Download pdf - fa DUKE A. se ENERGY

Charles A. Castle Associate General Counsel

Duke Energy 550 South Tryon Street

Charlotte, NC 28202

Malling Address. OEC45A I P.O. Box 1321

Charlotte, NC 28201

o· 704.382.4499 r. 980.373.8534

[email protected]

July 29, 2016

VIA ELECTRONIC FILING

The Honorable Jocelyn G. Boyd Chief Clerk/Administrator Public Service Commission or South Carolina 101 Executive Center Drive, Suite 100 Columbia, South Carolina 292 JO

Re: Duke Energy Progress, LLC - Monthly Fuel Report Docket No. 2006-176-E

Dear Mrs. Boyd:

Pursuant to the Commission's Orders in Docket No. 1977-354-E, enclosed for filing is the Monthly Fuel Report in Docket No. 2006-176-E for the month of June 2016.

Should you have any questions regarding this matter, please do not hesitate to contact me at 704-382-4499.

arles A. Cos(Ja; Enclosure

cc: Ms. Dawn Hipp, Office of Regulatory Staff Mr. Jeffrey M. Nelson, Office of Regulatory Staff Ms. Shannon Bowyer Hudson, Office of Regulatory Staff Ms. Nanette Edwards, Office of Regulatory Staff Michael Seaman-Huynh, Office of Regulatory Staff Ms. Heather Shirley Smith, Duke Energy Mr. Scott Elliott, Elliott & Elliott, P.A. Mr. Garrett Stone, Brickfield, Burchette, Ritts & Stone, PC Mr. Gary Walsh, Walsh Consulting, LLC

fa DUKEse ENERGY.

Charles A. CastleAssooate General Counsel

Duke Energy550 South Tryon Street

Charlotte, NC 28202

Matting Address:DEC45A / P.O. Box t32t

Charlotte, NC 2820t

o: 704.382.4499f. 980.373.8534

alex,castle@duke-energy,corn

July 29, 20 I 6

VIA ELECTRONIC FILING

The Honorable Jocelyn G. BoydChief Clerk/AdministratorPublic Service Commission ol South Carolina101 Executive Center Drive, Suite l00Columbia, South Carolina 292 l0

Rc: Duke Energy Progress, LLC — Monthly Fuel ReportDocket No. 2006-176-E

Dear Mrs. Boyd:

Pursuant to the Commission's Orders in Docket No. 1977-854-E, enclosed for filingis the Monthly Fuel Reporl in Docket No. 2006-l76-E for the month of June 20l6.

Should you have any questions regarding this matter, please do not hesitate tocontact me at 704-382-4499.

tie

Enclosure

Ms. Dawn Hipp, Office of Regulatory StaffMr. Jeffrey M. Nelson, Office of Regulatory StaffMs. Shannon Bowyer Hudson, Office of Regulatory StaffMs. Nanette Edwards, Office of Regulatory StaffMichael Seaman-Huynh, Office of Regulatory StaffMs. Heather Shirley Smith, Duke EnergyMr. Scott Elliott, Elliott & Elliou, P.A.Mr. Garrett Stone, Brickfield, Burchette, Ritts & Stone, PCMr. Gary Walsh, Walsh Consulting, LLC

M o n t h l y Fuel R e p o r t

I t e m

Fuel a n d F u e l - r e l a t e d C o s t s e x c l u d i n g DERP I n c r e m e n t a l c o s t s

MWH s a l e s :

T o t a l S y s t e m S a l e s

L e s s l n t e r s y s t e m s a l e s

4 T o t a l s a l e s l e s s i n t e r s y s t e m s a l e s

5

6

7 8 9

10 11

12

13

14

15

Total fuel and fuel-related costs (¢/KWH) (Line 1/Line 4)

Current fuel & fuel-related cost component (¢/KWH) (per Schedule 4)

Generation Mix (MWH):

Fossil (By Primary Fuel Type) Coal Oil Natural Gas - Combustion Turbine Natural Gas - Combined Cycle Total Fossil

Nuclear

Hydro - Conventional

Solar Distributed Generation

Total MWH generation

Note: Detail amounts may not add to totals shown due to rounding.

