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

AUSLEY & MCMULLEN ATTORNEYS AND COUNSELORS AT LAW

123 SOUTH CALHOUN STREET

P .O . BOX 391 (ziP 32302 )

TALLAHASSEE. FLOR I DA 32301

(8501 224·9115 FAX (8501 222· 7560

- :.D w

COM

Ms. Carlotta Stauffer, Director Office of Commission Clerk Florida Public Service Commission 2540 Shumard Oak Boulevard Tallahassee, FL 32399-0850

December 26, 2013

HAND DELIVERED

Re: Fuel and Purchased Power Cost Recovery Clause with Generating Performance Incentive Factor FPSC Docket No. 130001-EI

Dear Ms. Stauffer:

() 0

n 3: r ::.:: rrl -;:o(f) ~(f)

C) ... ......

0 rr1 ("")

N 0'1

:1!"" :X

C>

N ....J

Enclosed for filing in the above docket, on behalf of Tampa Electric Company, are the original and ten (I 0) copies of Schedules A I - A9 & A 12 for the month of November 2013 and revised pages for .Schedule A4s for the months of July 2013 (Bates page 8), August 2013 (Bates page 8), and October 2013 (Bates page 8).

Please acknowledge receipt and filing of the above by stamping the duplicate copy of this letter and returning same to this writer.

Thank you for your assistance in connection with this matter.

