) Various Various OS8 Southwest Power Pool (2,3,7,8) Various Various OS9 Southwest Power Pool (2,4) Various Various AD

10

11

12

13

14

15

16

17

18

19

20

21

22

23

24 ,

25

26

27

28

29

30

31

32

33

34

TOTAL


212

Name of Respondent

Southwestern Electric Power CompanyThis Report Is:(1) xAn Original(2) A Resubmission

Date of Report(Mo, Da, Yr)

Year/Period of Report201 2/Q4End of

(Including transactions reffered to as'whee il nu ^t 4 ontinue

5. In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contractdesignations under which service, as identified in column (d), is provided.6. Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report thedesignation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column(g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in thecontract.7. Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demandreported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.8. Report in column (i) and (j) the total megawatthours received and delivered.

FERC RateSchedule of

Point of Receipt(Subsatation or Other

Point of Delivery(Substation or Other

BillingDemand

TRANSFER OF ENERGY LineTariff Number

(e)Designation)

(^ Designation)(g)(MW)

(h)egaV att ours

Received(i)

Mega Watt oursDelivered

a)

No.

1NA Various Various 2NA Various Various 3NA Various Various 4105 Various Points in Various Points in 29,651 29,651 5

Arkansas Louisiana and Texas 6NA Various Various 7196 Various Various 8196 Various Various 9

10

11

12

13

14

15

16

17

18

19

20

21

22

23

24

25

26

27

28

29

30

31

32

33

34

0 29,651 29,651


213

Name of Respondent

Southwestern Electric Power Company

This Re ort Is:(1) Ân Original(2) r-J A Resubmission



TRANSIVIISS IUN ( ccount 456) (Continued)(Including transactions reffered to as 'wheelin ')9. In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demandcharges related to the billing demand reported in column (h). In column ( I), provide revenues from energy charges related to theamount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, includingout of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the totalcharge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero ( 11011) in column(n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or servicerendered.10. The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual reportpurposes only on Page 401, Lines 16 and 17, respectively.11. Footnote entries and provide explanations following all required data.

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERSDemand Charges

( $)(k)

Energy Charges($)(I)

(Other Charges)($)(m)

Total Revenues ($)(k+l+m)

(n)

ineNo.

13,667,035 13,667,035 2-1,329,233 -1,329,233 3

12 12 4

108,067 108,067 5

6

840 840 7

44,372,057 44,372,057 8

266,299 266,299 9

10

11

12

13

14

15

16

17

18

19

20

21

22

23

24

25

26

27

28

29

30

31

32

33

34

0 0 57,085,077 57,085,077

FERC FORM NO.1 (ED. 12-90) Page 330

214


Southwestern Electric Power Company 2) _ A Resubmission I 2012/Q4

FOOTNOTE DATA

Schedule Paê_328 Line No.: 2 Column: a

(1) Respondent is an affiliated company of American Electric Power Service Corporation

(2) Network Integrated Transmission Service (NITS)

(3) Southwest Power Pool base plan funding

(4) Prior year

(5) Transmission service charge

(6) Open access ancillary service

(7) Direct assignment

(8) Point to point transmission and ancillary service

FERC FORM NO. 1 ( ED. 12-87) Page 450 1

215

Name of Respondent This Report Is: Date of Report Year/Period of ReportSouthwestern Electric Power Company

(1) An Original (Mo, Da, Yr)End of 2012/Q4

(2) A Resubmission

TRANSMISSION OF ELECTRICITY BY OTHERS ( Account 565)(Including transactions referred to as "wheeling")

1. Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other publicauthorities, qualifying facilities, and others for the quarter.2. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company,abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with thetransmission service provider. Use additional columns as necessary to report all companies or public authorities that providedtransmission service for the quarter reported.3. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows:FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - OtherLong-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm TransmissionService, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications.4. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service.5. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report thedemand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of allother charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote allcomponents of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If 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 the last line.7. Footnote entries and provide explanations following all required data.

Line TRANSFER OF ENERGY EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERNo. Name of Company or Public

Authority (Footnote Affiliations)Statistical

Classificationagawatt-hours

Recei d

Me -hours

D li d

emanChar es

nergyCh ^$ges

utnerChar Total Cost of

Trans ission(a) (b)

ve(c)

e vere(d)

1(e)

)(f)

)

(g )

(^

(n)1 American Electric Power

2 Service Corporation

3 (AEPSC) (1,2;3,4,5) OS 897,821 897,8214 Southwest

5 Power Pool (3,6) OS 19,809,646 19,809,6466

7

8

9

10

11

12

13

14

15

16

TOTAL 20,707,467 20,707,467

FERC FORM NO. 1/3-Q (REV. 02-04) Page 332

216

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

Southwestern Electric Power Company (2) _A Resubmission 2012/Q4

FOOTNOTE DATA

Schedule Pa_qe: 332-_ Line No.: 3 Column: a

(1) Respondent is an affiliated company of American Electric Power Service Corporation

(2) Facility charge

(3) Southwest Power Pool base plan funding

(4) Southwest Power Pool ancillary service schedule 1

(5) Network Integrated Transmission Service (NITS)

(6) Transmission service charge

FERC FORM NO. 1 (ED. 12-87 ) Page 450.1

217

Name of RespondentSouthwestern Electric Power Company

This ort Is:(1) x An Original(2) A Resubmission


Year/Period of Report2012/Q4End of

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)LineNo.

Description(a)

Amount(b)

1 Industry Association Dues 459,0212 Nuclear Power Research Expenses

3 Other Experimental and General Research Expenses 10,6234 Pub & Dist Info to Stkhldrs.. expn servicing outstanding Securities 104,8565 Oth Expn >=5,000 show purpose, recipient, amount. Group if < $5,000

6

7 Valley Electric Membership Corporation (VEMCO)

8 VEMCO Litigation Settlement -3,033,0279

10 Associated Business Development 296,69711

12 AEP Service corporation and Other Affiliated

13 Companies Billed to or from Respondent -100,15114

15 Chamber of Commerce 36,77716

17 Miscellaneous Minor Items less than $5,000 29,82818

19

20

21

22

23

24

25

26

27

28

29

30

31

32

33

34

35

36

37

38

39

40

41

42

43

44

45

46 TOTAL -2,195,376


218

Name of Respondent This Report Is: Date of Report Year/Period of ReportSouthwestern Electric Power Company (1) Ân Original (Mo, Da, Yr)

End of 2012/Q4(2) A Resubmission

DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Account 403, 404, 405)(Except amortization of aquisition adjustments)

1. Report in section A for the year the amounts for :(b) Depreciation Expense (Account 403; (c) Depreciation Expense for AssetRetirement Costs (Account 403.1; (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other ElectricPlant (Account 405).2. Report in Section 8 the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used tocompute charges and whether any changes have been made in the basis or rates used from the preceding report year.3. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changesto columns (c) through (g) from the complete report of the preceding year.Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount,account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plantincluded in any sub-account used.In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showingcomposite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state themethod of averaging used.For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification Listed in column(a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type mortality curveselected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. Ifcomposite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis.4. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates state at,the bottom of section C the amounts and nature of the provisions and the plant items to which related.

A Summary of Depreciation and Amortization Charges

Depreciation Amortization ofLineNo. Functional Classification

DepreciationExpense

Expense for AssetRetirement Costs

Limited TermElectric Plant

Amortization ofOther Electric Total

(a (Accoun' 403) (Account 403.1) (Account 404) Plant (Acc 405)) (b(c) (d) (e) (f)

1 Intangible Plant 9,059,152 9,059,1522 Steam Production Plant 46,243,548 316,761 46,560,3093 Nuclear Production Plant

4 Hydraulic Production Plant-Conventional

5 Hydraulic Production Plant-Pumped Storage

6 Other Production Plant 2,994,562 2,994,5627 Transmission Plant 25,189,839 25,189,8398 Distribution Plant 45,051,564 45,051,5649 Regional Transmission and Market Operation

10 General Plant 8,000,389 16,908 1,106 8,018,40311 Common Plant-Electric

12 TOTAL 127,479,902 333,669 9,060,258 136,873,829

B. Basis for Amortization Charges

Line 1, Column D represents amortization of capitalized software development costs over a 5 year life.

Line 10, Column D represents leasehold improvements amortized over the life of the respective lease.