$

Schedule 1

June 2016

135,007,883

5,887,373 582,588

5,304,785

2.5450

2.6110

1,380,836 7,543

184,155 1,699,332 3,271,867

2,558,2n

27,700

11,525

5,869,369

Duke Energy ProgressSummary of Monthly Fuel Report Schedule 1

LineNo. Item June 2016

Fuel and Fuel-related Costs excluding DERP incremental costs $ 1 35,007,883

MWH sales:Total System SalesLess Intersystem sales

Total sales less intersystem sales

Total fuel and fuel-related costs (S/KWH)(Line 1/Line 4)

5,887,373582,588

5,304,785

2.5450

Current fuel 8 fuel-related cost component (C/KWH)

(per Schedule 4)

2.6110

Generation Mix (MWH):

789

1011

Fossil (By Primary Fuel Type)CoalOilNatural Gas - Combustion TurbineNatural Gas - Combined CycleTotal Fossil

1,380,8367,543

184,1551,699,3323,271,867

12

13

14

15

Nuclear

Hydro - Conventional

Solar Distributed Generation

Total MWH generation

2,558,277

27,700

11,525

5,869,369

Note: Detail amounts may not add to totals shown due to rounding.

0456949 c o a l b l e n d i n g m e r g e r s a v i n g s

0501016 c o a l p r o c u r e m e n t m e r g e r s a v i n g s

0501110 c o a l c o n s u m e d - s t e a m

0501310 f u e l o i l c o n s u m e d - s t e a m

T o t a l S t e a m G e n e r a t i o n - A c c o u n t 501

N u c l e a r G e n e r a t i o n - A c c o u n t 518

0518100 b u r n u p o f o w n e d f u e l

0518500 n u c l e a r f u e l s a v i n g s

0 5 1 8 6 0 0 - D i s p o s a l C o s t

T o t a l N u c l e a r G e n e r a t i o n - A c c o u n t 518

O t h e r G e n e r a t i o n - A c c o u n t 547

0547000 n a t u r a l g a s c o n s u m e d - C o m b u s t i o n T u r b i n e

0547000 n a t u r a l g a s c o n s u m e d - C o m b i n e d C y c l e

0547123 g a s c a p a c i t y m e r g e r s a v i n g s

0547200 f u e l o i l c o n s u m e d

T o t a l O t h e r G e n e r a t i o n - A c c o u n t 547

Fuel a n d f u e l - r e l a t e d c o m p o n e n t o f p u r c h a s e d p o w e r - A c c o u n t 555

L e s s f u e l a n d f u e l - r e l a t e d c o s t s r e c o v e r e d t h r o u g h i n t e r s y s t e m s a l e s - A c c o u n t 447

T o t a l C o s t s I n c l u d e d i n B a s e Fuel C o m p o n e n t

E n v i r o n m e n t a l C o s t s

0509030, 0509212, 0557451 e m i s s i o n a l l o w a n c e e x p e n s e

0 5 0 2 0 2 0 , 0 5 0 2 0 3 0 , 0 5 0 2 0 4 0 , 0 5 0 2 0 8 0 , 0 5 0 2 0 9 0 , 0 5 4 8 0 2 D r e a g e n t s e x p e n s e

0502160 r e a g e n t p r o c u r e m e n t m e r g e r s a v i n g s

E m i s s i o n A l l o w a n c e G a i n s

L e s s r e a g e n t s e x p e n s e r e c o v e r e d t h r o u g h i n t e r s y s t e m s a l e s - A c c o u n t 447

L e s s e m i s s i o n s e x p e n s e r e c o v e r e d t h r o u g h i n t e r s y s t e m s a l e s - A c c o u n t 447

T o t a l C o s t s I n c l u d e d i n E n v i r o n m e n t a l C o m p o n e n t

Fuel a n d F u e l - r e l a t e d C o s t s e x c l u d i n g DERP i n c r e m e n t a l c o s t s

DERP I n c r e m e n t a l C o s t s

T o t a l Fuel a n d F u e l - r e l a t e d C o s t s

N o t e s : D e t a i l a m o u n t s m a y n o t a d d t o t o t a l s s h o w n d u e t o r o u n d i n g .