Sincerely,

@]}) - !:>---

~~~ },PA ' !:co 1 ENG I

James D. Beasley

GCL - 1- ...+-JDB/ne 10~1 I ~nclosure TEL CLK --.-c: All Parties of Record (w/enc.)

Michael Barrett (w/cd - Schedules A1-A9)

m 0 :I! < •T"! '. t

0 I -" \..)

(/) ()

CERTIFICATE OF SERVICE

I HEREBY CERTIFY that a true CW of the foregoing Schedules, has been furnished by

U.S. Mail or hand delivery(*) on this 1.-(, day of December 2013 to the fo llowing:

Ms. Martha Barrera* Senior Attorney Office of General Counsel Florida Public Service Commission 2540 Shumard Oak Boulevard Tallahassee, FL 32399-0850

Mr. John T. Burnett Ms. Dianne M. Triplett Duke Energy Florida, Inc. Post Office Box 14042 St. Petersburg, FL 33733-4042

Mr. Paul Lewis, Jr. Duke Energy Florida, Inc. l 06 East College A venue, Suite 800 Tallahassee, FL 32301-7740

Mr. Jon C. Moyle, Jr. Moyle Law Firm 118 N. Gadsden Street Tallahassee, FL 32301

Ms. Patricia A. Christensen Associate Public Counsel Office of Public Counsel Ill West Madison Street- Room 812 Tallahassee, FL 3 23 99-1400

Ms. Beth Keating Gunster, Yoakley & Stewart, P.A. 215 S. Monroe St., Suite 618 Tallahassee, FL 32301

Mr. Randy B. Miller White Springs Agricultural Chemicals, Inc. Post Office Box 300 White Springs, FL 32096

Ms. Cheryl Martin Director, Regulatory Affairs Florida Public Utilities Company 1641 Worthington Road, Suite 220 West Palm Beach, FL 33409

Mr. John T. Butler Assistant General Counsel - Regulatory Florida Power & Light Company 700 Universe Boulevard Juno Beach, FL 33408-0420

Mr. Kenneth Hoffman Vice President, Regulatory Relations Florida Power & Light Company 215 South Monroe Street, Suite 810 Tallahassee, FL 32301-1859

Mr. Robert L. McGee, Jr. Regulatory and Pricing Manager Gulf Power Company One Energy Place Pensacola, FL 32520-0780

Mr. Jeffrey A. Stone Mr. Russell A. Badders Mr. Steven R. Griffin Beggs & Lane Post Office Box 12950 Pensacola, FL 32591-2950

Mr. Robert Scheffel Wright Mr. John T. LaVia, III Gardner, Bist, Wiener, Wadsworth,

Bowden, Bush, Dee, La Via & Wright, P.A. 1300 Thomaswood Drive Tallahassee, FL 32308

Ms. Cecilia Bradley Senior Assistant Attorney General Office of the Attorney General The Capitol - PLO 1 Tallahassee, FL 32399-1050

Mr. James W. Brew Mr. F. Alvin Taylor Brickfield, Burchette, Ritts & Stone, P.C. 1 025 Thomas Jefferson Street, NW Eighth Floor, West Tower Washington, D.C. 20007-5201

A~RNEY

TAMPA ELECTRIC

1. Schedule A1- A9 & A12

2. Schedule A4 Revised

3. Schedule A4 Revised

4. Schedule A4 Revised

TAMPA ELECTRIC COMPANY

TABLE OF CONTENTS

November 2013

October 2013

August 2013

July 2013

TAMPA ELECTRIC COMPANY DOCKET NO. 130001-EI

15 Pages

1 Page

1 Page

1 Page

s

COMPARISON OF ESTIMATED AND ACTUAL FUEL AND PURCHASED POWER COST RECOVERY FACTOR

TAMPA ELECTRIC COMPANY

MONTH OF: November 2013

MWH ----------------· 1. Fuel Cost of System Net Generation (A3)

2 Spent Nuclear Fuel OisposaJ Cost

3. CosJ Car Investment

4a. Adjustments to Fuel cost {Polk 1 eonversM;.n depre<:i.ation & ROI)

4b. Adjustments to Fuel Cost

5 . TOTAL COST OF GENERATED POWER (Lines 1 through •bl

6 FueJ Cost of Purchased Power . Firm (A7)

7 Energy CoSI of Sell c.x Eeon Puroh (Broker) (A91

8 . Energy CoSI of Other Eeon. Purch. (Non-Broker) (A91

9. Energy Cost of Sch E Economy Purcnases (A9)

to CapaCity Cost of S<:h E Economy Purchases

11 Payments to Qualifying Faohties (A8)

12. TOTAL COST OF PURCHASED POWER (Lines 6 through 111

13. TOTAL AVAILABLE KWH (LINE 5 +LINE 121

14. Fuel Cost or Sen o Jurisd. Sales (A61

15. Fuel Cost of Sell. C/CB Sates (A61

16. Fuel Cost ofOATI &lies (A6)

17. Fuel Cost of Market ease Sates (AS)

18. Gains on Sa'es

19. TOTAL FUEL COST AND GAINS OF POWER SALES

(LINE 14 + 15 + 16 • 17 + 18)

20. Net lnadven•nt Interchange

21. Wheeling Rec'd, less VI/heeling Oelv"d.

22. Interchange and Wheeling losses

23. TOTAL FUEL AND NET POWER TRANSACTIONS

(LINE5+ 12 · 19•20+21·22)

24. Net Unbilled

2.S. Company Use

26. T & 0 l osses

27. System KWH Sales

28. \Nholesate KWH Sales

29. Junsdictional K\1'111 sales

30. Jurls.dictlonaJ loss Muliplier

31. JuriSdictional KWH Sales Adjusted for Line losses

32. 01her

33. True-up •

34. Total JunsdlctionaJ Fuel Cos.t (Exct GPIF)

35. Revenue Tax Factor

36. Fuel Cost Adjusted for Taxes (Ex<l. GPIFI

37 GPIF • (Already Adjusted for Taxes)

38. Fuel Cost Adjusted for T~xes tine: I. GPIF}

39. Fuel FAC Rounded to the Nearest .001 c•nts per KWH

ACTUAL

405.589

•7.890,299

1.007.525

1.598.915

4 14.397

3,020,837

22,284

176.101

0

112.915

30,264

3.1.5S.

50,569,572

(3.893.122) (a)

92.674 (a)

1.229.812 (a)

50.569.572

50.569,572

50.569,572

(5.776.655)

44.792.917

44.825.168

(44.835)

U ,780,333

• Bas~ on JurisdictionaJ Sales. (a) included for informational purposes only

ESTIMATED

50.776.276

363.006

51,139,282

80.310

930.160

728.230

1.738.700

0

0

286.062

28.638

3U,700

52,563,282

(4.833.553) (a)

106.901 (a)

3 .856.316 (a)

52.563.282

52.563.282

52.563.282

(5.776.655)

46,786.627

46,820,313

(44,835)

46,775,. 78

AMOUNT

(3.291 .5661

42.583

0

(3,2.8,9831

927.215

668.755

0

0

0

(313.833)

1.282,137

22.284

176.101

0

(173.1471

1,626

26,86.

(1,993,710)

840.431

(14,227)

(2.626.504)

(1.993.710)

(1 .993.710)

(1.993.710)

(1 .993.710)

(1.995.145)

p.995,1.S)

%

-6.5%

0.0%

0.0%

117%

0.0%

·6 .• %

1154.5%

719%

0.0%

0.0%

0.0%

-431%

73.7%

0.0%

00%

0.0%

-60.5%

5.7%

8 .5%

·3.8%

-19.5%

-13.3%

-681%

-3.8%

0 .0%

·38%

·3.8 %

0 .0%

0.0%

-4 3%

·4.3%

0.0%

... 3%

ACTUAL

1.317, 196

0

0

0

1,317,196

22.388

44,198

0

0

0

14,591

81.177

1,398,373

809

6.256

0

4.373

11 •• 38

150

3 .994

3,986

1,387,093

(106,7861

2.542

33.733

1,457,604

1,457.604

1,457.604

1..57.604

1,457.604

1,.57.604

1 .• 57.604

1.457.604

1 •• 57,60.

ESTIMATED

1.315.830

0

0

0

0

1,315,830

1,500

28.450

0

0

0

16.030

.5.980

1,361,810

9,460

9 •• 80

152

1.352,178

(12042)

2 .750

99.203

1,374,567

1.374.567

1,374,567

1.374.567

1,37 • • 567

1.374.567

1.374.567

1.374.567

1,37 •• 567

DIFFERENCE CENTS/KWH ·------------ ·---------------AMOUNT

1.366

0

0

•t.

0.1%

0 .0%

0 .0%

ACTUAL

3 .60498

0.00000

0.00000

0 0 .0% 0.00000

------~0~ ~ --~0-~00000~~ 1.366 o .w. 3.63578

20,888 1392.5% 4,50029

15.748 55 4% 3.61762

0 0 .0% 0 .00000

0 0 .0% 0 00000

0 0 0% 0.00000

---~(1_,::. 4~39'!1.1 -9.0% 2.84009

35,197 76.5% 3 ,72130

36,563 2 .7%

809 0 .0%

6.256 0.0%

0 0 .0%

(5,107)

1,958

150

3.994

·53.9%

20.7%

0 .0%

0.0%

3.8J4 2519.1%

3 • • 915 2.6%

17.556 · 14 1%

(208) -7.6%

(65.470) -66.0%

83.037

83.037

83.037

83.037

83.037

83,037

6.0%

0 .0%

6.0%

60%

6.0%

6 .0%

6 .0%

83,037 6 .0%

83,037 ~

83,037 6.0%

2.7545 1

2 81491

0.00000

2.56209

2.98622

3.64572

3 .64572

3 .64571

3.64572

3 .46936

0 .00000

3.46936

100000

3.46936

0 00000

(0.396311

3 .07305

I 00072

3.07526

(0.00308)

3.07218

3.072

ESTIMATED

3 .85688

0 .00000

0.00000

0.00000

0.00000

3 .88S.7

5 .35400

3 .26846

0 .00000

0.00000

0 .00000

4.54292

3 .781.3

0.00000

0.00000

0 .00000

3.01753

3.31962

3.88731

3 .88731

3 .88731

3 .88731

3 .82399

0.00000

3 .82399

1.00000

3 .82399

0 .00000

(0.42025)

3 .40374

1 00072

3.40619

(0.00326)

3 .• 0293

3 •• 03

SCHEDULE AI PAGE 1 OF 2

(0 25389)

0.00000

0.00000

-6.6%

0.0%

0.0%

0.00000 0 .0%

0.00000 ~

(0.250691 -6.5%

(0 85371) · 15.9%

0.34816 10.6%

0.00000 0 .0%

0.00000 0.0%

0.00000 0.0%

(1.70283) -37.5%

(0.060131 ·1.6%

2.75451 0.0%

2.81491 0 .0%

0 .00000 0.0%

(0.43544) -14.4%

(0.333.0) -10.0%

(0.241561 -6.2%

(0.241601 -6.2%

(0.24156) ~

(0.354631 -9.3%

0 .00000 0 .0%

(0.354631

0 .00000

(0.354631

0.00000

0.02384

(0 330661

0.00000

·9 .3%

0 .0%

-9.3%

0 .0%

-5.7%

·9 .7%

0 .0%

(0.330931 ·9.7%

0.00019 ~

(0.3307.) ~

(0.3311 -9.7%

COMPARISON OF ESTIMATED AND ACTUAL FUEL AND PURCHASED POWER COST RECOVERY FACTOR

TAMPA ELECTRIC COMPANY PERIOO TO DATE THROUGH; November 2013

-------~--------· DIFFERENCE MWH --------------·----------------

I Fuel Cost ol Syo10111 Nel G_.,.,n ~)

2 S~nt Nuc:l .. r Fuel Otsposal Coot

3 Coal Car lnvestmef'll

4a AdJustments to Fuel Cost (Polk 1 conyers.on deprectahon & ROI)

•b AdJultmenta to fuel Col1

5. TOTAL COST OF GENERATED POWER (llnu 1 through 4b)

6 Fuel Coli or PurCI>aotd Power · Form (A7)

7 Energy Coot o r 5th C .X Econ Purth. (Broker) (A9)

8. Energy Coot o r Other Eeon Purch (Non-Broke~ (A9)