FERC FORM NO. 1(REV. 12-03) Page 336

219

Name of Respondent

Southwestern Electric Power CompanyThis Report Is:(1) An Original(2) A Resubmission



DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)

C. Factors Used in Estimating Depreciation ChargesLine Depreciable s ima e e App l ied Mo rta l ity verageNo. Account No. Plant Base Avg. Service Salvage Dep r. rates Curve Remaining(In Thousands) Life (Perdcent) ( Percent)

(e)e Life(a ) ( b ) (c)

12 STEAM--COAULIGNITE

13 311 - Dolet Hills 52,27414 311 - Flint Creek 22,19515 311 - Pirkey 107,26916 311 - Welsh 86,61117 312 - Dolet Hills 148,69418 312 - Flint Creek 59,798

19 312 - Pirkey 312,07720 312 - Welsh 376,33321 314 - Dolet Hills 35,73922 314 -Flint Creek 12,55823 314 - Pirkey 50,16524 314 - Welsh 107,98325 315 - Dolet Hills 9,61226 315 - Flint Creek 6,14527 315 - Pirkey 15,95328 315 - Welsh 25,10129 316 - Dolet Hills 14,72330 316 - Flint Creek 5,50731 316 - Pirkey 17,67432 316 - Turk 2,18833 316 - Welsh 21,57634 TOTAL COAULIGNITE 1,490,17535

36 STEAM--GAS/OIL

37 311.3-ArsenalHillStall 52,83338 311.3 - Arsenal Hill 5,27139 311.3 - Knox Lee 7 , 71840 311.3 - Lieberman 3,73641 311.3 - Lone Star 83642 311.3 - Wilkes 6,95243 312.3-ArsenalHillStall 86,66444 312.3-ArsenalHill Pipe 178

45 312.3 - Arsenal Hill 5,44546 312.3-KnoxLee Pipeline 86547 312.3 - Knox Lee 30,06348 312.3 - Lieberman 17,85549 312.3 - Lone Star 3,14850 312.3 -Wilkes Pipeline 170


220

Name of Respondent


This Re ort Is:(1) (XÂn Original(2) A Resubmission



DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT (Continued)

C. Factors Used in Estimating Depreciation Charges

LineNo. Account No.

(a )

DepreciablePlant Base

(In Thousands)(b

EstimatedAvg. Service

Lifec

NetSalvage

(Percent)(d )

App l iedDepr. rates

(Percent)(e )

mo rta l ityCurveT e

verageRemaining

Life

12 312.3 - Wilkes 34,681

13 314.3-ArsenalHillStall 164,039

14 j 314.3 - Arsenal Hill 4,473

15 314.3 - Knox Lee 19,227

16 314.3 - Lieberman 11,495

17 314 3- Lone Star 2,050

18 314.3 - Wilkes 29,308

19 315 3-ArsenalHillStall 40,157

20 315.3 - Arsenal Hill 680

21 315.3 - Knox Lee 3,674

22 315 3 - Lieberman 2,191

23 315.3 - Lone Star 528

24 315.3 - Wilkes 8,401

25 316.3-ArsenalHillStall 84,828

26 316.3 - Arsenal Hill 3,845

27 316.3 - Knox Lee 1,488

28 316.3 - Lieberman 1,861

29 316.3 - Lone Star 95

30 316.3 - Wilkes 3,057

31 TOTAL GAS/OIL 637,812

32

33 OTHER GENERATION

34 341 - Mattison 34,819

35 344 - Mattison 83,886

36 345 - Mattison 8,167

37 346 - Mattison 636

38 TOTAL OTHER 127,508

39

40 TRANSMISSION

41 350 (Rights) 59,625

42 352 8,460

43 353 394,730

44 354 39,863

45 355 341,530

46 356 256,661

47 357

48 359 132

49 I TOTAL TRANSMISSIO 1,101,005

50

FERC FORM NO. 1(REV. 12-03) Page 337.1

221

Name of Respondent


This Re ort Is:(1) Ân Original(2) A Resubmission



DEPRECIATION AND AMORTIZATION OF ELECTRIC PLANT ( Continued)

C. Factors Used in Estimating Depreciation ChargesLineNo. Account No.

(a )

Deprecia blePlant Base

(In Thousands)b

EstimatedAvg. Service

Life(c)

NetSalvage

(Percent)

App l iedDepr. rates

(Percent)

Mo rtalityCurveT e

verageRemaining

Life

12 DISTRIBUTION

13 360 (Rights) 3,48714 361 5,06115 362 222,61916 364 366,12717 365 357,84918 366 51,75619 367 177,05920 368 331,59021 369 68,68222 370 87,96323 371 37,39024 373 36,601

25 TOTAL DISTRIBUTION 1,746,18426

27 GENERAL PLANT

28 390 96,59929 391 10,566

30 391.11 498

31 392 4,11732 393 2,45133 394 20,34034 395 5,37535 396 2,56436 397 65,3937 398 2,37138 TOTAL GENERAL PLANT 210,27539

40 DEPRECIABLE SUM 5,312,959'41

42

43

44

45

46

47

48

49

50


222


Southwestern Electric Power Company (2 _ A Resubmission // 2012/Q4FOOTNOTE DATA

Schedule Page: 336.2 Line No.: 40 Column • bThe depreciable plant base is the November 30, 2012 total company depreciable plant.

FERC FORM NO. 1(ED.12-87 Page 450 1

223

Name of Respondent


Date of Report( Mo, Da, Yr)


REGULATORY COMMISSION EXPENSES1. Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, ifbeing amortized) relating to format cases before a regulatory body, or cases in which such a body was a party.2. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amountsdeferred in previous years.LineNo.

1

Description(Furnish name of regulatory commission or body the

docket or case number and a description of the case)(a)

Federal Energy Regulatory Commission Annual

Assessed byRegulatoryCommission(b)

Expensesof

Utcjty

TotalExpense forCurrent Year

(b)(+d)(c)

Deferredin Account182.3 at

Beginning of Year

2 Assessment 37,151 37,1513

4 Expenses incurred in rate review before the5 Public Utility Commission of Arkansas -6 Docket No. AR 09-008-U - 3 year Amortization 16,920 16,920 16,927

8 Expenses incurred in rate review before the9 Public Utility Commission of Texas (PUCT) -

10 Docket No. 37772, Recovery through a Rate11 Rider No. SA05 A-E which started in12 November 2010 with a 3 year amortization 1,652,193 1,652,193 2,683,9013

14 Expenses incurred in rate review before the15 PUCT Docket No. 40443, 2012 rate case filing 436,234 436,23416

17 Expense incurred related to Construction Work18 in Process for the Texas portion of the Turk19 Power Plant - PUCT Docket No.39708 756,203 756,20320

21 Expense incurred related to the Energy22 Efficiency Cost Recovery Factors23 PUCT Docket No. 39359 25,211 25,21124

25 Expenses incurred to defer Texas Fuel26 Reconciliation expenses

27 PUCT Docket No. 338614900,88

28

29 Other expenses related to Texas Fuel30 Reconciliation charges 63,957 63,95731

32 Expenses incurred related to Flint Creek FGD33 (Flue Gas Desulfurization) prudence34 determination 104,390 104,39035

36 Miscellaneous Minor Items 112,803 112,80337

38

39

40

41

42

43

44

45

46 TOTAL 37,151 3,167,911 3,205,062 3,601,717


224

Name of Respondent

Southwestern Electric Power CompanyThis Report is:

(2)(1) M AnAn Original

Resubmission



REGULATORY COMMISSION EXPENSES (Continued)3. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization.4. List in column (f), (g), and (h) expenses incurred during year which were charged currently to income, plant, or other accounts.5. Minor items (less than $25,000) may be grouped.

EXPENSES INCURRED DURING YEAR AMORTIZED DURING YEARCURRENTLY CHARGED TO Deferred to Contra A Deferred inDepartment

(f)

No n(g)

Amoun t(h

Account 182.3

(^)

Account

)

mount

(k)

Account 182.3End of Year

(I)

LineNo.

1Electric 928 37,151 2

3

4

5Electric 928 16,920 928 16,920 6

7

8

9

10

11Electric 928 1,652,193 136,003 928 1,652,193 1,167,719 12

13

14Electric 928 436,234 3,615,616 3,615,616 15

16

17

18Electric 928 756,203 19

20

21

22Electric 928 25,211 23

24

25

26

900,888 27

28

29Electric 928 63,957 30

31

32

33Electric 925 104,390 34

35Electric 928 112,803 36

37

38 ,39

40

41

42

43,

44

45

3,205,062^ _. 3,751,619 'T 1,669,113 5,684,223 46ren%, rvrcm rvtJ. l(tu. 1Z-96) Page 351

225

Name of Respondent


This Re ort Is:(1) An Original(2) A Resubmission



RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES

1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D &D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identifyrecipient regardless of affiliation ) For any R, D & D work carried with others, show separately the respondent's cost for the year and cost chargeable toothers (See definition of research, development, and demonstration in Uniform System of Accounts).2. Indicate in column ( a) the applicable classification, as shown below:

Classifications,A. Electric R, D & D Performed Internally: a. Overhead

(1) Generation b Undergrounda. hydroelectric (3) Distribution

L Recreation fish and wildlife (4) Regional Transmission and Market Operationii Other hydroelectric (5) Environment (other than equipment)

b. Fossil-fuel steam (6) Other (Classify and include items in excess of $50,000 )c. Internal combustion or gas turbine (7) Total Cost Incurredd. Nuclear B Electric, R, D & D Performed Externally:e. Unconventional generation ( 1) Research Support to the electrical Research Council or the Electricf. Siting and heat rejection Power Research Institute

(2) Transmission

LineNo.