$

$

$

$

$

Schedule 2

June 2016

(209,783) 876,793

48,780,848 n2,596

50,220,454

17,018,469 (3,853)

17,014,616

7,091,980 44,874,266

(71,811) 336,309

52,230,743

25,980,192

12,359,092

133,086,913

246,003 2,028,982

(6,647)

2n,114 70,195

1,920,969

135,007,883

261,156

135,269,039

Duke Energy ProgressDetails of Fuel and Fuel-Related Costs

Schedule 2

Description June 2016

Fuel and Fuel-Related Costs:

Steam Generation - Account 5010456949 coal blending merger savings0501016 coal procurement merger savings0501110 coal consumed - steam0501310 fuel oil consumed - steam

Total Steam Generation - Account 501

Nuclear Generation - Account 51805181 00 burnup of owned fuel0518500 nuclear fuel savings0518600 - Disposal Cost

Total Nuclear Generation - Account 518

$ (209,783)876,793

48,780,848772,596

50,220,454

17,018,469(3,853)

17,014,616

Other Generation - Account 5470547000 natural gas consumed - Combustion Turbine0547000 natural gas consumed - Combined Cycle0547123 gas capacity merger savings0547200 fuel oil consumed

Total Other Generation - Account 547

7,091,98044,874,266

(71,81 1)336,309

52,230,743

Fuel and fuel-related component of purchased power - Account 555

Less fuel and fuel-related costs recovered through intersystem sales - Account 447

Total Costs Included in Base Fuel Component

25,980,192

12,359,092

$ 133,086,913

Environmental Costs0509030, 0509212, 0557451 emission allowance expense0502020, 0502030, 0502040, 0502080, 0502090, 0548020 reagents expense0502160 reagent procurement merger savingsEmission Allowance GainsLess reagents expense recovered through intersystem sales - Account 447Less emissions expense recovered through intersystem sales - Account 447

246,0032,028,982

(6,647)

277,17470,195

Total Costs Included in Environmental Component

Fuel and Fuel-related Costs excluding DERP incremental costs

DERP Incremental Costs

Total Fuel and Fuel-related Costs

1,920,969

8 t 35,0071883

261,156

$ 135,269,039

Notes: Detail amounts may not add to totals shown due to rounding.

P R O G R E S S

J U N E 2 0 1 6

S c h e d u l e 3, P u r c h a s e s

P U R C H A S E D P O W E R A N D I N T E R C H A N G E

P a g e 1 o f 2

S O U T H C A R O L I N A

P u r c h a s e d P o w e r

T o t a l C a p a c i t y N o n - c a p a c i t y

M a r k e t e r s , U t i l i t i e s , O t h e r

$ m W $ m W h F u e l $

N o n - f u e l $

DE C a r o l i n a s - E m e r g e n c y

$ 1 2 , 7 3 9 2 9 0 $

7,771 $

4 , 9 6 8

Broad R i v e r E n e r g y , LLC.

7,203,751 8 3 7 $ 5,065,841 3 6 , 0 9 7 2 , 1 3 7 , 9 1 0

City of F a y e t t e v i l l e

9 8 5 , 2 3 8 220 905,025 1,487 80,213 Haywood EMC 29,650 7 29,650 NC EMC 3,668,030 513 2,349,723 34,146 1,318,307 PJM Interconnection, LLC. 44 44 Smurfit Stone Container Corp 19,437 750 19,437 Southern Company Services 3,939,411 150 1,081,080 96,908 2,858,331 DE Carolinas - Native Load Transfer 931,555 28,613 829, 114 102,441 DE Carolinas - Native Load Transfer Benefit 42,699 42,699 DE Carolinas - Fees 2,224 2,224 Generation Imbalance 13370 598 8155 5 215

$ 16,848,148 1,727 $ 9,431,319 198,889 $ 7,304,205 $ 112,624

Act 236 PURPA Purchases

Renewable Energy $ 16,179,815 246,666 $ 16, 179,815 Other Qualifying Facilities 2,496,172 27,355 2,496,172

$ 18,675,987 - $ 274,021 $ 18,675,987 $

Total Purchased Power $ 35,524,135 1,727 $ 9,431,319 472,910 $ 25,980,192 $ 112,624

NOTE: Detail amounts may not add to totals shown due to rounding.