9. Energy Cost o r 5th E Economy Purchases (A9)

10. Capacky CoOl or 5th E Economy Purchases

11 Paymenl>to Ouotilylng Facll~les (A8)

12. TOTAL COST OF PURCHASED POWER (Lineo 6 1hrough 11)

13. TOTAL AVAILABLE KWH (LINE 5 +LINE 12)

14. FueiCostorSth OJurisd Sales(A6)

15 Fuel Coot or 5th CICB Sales (A8)

16 FueiCOOIOI0ATTSalti(A8)

17 Fuol Coot or Mario.el Bast Sales (A8)

18 Gaono on Salts

1t. TOTAL FUEL COST AND GAINS OF POWER SALES

(UNE 14 • 15 • 16 • 17 • 18)

20 Nolin- lnterCI>ango

21 -long Roc'd less 'MIHiong Ootv'd

22 1ntorCI>onge and Whoftrlg Loss ..

23. TOTAL FUEL AND NET POWER TRANSACTIONS

(UNE 5 • 12 • 19 • 20 • 21 · 22)

24 NoiUnbllod

25 Company use 26 T &Dloss.,

27 Syotem K- Sales

28 Wholooalt K- Salts

29 Jun>dotelonal KWH Sales

30 Juri>dlc~onal lou Mukoplltr

31 JunSd~•onel KVVH Seles A<f,ulttd tor Line Losses

32 Other

33 True-up •

34. Total Jurlsdlcclonal Fuel CoOl (E<tl GPIF)

35. Revenue Ta• Faccor

36 Fuel Cost AdfU>Ied !Of To xu (Excl GPIF)

37. GP IF ' (A!Jeady Adjulled 101 Taxes)

31, Fuel Cost AdJusted for Tu11 (Incl. GPIFt

39. Fuel FAC Rounded to the ~artsl .001 cents ~r KWH

ACTUAL

632.525.209

0

0

2.050.983

0

634,576,192

7.121,582

16.553.299

0

0

7.333.625

31,001,506

334.972

4,490,889

0

1,423.601

865,'59

7,114,721

654,>169,977

(2.000,854) (I)

1137.149 (1)

27,483,558 (I )

658.469.977

0

658,469.977

658.469.977

0

(63.543,205)

594,926,772

595.355,119

(493,185)

594,861,934

• Based on JuriSdtc:bontl Sllea (a) •neludeCJ for if'ltonnattonal purposes onty

ESTIMATED

S66,015827

0

0

2 210 562

0

668,226,3Jt

4 ,568 200

1<.318 210

0

0

0

7.650.250

26.536.660

0

0

0

4 407.570

441 .240

4 ,841,110

6U,t14,23t

(2 .. 201<) (I )

1 175 357 (a)

35.887 127 (I )

889,91< 239

0

689.914.239

689.914.239

(63,5-43.205)

826.371 ,034

626.822.022

(493.185)

626,328,837

AMOUNT

(33490618)

0

0

(15t.579)

0

(33.150,117)

2.553,382

2 235089

0

0

0

(316.625)

4 ,471,t46

334.972

4 ,490,889

0

(2.$83.1169)

424.219

2,215,911

441160

(38 208)

(8 403 569)

(31 ... 4 262)

0

(31 .444 ,262)

(31 ,444,262)

0

0

(31 ,444.262)

(31 .486.903)

0

(31,41U03J

·5~

0~

0~

-72%

0~

4 .0%

559%

156%

0~

0.~

0.~

. 4,1%

16.9%

0~

0~

0~

-677%

961%

'6.7%

-18 t%

·33%

-23 4%

-4 6%

00%

-46%

00%

00%

·5.0%

-5.0%

ACTUAL

17,0«.086

0

0

17,044,016

197.331

474.550

0

0

259.121

931,002

17,975,088

12.268

149.043

51.230

211,581

(134)

35301

38,599

17,759 ,135

(54 959)

30,748

741 ,749

11041 .596

17,041 ,596

17.041 ,596

17,041 .596

17,04 1,596

17,041 .596

17,041 ,596

17.041.596

17,041,596

ESTIMATED

17.210,130

11,210,130

81 .200

406.450

177,610

665,260

17,875,390

0

135,480

135,410

0

0

2, 175

17,737,735

(61,781)

30,250

921,773

16.847,493

0

16.847.493

16,847,493

16.847,493

16,847,493

16.847,493

16.847.493

16.847.493

16,847,493

SCHEDULEA1 PAGE 2 OF 2

DIFFERENCE CENTS/KWH DIFFERENCE ·------------ ·----------------------------· AMOUNT ACTUAL ESTIMATED

(166,044) -1~ 371111

0~ 000000

0~ 000000

0 0~ 000000

-----'~ ~ _....::,0:::00000=~

3 86991

000000

000000

000000

000000

(166,044) ·1.0% 3.72315 3.11275

5 62586

3 52275

000000

0.00000

000000

4 .30733

116.131 1<3 0% 3 60895

68.100 16 8 % 346821

0~ 000000

0~ 0.00000

0~ 000000

81 .511 ~ _ _:..2::.:830::.:.:19~

265,742 3U% 3.330U 3.91U2

99,691

12288

1<9,043

(84.250)

77,011

(134)

35301

36 424

0.6%

00%

00%

00%

-62 2%

SJ.t%

0 0%

0~

1674 ~

2 72601

3 0 1302

000000

2 77884

3.34714

000000

000000

000000

3 25330

3 .57199

21,400 ~ _.....;3;:;.7;.;0;.:.77.:.;1:.. ___ .;:3;;.1:.:1.:;t5:.;3;..

6 822 · 11 0% 3 64063 3 95269

498 I 6% 3 69823 3 8!548

(180.024) ~ -~3 .:.:705::;2::.;4;.. __ ___;3:.;8::.::9:=;32:.;7_

194.103

194,103

194, 103

194. 103

194,103

194. 103

t 2% 3 86390 4 09506

~ _....::,0 :::00000=:.. __ ___;0:.:00000=::::..

I 2% 3 68390 4 09506

1 2%

12%

1 2%

1.2%

I 00000 I 00000

3 86390 4 09506

0 00000 0 00000

(0 37287) (0 37717)

3.49103 3.71789

1 00072 1 00072

194. 103 1.2% 34935-4 3.72057

194, 103 ~ (000289) (000293)

194103 ~ _....;3-..4;.;--5- ----3;.;.7.,;1;,;76_4_

3.491 3.711

AMOUNT

(0 15879)

0 00000

000000

0.00000

... I%

0~

0.~

D.~

000000 0.~

(0.15960) ... 1%

(2.01691) ·35.9%

(0.03454) ·1,0%

0.00000

0.00000

0.00000

0.0%

0.0%

0.0%

(1 .47714) ~

(0 .65826)

2 72601

3 .0 1302

000000

(0474~)

(0.23184)

-16.5%

0.0%

0.~

0.0%

·14.6%

-6.5%

(0.11175) ~

(0 31206) -7 9%

(0 18725) .. 8%

(0 18804) .. 8%

(0 23116) ·5.6%

000000 0.~

(0.23116)

0.00000

(0 23116)

0.00000

0.00430

(0 .22686)

000000

·5.6%

0.0%

·5.6%

0.0%

·1 .1%

-6. 1%

0 .0%

(0 .22703) ·6.1%

000003 ~

(0.22700) -6.1%

(0.227) -6.1%

SCHEDULE A.2 PAGE 1 Of 3

CALCULAT10N OF TRUE-UP AND INTEREST PROVISION TAMPA ELECTRIC COMPANY

MONTH OF: November 2013

CURRENT MONTH PERIOD TO DATE DIFFERENCE DIFFERENCE

ACTUAL EST1MATEO -------------· ACTUAL EST1MATEO ------------· AMOUNT % AMOUNT %

A. FUEL COST & NET POWER TRANSACT10N

I FUEL COST OF SYSTEM NET GENERATION 47,484.710 50776276 (329\ 566) -6 5% 632 .525 209 666.015.827 (33,490.618) -50%

1a FUEL REL R & 0 AND DEMO COST 0 0 0 00% 0 0 0 00%

2 FUEL COST OF PO'M:R SOLO 311 .300 286.062 25.238 8.8% 6,249,282 4,407.570 1.841.692 41 ,8%

2a GAINS FROM SALES 30,284 28.638 \,626 5.7% 865,459 441 ,240 424.219 961%

3 FUEL COST OF PURCHASED POWER 1,007,525 80.310 927.215 1154.5% 7, 121,582 4,568.200 2,553.382 559%

3a DEMAND & NONFUEL COST OF PUR PWR 0 0 0 00% 0 0 0 00%

3b PAYMENT TO QUALIFIED FACILITIES 4 \ 4 397 728,230 (313 833) -431% 7,333.625 7,650.250 (316 625) -41%

4 ENERGY COST OF ECONOMY PURCHASES 1,598.915 930, 160 668 755 719% 16,553299 14,318,210 2 235089 156%

5 TOTAL FUEL & NET PO'M:R TRANSACT10N 50,163,983 52,200,276 (2.036.293) -39% 656,418,994 687,703.677 (31 .284.683) -4 5%

6a. ADJUSTMENTS TO FUEL COST (Polk 1 convers~on depreciation & RQI) 405,569 363,006 42,563 1\ 7% 2.050,983 2.210.562 (159,579) -7 2%

6b. ADJUSTMENTS TO FUEL COST 0 0 0 0.0% 0 0 0 00% 7. ADJUSTED TOTAL FUEL & NET PWR TRANS 50,569,572 52.563,282 ( 1,993.710) ·3.8% 658,469,977 689,914.239 (31 .444.262) -46%

B. MWHSALES

I JURISDICTIONAL SALES 1,457,604 1.374 567 63,037 6 0% 17.041 .596 16.847.493 194103 1.2%

2 NONJURISOICTIONAL SALES 0 0 0 0 0% 0 0 0 00%

3 TOTAL SALES 1,457.604 1.374.567 83,037 6.0% 17.041 ,596 16,847,493 194, 103 1 2%

4 JURISDIC. SALES-% TOTAL MWH SALES 1 0000000 1 0000000 0.0000000 0.0% 1 0000000 I 0000000 0.0000000 0.0%

C. TRUE.OP CALCULAnON

1 JURISDICTIONAL FUEL REVENUE

FUEL ADJUSTMENT NOT APPLICABLE

2a TRUE-UP PROVISION

2b. INCENTIVE PROVISION

2e ADJUSTMENT

3 JURIS FUEL REVENUE APPL TO PERIOD

4 ADJ TOTAL FUEL & NET PWR TRANS (LINE A7)

~ JURISDIC SALE5- % TOTAL MWH SALES (LINE 84)

6 JURISOIC TOTAL FUEL & NET PWR TRANS

6a JURISOIC LOSS MULTIPLIER

6b (LINE C6 x LINE C6a)

6e OTHER

6d JURISOIC TOTAL FUEL & NET PWR

INCL All ADJ (LNS C6b+C6e)

7 TRUE-UP PROV FOR MO +/- COLLECTED

(LINE C3 • LINE C6d)

8 INTEREST PROVISION FOR THE MONTH

9 TRUE-UP & INT PROV BEG OF MONTH

10. TRUE-UP COLLECTED (REFUNDED)

, END OF PERIOD TOTAL NET TRUE-UP (LINE C7 through C10)

CALCULA OON OF TRUE.OP AND INTEREST PROVISION TAMPA El.ECTRIC COMPANY

MONlli OF: November 2013

CURRENT MONlli DIFFERENCE -------------· AMOUNT %

ACTUAL ESnMATED

53 381 .825 50,521 628 2,860,197 57%

0 0 0 00%

5,776,655 5.776,655 0 00%

44,835 44,835 0

0 0 0 0.0%

59.203,315 56.343,118 2,860,197 5.1%

50.569.572 52.563,282 ( 1,993,710) ·3.8%

10000000 10000000 00000000 00%

50,569 572 52 563,282 (1993,710) -38%

100000 100000 000000 0.0%

50569,572 52 563282 (1.993 710) -38%

0 0 0 00%

50569,572 52,563282 (1,993,710) -38%

8.633,743 3,779 836 4,853,907 128A%

1,983 1,974 9 0.5%

ACTUAL

628813.567

0

63.543.205

493.185

0

692.849,957

658,469,977

658.469977

658469.977

0

658,469.977

34 379,980

36,731

38.237,364 8,048,779 30,188,585 375.1% --------

SCHEOUL.E A2 PAGE 20F 3

PERIOD TO OA TE DIFFERENCE ------------· AMOUNT %

ESnMATED

626,039,193 2,774,374 0.4%

0 0 0.0%

63,543.205 0 0.0%

493,185 0 0.0%

0 0 0.0%

690.075,583 2,774,374 04%

889,914,239 (3 1 ,444,262) -4.6%

0.0%

88~.914,239 (31.444.262) -4.6%

00%

889.914 239 (31 444,262) -46%

0 0 00%

889,914,239 (31,444,262) -46%

161,344 34 218,636 21208.5%

115,937 (79,206) -68.3%

·NOT APPLICABLE------

(5.776.655) (5,776,655) 0 __ ___;0:::..0::..:%.:.·--·--·----iNOT APPLICABLE-------------