Classification(a)

Description

(b)1

2 A (1) Generation

3 (b) Fossil-fuel Steam 6 Items < $50,0004

5 (c) Internal Combustion or Gas Turbine 1 Items < $50,0006

7 (e) Unconventional Generation 2 Items < $50,0008

9

10 A. (2) Transmission 4 Items < $50,00011

12 A. (2)aTransmission Overhead 1 Item < $50,00013

14 A. (3) Distribution 1 Items < $50,00015

16 A. (5) Environmental (other than equipment) Industrial Advisory Committee - Southern Company17 3 ►tems < $50,00018

19 A. (6) Other 6 Items < $50,00020

21

22

23 A. (6)f MeteringOther 1 Items <$50,00024

25

26 A. (7) Total Cost Incurred Internally27

28

29

30,

31

32

33

34

35

36

37

38


226

Name of Respondent




RESEARCH, DEVELOPMENT, AND DEMONSTRATIO N ACTIVITIES ( Continued )(2) Research Support to Edison Electric Institute(3) Research Support to Nuclear Power Groups(4) Research Support to Others ( Classify)(5) Total Cost Incurred

3. Include in column (c) all R, D & D items performed internally and in column (d) those items performed outside the company costing $50,000 or more,briefly describing the specific area of R, D & D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.).Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D &D activity.4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year,listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e)5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research,Development, and Demonstration Expenditures, Outstanding at the end of the year.6. If costs have not been segregated for R, D &D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by"Est."7. Report separately research and related testing facilities operated by the respondent.

Costs Incurred InternallyCurren Year

Costs Incurred Externally AMOUNTS CHARGED IN CURRENT YEAR UnamortizedLine

(c^ Current Year(d) Ac(ej nt Am(ôûnt Accumulation(g) No.

1

243,112 506 43,112 3

48,765 506 8,765 5

66,098 506 6,09 73,977 588 3,977 8

97,234 566 7,23 10

1128 566 28 12

1328 588 28 14

15261,209 506 261,20 16

3,419 506 3,419 17

183,403 506 3,403 194,579 566 4,579 20

14,590 588 14,590 21

2214 588 14 23

24

25356,456 356,456 26

27

28

29

30 ,

31

32

33

34

35

36

37


227

Name of Respondent


This Report Is-

(2)(1)

AAn Original

Resubmission


YearlPeriod of ReportEnd of 2012/Q4

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES1. Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D&D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects. (Identifyrecipient regardless of affiliation.) For any R, D & D work carried with others, show separately the respondent's cost for the year and cost chargeable toothers (See definition of research, development, and demonstration in Uniform System of Accounts).2. Indicate in column (a) the applicable classification, as shown below:

Classifications:A. Electric R, D & D Performed Internally: a. Overhead

(1) Generation b Undergrounda. hydroelectric (3) Distribution

I. Recreation fish and wildlife (4) Regional Transmission and Market Operationii Other hydroelectric ( 5) Environment (other than equipment)

b Fossil-fuel steam (6) Other (Classify and include items in excess of $50,000 )c. Internal combustion or gas turbine (7) Total Cost Incurredd. Nuclear B. Electric, R, D & D Performed Externally:e. Unconventional generation ( 1) Research Support to the electrical Research Council or the Electricf. Siting and heat rejection Power Research Institute

(2) Transmission

LineNo.

Classification(a)

Description

(b)1

2

3 B. (1) Electric Power Research Institute Full Scale Demonstration Sorbent Activation Process4 Environmental Controls

5 Environmental Science

6 Research Portfolio7

8

9 79 Items < $50,00010 ,

11

12

13 B. (4) Research Support to Others 5 Items <$50,00014

15

16 B. (5) Total Cost Incurred Externally

17

18 Total19

20

21

22

23

24

25

26

27

28

29

30

31

32

33,

34

35

36

37

38


228

Name of Respondent


This Re ort Is:(1) [An Original(2) A Resubmission



RESEARCH, DEVELOPMENT. AND DEMONSTRATIO N ACTIVITIES ( Continued )(2) Research Support to Edison Electric Institute(3) Research Support to Nuclear Power Groups(4) Research Support to Others (Classify)(5) Total Cost Incurred

3. Include in column (c) all R, D & D items performed internally and in column (d) those items performed outside the company costing $50,000 or more,briefly describing the specific area of R, D & D (such as safety. corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.).Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D &D activity.4. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year,listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e)5. Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research,Development, and Demonstration Expenditures, Outstanding at the end of the year.6. If costs have not been segregated for R, D &D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by"Est."7. Report separately research and related testing facilities operated by the respondent.

Costs Incurred InternallyC r en t Y

Costs Incurred Externally AMOUNTS CHARGED IN CURRENT YEAR UnamortizedLineu r ear

)Current Year

(d)Account

(e)Amount

(fl

Accumulation(g)

No.

38

1

256,311 506 56,311 3

206,786 506 206,786 4765,540 506 765,540 5254,812 506 254,812 6

100,124 566 100,124 732,536 588 32,536 8

176,404 506 176,404 937,336 566 37,336 1068,328 588 68,328 11

1211,425 566 11,425 1333,954 588 33,954 14

151,743,556 1,743,556 16

17356,456 1,743,556 2,100,012 18

19

20

21

22

23

24

25

26

27

28

29

30

31

32

33

34,

35

36


229

Name of Respondent This Re art Is.(1) Ân Original

Date of ReportM

Year/Period of ReportSouthwestern Electric Power Company ( o, Da, Yr)

End of 2012/Q4(2) A Resubmission / /

DISTRIBUTION OF SALARIES AND WAGES

Report below the distribution of total salaries and wages. for the year. Segregate amounts originally charged to clearing accounts toUtility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and column sprovided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximationgiving substantially correct results may be used.

Line Classification Direct Payroll A ocationNo. Distribution Payroll charged for Total

(a) (b) CleacingcAccounts(1 Electric

(d

2 Operation3 Production

20,398,908 ^,4 Transmission .;^

1,806 0765 Regional Market 8

^

4 5 yf77777776 Distribution

12,994 084 h ^^ ' ^'- ^. ^• ^' : r ^' ,,7 Customer Accounts

5,653 045 ^-"^ ^8 Customer Service and Informational ^

2,575 , 9089

10Sales

Administrative and General11 TOTAL Operation (Enter Total of lines 3 thru 10)

2,603 , 31246,031 , 333

12 Maintenance13 Production

^

"12,136,992 bi14 Transmission

895 00915 Regional Market

,

16 , Distribution12,8i4 , 612 :

17 Administrative and General 1 468 8 38118 TOTAL Maintenance (Total of lines 13 thru 17)

, ,27,334,994

19 Total Operation and Maintenance i;'•,20 Production (Enter Total of lines 3 and 13) 32,535,900!'21 Transmission (Enter Total of lines 4 and 14) 2,701,08522 Regional Market (Enter Total of Lines 5 and 15)23 Distribution (Enter Total of lines 6 and 16) 25,828,69624 Customer Accounts (Transcribe from line 7) 5,653,04525 Customer Service and Informational (Transcribe from line 8) 2,575,90826 Sales (Transcribe from line 9)27 Administrative and General (Enter Total of lines 10 and 17) 4,071 , 69328 TOTAL Oper. and Maint. (Total of lines 20 thru 27) 73 366 327: 4 626 48529 Gas

, , , , 77,992, 12

30 Operation1, , M ,,31 Production-Manufactured Gas pl

32 Production-Nat. Gas (Including Expl. and Dev.)33 Other Gas Supply34 Storage, LNG Terminaling and Processing35 Transmission36 Distribution37 Customer Accounts38 Customer Service and Informational

{^.

39 Sales40 Administrative and General41 TOTAL Operation (Enter Total of lines 31 thru 4042

)Maintenance

43 Production-Manufactured Gas44 Production-Natural Gas (Including Exploration and Development)45 Other Gas Supply46 Storage, LNG Terminaling and Processing47 Transmission


230

Name of Respondent

Southwestern Electric Power CompanyThis Report Is:( 1) An Original(2) r-JA Resubmission


Year/Period of ReportEnd of 2012/04

DISTRIBUTION OF SALARIES AND WAGES (Continued)

LineNo.