DUKE ENERGY PROGRESSPURCHASED POWER AND INTERCHANGE

SOUTHCAROUNA

JUNE 2016 Schedule 3, PurchasesPage 1 of 2

Purchased Power

Marketers, Utilities, Other

Total Capacity

mw $ mWh

Nonwapaclty

Fuel $ Non.fuel $

DE Carolinas - EmergencyBroad River Energy, LLC.City of FayettevilleHeywood EMCNCEMCPJM Interconnection, LLC.Smuda Stone Container CorpSoulhem Company ServicesDE Carolinas - Native Load TransferDE Carolinas - Native Load Transfer BenefitDE Carolinas - FessGeneration Imbalance

$ 12,7397,203,751

985,23829,650

3,6M,03044

19,4373,939,41 1

931,55542,6992,224

$ 16,848,148

837 $220

7513

5,065,841905,02529,650

2,349,723

1,081,080

1,727 $ 9,431,319

290 $36,097

1,487

7,771 $2,137,910

80,213

34,146 1,318,30744

19,4372,858,331

829,11442,699

2,2248 155

75096,9M28,613

198,889 $ 7,304,205 8

4,968

102,441

5 215112,624

Act 236 PURPA Purchases

Renewable EnergyOther Qualifying Facilities

$ 16,179,8152,496,172

$ 18,675,987

246,666 $27,355

274,021 5

16,179,8152,496,172

18,675,987 $

Total Purchased Power $ 35,524,135 1,727 $ 9,431,31 9 472,910 $ 25,980,192 $ 112,624


E N E R G Y P R O G R E S S

INTERSYSTEM S A L E S *

SOUTH C A R O L I N A

S a l e s

M a r k e t B a s e d :

N C E M C

N C E M C Purchase P o w e r A g r e e m e n t

PJM I n t e r c o n n e c t i o n , LLC.

Other: DE Carolinas - Native Load Transfer Benefit DE Carolinas - Native Load Transfer Generation Imbalance

Total lntersystem Sales

• Sales for resale other than native load priority.

$

$


JUNE2016

Total Capacity

$ mW $

8,910 919,508 150 $ 652,500 600,352

708,714 12,147,944

75 14,385,503 150 $ 652,500

Schedule 3, Sales Page 2of 2

Non-capacity

mWh Fuel$ Non-fuel$

270 $ 7,019 $ 1,891 8,733 204,827 62,181

12,841 397,885 202,467

708,714 560,695 11,387,948 759,996

49 68 7 582,588 $ 12,706,461 $ 1,026,542

DUKE ENERGY PROGRESSINTERSYSTEM

SALES'OUTH

CAROLINA

JUNE 2016Schedule 3, Sales

Page 2 ol 2

Sales

Total Capacity

mW $ mwn

Norvcapaclty

Fuel 5 Non-fuel $

Market Based:NCEMCNCEMC Purchase Power AgreementPJM Interconnection, LLC.Other:

OE Carolinas - Nalivs Load Transfer BenefitOE Carolinas - Native Load TransferGeneration Imbalance

Total Intersystem Sales

708,71412,147,944

755 I 4,385A03 150 $ 652A00

$ 8,910919,508 150 $ 652,500600,352

270 68,733

12,841

7,019 $ 1,891204,827 62, 181397,885 202,467

708,714I 1,387,948 759,996

7560,695

49582,SSS $ 12 706,461 $ 1,026,542

'ales lor resale other than native load priority.

NOTE; Detail amounts may not add to totals shown due to rounding.