41,096,435 6,053,934 35.042,501 ===5:.7.;.;8·.;.8%= ---·-·-------NOT APPLICABLE----·-·----

D. INTEREST PROVISION

1 BEGINNING TRUE-UP AMOUNT

(LINE C9)

ENDING TRUE·UP AMOUNT BEFORE INT

(LINES C7 + C9 + C 10)

3 TOTAL BEG & END TRUE·UP AMOUNT

4 AVG TRUE-UP AMOUNT · (50% OF LINE 03)

5 INT RATE-FIRST DAY REP BUS MONTH

(11 6 INT RATE-FIRST DAY SUBSEQUENT MONTH

7 TOTAL (LINE 05 + LINE 06)

8 AVERAGE INT RATE (50% OF LINE D7)

9 MONTHLY AVG INT RATE (LINE 08112)

10 INT PROVISION (LINE Q.l x LINE 09)

CALCULA TlON OF TRUE-UP AND INTEREST PROVISION TAMPA ELECTRIC COMPANY MONTH OF: November 2013

CURRENT MONTH DiFfERENCE

PERIOD TO DATE

SCHEDUL£A2 PAGE 30F 3

DIFFERENCE ACl\JAL ESTlMATED -------------· ACl\JAL ESTlMATED ------------· AMOUNT % AMOUNT %

38,237,364 8 048,779 30,168,585 375.1%------ NOT APPLICABLE

41 ,094.452 6,051 ,960 35.042.492 579.0%------ -----NOT APPLICABLE----··-

79.331 ,816 14,100.739 65.231.077 462.6%---- ·---NOT APPLICABLE-·-·

39.665,908 7,050.370 32,615.538 462.6% -----------NOT APPLICABLE

0050 0 330 (0280) -84.8% NOT APPLICABLE

0060 0 330 (0270) -$1 ,8% -----------NOT APPLICABLE-----

0110 0660 (0550) -$33% NOT APPLICABLE·

0055 0330 (0275) -$33% OT APPLICABLE

0005 0028 (0023) -$21% NOT APPLICABLE

1983 1974 9 05% NOT APPLICABLE

SCHEDULE A3 PAGE 1 OF 2

GENERATING SYSTEM COMPARATIVE DATA BY FUEL TYPE TAMPA ELECTRIC COMPANY MONTH OF: November 2013

CURRENT MONTH PERIOD TO DATE

ACTUAL ESTIMATED DIFFERENCE - "A;oi.i'Nr _____ "" ___ ACTUAL ESTIMATED

DIFFERENCE - "AMO'u"Nr-----,r--

FUEL COST OF SYSTEM NET GENERATION($) HEAVY OIL 0 0 0 0.0% 0 0 0 0.0%

2 LIGHT OIL 0 0 0 0.0% 2.070.6 17 2.476.727 (406.110) ·16.4% 3 COAL 30.260.877 32.064.878 (1 .804.001) ·5.6% 348,227.406 368.746.638 (20.519,.232) ·5.6% 4 NATURAL GAS 17,223,833 18.7 11 ,398 ( 1.487 .565) -8.0% 282,227.186 294.792.462 (12,565,276) -4.3% 5 NUCLEAR 0 0 0 0.0% 0 0 0 0.0% 6 OTHER 0 0 0 0.0% 0 0 0 0.0% 7 TOTAL($) 47,484,710 50,776,276 (3,291 ,566) -6.5% 632,525.209 666.015,827 (33,490,618) -5.0%

SYSTEM NET GENERATION (MWH) 8 HEAVY OIL 0 0 0 0.0% 0 0 0 0.0% 9 LIGHT OIL 0 0 0 0.0% 8.475 10,760 (2.285) ·21.2% 10 COAL 872,034 887.180 (1 5.146) ·1.7% 9,856.782 10.314,920 (458,138) -4.4% 11 NATURAL GAS 445,162 428,650 16.512 3.9% 7.178.829 6,884,450 294.379 4.3% 12 NUCLEAR 0 0 0 0.0% 0 0 0 0.0% 13 OTHER 0 0 0 0.0% 0 0 0 0.0% 14 TOTAL(MWH) 1 ,317,196 1,315,830 1.366 0.1% 17.044.086 17.210,130 (166.044) -1.0%

UNITS OF FUEL BURNED 15 HEAVY OIL (BBL) 0 0 0 0.0% 0 0 0 00% 16 LIGHT OIL (BBL) 0 3,630 (3.630) -100.0% 16.398 55,580 (39,182) -70.5% 17 COAL (TON) 374,180 361,080 (6.900) -18% 4.286.515 4.42.2,250 (135.735) -31% 18 NATURAL GAS (MCF) 3,413,274 3.193.490 219.784 69% 53.370.284 50.930.450 2,439.834 4.8% 19 NUCLEAR (MMBTU) 0 0 0 00% 0 0 0 0.0% 20 OTHER (MMBTU) 0 0 0 0.0% 0 0 0 0.0%

BTUS BURNED (MMBTU) 21 HEAVY OIL 0 0 0 0.0% 0 0 0 0.0% 22 LIGHT OIL (0) 0 (0) 00% 83.760 110.790 (27 .030) -24.4% 23 COAL 9.139.605 9,143.980 (4,375) 00% 103.404.024 106,079,280 (2,675.256) -2.5% 24 NATURAL GAS 3.467.202 3.282.940 184.262 5.6% 54 ,172.656 52.356.700 1,815,956 3.5% 25 NUCLEAR 0 0 0 0.0% 0 0 0 0.0% 26 OTHER 0 0 0 0.0% 0 0 0 0.0% 27 TOTAL (MMBTU) 12.606,807 12.426,920 179.887 1.4% 157.660.440 158,546,770 (886.330) -0.6%

GENERATION MIX(% MWH) 28 HEAVY OIL 0.00% 0.00% 0.00% 0.0% 0.00% 0.00% 0.00% 0.0% 29 LIGHT OIL 0.00% 0.00% 0.00% 0.0% 0.05% 0.06% -0.01% -20.5% 30 COAL 66.20% 67.42% -1.22% -1.8% 5783% 59.94% -2 .10% -3.5% 31 NATURAL GAS 33.80% 32.58% 1.22% 3.7% 42.12% 40.00% 2.12% 5.3% 32 NUCLEAR 0.00% 0.00% 0.00% 0.0% 0.00% 0.00% 0.00% 0.0% 33 OTHER 0.00% 0.00% 0.00% 0.0% 0.00% 0.00% 0 .00% 0.0% 34 TOTAL (%) 100.00% 100.00% 0.00% 0.0% 100.00% 100.00% 0.00% 0.0%

FUEL COST PER UNIT 35 HEAVY OIL (S/BBL) 0.00 0.00 0 .00 0.0% 0.00 0.00 0.00 0.0% 36 LIGHT OIL ($/SBL) 0.00 0.00 0 .00 0.0% 126.27 44.56 81.71 183.4% 37 COAL ($/TON) 80.87 84.14 (3.27) -3.9% 81.24 83.38 (2.15) · 2.6% 38 NATURAL GAS (SIMCF) 5,05 5.86 (0.81) -13.9% 5 29 5.79 (0.50) -8.6% 39 NUCLEAR (SIMMBTU) 0.00 0.00 0.00 0.0% 000 0.00 0.00 0.0% 40 OTHER (SIMMBTU) 0.00 0.00 0.00 0.0% 0.00 0.00 0.00 0.0%

FUEL COST PER MMBTU (SIMMBTU) 4 1 HEAVY OIL 0.00 0.00 0 .00 0.0% 0.00 0.00 0.00 0.0% 42 LIGHT OIL 0.00 0.00 0 .00 0.0% 24.72 22.36 2.37 10.6% 43 COAL 3.31 3.51 (0.20) -5.6% 3.37 3.48 (0.11) -3.1% 44 NATURAL GAS 4.97 5.70 (0.73) -12.8% 5.21 5.63 (0.42) -7.5% 45 NUCLEAR 0.00 0.00 0.00 0.0% 000 0.00 0.00 0.0% <16 OTHER 0.00 0.00 0.00 0.0% 000 0.00 0.00 0.0% 47 TOTAL (SIMMBTU) 3.77 4.09 (0.32) -78% 4 01 4.20 (0.19) -4.5%

6

48 49 50 51 52 53 54

55 56 57 58 59 60 61

GENERATING SYSTEM COMPARATIVE DATA BY FUEL TYPE TAMPA ELECTRIC COMPANY MONTH OF: November 2013

CURRENT MONTH

ACTUAL DIFFERENCE

ESTIMATED -AMOUNT-----;.<.-- · ACTUAL

BTU BURNED PER KWH (BTU/KWH) HEAVY OIL 0 0 0 0.0% 0 LIGHT OIL 0 0 0 0.0% 9.883 COAL 10,481 10,307 174 1.7% 10,491 NATURAL GAS 7,789 7,659 130 1.7% 7,546 NUCLEAR 0 0 0 0.0% 0 OTHER 0 0 0 0.0% 0

TOTAL (BTU/KWH) 9.571 9,444 127 1.3% 9.250

GENERATED FUEL COST PER KWH (cents/KWH) HEAVY OIL 0.00 0.00 0.00 0.0% 0.00 LIGHT OIL 0.00 0.00 0.00 0.0% 24.43 COAL 3.47 3.61 (0.14) -3.9% 3.53 NATURAL GAS 3.87 4.37 (0.50) -11.4% 3.93 NUCLEAR 0.00 0.00 0.00 0.0% 0.00 OTHER 0.00 0.00 0.00 0.0% 0.00

TOTAL (cents/KWH) 3.60 3.86 (0.26) -6.7% 3.71

7

SCHEDULE A3 PAGE 2 OF 2

PERIOD TO DATE

ESTIMATED

0 10,296 10,284 7,605

0 0

9.212

0.00 23.02

3.57 4.28 0.00 0.00 3.87

DIFFERENCE - -A'Mou'Nr - - ---.z---

0 0.0% (413) -4.0% 207 2.0% (59) -0.8%

0 0.0% 0 0.0%

38 0.4%

0.00 0.0% 1,41 6.1%

(0.04) -1.1% (0.35) -8.2% 0.00 0.0% 0.00 0.0%

(0.16) -4.1%

00

PLANT/UNIT

BBII BB~ B B l 3 BB 14 BB IGNITION B.B. COAL

(AI

B BC T 14 (GASI B BC T 14 (OIL) B.B.C.T. 14 TOTAL

BIG BEND STATION TOTAL

POLK I I GASIFIER POLK II CT (GASI POLK I I CT (OIL) POLK 11 TOTAL

POLK 12 CT (GAS) POLK 12 CT (OIL) POLKUTOTAL

POLK 13 CT (GAS I POLK 13 CT (OIL) POLKUTOTAL

POLK 14 (GAS)

POLK 15 (GAS)

POLK STATION TOTAL

COT I COT2 CITY OF TAMPA TOTAL

BAYSIDE ST 1 BAYSIDE CT1A BAYSIDE CT1B BAYSIDE CTIC BAYSIDE UNIT 1 TOTAL

BAYSIDE ST2 BAYSIDE CT2A BAYSIDE CT2B BAYSIDE CT2C BAYSIDE CT2D BAYSIDE UNIT 2 TOTAL

BAYSIDE UNIT 3 TOTAL BAYSIDE UNIT 4 TOTAL BAYSIDE UNIT 5 TOTAL BAYSIDE UNIT 6 TOTAL

BAYSIDE STATION TOTAL

SYSTEM Footnotes:

LEGEND: B.B • BIG BEND C T • COMBUSTION TURBINE COT • CITY OF TAMPA

(81

NET CAP·

ABIUTY (MW)

385 38S 365 407

--;:m-56

___ 56_

51 1,591

220 218

------m-151 159

---1,- 1-

151 159 _ __ 15_1_

151

151 824

0 0 '" ---0-

233 156 156 156

---70_1_

305 156 156 156 156

--;n 56 56 56 56

1,454

(CI

NET GENERATION

(MWH)

195.527 149,104 225,988 208.937

779,556

I 421 0

1,421 780,977

92.478 21 ,029

113,507

11 ,337 0

11,337

2,965 0

2,965

955

1,087

129,851

0 0 0

60,342 29,993 36,571 43944

170,850

78,317 22, 187 31,036 56,318 40716

221,574

448 2,383 1,826 2,287

406,368

(0)

NET CAPACITY

FACTOR (%)

704 53 7 859 712

70.1

35 00 3.5

67.8

583 134

71 .6

10 4 0.0

10.4

27 00 2.7

0.9

1.0 21.9

00 00 0.0

359 26 7 325 391 33.8

356 197 276 SO l 362 34.1

1.1 5.9 4.5 5.7

30.4

SYSTEM NET GENERATION AND FUEL COST TAMPA ELECTRIC COMPANY MONTH OF: Nowmt..r 2013

(E)

NET AVAIL.

FACTOR (%)

74 9 583 83 2 76 5

73. 1

999 999 99.t 74.1

78 8 808

80.8

1000 1000 100.0

1000 1000 100.0

28.0

100.0 81.7

00 00 0.0

77 4 69 8 73.8 71 4 51.0

750 45 I 59 7 73 4 750 38.3

9t.t 100.0 99.3 tl.5

50.5

(F)

NET OUTPUT FACTOR

(%)

908 916

102 8 896

93.8

899 00

89.9

93.8

938 46.4

88.5

69.3 0.0

69.3

75 7 0.0

75.7

11 .1

62. 1 85.7

00 00 0.0

63.3 84.5 82.8 81 .8 59.6

47.5 84.5 87.5 80.9 862 45.5

65.8 92.4 84.7 62.5

50.9

(GI

AVG. NET HEAT RATE BTU/KWH

10.511 10.232 10,423 10.443

10,414

12 217 0

12,217 10,417

11.045 8.669

10,605

11.713 0

11,713

12. 142 0

12,142

14.271

14,102 10,793

0 0

11.612 11,530 II 283 7,408

11.285 11.367 11,667 II 375 7,540

12,629 11.094 11,357 11 ,005

7.548

(H)

FUEL TYPE

(II

FUEL BURNED (UNITS)

COAL 84,832 COAL 63,545 COAL 97.907 COAL 91, 150 !Q!..Q!l,_ __ __,6.,06,_7,_

GAS 17,071 .!&!.Q!.L ------'0~

COAL GAS

36.746 183,283 .!&!.Q!.L __ ..;_ __

GAS 130.573 .!&!.Q!.L _ __ __;0,_

GAS 35,398 LGT OIL ------'0~

GAS

GAS

13,407

15,073

GAS 0

g:~ ----~~~

GAS 342,887 GAS 415, 126

g:~ ---,.1."'~~~ ... ~;.:8~:'-

G AS GAS GAS GAS GAS

GAS GAS GAS GAS

GAS

246,218 347.535 646,452 455 756

1.195,961

5,564 26.008 20,391 24,759

3,018,469

~ 1,3171196 42.7 Aa bumtd fuel co1t system total includes Ignition oil