Classification

(a)Direct PayrollDistribution

(b)

A llocation oPayroll charged forClearingAccounts

(

Total(d)

48 Distribution ^ Î i^^( E ^^'! h

49 Administrative and General50 TOTAL Maint. (Enter Total of lines 43 thru 49)51 Total Operation and Maintenance52 Production-Manufactured Gas (Enter Total of lines 31 and 43)53 Production-Natural Gas (including Expl. and Dev.) (Total lines 32,54 Other Gas Supply ( Enter Total of lines 33 and 45)55 Storage, LNG Terminaling and Processing (Total of lines 31 thru SK (56 Transmission (Lines 35 and 47)57 Distribution (Lines 36 and 48)58 Customer Accounts (Line 37)59 Customer Service and Informational (Line 38)60 Sales (Line 39) + ;. a t3< < crt f.;.61 Administrative and General (Lines 40 and 49) N

62 TOTAL Operation and Maint. (Total of lines 52 thru 61)63 Other Utility Departments64 Operation and Maintenance65 TOTAL All Utility Dept. (Total of lines 28, 62, and 64) 73,366,327 4,626,485 77,992,812 ,6667

Utility PlantConstruction (By Utility Departments)

y+61r{,

fiF2 l M68 Electric Plant 32,105,541 2,024,577 34,130,11869 Gas Plant70 Other (provide details in footnote):71 TOTAL Construction (Total of lines 68 thru 70) 32,105,541 2,024,577 34,130,11872 Plant Removal (By Utility Departments) `73 Electric Plant 5,662,347 357,068 6,019,41574 Gas Plant75 Other (provide details in footnote):76 TOTAL Plant Removal (Total of lines 73 thru 75) 5,662,347 357,068 6,019,41577 Other Accounts (Specify, provide details in footnote):78 151 - Fuel Stock 563,427 563,42779 152 - Fuel Stock Undistributed 2,712,666 2,712,66680 163 - Stores Expense Undistributed 2,952,645 -2,952,64581 182 - Other Regulatory Assets 222 -22282 184 - Clearing Accounts 4,055,263 -4,055,26383 185 - ODD Temporary Facilities 128,492 128,49284 186 - Misc Deferred Debits 2,489,005 2,489,00585 188 - Research & Development -2,315 -2,31586 242 - Misc Current & Accrued Liab 19,875 19,87587 426 - Political Activities 238,652 238,65288 456 - Other Electric Revenue -56,748 -56,74889

90

91

92

93

94

95 TOTAL Other Accounts 13,101,184 -7,008,130 6,093,05496 TOTAL SALARIES AND WAGES 124,235,399 124,235,399


231


Southwestern Electric Power Company (2) _ A Resubmission // 2012lQ4FOOTNOTE DATA

Schedule Page: 354 Line No.: 28 Column-.--b-----

Determined by a query of the general ledger. (Formula Rates)

FERC FORM NO. I ( ED. 12-87 ) Page 450.1

232

Name of Respondent


This Re ort is:(1) Ân Original(2) A Resubmission


Year/Period of Report

End of 2012/Q4

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS

1. The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales forResale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy marketfor purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determiningwhether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated andseparately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.

LineNo.

Description of Item(s)

(a)

Balance at End ofQuarter 1

(b)


(c)


(d)

Balance at End ofYear

(e)1 Energy

2 Net Purchases (Account 555) 33,232,3643 Net Sales (Account 447) ( 38,695,607)4 Transmission Rights

5 Ancillary Services 79,7646 Other Items (list separately)

7

8

9

10

11

12

13

14,

15

16

17

18

19 ,

20

21

22

23

24,

25

26

27

28

29,

30

31

32

33

34,

35

36

37

38

39

40

41

42

43

44 ,

45

46 TOTAL ( 5,383,479)

FERC FORM NO. 1/3-Q (NEW. 12-05) Page 397

233

Name of Respondent


This Re ort Is:(1) XÂn Original(2) Â Resubmission



MONTHLY TRANSMISSION SYSTEM PEAK LOAD

(1) Report the monthly peak load on the respondent's transmission system If the respondent has two or more power systems which are not physicallyintegrated, furnish the required information for each non-integrated system.(2) Report on Column (b) by month the transmission system's peak load.(3) Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b).(4) Report on Columns (e) through 0) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction forthe definition of each statistical classification.

NAME OF SYSTEM:

LineNo. Month

(a)

Monthly PeakMW - Total

(b)

Day ofMonthly

Peak

(c)

Hour ofMonthly

Peak

(d)

Firm NetworkService for Self

(e)

Firm NetworkService for

Others

M

Long-Term FirmPoint-to-pointReservations

(g)

Other Long-Term Firm

Service

(h)

Short-Term FirmPoint-to-pointReservation

(i)

OtherService

G)1 January

2 February

3 March

4 Total for Quarter 1

5 April

6 May

7 June


9 July

10 August

11 September


13 October

14 November

15 December

16 Total for Quarter 4 ^4

17 Total Year to

Date/Year

FERC FORM NO. 113-Q (NEW. 07-04) Page 400

234


Southwestern Electric Power Company (2) -A Resubmission !/ 2012/Q4FOOTNOTE DATA

-- -- - --- - ----Schedule age: 400 Line No.: 1 Column: b

Southwestern Electric Power Company's transmission service is administered through aRegional Transmission Organization (RTO) and requested information is not available on anindividual company basis.

FERC FORM NO. I ( ED. 12-87 ) Page 450.1

235

Name of Respondent This Re on portMoepaR Year/Period of ReportSouthwestern Electric Power Company An(1) Ân Original

Y

) End of 2012^Q4(2) A Resubmission / /

ELECTRIC ENERGY ACCOU T

Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year.

LineNo

ItemMegaWatt Hours Line Item MegaWatt Hours.

(a) (b)No.

(a) (b)

1 SOURCES OF ENERGY

T

21 DISPOSITION OF ENERGY2 Generation ( Excluding Station Use). 5 p^g^ y 22 Sales to Ultimate Consumers ( Including 18,146,5173 Steam 23,391,691 Interdepartmental Sales)4 Nuclear 23 Requirements Sales for Resale (See 6,117,2575 Hydro-Conventional instruction 4, page 311.)6 Hydro-Pumped Storage 24 Non-Requirements Sales for Resale (See 2,942,2507 Other 101,77 instruction 4, page 311.)

S Less Energy for Pumping 25 Energy Furnished Without Charge9 Net Generation (Enter Total of lines 3 23,493,46 26 Energy Used by the Company ( Electric 68,645

through 8) Dept Only, Excluding Station Use)10 Purchases 5,402,09 27 Total Energy Losses 1,620,89611 Power Exchanges: 28 TOTAL (Enter Total of Lines 22 Through 28,895,56512 Received 27) (MUST EQUAL LINE 20)

13 Delivered

14 Net Exchanges (Line 12 minus line 13)

15 Transmission For Other (Wheeling)

16 Received 29,65117 Delivered 29,65118 Net Transmission for Other (Line 16 minus

line 17)

19 Transmission By Others Losses

20 TOTAL (Enter Total of lines 9, 10, 14, 18 28,895,56and 19)

FERC FORM NO. 1(ED. 12-90) Page 401a

236

Name of Respondent


This Re ort Is:(1) X[Ân Original(2) A Resubmission



MONTHLY PEAKS AND OUTPUT1. Report the monthly peak load and energy output. If the respondent has two or more power which are not physically integrated, furnish the requiredinformation for each non- integrated system.2. Report in column (b) by month the system's output in Megawatt hours for each month.3. Report in column (c) by month the non-requirements sales for resale. Include in the monthly amounts any energy losses associated with the sales.4 Report in column (d) by month the system's monthly maximum megawatt load (60 minute integration) associated with the system.5. Report in column (e) and (f) the specified information for each monthly peak load reported in column (d).

NAM E OF SYSTEM:

Line Monthly Non-RequirmentsSales for Resale & MONTHLY PEAK

No. Month

(a)

Total Monthly Energy

(b)

Associated Losses

(c)

Megawatts (See Instr. 4)

(d)

Day of Month

(e)

Hour

(f)29 January 2,449,342 430,530 4,021 3 80030 February 2,257,639 427,691 3,670 12 90031 March 2,546,970 475,139 3,131 31 180032 April 2,058,335 261,838 3,507 26 170033 May 2,411,692 218,541 4,485 29 170034 June 2,622,433 169,812 5,156 26 170035 July 2,922,907 247,933 5,205 30 160036 August 2,827,512 187,140 5,121 7 160037 September 2,335,901 115,116 5,036 6 170038 October 2,073,155 177,650 3,382 4 170039 November 1,976,332 135,832 3,412 28 80040 December 2,413,347 377,181 3,993 12 800

41 TOTAL 28,895,565 3,224,403I -

"^^`^ ^^,^1?