Duke Energy Progress Schedule 4Over / (Under) Recovery of Fuel Costs Page 1 of 2

June 2016

Line No. Total ResidentialGeneral Service

Non-Demand Demand Lighting Total

1 Actual System kWh sales Input 5,304,784,6512 DERP Net Metered kWh generation Input 4,0263 Adjusted System kWh sales L1 + L2 5,304,788,677

4 Actual S.C. Retail kWh sales Input 168,184,677 26,311,482 295,913,409 7,780,059 498,189,6275 DERP Net Metered kWh generation Input 1,554 2,472 - 4,0266 Adjusted S.C. Retail kWh sales L4 + L5 168,186,231 26,313,954 295,913,409 7,780,059 498,193,653

7 Actual S.C. Demand units (kw) L32 / 31b *100 675,850

Base fuel component of recovery - non-capacity8 Incurred System base fuel - non-capacity expense Input $129,430,8029 Eliminate avoided fuel benefit of S.C. net metering Input $16210 Adjusted Incurred System base fuel - non-capacity expense L8 + L9 $129,430,96411 Adjusted Incurred System base fuel - non-capacity rate (¢/kWh) L10 / L3 * 100 2.440

12 S.C. Retail portion of adjusted incurred system expense L6 * L11 / 100 $4,103,558 $642,031 $7,219,959 $189,825 $12,155,37313 Assign 100 % of Avoided Fuel Benefit of S.C net metering Input ($95) ($9) ($57) $0 ($162)14 S.C. Retail portion of incurred system expense L12 + L13 $4,103,463 $642,022 $7,219,902 $189,825 $12,155,211

15 Billed base fuel - non-capacity rate (¢/kWh) - Note 1 Input 2.488 2.489 2.489 2.489 2.48916 Billed base fuel - non-capacity revenue L4 * L15 /100 $4,184,863 $654,893 $7,365,285 $193,646 $12,398,68717 DERP NEM incentive - fuel component Input ($25) ($2) ($15) $0 ($42)18 Adjusted S.C. billed base fuel - non-capacity revenue L16 + L17 $4,184,838 $654,890 $7,365,270 $193,646 $12,398,645

19 S.C. base fuel - non-capacity over/(under) recovery L18 - L14 $81,376 $12,869 $145,368 $3,821 $243,43420 Adjustment - Docket 2016-1-E Input $0 $0 $0 $0 $72,42721 Total S.C. base fuel - non-capacity over/(under) recovery L19 + L20 $81,376 $12,869 $145,368 $3,821 $315,861

Base fuel component of recovery - capacity22a Incurred base fuel - capacity rates by class (¢/kWh) L23 / L4 * 100 0.120 0.074 0.00022b Incurred base fuel - capacity rate (¢/kW) L23 / L9 * 100 18 23 Incurred S.C. base fuel - capacity expense Input $202,209 $19,582 $121,566 $0 $343,357

24a Billed base fuel - capacity rates by class (¢/kWh) Input 0.142 0.106 (0.044)24b Billed base fuel - capacity rate (¢/kW) Input 2125 Billed S.C. base fuel - capacity revenue L24a * L4 /100 $238,610 $27,890 144,425$ ($3,423) $407,50226 S.C. base fuel - capacity over/(under) recovery L25 - L23 $36,401 $8,308 $22,859 ($3,423) $64,14527 Adjustment - Docket 2016-1-E Input ($434) ($42) ($261) $17,679 $16,94228 Total S.C. base fuel - capacity over/(under) recovery L26 + L27 $35,967 $8,266 $22,598 $14,256 $81,087

Environmental component of recovery29a Incurred environmental rates by class (¢/kWh) L30 / L4 * 100 0.063 0.03929b Incurred environmental rate (¢/kW) L30 / L7 * 100 9 30 Incurred S.C. environmental expense Input $106,243 $10,289 $63,872 $180,404

31a Billed environmental rates by class (¢/kWh) Input 0.073 0.04031b Billed environmental rate (¢/kW) Input 1032 Billed S.C. environmental revenue L31a * L4 /100 $123,477 $10,525 67,585$ $201,58733 S.C. environmental over/(under) recovery L32 - L30 $17,234 $236 3,713$ $0 $21,18334 Adjustment - Docket 2016-1-E Input ($243) ($23) ($146) $0 ($412)35 Total S.C. environmental over/(under) recovery L33 + L34 $16,991 $213 $3,567 $0 $20,771