•'*1 City of Tempe on Long Term Reserve St•nd-by.

65.3 73.9 9 569 ___,;,.._ ~~~~-ill Fuel burned (MM BT\J)aystem tollltxcludta Ignition oil.

(JI

FUEL HEAT VALUE (BTU/UNIT)

24,226,000 24,008,000 24.058,000 23.938.000

5 744 146

1,017,000 0

27,798,230 1,017,000

1.017.000

1,017,000 0

1,017,000

1.017,000

0 0 0

1.017,000 1,017,000 1 017 000 1,017,000

1,017,000 1.017,000 1,017,000 I 017 000 1,017.000

1,017,000 1.017.000 1,017,000 1,017,000

1.017,000

IKI

FUEL BURNED

(MM BTU)1"

2,055,146.6 1.525,584 8 2,355.455 7 2.181,954 9

34 848 4

17 361 0 00

17,361.0

1 ,135,503.0

1,021,463.2 182,304 0

1,203,767.2

132.793.0 0.0

132,793.0

36,0000 00

31,000.0

13.635.0

15,329.0

1,401,524.2

00 0.0 0.0

348,716.0 422. 182.0 496 065.0

1,266,963.0

250.404.0 353,442.0 657.441 0 463504 0

1,724,791.0

5,658.0 26,450.0 20,738.0 25,180.0

3,069,780.0

12.606.807.2

Cll

AS BURNED FUEL COST

($)1'1

6.597.910 4,942.288 7.614.834 7 089,300

802 104

87,220 27,133,656

3,2 14.441 858.892

4,073,333

611.599 0

611,599

165,401 0

165,401

62,731

70,390

4,ti3,4S4

0 0

1.745.602 2,113.605 2 483 486 6,342,893

1.253,387 1,769, 147 3.290.802 2 320052 8,633.318

28,381 132.663 103,917 126,3511

15,367,600

SCHEOULEA4 PAGE I OF I

(M)

FUEL COST PER KWH

(centiiiKWH)

337 331 337 339

6.14

3.47

348 4,08

3.59

5 39 000 5.39

558 000 5.58

8.57

1.48

3.14

000 000 o.oo

5 82 5.78 5,65 3.71

565 5 70 584 5 70 3.78

1 .34 5.57 5.69 5.53

3.78

3 60

INI

COST OF FUEL

($/UNIT)

77.78 77.78 7778 77 78

13221

5. 11 000

87.48 4.69

4.66 000

4.67 000

000 0.00 0.00

5.09 5.09 5.09 5.09

5.09 5.09 5.09 509 5.09

5.10 5.10 5.10 5.10

5.09

HEAVY OIL 1 PURCHASES 2 UNITS (88L) 3 UNIT COST (SIBBL) 4 AMOUNT ($) 5 BURNED 6 UNITS (BBL) 7 UNIT COST (SIBBL) 8 AMOUNT ($) 9 ENDING INVENTORY

10 UNITS (BBL) 11 UNIT COST ($/BBL) 12 AMOUNT ($) 13 14 DAYS SUPPLY

LIGHT OIL1' 1

15 PURCHASES· 16 UNITS (BBL) 17 UNIT COST (SIBBL) 18 AMOUNT ($} 19 BURNED 20 UNITS (BBL) 21 UNIT COST (SIBBL} 22 AMOUNT ($} 23 ENDING INVENTORY 24 UNITS (BBL) 25 UNIT COST (S/88l) 26 AMOUNT ($} 27 28 DAYS SUPPLY NORMAL 29 DAYS SUPPLY EMERGENCY

COAL, 30 PURCHASES 31 UNITS (TONS} 32 UNIT COST ($/TON} 33 AMOUNT ($} 34 BURNED 35 UNITS (TONS} 36 UNIT COST ($/TON} 37 AMOUNT ($} 38 ENDING INVENTORY 39 UNITS (TONS} 40 UNIT COST ($/TON) 41 AMOUNT ($) 42 43 DAYS SUPPLY

NATURAL GAS P> 44 PURCHASES 45 UNITS (MCF} 46 UNIT COST (S/MCF) 47 AMOUNT ($} 48 BURNED 49 UNITS (MCF} 50 UNIT COST ($/MCF} 51 AMOUNT (S) 52 ENDING INVENTORY 53 UNITS (MCF) 54 UNIT COST (SIMCF) 55 AMOUNT ($) 56 57 DAYS SUPPLY

NUCLEAR 58 BURNED 59 UNITS (MMBTU) SO UNIT COST (SIMMBTU) 61 AMOUNT ($}

ACTUAL

0 000

0

0 000

0

000 0

0

0 0.00

0

0 000

0

83.999 12964

10,889.406

587 12

354 473 7412

28 274,423

374,180 8087

30,260,877

450,641 17.29

34,831 ,218

36

3,478,777

501 17,427 993

3,413,274

505 17.223.833

705,953

3 73 2 .632 953

5

0 000

0

SYSTEM GENERA TED FUEL COST INVENTORY ANALYSIS

TAMPA ELECTRIC COMPANY MONTll OF: November 2013

CURRENT M&lfll ESTNATED

0 0.00

0

0

0.00 0

0 0.00

0

0

3.630 137 47

499.027

3,630 000

0

89.664 132.51

11,881 ,496

626 13

370,000 8201

30,344,717

381.080 84,14

32,064,878

635.234 83.91

53.300,874

51

2,940,572

6.12 17,991 .542

3,193,490

586 18,711,398

758,755

390 2.956.824

5

0 000

0

DifFERE.NCE

0 000

0

0 0.00

0

0 0.00

0

0

(3.630} (137 47)

(499,027)

(3.630) 000

0

(5.665) (2 87}

(992,090}

(39) (I)

(15.527) (7 89}

(4,070294)

(6.900) (3.27)

(1.804,001 }

(164,593} (6.61)

(18,469.656)

(15)

538,205 (11 1)

(563,549)

219,784 (081)

(1 ,487 565)

(52 802) (0 17)

(323 871)

0

0 000

0

9

00% 00% 00%

00% 00% 00%

00% 00% 00%

00%

· 100.0% -100.0% -1000%

· 1000% 00% 00%

-63% -22% -8 3%

· 10 0% -77%

42% -96%

· 134%

· 18% -39% -56%

-291% -79%

·34 7%

-300%

18.3% ·181% -31%

69% -139% -80%

-7 0% -43%

· 11 0%

0 0%

00% 00% 00%

ACTUAL

0 000

0

0 000

0

000 0

53.523 133 34

7, 136,953

16,398 126 27

2,070,617

83,999 12964

10.889 406

4 328984

8023 347 169 385

4,286,515 81 24

348,227,406

450,641 77 29

34,831 ,218

53.279.310 529

282.007.995

53,370.284 529

282 227. 166

705 953 3 73

2 632 953

0 000

0

SCHEDULE AS PAGE 1 OF 2

PERIOD TO DAfE ESTNATED

0 000

0

0 0.00

0

0 0.00

0

55,580 137 67

7,651 ,839

55,580 44 56

2,476,727

89,664 132 51

11 ,881 ,496

4,365 000

6231 359.270,497

4.422,250 8338

368,746,638

635.234 8391

53,300,874

50,930,450

581 296.023,472

50,930,450 579

294,792.462

758.755 390

2.956.624

0 000

0

DFFERENCE --------------AMOUNT %

0 0 .00

0

0 0 .00

0

0 0.00

0

(2.057} (4.33)

(51 4.866}

(39,182}

81 .71 (408,110)

(5.665) (2 87}

(992.090)

(38,016} (2 07}

(12,101,112}

(135,735) (215)

(20,519,232}

(184,593) (6.61 )

( 18,469.656)

2,348,860 (0.52)

(1 4.015,4 77)

2,439,834 (0.50}

(12.565.276}

(52.802) (0 17)

(323,871)

0 000

0

00% 00% 00%

00% 0.0% 00%

0,0% 0.0% 00%

-37% -31%

-6.7%

-705% 1834% -164%

-63% ·22% -83%

-0 9% ·25% -34%

-31% ·26% -5.6%

-291% -7.9%

-34 7%

46% -89% -4 7%

48%

-8.6% ·4.3%

-70% 43%

-11 0%

00% 00% 00%

OTHER 62 PURCHASES· 63 UNITS (MMBTU) 64 UNIT COST (SIMMBTU) 65 AMOUNT (S) 66 BURNED. 67 UNITS (MMBTU) 68 UNIT COST (SIMMBTU) 69 AMOUNT (S) 70 ENDING INVENTORY: 71 UNITS (MMBTU) 72 UNIT COST (SIMMBTU) 73 AMOUNT (S)

74 DAYS SUPPLY:

ACTUAL

0 0.00

0

0 0.00

0

0 0.00

0

0

"lndudesQctober 2013 ad)Ustment of 2,566 md.

(1) RECONCILJA TION • LIGHT OIL

SYSTEM GENE.RA TEO FUEL COST INVENTORY ANALYSIS

TAMPA ELECTRIC COMPANY MONTH OF: November 2013

CURRENT MONTH ESTlMATED

DIFFERENCE

0 0 0.00 0.00

0 0

0 0 0.00 0.00

0 0

0 0 0.00 0.00

0 0

0 0

DIFFERENCE IN ENDING INVENTORY UNITS AND DOLLARS DUE TO: UNITS DOLLARS

START-UP FUEL IGNITION OTHER USAGE TOTAL

(2) RECONCILIATION- COAL

0 (6,067)

(287) (6.354)

DIFFERENCE IN ENDING INVENTORY DOLLARS DUE TO.

FUEL ANALYSIS IGNITION #2 OIL IGNITION PROPANE AERIAL SURVEY ADJ. ADDITIVES

TOTAL

(3) RECONCILIATION - NATURAL GAS DIFFERENCE IN ENDING INVENTORY DOLLARS DUE TO:

ADDITIVES

0 (802,104)

(37,898) (840.002)

DOLLARS 63,349

802.104 0 0

29.016

894,469

DOLLARS 0

10

ACTUAL

00% 0 0 .0% 0 .00 00% 0

0.0% 0 00% 0 .00 0 .0% 0

0 .0% 0 00% 0.00 0 .0% 0

0 .0%

PE.RJOO TO DATE

ESTIMATED

0 0.00

0

0 0 .00

0

0 0.00

0

0 0.00

0

0 0.00

0

0 0 .00

0

SCHEDULE AS PAGE20F 2

0.0% 0.0% 0.0%

0.0% 0.0% 0.0%

0.0% 0.0% 0.0%

Ill

SOLO TO

ESTIMATED:

VARIOUS

TOTAL

ACTUAL:

SEMINOLE ELEC PREC0.1

SEMINOLE ELEC HARDEE

REEDY CREEK

CITY OF HOMESTEAD

PROGRESS ENERGY FLORIDA

FLORIDA POWER & LIGHT

REEDY CREEK

ORLANDO UTII.ITIES COMMISSION

SEM INOLE ELECTRIC

THE ENERGY AUTHORITY

EXGEN (CONSTELLATION)

NEW SMYRNA BEACH

SOUTHERN COMPANY

THE ENERGY AUTHORITY

EOF TRADING

JP MORGAN VENTURES

MORGAN STANLEY

CITY OF HOMESTEAD

LESS 20" • THRESHOLD E.XCESS

LESS 20" ·THRESHOLD EXCESS

LESS 20" ·THRESHOLD EXCESS

LESS 20" • THRESHOLD EXCESS

SUB· TOTAL CURRENT MONTH

NO ADJUSTMENTS TO PRIOR MONTHS

121

TYPE &

SCHEDULE

JVRISD MKT BASE

JURISO SCH • D

JURISD SCH. • D

SCH • C

SCH • C

SCH • CB

SCH • CB

SCH • CB

SCH • CB

SCH • CB

SCH ·CB

SCH ·MA

SCH ·MA

SCH ·MA

SCH ·MA

SCH ·MA

SCH ·MA

SCH ·MA

SCH · MA

SCH ·D

SCH ·C

SCH • CB

SCH • MA

SUB-TOTAL SCHEDULED POWER SALES·JURISD

SUB-TOTAL SCHEDULE C POWER SALES

SUB-TOTAL SCHEDULE CB POWER SALES

SUB-TOTAL SCHEDULE MA POWER SALES·JURISD

SUB-TOTAL OATT POWER SALES

TOTAL

CURRENT MONTH:

DIFFERENCE

DIFFERENCE"

PERIOD TO DATE:

ACTUAL

ESTIMATED

DIFFERENCE

DIFFERENCE"

Cll

TOTAL MWH SOLO

9 .4800

t ,UO.O

8011

0.0

20.0

9.0

1.200.0

180.0

3,595.0

800.0

65.0

387 0

:MiO.O

247 0

1850

2.157 0

490

200

1,3410

140

11,438.1

809.1

29.0

6 .227 0

4 ,373.0

0.0

11 ,431.1

1.951.1

20.7"

212 SIOO

135.480 0

770800

561"

POWER SOLO TAMPA ELECTRIC COMPANY MONTH OF: November 20U

.. , MWH

WHEELED OTHER

SYSTEM

151

MWH FROM OWN

GE.NERA TlON

.. , CENTSIKWH

CAl IBI FUEL TOTAL COST COST

0.0

0.0

__ _:1:..;4:.:80:::..:0_ ____!.!!!!... ____!1!!.

__ ....;';o.4;.;';.;o;.;;.o. --!!!!.. ~

00

0.0

0.0

0,0

0 .0

0.0

00

00

00

00

00

00

00

00

00

00

00

00

809 1

00

20 0

90

1.200 0

180 0

3,595 0

8000

85 0

387 0

3800

247 0

1850

2 157 0

490

200

13410

14 0

2 754

0000

2 210

2 328

2 76 1

2228

2810

2 718

2776

2843

2 370

2973

2"2

2 505

2 208

2 200

2698

2 433

3030

0000

2948

3 313

3 358

2 729

3 357

3 U4

3 122

3001

3050

3580