FERC FORM NO. 1(ED. 12-90) Page 401b

237

Name of Respondent This Report is:O i iRÂ(1)

Date of Report Year/Period of RepoSouthwestern Electric Power Company n r g nal[ (Mo, Da, Yr)

(2) []A Resubmission End of 2012/Q4

STEAM-ELECTRIC GENERATING PLANT STATISTICS ( Large Plants)1. Report data for plant in Service only. 2. Large plants are steam plants with installed capacity ( name plate rating) of 25 000 K R, w or more. eport inthis page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants. 3. Indicate by a footnote any plant leased or operatedas a joint facility. 4 If net peak demand for 60 minutes is not available, give data which is available, specifying period. 5. If any employees attendmore than one plant, report on line 11 the approximate average number of employees assignable to each plant. 6. If gas is used and purchased on atherm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct. 7. Quantities of fuel burned ( Line 38) and average costper unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20. 8 If more than one.fuel is burned in a plant furnish only the composite heat rate for all fuels burned.

Line Item Plant PlantNo. Name: Arsenal Hill, Name: Lieberman(a) (b) (c)

1 Kind of Plant (Internal Comb Gas Turb Nuclear, , Steam St2 Type of Constr (Conventional, Outdoor Boiler etc)eam

3, ,

Year Originally ConstructedOutdoor Boiler Outdoor Boiler

1960 19474 Year Last Unit was Installed2010 19595 Total Installed Cap (Max Gen Name Plate Ratin s-MWg ) 738.00 277 276 Net Peak Demand on Plant - MW (60 minutes)

.622 2177 Plant Hours Connected to Load

8330 31 68 Net Continuous Plant Capability (Megawatts)4

0 09 When Not Limited by Condenser Water0 010 When Limited by Condenser Water

653 26811 Average Number of Employees26 2412 Net Generation, Exclusive of Plant Use - KWh

13 Cost of Plant: Land and Land Rights3593074000 97098000

370798 2402614 Structures and Improvements15 Equipment Costs

58154030 3745009

16 Asset Retirement Costs390793662 33757191

17 Total Cost507714 1293455

18 Cost per KW of Installed Capacity ( line 17/5) Including449826204 38819681

19 Production Expenses: Oper, Supv, & Engr609.5206 140.0068

20 Fuel1475612 220714

21 Coolants and Water (Nuclear Plants Onl )77389085 5135904

y 022 Steam Expenses 0

23 Steam From Other Sources99128 128838

0 024 Steam Transferred (Cr)0 025 Electric Expenses

26 Misc Steam (or Nuclear) Power Expenses1630825 747730

27 Rents1033570 1077460

87647 236928 Allowances6319 17029 Maintenance Supervision and Engineering

30 Maintenance of Structures233154 143688

31 Maintenance of Boiler (or reactor) Plant199269 149331

32 Maintenance of Electric Plant1861838 5929758829183 28711533 Maintenance of Misc Steam (or Nuclear) Plant

34 Total Production Expenses396995 33290

35 Expenses per Net KWh93242625 8519584

36 Fuel: Kind (Coal, Gas, Oil, or Nuclear)0.0260

Gas0.0877

37 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate) MCFGas Oil Composite

38 Quantity (Units) of Fuel Burned 25340194 0 0MCF BBLs

39 Avg HeatCont - Fuel Burned (btu/indicate if nuclear) 1016 01522654 3 0

40 Avg Cost of Fuet/unit, as Delvd f.o.b. during year0

3.048 0 000 0 0001010 137965 03 367

41 Average Cost of Fuel per Unit Burned. .

3.048 0.000 0.000. 78.350 0.000

3.367 78.350 0 00042 Average Cost of Fuel Burned per Million BTU 3.000 0.000 0.000 3.330 13.520 0 00043 Average Cost of Fuel Burned per KWh Net Gen 0.021 0.000 0.000.

0.053 0.011 0 00044 , Average BTU per KWh Net Generation 7162.000 0.000 0.000.

15840.000 845.000 15837.000


238

Name of Respondent


This Report Is:(1) R[An Original(2) DA Resubmission

Date of Report(Mo, Da. Yr)


2012/04End of

STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued)

9. Items under Cost of Plant are based on U. S. of A Accounts. Production expenses do not include Purchased Power, System Control and LoadDispatching, and Other Expenses Classified as Other Power Supply Expenses. 10. For IC and GT plants, report Operating Expenses, Account Nos.547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos. 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plantsdesigned for peak load service. Designate automatically operated plants. 11 For a plant equipped with combinations of fossil fuel steam, nuclearsteam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combinedcycle operation with a conventional steam unit, include the gas-turbine with the steam plant. 12. If a nuclear power generating plant, briefly explain byfootnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost unitsused for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for thereport period and other physical and operating characteristics of plant.PlantName: Knox Lee

(d)

PlantName: Lone Star

(e)

PlantName: Wilkes

(f)

LineNo.

Steam Steam Steam 1Outdoor Boiler Outdoor Boiler Outdoor Boiler 2

1950 1954 1964 31974 1954 1971 4

499.50 50.00 881.52 5403 49 793 65515 1279 6992 7

0 0 0 8

0 0 0 9475 49 841 1028 0 31 11

608492000 23685000 1202890000 12102781 58487 443729 13

7731231 836225 6952269 1455371172 5824834 75870934 152036608 123592 1093951 1665241792 6843138 84360883 17130.6142 136.8628 95.6993 18831892 51228 613325 19

21501444 1130777 41310757 20

0 0 0 21670405 188140 1195042 22

0 0 0 23

0 0 0 24677730 88854 645803 25703469 52948 719853 2614843 578 29342 271519 -1 1811 28

321747 1903 439752 2950938 14183 111633 30983142 254179 2339572 31799630 220737 859345 32

3776 -12390 51745 3326560535 1991136 48317980 34

0.0436 0.0841 0.0402 35Gas Oil Composite Gas Gas Oil Composite 36MCF BBLs MCF MCF BBLs 377220465 0 0 337205 0 0 13848787 509 0 381025 0 0 1049 0 0 1022 140000 0 392.970 0.000 0.000 3.350 0.000 0.000 2.970 113.140 0.000 402.970 0.000 0.000 3.350 0.000 0.000 2.970 113.140 0.000 412.900 0.000 0.000 3.190 0.000 0 000 2.910 19.240 0.000 420 035 0.000 0.000 0.048 0.000 0.000 0.034 0.234 0.000 4312163.000 0.000 12163.000 14931.000 0.000 0.000 11766.000 12141.000 11766.000 44


239

Name of Respondent This Report Is:^

Date of Report Year/Period of ReportSouthwestern Electric Power Company (1) An Original (Mo, Da, Yr)

(2) 0A Resubmission End of 2012/04

STEAM-ELECTRIC GENERATING PLANT STATISTICS ( Large Plants) (Continued)1. Report data for plant in Service only. 2. Large plants are steam plants with installed capacity (name plate rating) of 25 000 Kw or more Re ort i, . p nthis page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants. 3. Indicate by a footnote any plant leased or operatedas a joint facility 4. If net peak demand for 60 minutes is not available, give data which is available, specifying period. 5. If any employees attendmore than one plant, report on line 11 the approximate average number of employees assignable to each plant. 6 If gas is used and purchased on atherm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct. 7 Quantities of fuel burned (Line 38) and average costper unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20 8. If more than onefuel is burned in a plant furnish only the composite heat rate for all fuels burned.