36 Total over / (under) recovery L21 + L28 + L35 $134,334 $21,348 $171,533 $18,077 $417,719

Duke Energy ProgressOver / (Under) Recovery of Fuel Costs Schedule 4

June 2016 Page 2 of 2

Year 2016-2017

Cumulative over / (under) recovery Cumulative Total ResidentialGeneral Service

Non-Demand Demand Lighting SubtotalPrior Period Adjustments Total

Balance ending February 2016 (8,178,450) March 2016 - actual (5,113,937) $1,257,169 $149,823 $1,614,366 $43,155 $3,064,513 $0 $3,064,513

_/2 April 2016 - actual (2,862,055) $579,097 $91,208 $1,546,143 $35,434 $2,251,882 $0 $2,251,882May 2016 - actual (2,055,487) $166,326 $33,470 $597,607 $9,165 $806,568 $0 $806,568

_/2 June 2016 - actual (1,637,768) $134,334 $21,348 $171,533 $18,077 $345,292 $72,427 $417,719_/3 July 2016 - forecast (1,953,670) ($84,786) ($11,624) ($213,665) ($5,827) ($315,902) $0 ($315,902)_/3 August 2016 - forecast (2,454,005) ($140,784) ($17,519) ($334,425) ($7,607) ($500,335) $0 ($500,335)_/3 September 2016 - forecast (2,369,802) ($4,830) $4,761 $83,877 $395 $84,203 $0 $84,203_/3 October 2016 - forecast (2,599,787) ($107,158) ($7,034) ($112,301) ($3,492) ($229,985) $0 ($229,985)_/3 November 2016 - forecast (1,933,542) $224,014 $27,434 $404,763 $10,034 $666,245 $0 $666,245_/3 December 2016 - forecast (1,584,219) $176,769 $9,346 $158,553 $4,655 $349,323 $0 $349,323_/3 January 2017 - forecast (1,435,605) $119,723 ($533) $27,580 $1,844 $148,614 $0 $148,614_/3 February 2017 - forecast (1,667,067) ($74,731) ($15,050) ($139,058) ($2,623) ($231,462) $0 ($231,462)_/3 March 2017 - forecast (2,696,086) ($366,744) ($41,629) ($606,401) ($14,245) ($1,029,019) $0 ($1,029,019)_/3 April 2017 - forecast (2,879,735) ($129,395) ($6,229) ($46,483) ($1,542) ($183,649) $0 ($183,649)_/3 May 2017 - forecast (1,834,622) $252,872 $51,369 $723,562 $17,310 $1,045,113 $0 $1,045,113_/3 June 2016 - forecast (1,674,360) $48,159 $8,814 $100,732 $2,557 $160,262 $0 $160,262

Line No. Residential Commercial Industrial TotalDistributed Energy Resource Program component of recovery: incremental costs

37 Incurred S.C. DERP incremental expense Input $153,800 $67,527 $39,829 $261,15638 Billed S.C. DERP incremental rates by account ($/account) Input 0.58 1.21 46.52 39 Billed S.C. DERP incremental revenue Input $78,159 $38,201 $12,314 $128,67440 S.C. DERP incremental over/(under) recovery L39 - L37 ($75,641) ($29,326) ($27,515) ($132,482)41 Adjustment Input $0 $0 $0 $042 Total S.C. DERP incremental over/(under) recovery L40 + L41 ($75,641) ($29,326) ($27,515) ($132,482)

Year 2016-2017

Cumulative over / (under) recovery Cumulative Residential Commercial Industrial SubtotalPrior Period Adjustments Total

Balance ending February 2016 (409,036)March 2016 - actual (332,983) $47,587 $24,676 $3,790 $76,053 $0 $76,053

_/2 April 2016 - actual (239,880) $57,498 $29,093 $6,512 $93,103 $0 $93,103May 2016 - actual (230,645) $8,264 $7,454 ($6,483) $9,235 $0 $9,235June 2016 - actual (363,127) ($75,641) ($29,326) ($27,515) ($132,482) $0 ($132,482)