3403

2698

2 747

3130

3 253

3 133

171 TOTALS

FOR FUEL An.IUSTMENT

(5)X(aAJ

288,062 00

111,062.00

22,284.21

000

458 00

209 35

33,130.38

4,009.86

103,892.68

22.~.92

1.804.31

10 ,229 81

6,532 11

7,344.45

4.981 SIS

54 029 32

1,06209

439 Sl7

38.184 31

34088

------- ------0.0

0.0

0.0

GO

0.0

0.0

0.0

0.0

0~

00

00

00

0~

11 ,43f.l

801 1

290

6 .227 0

4.373 0

2.722

2 754

2 301

2 817

2 582

3.210

3 030

3 061

3 326

3 080

311,300.40

22,284.21

667.35

115 433 96

112,914.88

___ __:0::.0::.. ~ ~ ____ ,.:0::.;00::::..

11,431.1 ~ --.!ll2. __ ...,;;;31;,;1,:,;,3;;;00;.;.4;;;0;..

11581

20 7"

212 sao o 135 4800

770800

S6K

(0298)

.g 8"

2940

3 253

(0 313)

·98"

(0 518)

·13 '"

3511

3987

(0 478)

·11 9"

25,238 40

8 8"

8 249.283 17

4407 57000

I 841,69317

.. , attt

' NO SALES TO HARDEE POWER PARTNERS FOR OTHERS IN THE MONTH OF NOVEMB£R 2013

11

(8)

TOTAL I FOR TOTAL

COST C5)X(IBJ

353,39000

353,310.00

24.51263

0.00

589.57

298.20

40,297.98

4,912.47

120.682.37

27.551.72

2,029 4.9

11 ,646.71

10,980 94

8 842.79

&.29•77

62 517 73

1,345 92

625.90

43 .623.38

• 38.62

367,191.17

24,512.63

887,77

207.120.74

134.670.03

0.00

367,191 .17

13,801 17

3~

7 463,382 88

5.401.580 00

2.061 ,802 88

38 2"

SCHEDULE A' PAGE I OF 1

,., GAJNSON MARKET

BASED SALES

28.838 00

21,UI.OO

1,092 08

000

80 71

68 711

3 ,663.60

448.61

8.588.59

2.504 80

133 53

802 83

1,424 78

1.017 97

• 318 lot

13821

133 33

4 ,555 38

6692

000

0 .00

0 .00

0 .00

30,263.15

1.092 08

149 56

16, 111196

12.901 .55

000

30,2U.15

1.625 15

57"

665,457 27

••t 2.t0 00

424 217 27

961"

SCHEDULEA7 PAGE 1 OF 1

PURCHASED POWER (EXCLUSIVE OF ECONOMY & COGENERATION)

TAMPA ELECTRIC COMPANY MONTH OF: November 2013

(I) (2)

(3) (4) (5) (6) (7) (8) MWH MWH CENTS/KWH TOTAL $

TYPE TOTAL FROM FOR MWH (A) (B) FOR FUEL & MWH OTHER INTER· FOR FUEL TOTAL ADJUSTMENT

PURCHASED FROM SCHEDULE PURCHASED UTlLITlES RUPTlBLE FIRM COST COST (6)X(7A)

ESTIMATED:

OLEANDER SCH. · D 0.0 0.0 0.0 0.0 0.000 0.000 0.00

CALPINE SCH.· D 0.0 0.0 0.0 0.0 0.000 0.000 0.00

PASCOCOGEN SCH. ·D 1.500.0 0.0 0.0 1,500.0 5.354 5.354 80,310.00 TOTAL 1,500.0 0.0 0.0 1,500.0 5.354 5.354 80,310.00

ACTUAL:

HARDEE PWR. PART.·NATIVE IPP 0.0 0.0 0.0 0.0 0.000 0.000 0.00

HARDEE PWR. PART.·OTHERS IPP 0.0 0.0 0.0 0.0 0.000 0.000 0.00

FLORIDA POWER & LIGHT EMERGA 0.0 0.0 0.0 0.0 0.000 0.000 0.00

OLEANDER SCH.·D 0.0 0.0 0.0 0.0 0.000 0.000 0.00

CALPINE SCH.· D 0.0 0.0 0.0 0.0 0.000 0.000 0.00

PASCOCOGEN SCH.· D 2 1.317.0 0.0 0.0 21 .317.0 4.601 4.601 980,81 4.54

CALPINE DATI 1,071.0 0.0 0.0 1,071.0 2.840 2.840 30,417.00

SUB-TOTAL CURRENT MONTH 22,388.0 0.0 0.0 2.2,388.0 ... 517 ... 517 1,011,231.54

ADJUSTMENTS TO PRIOR MONTHS:

OLEANDER Od. 2013 SCH. ·D (1,370.0) 00 0.0 (1.370.0) 6.838 6.838 (93.683.76)

OLEANDER 0d. 2013 SCH.· D 1,370.0 0.0 00 1.370.0 6.838 6.838 93,674.88

PASCOCOGEN Od. 2013 SCH. ·D (6,558.0) 0.0 00 (6,558.0) 4.794 4.794 (31 4,387.96)

PASCOCOGEN Od. 2013 SCH. · D 6,558.0 0.0 0.0 6,558.0 4.738 4.738 310,690.07

SUB-TOTAL ADJUSTMENTS 0.0 0.0 0.0 0.0 0.000 0.000 (3,706.77)

SUB-TOTAL SCHEDULE EMERGENCY A 0.0 0.0 0.0 0.0 0.000 0.000 0.00

SUB· TOTAL SCHEDULE IPP PURCHASED POWER 0.0 0.0 0.0 0.0 0.000 0.000 0.00

SUB· TOTAL SCHEDULED PURCHASED POWER 21,317.0 0.0 0.0 21 .3 17.0 4.584 4.584 977.107.77

SUB-TOTAL SCHEDULE OATI PURCHASED POWER 1,071.0 0.0 0.0 1,07 1.0 2.840 2.840 30.417.00

TOTAL 22,388.0 0.0 0.0 22,388.0 4.500 4.500 1,007 ,524. 77

CURRENT MONTH:

DIFFERENCE 20,888.0 0.0 0.0 20,888.0 (0.854) (0.854) 927,2 14.77

DIFFERENCE % 1392.5% 0.0% 0.0% 1392.5% ·16.0% -16.0% 1154.5%

PERIOD TO DATE:

ACTUAL 197,331.0 0.0 00 197,331.0 3.609 3.609 7,121 .581 .84

ESTIMATED 81 ,200.0 0.0 0.0 81 ,200.0 5.626 5.626 4.568.200 00

DIFFERENCE 116,131.0 0.0 00 116.131.0 (2.017) (2.017) 2,553.381.84

DIFFERENCE % 143.0% 0.0% 00% 143.0% -35.9% ·35.9% 55 9%

12

(1)

PURCHASED FROM

ESTIMATED: VARIOUS

TOTAL

ACTUAL:

ORANGE COGENERATION L.P.

McKAY BAY REFUSE

CARGILL RIDGEWOOD

CARGILL GREEN BAY

CARGILL MILLPOINT

CF INDUSTRIES INC

IMC-AGRICO-NEW WALES

IMC-AGRICO-S. PIERCE

AUBURNDALE POWER PARTNERS

HILLSBOROUGH COUNTY

CUTRALE CITRUS

SUB-TOTAL FOR November 2013

ADJUSTMENTS FOR THE MONTH OF:

ORANGE COGENERATION L.P.

McKAY BAY REFUSE

CARGILL RIDGEWOOD

CARGILL GREEN BAY

CARGILL MILLPOINT

CF INDUSTRIES INC.

IMC·AGRICO-NEW WALES

IMC-AGRICO-S PIERCE

AUBURNDALE POWER PARTNERS

HILLSBOROUGH COUNTY

CUTRALE CITRUS

SUB-TOTAL FOR OCTOBER 2013

SUB· TOTAL FOR FIRM

SUB-TOTAL FOR AS AVAIL.

TOTAL

CURRENT MONTH:

DIFFERENCE

DIFFERENCE %

PERIOD TO DATE:

ACTUAL

ESTIMATED

DIFFERENCE

DIFFERENCE %

OCTOBER 2013

ENERGY PAYMENT TO QUALIFYING FACILITIES TAMPA ELECTRIC COMPANY

(2)

TYPE &

SCHEDULE

COG EN. FIRM

AS AVAIL.

FIRM

COG EN.

AS AVAILABLE

COGEN.

COG EN.

COG EN.

COG EN.

COG EN.

COG EN.

COGEN.

COGEN.

COGEN.

COGEN.

FIRM

COGEN

AS AVAILABLE

COG EN

CO GEN.

CO GEN.

CO GEN.

CO GEN.

COGEN.

COGEN

COG EN

COG EN

COGEN

MONTH OF: November 2013

(3)

TOTAL MWH

PURCHASED

6.210.0

9.620.0 16,030.0

5,428.0

21.0

463.0

0.0

1,249.0

38.0

146.0

7,209.0

0.0

37 0

0.0

14,591 .0

(7,108.0) 7,108.0

(1 .0) 1,0

(1,513.0) 1,513.0

0.0 0.0

(5,281.0) 5,281 .0 (332.0) 332.0

(367 0) 367 0

(7.285.0) 7,285.0

(10.0) 10.0

(10.0) 10.0 00 0.0 0.0

5,428.0

9,163.0

14,591 .0

(1.439.0)

·9.0%

259,121 0

177,610.0

81.511 0

45.9%

13

(4)

MWH FROM

OTHER UTILITIES

0.0 0.0 0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

00

0.0

0.0

00 0.0

0.0 0.0 0.0 0.0 0.0 0.0

0.0 0.0 0.0 0.0 0.0 0.0

0.0 00 0.0

0.0 0.0 0.0

0.0 0.0 0.0

0.0

0.0

0.0

0.0

0.0%

0.0

0.0

00

0.0%

(5)

MWH FOR

INTER­RUPTIBLE

(6)

MWH FOR FIRM

(7) CENTS/KWH

(A) (B) FUEL TOTAL COST COST

00 00

6,210.0 3.682 3.682

0.0 9,820.0 5.087 -~5.708::7~

16,030.0 ----.:543 _...;;4-,;;543~

0.0

0.0

0.0

0.0

0.0

00

0.0

0.0

00

0.0

0.0

0.0

0.0 00

00 00 0.0 0.0 0.0 00 0.0 0.0 0.0

0.0 0.0 0.0 0.0 00 00 0.0 0.0 0.0 0.0 0.0 0.0

0.0

0.0

0.0

5,428.0

21.0

4630

00

1,249.0

380

1460

7,209.0

00

37 0

0.0

14,591.0

(7,108.0) 7,108 0

(1 0) 10

(1,5130) 1.5130

00 0.0

(5,281 0) 5,281 0

(332.0) 332.0

(367.0) 367.0

(7.285.0) 7,285 0

(10.0) 100

(10.0) 10.0

0.0 0.0 0.0

5,428.0

9,163.0

14,591 .0

0.0 (\ .439.0)

0.0% -9.00.4

00 259,1210

0.0 177,610.0

0 0 81 ,5110

0.0% 45.9%

2.728

2.598

2.945

0000

2.787

2.855

2.932

2.926

0.000

2.571

0.000

2.839

2639 2.640

2.863 2.863 2.695 2.695 0.000 0.000 2.761 2.761 2.841 2.841 2.925 2.925 2.793 2.793 2 756 2.756 2.844

2.844 0.000 0.000 0.000

2.730

2.905

(1.703)

-37.5%

2.830

4.307

(1.477)

-34.3%

2.728

2.598

2.945

0.000

2.787

2.855

2.932

2.926

0.000

2.571

0.000

2.839

2.639 2.640

2.863 2.863 2.695 2.695 0.000 0.000 2.761 2.761 2.841 2.841 2.925 2.925 2.793 2.793 2.756 2.756 2.844 2.844 0.000 0.000 0.000

2.730

2.905

(1 .703)

-37.5%

2.630

4.307

(1.477)

-34.3'.4

SCHEDULEA8 PAGE 1 OF 1

(8)

TOTAL$ FOR FUEL

ADJUSTMENT (6)X(7A)

2.26,650.00 499,560.00 728,230.00

146,083.86

545.64

13,634.48

0.00

34,814.95

1,065,07

4,280.37

210,911 .15

0.00

951 .38

0.00

414,306.70

(1 67.562.65) 187.673.01

(28.63) 26.63

(40,775.68) 40.775.68

0.00 0.00

(1 45, 791 .02) 145,791.02

(9,431.05) 9,431.05

( 1 0, 733. 69) 10,733.69

{203.479.32) 203,479.32

{275.57) 275.57

(264.40)

284.40 0.00 0.00

90.16

148,173.82

266,223.04

414,396.86

{313,633.14)

-431%

7,333,623. 77

7,650,250.00

(316,626.23)

-4.1%

(1)

PURCHASED FROM

ESTIMATED:

VARIOUS

TOTAL

ACTUAL:

OKEELANTA

PROGRESS ENERGY FLORIDA

FLA. POWER & LIGHT

ORLANDO UTIL COMM

THE ENERGY AUTHORITY

CITY OF TALLAHASSEE

CALPINE

SEMINOLE ELEC CO·OP

J P MORGAN VENTURES

MORGAN STANLEY

EDF TRADING

EXGEN (CONSTELLATION)

SOUTHERN COMPANY

SUB-TOTAL CURRENT MONTH

NO ADJUSTMENTS TO PRIOR MONTHS

SUB-TOTAL SCHEDULE REB ECONOMY PURCHASES

SUB-TOTAL SCHEDULE C ECONOMY PURCHASES

SUB-TOTAL SCHEDULE J ECONOMY PURCHASES

TOTAL

CURRENT MONTH:

DIFFERENCE

DIFFERENCE %

PERIOD TO DATE:

ACTUAL

ESTIMATED

DIFFERENCE

DIFFERENCE %

121 131

TYPE TOTAL & MWH

SCHEDULE PURCHASED

Economy

SCH. · REB

SCH. -J

SCH. -J

SCH. ·J

SCH. -J

SCH. -J

SCH. - J

SCH -J

SCH -J

SCH - J

SCH · J

SCH - J

SCH. -J

28,450.0

28,<150.0

980

75.0

5.353.0

450.0

181.0

50.0

24,221 0

4,102 0

3000

122.0

659.0

2,895.0

5,692.0

44,198.0

98.0

0.0

44, 100.0

44,198.0