Line Item Plant PlantNo. Name: Welsh Name: 'Flint Creek (1)(a) (b) (c)

1 Kind of Plant ( Internal Comb, Gas Turb, Nuclear Steam2 Type of Constr (Conventional, Outdoor, Boiler, etc) Outdoor Boiler

SteamOutdoor Boiler3 Year Originally Constructed

19774 Year Last Unit was Installed 1982

1978

5 Total Installed Cap (Max Gen Name Plate Ratings-MW) 1674 001978

6 Net Peak Demand on Plant - MW (60 minutes).

1576279.00

7 Plant Hours Connected to Load 7810267

8 Net Continuous Plant Capability (Megawatts) 07755

9 When Not Limited by Condenser Water 00

10 When Limited by Condenser Water 15840

11 Average Number of Employees264

12 Net Generation, Exclusive of Plant Use - KWh132

1028165000067

13 Cost of Plant. Land and Land Rights1888924000

14 Structures and Improvements1895474 3376087

15 Equipment Costs87964578 22986835

16 Asset Retirement Costs544850717 90942649

17 Total Cost4786571 3746582

18 Cost per KW of Installed Capacity (line 17/5) Including639497340 121052153

19 Production Expenses: Oper, Supv & Engr382.0175 433.8787

20,

Fuel3826417 942254

21 Coolants and Water (Nuclear Plants Only)210528995 33003763

22 Steam Expenses0

36600140

56374223 Steam From Other Sources 024 Steam Transferred (Cr) 0

25 Electric Expenses0

25966520

60113026 Misc Steam (or Nuclear) Power Expenses 534281227 Rents

721756

28 Allowances250803 46077

29 Maintenance Supervision and Engineering49094 4030

30 Maintenance of Structures617334 231760

31 Maintenance of Boiler (or reactor) Plant580259 640197

32 Maintenance of Electric Plant12371204 2887043

33 Maintenance of Misc Steam (or Nuclear) Plant3872412 384797

34 Total Production Expenses1085968 511679

35 Expenses per Net KWh244781964 40538228


Coal Oil Composite0.0215

Coal Oil Composite37 Unit (Coal-tons/Oil-barrel/Gas-mcf/Nuclear-indicate) TONs BBLs TONs BBLs38 Quantity (Units) of Fuel Burned 6376283 23925 0 1151342 1891 039 Avg Heat Cont - Fuel Burned (btu/indicate if nuclear) 8586 140000 0 8442 140000 040 Avg Cost of Fuel/unit, as Delvd f.o.b. during year 32.190 133.190 0.000 25.990 121 090 0.00041 Average Cost of Fuel per Unit Burned 32.190 133.190 0.000 25.990 121.090 0.00042 Average Cost of Fuel Burned per Million BTU 1.870 22.650 0.000 1.540 20.590 0.00043 Average Cost of Fuel Burned per KWh Net Gen 0.019 ^ 0.241 0.000 0.016 0.210 0.00044 Average BTU per KWh Net Generation 10663.000 10652.000 10663.000 10297.000 10220.000 10297 000


240

Name of Respondent

Southwestern Electric Power CompanyThis Re ort Is,(1) Ân Original(2) DA Resubmission



End of 2012/Q4

STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued)

9. Items under Cost of Plant are based on U. S. of A. Accounts. Production expenses do not include Purchased Power, System Control and LoadDispatching, and Other Expenses Classified as Other Power Supply Expenses. 10. For IC and GT plants, report Operating Expenses, Account Nos.547 and 549 on Line 25 "Electric Expenses," and Maintenance Account Nos 553 and 554 on Line 32, "Maintenance of Electric Plant." Indicate plantsdesigned for peak load service. Designate automatically operated plants. 11. For a plant equipped with combinations of fossil fuel steam, nuclearsteam, hydro, internal combustion or gas-turbine equipment, report each as a separate plant. However, if a gas-turbine unit functions in a combinedcycle operation with a conventional steam unit, include the gas-turbine with the steam plant. 12. If a nuclear power generating plant, briefly explain byfootnote (a) accounting method for cost of power generated including any excess costs attributed to research and development; (b) types of cost unitsused for the various components of fuel cost; and (c) any other informative data concerning plant type fuel used, fuel enrichment type and quantity for thereport period and other physical and operating characteristics of plant.PlantName: "PirkeY(2)

(d)

PlantName: 'Dolet Hills (3)

(e)

PlantName: Harry D Mattison

(f)

LineNo.

Steam Steam Combustion Turbine 1Outdoor Boiler Outdoor Boiler GasTurbine No Boiler 2

1985 1986 2007 31985 1986 2007 4

619.38 289.99 340.00 5572 266 294 6

6959 7579 722 7

0 0 0 8

0 0 0 9580 257 312 10102 0 2 11

3718244000 1870753000 101777000 125439861 1528836 1451852 13

107269421 52274419 34851323 14396019300 208776486 92753751 15

5104551 69004 0 16513833133 262648745 129056926 17829.5927 905.7166 379.5792 182436800 734608 79705 19

114974121 64682814 17774948 20

0 0 0 213327382 2310498 0 22

0 0 0 23

0 0 0 24899385 569855 515902 25

2611267 3098016 0 2690700 45634 0 277198 15014 0 28

1294637 549216 22047 29943959 594466 0 30

9869307 6980214 0 312479913 516433 620037 321031857 615390 2177 33

139966526 80712158 19014816 340.0376 0.0431 0.1868 35

Lignite Gas Composite Lignite Gas Composite Gas 36TONs MCF TONs MCF MCF 373048607 66608 0 1578793 41205 0 1331048 0 0 386550 1042 0 6653 1041 0 1014 0 0 3935.980 3.460 0.000 40 490 3.670 0.000 13.350 0.000 0.000 4035.980 3.460 0.000 40.490 3.670 0.000 13.350 0.000 0.000 412.750 3.320 0.000 3 040 3.520 0.000 13.160 0.000 0.000 420.030 0.037 0.000 0.034 0.039 0.000 0.175 0.000 0.000 4310759.000 10999.000 10759.000 11253.000 11150.000 11252.000 13266.000 0.000 0.000 44

T I IFERC FORM NO. 1(REV. 12-03) Page 403.1

241

Name of Respondent This Re ort is: Date of Report Year/Period of Re ortSouthwestern Electric Power Company (1) An Original (Mo, Da, Yr) p(2) MA Resubmission End of 2012/Q4

STEAM-ELECTRIC GENERATING PLANT STATISTICS (Large Plants) (Continued)1. Report data for plant in Service only 2. Large plants are steam plants with installed capacity (name plate rating) of 25,000 Kw or more. Reportinthis page gas-turbine and internal combustion plants of 10,000 Kw or more, and nuclear plants. 3. Indicate by a footnote any plant leased or operatedas a joint facility.

4. If net peak demand for 60 minutes is not available, give data which is available, specifying period.5 If any employees attendmore than one plant, report on line 11 the approximate average number of employees assignable to each plant.

6. If gas is used and purchased on atherm basis report the Btu content or the gas and the quantity of fuel burned converted to Mct. 7. Quantities of fuel burned (Line 38) and average costper unit of fuel burned (Line 41) must be consistent with charges to expense accounts 501 and 547 (Line 42) as show on Line 20 8. If more than onefuel is burned in a plant furnish only the composite heat rate for all fuels burned.

Line Item PlantNo. Plant

Name: Turk (4) Name:

1 Kind of Plant (internal Comb, Gas Turb, Nuclear2 Type of Constr (Conventional, Outdoor, Boiler, etc)

Steam

3 Year Originally ConstructedOutdoor Boiler

4 Year Last Unit was Installed2012

5 Total InstaliPd Can inn- r_e., nl...,,., oi_._ 2012

6- _....^ ,.,..,

Net Peak Demand on Plant - MW (60 minutes)523.60

7 Plant Hours Connected to Load375

8 Net Continuous Plant Capability (Megawatts)276

9 When Not Limited by Condenser Water0

10 When Limited by Condenser Water0

11 Average Number of Employees440

12 Net Generation, Exclusive of Plant Use - KWh105

13 Cost of Plant: Land and Land Rights106881000

14 Structures and Improvements11468781

15 Equipment Costs582245843

16 Asset Retirement Costs1018903569

17 Total Cost 0

18 Cost per KW of Installed Capacity (line 17/5) Includin1612618193

19g

Production Expenses: Oper, Supv, & Engr3079.8667

20 Fuel 50994

21 Coolants and Water (Nuclear Plants only)2509742

22 Steam Expenses0

23 Steam From Other Sources155172

24 Steam Transferred (Cr) 0

25 Electric Expenses0

26 Misc Steam (or Nuclear) Power Expenses-59

27 Rents 56333

28 Allowances 2607

29 Maintenance Supervision and Engineering-3

30 Maintenance of Structures266028

31 Maintenance of Boiler (or reactor) Plant36

32 Maintenance of Electric Plant2481

33 Maintenance of Misc Steam (or Nuclear) Plant-79

34 Total Production Expenses 84

35 Expenses per Net KWh 3043336


Coal G37 Unit (Coal-tons/Oil-barreUGas-mcf/Nuclear-indicate)

as CompositeTONs MCF

38 Quantity (Units) of Fuel Burned 58021 4217 0 039 Avg Heat Cont - Fuel Burned (btu/indicate if nuclear) 8521 102340 Avg Cost of Fuel/unit as Delvd f o b d i

0 0, . . . ur ng year 42.620 3.830 0 000 O41 Average Cost of Fuel per Unit Burned 42.620 3 830

. .0 00042 Average Cost of Fuel Burned er Milli BT

. . 0.p on U 2.500 3 750 0 000 043 Average Cost of Fuel Burned er KWh N G

. .p et en 0.023 0 035 0 000 044 Average BTU per KWh Net Generation 9292.000

.

9292 000. .

9292.000 0.