_/3 July 2016 - forecast (363,859) ($1,068) ($294) $630 ($732) $0 ($732)_/3 August 2016 - forecast (364,677) ($1,121) ($294) $597 ($818) $0 ($818)_/3 September 2016 - forecast (365,492) ($1,112) ($266) $563 ($815) $0 ($815)_/3 October 2016 - forecast (366,270) ($1,115) ($309) $646 ($778) $0 ($778)_/3 November 2016 - forecast (367,087) ($1,107) ($323) $613 ($817) $0 ($817)_/3 December 2016 - forecast (367,750) ($1,044) ($299) $680 ($663) $0 ($663)_/3 January 2017 - forecast (367,848) ($729) ($118) $749 ($98) $0 ($98)_/3 February 2017 - forecast (367,139) ($173) $102 $780 $709 $0 $709_/3 March 2017 - forecast (366,359) ($110) $110 $780 $780 $0 $780_/3 April 2017 - forecast (365,653) ($82) $74 $714 $706 $0 $706_/3 May 2017 - forecast (365,076) ($189) $36 $730 $577 $0 $577_/3 June 2016 - forecast (364,444) ($158) $76 $714 $632 $0 $632

Notes:Detail amounts may not recalculate due to percentages presented as rounded.

_/1 Total residential billed fuel rate is a composite rate reflecting the approved residential rate of 2.508 and RECD 5% discount._/2 Includes prior period adjustments._/3 Forecast amounts based on low end of range of expected fuel rates.

D e s c r i p t i o n

C o s t o f F u e l P u r c h a s e d ($)

1 Coal 2 Oil 3 Gas-CC 4 Gas-CT 5 Total

6 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 47

Average Cost of Fuel Purchased (e/MBTU)

Coal Oil

Gas·CC Gas·CT Weighted Average

Coat of Fuel Bumed ($)

Coal

Oil·CC Oil • Steam/CT Gas·CC Gas-CT Nudear Total

Average Cost of Fuel Burned (e/MBTU) Coal

Oil·CC Oil • Steam/CT Gas-CC Gas-CT Nu dear Weighted Average

Average Cost of Generation (¢/kWh) Coal Oil-CC

Oil • Steam/CT Gas-CC

Gas·CT Nu dear Weighted Average

Bumed MBTU's Coal Oil-CC

Oil • Steam/CT

Gas·CC Gas-CT

Nudear Total

Net Generation (mWh)

Coal Oil·CC

Oil • Steam/CT Gas-CC Gas-CT

Nudear Hydro (Total System) Solar (Total System) Total

Cost of Reagents Consumed ($)

48 Ammonia

49 Limestone 50 Sorbents 51 Urea 52 Total

Weatherspoon CT

174,313

24 $174,337

1,136.55

1,136.71

190,114

24

$190,138

1,560.65

1,560.64

35.34

35.34

12,182

12,182

538

538

~

Lee

cc

15,801,685

$15,801,685

376.70

376.70

15,801,685

$15,801.685

376.70

376.70

2.73

2.73

4,194,719

4,194,719

579,4n

579,4n

Duke Energy Progress Fuel and Fuel Related Cost Report

June2016

Sutton CC/CT

12,005,825

$12,005,825

442.83

442.83

2,928 24,116

12,005,825

$12,032,869

2,126.74 2,021.61

442.83

443.61

24.94

3.07

3.08

138 1,193

2,711,167

2,712,498

12 (25)

390,585

390,572

Robinson Nuclear

515

$515

3,473,294 $3,473,294

60.49 80.49

0.65 0.65

5,741,832 5,741,832

537,521

537,521

Asheville Steam

$2,473,915 4,242

$2,478,157

291.99

292.49

$3,727,576

124,486

$3,852,062

317.25

1,421 .65

325.42

4.54

20.25

4.66

1, 174,982

8,756

1,183,738

82,048

615

82,663

82,097 19,143 64,078

165,319

Detail amounts may nol add lo lolals shown due lo rounding.