15,748,0

55.4%

474,550.0

406,450.0

68,100.0

16.8%

ECONOMY ENERGY PURCHASES TAMPA ELECTRIC COMPANY MONTH OF: November 2013

MWH FOR

INTERRUf>­TIBLE

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0%

0.0

0.0

0.0

0.0%

14

(5)

MWH FOR FIRM

28.450.0

28,450.0

98.0

75.0

5.353.0

450.0

181.0

50.0

24)21.0

4,102.0

300.0

122.0

659.0

2.895.0

5,692.0

44,198.0

98.0

0.0

H , IOO.O

44.198.0

15,748.0

55.4%

474,550.0

406.450.0

68,100 0

168%

(6)

TRANSACTION COSTS

CENTSII<\Mi

3.269

3.269

000

4.200

3.776

4.044

3.500

2.500

3.539

4 144

3.600

3.300

3.267

3.570

3.449

3.618

4.700

0.000

3.615

3.618

0.348

10.6%

3.488

3.523

(0.035)

-1.0%

(8) 17)

TOTALS FOR FUEL

ADJUSTMENT !51 XIS)

COST IF GENERA TED

(A) CENTS

PER KWH

930,160.00 3.269

930,160.00 3.269

4.606.00 6.347

3,150.00 4,366

202,127.00 4.626

18,200.00 4.865

6,335.00 5 766

1,250.00 2.898

857,219.00 4.368

169,984.00 4.844

10.800.00 4.284

4,026.00 3.300

21,532.00 4.276

103,350 00 4.300

196,336.00 ~

1,598,915.00 4.442

4,606.00 6.347

0.00 0,000

1,594,309.00 4.437

1,598,915.00 4.442

668,755.00

71.9%

16,553.298.03

14,318,210.00

2,235.088.03

15.6%

1,172

35.8%

3.888

3.523

0.365

10.4%

(B) TOTAL COST

930,160.00

930,160.00

6.220.06

3,274.50

247,646.46

21 ,890.50

10,437.00

1,449.00

1,057.917. 13

198.695.91

12.852.00

4,026.00

28.177.22

124,493. 10

245,993.01

1,963,071.89

6,220.06

0.00

1,956,651.83

1,963,071.89

1.032,911.89

111.0%

18,449,553,83

14,318,210.00

4,13 1,343.83

28.9%

SCHEDULE A9 PAGE 1 OF 1

(t)

FUEL SAVINGS

(aB)-4

0.00

0.00

1,614.06

124.50

45,519.46

3,690.50

4,102.00

199.00

200,698.13

28,711 .91

2,052.00

0.00

6,645.22

21 ,143 10

49,657.01

364,156.89

1,614.06

0.00

362.542.83

364,158.89

364.156.89

0.0%

1,896,255.80

0.00

1,896,255.80

0.0%

.... (II

CONTRACT

ORANGE COG EN LP

CALPINE

PASCO COG EN L TO

OLEANDER

SEMINOLE ELECTRIC ••

CONTRACT

ORANGE COGEN LP

CALPINE

PASCO COG EN L TO

OLEANDER

SEMINOLE ELECTRIC

CAPACITY

ORANGE COG EN LP

TOTAL COGENERATION

TOTAL PURCHASES AND (SALES)

TOTAL CAPACITY

START

411711989

11/ 112011

11112009

11112013

61111992

JANUARY MW

TERM

23.0

117.0

121.0

160.0

11

JANUARY ($)

1, 115.270

1,115,270

1,398,124

2,513,394

END

1213112015

1213112016

1213112018

1213112015

1213112016

FEBRUARY MW

23.0

117.0

121.0

160.0

1. 1

FEBRUARY ($)

1,115.270

1,115.270

1,373,336

2,488,606

CONTRACT TYPE

OF

LT

LT

LT

MARCH MW

23 0

117.0

121 .0

160.0

4.8

MARCH (S)

1.115.270

1,115,270

1,267,179

2,382,449

CAPACITY COSTS ACTUAL PURCHASES AND SALES

TAMPA ELECTRIC COMPANY MONTH OF: November 2013

OF • QUALIFYING FACILITY

LT = LONG TERM

ST • SHORT-TERM

•• THREE YEAR NOTICE REQUIRED FOR TERMINATION.

APRIL MAY JUNE MW MW MW

230 23.0 23.0

117 0 117.0 117.0

121.0 121 .0 121 .0

1600 1600 160.0

5.3 1.0 1.2

APRIL MAY JUNE ($) ($) ($)

1, 115.270 1, 115.270 1,115.270

1,115,270 1,115,270 1,115,270

1,192,802 1,847,026 1,457,180

2,308,072 2,962,296 2,572,450

JULY AUGUST SEPTEMBER MW MW MW

23.0 23.0 23.0

117.0 1170 117.0

121.0 121.0 121.0

160.0 160.0 160.0

6.2 7.2 65

JULY AUGUST SEPTEMBER ($) IS! ($)

1,115,270 1,115,270 1. 115,270

1,115,270 1,115,270 1,115,270

1,474,586 1,490,264 1,462,867

2,589,856 2,605,534 2,578,137

OCTOBER NOVEMBER MW MW

23.0 23.0

117.0 117.0

121.0 121.0

160.0 160.0

4.3 3.9

OCTOBER NOVEMBER ($) ($)

1,115,270 1, 115.270

1,115,270 1,115,270

1,310,599 1,362,128

2,425,869 2,477,398

DECEMBER MW

DECEMBER ($)

SCHEDULE A12 PAGE 1 OF 1

TOTAL ($)

12,267.970

12,267,970

15,636,091

27,904,061

00

PLANT/UNIT

B.B.# 1 B.B.#2 B.B.#3 B.B.II4 8.8. IGNITION B.B. COAL

(A)

B.B.C.T.114 (GAS) B.B.C. T.114 (OIL) B.B.C.T. 114 TOTAL

BIG BEND STATION TOTAL

POlK #1 GASIFIER POlK #1 CT (GAS) POLK #1 CT (Oil) POLK 111 TOTAL

POLK #2 CT (GAS) POlK #2 CT (OIL) POLK 112 TOTAL

POLK #3 CT (GAS) POLK #3 CT (OIL) POLK 113 TOTAL

POLK 114 (GAS)

POLK 115 (GAS)

POLK STATION TOTAL

COT1 COT2 CITY OF TAMPA TOTAL

BAYSIDE ST 1 BAYSIDE CT1A BAYSIDECT1B BAYSIDE CT1C BAYSIDE UNIT 1 TOTAL

BAYSIDE ST 2 BAYSIDE CT2A BAYSIDE CT2B BAYSIDE CT2C BA YSIOE CT20 BAYSIDE UNIT 2 TOTAL

BAYSIDE UNIT 3 TOTAL BAYSIDE UNIT 4 TOTAL BAYSIDE UNITS TOTAL BAYSIDE UNIT 6 TOTAL

BAYSIDE STATION TOTAL

SYSTEM Footnotes:

LEGEND: 8 .8 . • SIG BEND C.T. • COMBUSTION TURBINE COT= CITY OF TAMPA

'"

(9)

NET CAP·

ABILITY (MW)

385 385 385 407

56 1,598

220 218

220

151 159

- --15_1_

151 159

---15_1_

151

151 824

0 0 ---0-

233 156 156 156

- - -70_1_

305 156 156 156 156 929

56 56 56 56

1,854

(C) (D)

NET NET CAPACITY

GENERATION FACTOR (MWH) (%)

187.132 228,133 203.784 273.149

892,198

551 82

633

892,831

153,937 6.621

160,558

5.675 0

5,675

4.968 0

4,968

712

3,244

175,157

0 0 0

82,870 61,145 51,877 40687

236,579

119,037 41,045 62,145 68,936 58612

347,775

74 958

1,472 151

587,009

65.3 79.6 75.0 90.2

77.8

1.3 02 1.5

75.1

94.0 4.1

98.1

5,1 0.0 5,1

4.4 0.0 4.4

0.6

2.9 28.6

0.0 0 .0 0.0

478 52.7 44.7 35.1 45.4

52.5 35,4 53.5 57.7 50,5 50.3

0.2 2.3 3,5 0.4

42.6

SYSTEM NET GENERATION AND FUEL COST TAMPA ELECTRIC COMPANY

MONTH OF: October 2013

(E)

NET AVAIL.

FACTOR (%)

69 5 852 73.3 94.2

80.8

867 86.7 99.3

81.5

98.2 99.5

99.5

68.2 68.2 68.0

89.1 89.1 81.1

52.6

68.8

83.5

00 0.0 0.0

893 100.0 97.8 93.3 86.3

100.0 97.4 98.7 96.9

100.0 98.2

100.0 100.0 98.6 98.6

93.9

(f)

NET OUTPUT FACTOR

(%)

88.2 92.0

101 1 95.3

93.6

81.8 93.7 82.0

93.6

96.9 25.7

99.4

75.9 0.0

75.9

75.0 0.0

75.0

67.5

75.9

96.7

0.0 0.0 0.0

53.6 79.6 81 .3 84.3 50.8

52.5 87.5 92.6 82.9 85.8 50.3

64,5 88.9 93.3 74.9

50.6

(G)

AVG. NET HEAT RATE BTU/KWH

10.624 10,294 10,414 10.330

10,402

14.635 4 538

13,325

10,404

10.156 6,938

10,023

12.031 0

12,031

11.801 0

11,801

14,860

12,229 10,199

0 0 0

11,524 11,433 11 056 7,387

11,216 11,423 11 ,568 11 459 7,523

16,108 11,216 11,332 12,722

(H)

FUEL TYPE

(I)

FUEL BURNE.D (UNITS)

COAL 83,321 COAL 98,967 COAL 91 ,270 COAL 120,799 .bQLQ!L_ __ __,_2.""85"'9'-

GAS 7,935 .bQLQ!L_ ___ _;6"'5'-

COAL GAS

56.055 45,415

LGT.OIL ---=-- -

GAS 67,202 .bQLQ!L_ ___ __,0:...

GAS 57,704 LGT.OIL ____ l!,.O

GAS

GAS

GAS GAS ~

10,413

39,047

0 0 0

GAS 693,100 GAS 563.269

g~~ --=-1 ,;;:~~;c:,:~~~3

GAS GAS GAS GAS GAS

GAS GAS GAS GAS

453,077 698,072 761,804 660 729

2,573,682

1,173 10,564 16,417

1,879

7,486 GAS 4 ,322,578

4.276 1.654 997 52 0 hi As bumed fuel cost system total includes ignition oil ''1City of Ta mpa on Long Te rm Reserve Stand·by.

87 2 72.1 9 347 --·-- -~....;~-OJ Fuel burned (MM BTU) system total excludes ignition oil.

(J)

FUEL HEAT VALUE (BTU/UNIT)

23,880,000 23.730,000 23,252,000 23.358,000

5 744 067

1,016,000 5 744 064

27,889,782 1.016,000

1.016,000 0

1.016.000 0

1,016,000

1,016,000

0 0 0

1.016,000 1.016.000 1016000 1,016,000

1,016,000 1,016.000 1,016,000 1 016 000 1,016,000

1,016,000 1,016,000 1,016,000 1,016,000

1,016,000

(K)

FUEL BURNED

(MMBTIJ)1' 1

1,968,040.7 2,348.499.2 2.122.218.6 2,821,6116

16 421.5

8,061 ,9 372.8

8,434.7

9,288,804.8

1,563.355.6 45,935.0

1,609,290.6

68,276.0 0.0

68,276.0

58.627 0 0 ,0

58,627.0

10,580.0

39,672.0

1 '786,445.6

0.0 0 .0 0.0

704, 190 0 592,801.0 449 574.0

1,746,365.0

480.326.0 709,241.0 773.993.0 871 301.0

2,614,861 .0

1,192.0 10,733.0 16,680,0 1,909.0

4,391 ' 740.0

15 4§6 999.1

(L)

AS BURNED FUEL COST

($) ,, ,

7,064,534 8,391,111 7.738.506

10,242,180 377 922

33,814,253

41 ,795 8579

50,374 33,864,627

5,333,811 245,155

5,578,966

362,755 0

362,755

311,490 0

311 ,490

56,212

210,780

6,520,203

0 0 0

3,739,450 3,146,884 2 387 387 9,273,701

2.444,485 3,766,275 4,110,125 3 584800

13,885,665

6,330 56,995 88,576 10,137

23,321,404

63.706.231

SCHEDULE A4 PAGE 1 OF 1

REVISED 12/16/13

(M)

FUEL COST PER KWH

(cents /KWH)

3.78 3.88 3.80 3.75

3.79

7.59 10.46 7.96

3.79

3.46 3.70

3.47

6 .39 0.00 6.39

6 27 0.00 6.27

7.89

6.50 3.72

0.00 0.00 0.00

6 .12 6 .07 5.87 3.92

5.96 6 .06 6.14 6.08 3.99

8.55 5.95 6.02 6.71

3.97

3.85

(N)

COST OF FUEL

($/UNIT]

84.79 84.79 84.79 84,79

132.19

5.27 131 .98

95.15 5.40

5.40 0.00

5.40 0.00

5.40

5.40

0 .00 0 .00 0.00

5.40 5.40 5.40 5.40

5.40 5.40 5.40 5.40 5.40

5.40 5.40 5.40 5.39

5.40

SYSTEM NET GENERATION AND FUEL COST SCHEDULEA4

PAGE 1 OF 1 TAMPA ELECTRIC COMPANY

REVISED 12116113 MONTH OF: August 2013