0.00

00

0

00

00

00

000

000

00

0

00

0

00

000

0

00

00000

0 0

0 0

000 0.000 0.000000 0.000 0.000)00 0.000 0.000)00 0.000 0.000)00 0.000 0.000

242 1


Southwestern Electric Power Company (2) A Resubmission 2012/04FOOTNOTE DATA

Schedule Page: 402 Line No.: - 1 Column: b

Arsenal Hill Unit 6(J. Lamar Stall Unit), a natural gas-fired combustion turbine combinedcycle generating unit, became operational in June 2010. Unit 6 consists of 2 combustionturbines feeding one steam turbine.

z)cneauie vage: 4oz.7 Line No.: -1 Column: c

Page 402.1 Line 0 Column (c)

(1) Flint Creek Power Station is jointly owned in the percentages shown below:

Southwestern Electric Power Company 50%Arkansas Electric Cooperative Corporation 50%

Total 100%

Page 403.1 Line 0 Column (d)

(2) Pirkey Power Station is jointly owned in the percentages shown below:

Southwestern Electric Power Company 85.936%Northeast Texas Electric Cooperative 11.720%Oklahoma Municipal Power Authority 2.344%

Total 100.000%

Page 403.1 Line 0 Column (e)

(3) Dolet Hills Power Station is jointly owned in the percentages shown below:

Southwestern Electric Power Company 40.234%Central Louisiana Electric Company 50.000%Northeast Texas Electric Cooperative 5.860%Oklahoma Municipal Power Authority 3.906%

Total 100.000

Page 402.2 Line 0 Column (b)

(4) Turk Power Station is jointly owned in the percentages shown below:

Southwestern Electric Power Company 73.33%Arkansas Electric Cooperative Corporation 11.67%East Texas Electric Cooperative 8.33%Oklahoma Municipal Power Authority 6.67%

Total 100.000%

scneaule Nage: 402.1 Line No.: -1 Column: d

5cneaule Page: 402.1 Line No.: -1 Column: e

Schedule Page: 402.2 Line No.: -1 Column: bTurk Plant, a 600MW Ultra-supercritical coal unit, became operational in December 2012.

FERC FORM NO. 1 (ED. 12-87 ) Page 450.1

243

Name of Respondent This Re ort Is:O i i(1) Â

Date of Report Year/Period of ReportSouthwestern Electric Power Company n r g nal

-(Mo, Da, Yr)

End of 2012/Q4(2) F J A Resubmission

TRANSMISSION LINE STATISTI CS1. Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage.2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts Do not reportsubstation costs and expenses on this page.3- Report data by individual lines for all voltages if so required by a State commission .4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.5 Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower;or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of constructionby the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from theremainder of the line6. Report in columns ( f) 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 for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line Report.pole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether ex enses thp wirespect to such structures are included in the expenses reported for the line designated.

LineNo.

DESIGNAI (Indicate where

other thanType of LE, ^Pole miles)

n t e ass ofd Number60 cycle , 3 hase Supporting

u ergrounlinesreport circuit miles) Of

From To Operating Structure of Line of Aqot er(a) (b) (c) (d) (e) Desigfl ated Line

1 345 kV in AR ( ( g) (h)

2 90-001 Chamber Springs Clarksville 345 345.0 345.00 1-6.85 6 853 90-009 Flint Creek GRDA GRDA 1 ( Interconnect) 345.0 345.00 2-3.04 3.044 90-010 Flint Creek CUS Brookline ( Interconnect 345.0 345.00 3-17.92 17.925 90-023 Chambers Spring Tontitown 345.0 345.00 1-11.5267 11.536 TL327 Turk (AR) NW Texarkana 345.0 345.00 2-22.15 22.157

8 Subtotal 345 kV in AR9

61 .49 5

10 345kVinLA11 90-005 Diana Southwest Shreveport 345.0 345.00 3-3.3 3.30 7.5012

13 90-008 Southwest Shreveport CLECO Dolet Hills 345.0 345.00 3-34.6 34.6014 (Interconnect)15 90-011 Longwood Entergy El Dorado 345.0 345.00 2-37.72 37.7216 (Interconnect)17 90-012 Longwood Southwest Shreveport 345.0 345.00 1-19.02 19.0218 90-013 Longwood Wilkes 345.0 345.00 3-3.06 3.0619

20 Subtotal 345 kV in LA,

2197.70 7.50 5

22 345 kV in OK23 90-001 Chamber Springs Clarksville 345 345.0 345.00 1-61.57 61.57 124

25 Subtotal 345 kV in OK61.57 1

26

27 345 kV in TX28 90-002 Crockett Entergy Grimes 345.0 345.00 3-26.4 26.40 129 (Interconnect)30 90-003 Lebrock Pirkey 345.0 345.00 2-0.11 6.30 0.47 131

3-6.1932 90-004 Diana Pirkey 345.0 345.00 2-0.15 24 75 133

3-24.634 90-005 Diana Southwest Shreveport 345.0 345.00 3-46.45 46.45 135 90-006 Diana W l he s 345.0 345.00 3-23.69 23.69 1

36 TOTAL 3,982.02 103 48 308

FERC FORM NO. 1 (ED. 12-87) Page 422

244

Name of Respondent


This Re ort is:(1) An Original(2) A Resubmission



TRANSMISSION LINE STATISTICS (Continued)

7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote ifyou do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report thepole miles of the primary structure 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. If such property is leased from another company,give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, forwhich the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining thearrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharingexpenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, orother 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 for year, and howdetermined. Specify whether lessee is an associated company.10. Base the plant cost figures called for in columns (j) to([) on the book cost at end of year.

Size ofConductor

COST OF LINE (I nc l ude in Co lumn Q Land ,

Land rights, and clearing right-of-way)EXPENSES, EXCEPT DEPRECIATION AND TAXES

and Material

(i)

Land

U)

Construction andOther Costs

(k)

Total Cost

(I)

OperationExpenseses

MaintenanceExpenses

Rents(o)

TotalExpenses

(p)

LineNo.

12x795.0 ACSR 22x1431.0 ACSR 3156.0 ACSR 4795.0 ACSR 5

954.0 ACSR 6

78910

156.0 ACSR 11795.0 ACSR 12

156.0 ACSR 1314

1024.0 ACAR 15

16795.0 ACSR 17

2x1024.0 ACAR 1819

20

21

22795.0 ACSR 23

24

25

26

271024.0 ACAR 28

291024.0 ACAR 30

2x1272.0 ACSR 311024.0 ACAR 32

33156.0 ACSR 34156.0 ACSR 35

63,897,350 641,146,183 705,043,533 246,957 4,744,792 4,991,74 36


245

Name of Respondent This Report Is:O i i l(1) A

Date of Report Year/Period of Re ortpSouthwestern Electric Power Company n r g na (Mo, Da, Yr)

End of 2012/04(2) A Resubmission

TRANSMISSION LINE STATISTICS1. Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132kilovolts or greater. Report transmission lines below these voltages in group totals only for each volta eg .2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not reportsubstation costs and expenses on this page.3. Report data by individual lines for all voltages if so required by a State commission.4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.5. Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower;or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of constructionby the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from theremainder of the line.6. Report in columns (f) 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 for the line designated, conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Reportpole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses ithwrespect to such structures are included in the expenses reported for the line designated.

LineNo

D A ( )Indicate where

oType of LENGTH Pole iles( ^^ mf }l s

. ther than urldergôund 11nes Number60 cycle , 3 phase ) Supporting report circuit miles) Of

From To Operating Designed Structure of Line of ^not er(a) (b) (c) (d) (e) Designated me

1 90-007 Diana W l h(r) (g) (h)

e s 345.0 345.00 3-23.6 23.60 12 90-013 Longwood Wilkes 345.0 345 00 3-35.34 35.34 13 1 90-014 Welsh Welsh DC 345.0 345.00 3-0.48 0.48 14 1 90-015 Northwest Texarkana Welsh 345.0 345.00 3-44.02 44.02 12.08 15 90-017 Welsh Wilkes 345.0 345.00 3-30.63 30.63 167 90-018 Crockett Tenaska Rusk County 345.0 345.00 3-67.14 67.14 18 90-019 Lebrock Pirkey 345.0 345.00 1-5.21 6.11 19

2-0.910 90-022 Lebrock Tenaska Rusk County 345.0 345.00 3-30.63 30.63 111

12 90-905 Welsh PSO Valliant ( Interconnect) 345.0 345.00 3-87.22 87.22 113 w/tap to NW Texarkana14 75000 (TL199) Welsh Monticello 345 0 345.00 3-16.0 16.00 115 TL328 Turk (TX) NW Texarkana 345.0 345.00 2-7.43 7.43 116

17 Subtotal 345 kV in TX18

476.19 12.55 16

19 Total 345 kV SWEPCO20

696.95 20.05 27

21 161 kV in AR22 83-001 Chamber Springs Tontitown 161.0 161.00 1-008 11.61 0.64 123 2-11.5324 83-002 Chamber Springs South Fayetteville 161.0 161.00 1-0.37 16.82 125

2-16.4526 83-003 Dyess East Rogers 161.0 161.00 2-13.42 13.42 127 83-004 Dyess T titon own 161.0 161.00 1-6.207 7.09 128

2-0.878829

30 83-005 Dyess Hyland 161 0 161.00 1-9.49 13.99 131

2-4.532 83-006 East Centerton East Rogers 161.0 161.00 1-9.18 9.18 133

34

35

36 TOTAL 3,982.02 103.48 308


246

Name of Respondent


This Report Is:(1) An Original(2) A Resubmission



TRANSMISSION LINE STATISTICS (Continued)

7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote ifyou do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report thepole miles of the primary structure 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. If such property is leased from another company,give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, forwhich the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining thearrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharingexpenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, orother 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 for year, and howdetermined. Specify whether lessee is an associated company.10. Base the plant cost figures called for in columns 0) to (I) on the book cost at end of year.

Size ofnductorC

--CDSTOF LINE ( I nclude in Co l umn 0 Land,

Land rights, and clearing right-of-way)EXPENSES, EXCEPT DEPRECIATION AND TAXES

oand Material

()

Land

U)

Construction andOther Costs

(k)

Total Cost

(D

OperationExpenses

(m)

MaintenanceExpenses

(n)

Rents

(°)

TotalExpenses

(p)

LineNo.

156.0 ACSR 1

x1024.0 ACAR 2

2156.0 ACSR 3

156.0 ACSR 4

156.0 ACSR 5

2x795.0 ACSR 6

2x1024.0 ACAR 7

1272.0 ACSR 89

x1024.0 ACAR 10

1272.0 ACSR 11

156.0 ACSR 12

795.0 ACSR 13

156 ACSR 14

954.0 ACSR 1516

17

18

19

20

21

1020.0 ACCC/TW 22

156.0 ACSR 23

1272.0 ACSR 24

2x397.0 ACSR 25

66.0 ACSR 26

1272.0 ACSR 27

156.0 ACSR 28

397.0 ACSR 29

1272.0 AAC 30

2x397.0 ACSR 31

1272.0 ACSR 32

1590.0 ACSR 3334

35

63,897,350 641,146,183 705,043,533 246,957 4,744,792 4,991,74 36


247

Name of Respondent

Southwestern Electric Power CompanyThis Report Is:(1) RAn Original(2) A Resubmission



TRANSMISSION LINE STATIST CS1. Report information concerning transmission lines, cost of lines, and expenses for year. List each transmission line having nominal voltage of 132kilovolts or greater. Report transmission lines below these voltages in group totals only for each voltage.2. Transmission lines include all lines covered by the definition of transmission system plant as given in the Uniform System of Accounts. Do not reportsubstation costs and expenses on this page.3. Report data by individual lines for all voltages if so required by a State commission.4. Exclude from this page any transmission lines for which plant costs are included in Account 121, Nonutility Property.5 Indicate whether the type of supporting structure reported in column (e) is: (1) single pole wood or steel; (2) H-frame wood, or steel poles; (3) tower,or (4) underground construction If a transmission line has more than one type of supporting structure, indicate the mileage of each type of constructionby the use of brackets and extra lines. Minor portions of a transmission line of a different type of construction need not be distinguished from theremainder of the line.6. Report in columns (f) 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 for the line designated; conversely, show in column (g) the pole miles of line on structures the cost of which is reported for another line. Reportpole miles of line on leased or partly owned structures in column (g). In a footnote, explain the basis of such occupancy and state whether expenses withrespect to such structures are included in the expenses reported for the line designated.

LineNo.

DES I GNAT ION VOLTAGE )(Indicate whereother than60 cycle , 3 hase

Type of

Supporting

LENGTH Pole miles)( In the â ofwldergrouns? lines

report circuit miles)Number

Of

1

From

(a)83-007 East Centerton

To

(b)Flint Creek

O eratinp 9(c)

161.0

Desi ned9(d)

161.00

Structure(e)

1-14.985

On Structureof Line

Designated(fl

14.99

On ru uresof Aqot er

Line(g)

5.28

Circuits

(h)

2345 83-008 East Rogers SWPA Beaver Dam 161.0 161.00 2-16.81 16.816 (Interconnect)7 83-009 Eureka Springs SWPA Beaver Dam 161.0 161.00 2-1.25 1.258 (interconnect)9 83-010 Eureka Springs Entergy Harrison 161.0 161.00 1-0.94 5.34

10 (Interconnect) 2-4.411 83-011 Eureka Springs SWPA Table Rock 161.0 161.00 2-1.25 1.2512 (Interconnect)13 83-012 Flint Creek EDE Decatur South 161.0 161.00 2-0.03 0.03 114 (Interconnect)15 83-013 Flint Creek Siloam Springs 161.0 161.00 1-5.4379 7.11 2.29 116 2-1.675417 83-014 Hyland Southeast Fayetteville 161.0 161.00 1-2.81 2.81 118 83-015 North Huntington OGE Fort Smith 161.0 161.00 2-13.1921 13.19 119 (Interconnect)20

21 83-016 North Huntington West Booneville 161.0 161.00 1-19.61 19.61 122 83-017 North Magazine Danville 161.0 161.00 1-25.9462 25.95 123 1 83-018 North Magazine VBI (OG&E) 161.0 161.00 2-8.8 8.80 124 83-020 Siloam Springs GRDA Siloam Springs 161.0 161.00 2-2.06 2.06 125 (Interconnect)26 83-021 South Fayetteville Southeast Fayetteville 161 0 161.00 1-2.96 2.96 127 83-022 North Magazine West Booneville 161.0 161.00 1-13.96 13.96 128 83-026 Dyess Tontitown 161.0 161.00 1-7.44 7.44 129 83-025 Chamber Springs Flint Creek 161.0 161.00 1-4.0138 14.35 130

2-10.337131 83-027 Flint Creek Tontitown 161.0 161.00 1-5.629 16.22 0.40 132 2-10.59433 83-028 Lowell Tontitown 161.0 161.00 1-11.2 11.20 134 83-029 Lowell Rogers 161.0 161.00 1-4.4 4.40 135 83-030 East Rogers Rogers 161.0 161.00 1-4.6 4.60 1

36 TOTAL 3,982.02 103.48 308


248

Name of Respondent This Re ort Is: Date of Report Year/Period of ReportSouthwestern Electric Power Company (1) [ An Original (Mo, Da, Yr)

End of 2012/04(2) A Resubmission

TRANSMISSION LINE STATISTICS (Continued)7. Do not report the same transmission line structure twice. Report Lower voltage Lines and higher voltage lines as one line. Designate in a footnote ifyou do not include Lower voltage lines with higher voltage lines. If two or more transmission line structures support lines of the same voltage, report thepole miles of the primary structure 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. If such property is leased from another company,give name of lessor, date and terms of Lease, and amount of rent for year. For any transmission line other than a leased line, or portion thereof, forwhich the respondent is not the sole owner but which the respondent operates or shares in the operation of, furnish a succinct statement explaining thearrangement and giving particulars (details) of such matters as percent ownership by respondent in the line, name of co-owner, basis of sharingexpenses of the Line, and how the expenses borne by the respondent are accounted for, and accounts affected. Specify whether lessor, co-owner, orother 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 for year, and howdetermined. Specify whether lessee is an associated company.10. Base the plant cost figures called for in columns Q) to (I) on the book cost at end of year.

COST LI NE ( I nclude in Co l umn (j and,EXPENSES, EXCEPT DEPRECIATION AND TAXES

Size of Land rights, and clearing right-of-way)Conductor

and Material Land Construction and Total Cost Operation Maintenance Rents Total Line0) G)

Other Costs(k) I

Expenses Expenses Expenses( ) (m) (n) (o) (p) No.

1020.0 ACCCITW1

1590.0 ACSR 22 156.0 ACSR

34

666.0 ACSR56

95.0 ACSR7

866.0 ACSR

910

95.0 ACSR11

12795.0 ACSR

13

14397.0 ACSR

15

16397.0 ACSR

171272.0 ACSR

1897.0 ACSR

1995.0 ACSR

2097.0 ACSR

211272.0 ACSR

2250.0 CW

23397.0 ACSR

24

252x397.0 ACSR

26397.0 ACSR

272156.0 ACSR

281272.0 ACSR

29397.0 ACSR

302156.0 ACSR

31397.0 ACSR

321590.0 ACSR

331590.0 ACSR

341272.0 ACSR

35

63,897,350 641,146,183 705,043,533 246,957 4,744,792 4,991,74 36


249

Name of Respondent This Report Is: Date of Report Year ...

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