(A) (B ) (C) (0) IE) (F) (G) (H) (f) (J) (K) (L) (M) (N)

NET NET NET NET CAP- NET CAPACITY AVAIL. OUTPUT AVG. NET FUEL FUEL FUEL AS BURNED FUEL COST COST OF

ABILITY GENE.RA TlON FACTOR FACTOR FACTOR HEAT RATE FUEL BURNED HEAT VALUE BURNED FUEL COST PER KWH FUEL PLANT/UNIT (MW) (MWH) (%) ( 'l'o) ('l'o) BTU/KWH TYPE (UNITS) (BTUIUNin (MM BTU) 121 (S) ''' (cents/KWH) (SIUNin

B.B.-1 385 270,885 94.6 97.2 946 10.461 COAL 115,577 24.518,000 2,833. 722.8 9,379.948 3.46 81 .16 B.B.JII2 385 172.064 80.1 63.9 90.3 10,397 COAL 73,930 24,198,000 1,788,947,0 5,999,978 3.49 81 .16 8 .8 .1113 365 266,551 98.2 95.3 100.6 10,510 COAL 120,767 23,196,000 2,601 ,318.8 9,601 ,155 3.88 81 .16 B.B.1114 407 269,066 88.9 92. 1 952 10,569 COAL 122.648 23,186,000 2.643,7 18.8 9.953.813 3.70 81.16 B.B. IGNITION LGT OIL 5528 5 742 353 31741.4 727 473 131.61 B.B. COAL ~ 978,566 85.3 87.1 95.5 10,493 35,862,367 3.66

B.B.C.T.1114 (GAS) 56 1.268 3.0 67.3 46.4 12.445 GAS 15,532 1.016.000 15.760.0 82,855 6 .53 5.33 B. B.C. T 1114 (OIL) ___ 56_ 0 0.0 87.3 0.0 0 LGT.OIL 0 0 0 .0 0 0.00 0.00 B.B.C.T. 1114 TOTAL 56 1,268 3.0 87.3 46.4 12,445 15,780.0 82,855 6.53 BIG BEND STATION TOTAL 1,598 979,834 82.4 87.1 95.4 10,495 10,283,487.4 35,945,222 3.67

POLK #1 GASIFIER 220 151.880 92.8 99.5 96.4 10,295 COAL 56,010 27,9 12, 173 1,563.351 6 4,905.941 3.23 87.59 POLK #1 CT (GAS) 218 10,034 6.2 99.5 14.0 6 ,758 GAS 67,389 1,016,000 67,808.0 345,024 3.44 5.12 POLK #1 CT (OIL) .!&!.Q!L 0 0.0 0 0.00 POLK #1 TOTAL -----no 161 ,894 98.9 99.5 99.4 10,075 1,631 ,159.6 5,250,965 3.24

POLK #2 CT (GAS) 151 4,158 3.7 100.0 823 12.189 GAS 49,864 1,016,000 50,682.0 255,833 6 .15 5.1 3 POLK #2 CT (OIL) 159 0 0.0 100.0 0.0 0 LGT.OIL 0 0 0 .0 0 0 .00 0.00 POLK #2 TOTAL ---1-51- 4,158 3.7 100.0 82.3 12,189 50,682.0 255,833 6.15

POLK #3 CT (GAS) 151 6 ,389 5.7 100.0 73.7 12.309 GAS 77,407 1,016,000 78.645.0 396,712 6.21 5.13 POLK 113 CT (OIL) 159 0 0.0 100.0 0.0 0 LGT.OIL 0 0 0 .0 0 0 .00 0.00 POLK 1113 TOTAL ---1-51- 6,389 5.7 100.0 73.7 12,309 78,645.0 396,712 6.21

POLKJII4(GAS) 151 5,395 4.8 99.7 80.7 10,365 GAS 55,037 1,016,000 55,918.0 282,325 5.23 5.13

00 POLK #5 (GAS) 151 6,404 5.7 100.0 81 .5 11 ,384 GAS 71,758 1,016,000 72,906.0 367,987 5.75 5.13 POLK STATION TOTAL 824 184,240 30.1 99.8 96.4 10,255 1,889,310.6 6,553,822 3.56

COT1 0 0 00 0.0 00 0 GAS 0 0 0 .0 147 0 .00 0.00 COT2 0 0 0,0 0.0 0 .0 0 GAS 0 0 0.0 147 0.00 0.00 CITY OF TAMPA TOTAL 0 0 0.0 0.0 0.0 0 'GA's- 0 0 0.0 294 0.00 0.00

BAYSIDEST 1 233 109,971 63.4 100.0 63.4 BAYSIDE CT1A 158 62,260 53,6 89.8 85.3 11,310 GAS 693.048 1,0 16,000 704,137.0 3,704,037 5.95 5.34 BAYSIDE CT1B 156 61,554 53.0 100.0 85.5 11.242 GAS 681 ,063 1.0 16,000 691.960.0 3.639.983 5.91 5.34 BAYSIDE CT1C 158 81 784 70.5 100.0 84.1 10.993 GAS 884 915 1016000 899074.0 4 729 482 5.78 5.34 BAYSIDE UNIT 1 TOTAL ---70_1_ 315,569 60.5 96.6 60.5 7,273 'GA's- 2,259,026 1,016,000 2,295,171.0 12,073,502 3.83 5.34 BAYSIDE ST 2 305 135,558 59.7 100.0 59.7 BAYSIDE CT2A 156 69,999 80.3 98.7 87.0 11.203 GAS 771.871 1,016.000 784,221 .0 4,124,951 5.89 5.34 BAYSIDE CT2B 156 43,298 37.3 77.7 87.0 11.309 GAS 481 ,931 1,016,000 489,642 0 2.575.485 5.95 5.34 BAYSIDE CT2C 156 93,086 80.2 98.7 84.1 11.451 GAS 1.049,115 1.016,000 1.065,901.0 5.606.570 6.02 5.34 BAYSIDE CT2D 156 50890 43.8 98.3 87.5 11392 GAS 570593 1016000 579 723.0 3049303 5.99 5.34 BAYSIDE UNIT 2 TOTAL 929 392,831 56.8 93.4 56.8 7,432 GAS 2,873,510 1,016,000 2,919,487.0 15,356,309 3.91 5.34 BAYSIDE UNIT 3 TOTAL 56 1,235 3.0 100.0 94.7 11 ,401 GAS 13,858 1,016,000 14,080.0 74,158 6.00 5.35 BAYSIDE UNIT 4 TOTAL 56 1,116 2.7 100.0 81.5 11,107 GAS 12,200 1,016,000 12,395.0 65,274 5.85 5.35 BAYSIDE UNIT 5 TOTAL 56 2,397 5.8 97.5 92.8 11 ,051 GAS 26,073 1,016,000 26,490.0 139,407 5.82 5.35 BAYSIDE UNIT 6 TOTAL 56 967 2.3 97.5 90.2 11 ,222 GAS 10,681 1,016,000 10,852.0 57,118 5.91 5.35

BAYSIDE STATION TOTAL 1,854 714,115 51.8 95.2 58.6 7,392 GAS 5,195,348 1,016,000 5,278,475.0 27,765,768 3.89 5.34

SYSTEM Footnotes:

1 878189 59.0 ·~~zs hi As burned fuel cost system total includes ignition oil

93.1 770 9 2?2 . iii Fuel bumed (MM BTU) system ~eslgnition oil.

17 451 273.0 70 i§512§ ~ Z!

LEGEND: B.S. • BIG BEND C.T. • COMBUSTION TURBINE COT= CITY OF TAMPA

SYSTl:M NET GENERA liON AND FUEL COST SCHEDULE A4 TAMPA ELECTRIC COMPANY PAGE 1 OF 1

MONTH OF: July 2013 REVISED 12116113

V.l (8 1 (CI (0 1 lEI (FI (0 ) (H) (I) (J ) (K) (L) (MI (NI NET NET NET NET

CAP· NET CAPACITY AVAIL OUTPUT AVG. NET FUEL FUEL FUEL AS BURNED FUEL COST COST OF ABIU TY GENERATION FACTOR FACTOR FACTOR HEAT RATl: FUEL BURNED HEAT VALUE BURNED FUEL COST PER KWH FUEL

PLANT/UNIT (MW) (MWH) (%) (%) (%) BTUII(WH TYPE (UNITS) (BTU/UNIT) (MM BTU! '" (SI1' 1 (centsiKWH) ($/UNIT)

B.BI1 385 251.543 878 932 912 10.361 COAL 107, 167 24,320.000 2.eo&.3129 8,431694 335 7868 BBI2 385 249.537 87. 1 921 871 10513 COAL 107.868 24,320,000 2 .6233398 8,468847 340 78.68 BBI3 365 249,965 920 89.6 920 10,499 COAL 111,341 23,570,000 2,624,3036 8,780.096 350 78.68 B.B14 407 260,830 861 923 928 10440 COAL 116,544 23,368.000 2.7231753 9, 189 458 352 78.68 B B. IGNITION LGTOtL 1989 5 739699 11413 7 260580 131.00 B.B. CDAL -----;:542 1,011 ,875 88.2 91.1 90.8 10,453 35,108,655 3.47 B B C.T.14 (GAS) 56 1,081 26 970 866 10,901 GAS 11 ,598 1,016.000 11 .783 8 68,474 6.15 5.73 BBCT 14 (01L) ___ 56_ 0 00 970 00 0 LGTOIL 0 0 00 0 0.00 0.00 B.B.C.T. I4 TOTAL 56 1,081 2.6 97.0 86.6 10,901 11 ,783.8 66,474 6.15 BIG BEND STATION TOTAL 1,598 1,012,956 85.2 92.0 90.8 10,453 10,588,915.4 35,175,129 3.47

POLK #1 GASIFIER 220 132.599 81.0 96.5 921 10.906 COAL 52.124 27.745,061 1,446,185.8 4,884,314 3.67 93.32 POLK #1 CT (GAS I 218 6.698 4 1 1000 402 7.938 GAS 57.210 1,018,000 53.170 0 388,559 5.80 6 79 POLK 1 1 CT (OIL) .!&I..Q!L_ 0 0.0 0 0.00 POLK •1 TOTAL -no 139,297 85.1 100.0 91 .1 10,764 1,499,355.8 5,252,873 3.77

POLK #2 CT (GAS) 151 1.401 12 980 75 7 13,261 GAS 18,286 1.018,000 18,579 0 124,368 8 88 8.80 POLK 12 CT (OIL) 159 0 0 .0 980 00 0 LGT.OIL 0 0 0.0 0 0 .00 0.00 POLK 12 TOTAL ---15_1_ 1,401 1.2 98.0 75.7 13,261 18,579.0 124,366 8.68 POLK #3 CT !GAS) 151 2,201 2.0 1000 487 12.272 GAS 28.585 1,018.000 27,010 0 180,7 17 8 21 6.80 POLK #3 CT (OIL) 159 0 00 1000 0.0 0 .l&LQ!L_ 0 0 0.0 0 000 0.00 POLK 13 TOTAL - --,5_1_ 2,201 2.0 100.0 48.7 12,272 27,010.0 180,717 8.21 POLK 14 (GAS) 151 2,033 1.8 100.0 73.8 12,485 GAS 24,942 1,016,000 25,341.0 189,485 8.34 6.80

00 POLK 15 (GAS) 151 1,170 1.0 100.0 64.8 13,915 GAS 16,025 1,016,000 16,281.0 109,097 9.32 6.81 POLK STATlON TOTAL 824 148,102 23.8 99.6 89.0 10,859 I ,586,566.8 5,838,538 3.99

COT1 0 0 0.0 00 00 0 GAS 0 0 00 147 000 0.00 COT2 0 0 0 .0 00 00 0 ~ 0 0 00 147 0.00 0.00 CITY OF TAMPA TOTAL

- --0-0 0.0 0.0 0.0 0 GAS 0 0 0.0 294 0.00 0.00

BAYSIDEST I 233 99,361 573 1000 573 BAYSIDE CTIA 156 53778 483 968 827 11501 GAS 808,768 1,016,000 618 508 0 3426,858 637 5.63 BA YSIOE CTI B 156 69,334 597 961 810 11368 GAS 775.770 1,016.000 7881820 4 .388941 630 5.63 BAYSIDE CTIC 156 62138 535 1000 854 10983 GAS 671733 1016000 682 4820 3,761,299 609 563 BAYSIDE UNIT 1 TOTAL ---70_1_

284,6 11 54.6 99.0 54.6 7,340 ~ 2,056,271 1,016,000 2.,089,172.0 11 ,575,098 4.07 5.63 BAYSIDEST2 305 119,754 528 1000 52 8 BAYSIDE CT2A 156 43,973 37.9 968 805 11282 GAS 488,271 1,018.000 496084 0 2 .748.666 625 563 BAYSIDE CT2B 156 48,621 402 952 825 11.529 GAS 529,025 1,016.000 537 4900 2 978,088 639 563 BAYSIDE CT2C 156 86,173 74.2 96.7 805 11.533 GAS 978,148 1,016,000 993 7960 5506.361 639 5.63 BAYSIDE CT2D 156 48942 42 2 1000 866 11480 GAS 552028 1016000 5808580 3107 567 635 5.63 BAYSIDE UNIT 2 TOTAL ---m- 345,463 50.0 98.2 50.0 7,492 GAS 2,547,488 1,016,000 2.588,228.0 14,340,680 4.15 5.63 BAYSIDE UNIT 3 TOTAL 56 1,479 3.5 100.0 22.2 11 ,425 GAS 16,632 1,016,000 16,898.0 93,349 6.31 5.61 BAYSIDE UNIT 4 TOTAL 56 272 0.7 100.0 89.1 11 ,974 GAS 3,206 1,016,000 3,257.0 18,088 6.65 5.64 BAYSIDE UNIT 5 TOTAL 56 2,091 5.0 86.7 83.9 11,371 GAS 23,402 1,016,000 23,776.0 131 ,403 6.28 5.62 BAYSIDE UNIT 6 TOTAL 56 745 1.8 88.7 92.7 11 ,360 GAS 8,330 1,016,000 8,463.0 46,787 6.28 5.62

BAYSIDE STATlON TOTAL 1,854 634,661 48.0 97.9 51 .9 7,452 GAS 4,655,309 1,016,000 4, 729.794.0 26,205,405 4.13 5.63

SYSTl:M ~ 1793719 56~ 2il Footnotes: As bumed ruel cost system total includes ignit ion oil

717 9 425 (ij Fuel burned (MM BT'U) system total ~actudes ignition oil.

16.J05 iii i IZ ilZ ~U ~.zs

LEGEND: B B •BIG BEND C T • COMBUSTION TURBINE COT • CITY OF TAMF'A