Schedule exclUdes ln·lransll, terminal and lolling agreement ecllvliy.

CenlSIMBTU end cenlslkWh are nol computed when costs end/or net generation Is negative.

Asheville CT

1,000,411 $1,000,411

341.16 341.16

616

1,000,411

51,001,026

1,421.67

341.16

341 .32

17.64

4.23

4.23

43

293,234

293,2n

3

23,660

23,663

Roxboro Steam

$18,247,183 572,641

$18,820,024

332.97 1,007.76

339.90

$37,473,515

3n,229

$37,850,743

331.13

983.64

333.33

3.40

10.04

3.43

11,316,835

38,342

11,355.1n

1,100,782

3,758

1,104,540

$334,988 867,807 254,629

1,457,425

Schedules Page 1of2

Mayo Steam

$317,232

329,565

$646,797

0.00 1,008.46

1,979.18

$7,579,758

270,881

$7,850,639

353.33

993.25

361 .37

3.83

10.76

3.92

2,145,206

27,272

2,172,478

198,006

2,517

200,523

$59,945 197,261 118,661

375,867

Fuel cost Information on lhls report does not ranacl lntercompany sharing ol luel·relaled merger savings between Duke Energy Carolinas end Duke Energy Progress.

Lee end Wayne oil bum Is associated wllh Inventory consumption shown on Schedule 6 lor Wayne.

Duke Energy ProgressFuel and Fuel Related Coal Report

June 2018

Schedule 5Page I olg

LineNo. Descdpl los

Coal ot Fuel Purchased (3)CoalOg

Gas ~ CC

Gas - CTTotal

WsalhetspoonCT

174,313

24

$174,337

LeeCC

I 5.801,685

$ 1 5,S01,685

SuttonCC/CT

I 2,005,825

$12,005.825

RohlnaonNCOI4ar

515

$515

AshevglsSteam

$2,473,9154,242

$2,478,1 57

AshevgleCT

1,000,411

$1,000,411

RoshoroSteam

$18,247,183572,841

$1 8,820,024

Illltyo

Steam

$317,232329,565

$646.797

67

8910

Average cost at Fust Purchased (slMBTU)CoalOg

Gas - CCGes - CTWeighted Average

1,136.55

1,136.71

376.70

378.70

442.83

442.83

291.99

292.49341.16341.16

332 971,007.76

0.001,008.46

1,979.16

11

12

13

14

15

18

17

Coal al Fuel Burned (5)CoalOS-CCOil ~ SieamfCT

Gas - CCGas - CTNudearTotal

190,114

24

$190,138

15,801,685

$15,801,685

2,92824,116

12.005,825

$12,032,8693,473394

$3,473,294

53,727,576

124,486

$3,852,062

SIS

1,000,411

$1,001,026

$37,473,515

377,228

S37,850,743

$7.579,758

270,881

$7,85O.839

18

19

2021

222324

Average Coal ol Fuel Burned (CIMBTU)

CoalOil ~ CCOg ~ SlesmfCTGas - CCGss - CTNudsarWeighted Average

376.70

376.70

2,126.742,021.81

442 83

443.6160 4950.49

317.25

1,421.65

325.42

1,421 67

341.18

331.13

33$33

353.33

993.25

361.37

25262728293031

Avamge Cost cf Generadon (ClkWh)CoalOg - CCOil - Steam/CTGes - CC

Gas - CTNuclaafWeighted Average

35.34

35 34

2.73

2.73

24.94

3.07

0.650.65

20.25

4.23

4.23

340

10.04

3 43

10 76

3 92

32333435363738

Burned MBTU'e

CoalOft - CCOil - SteamfCTGss-CCGas-CTNudearTotal

12,182

12,182

4.194,719

4,194,719

1381,193

2,711,187

2,71 2,4985,741,8325,741,832

1,174,982

8,756

1,183,738

43

293.234

293,277

11,316,835

3S,342

11,355,177

2,145,206

27,272

2,172,478

$84041

424344454647

Net Genersdon (mWh)CoalOil ~ CCOg - SleamfCTGas - CCGas - CTNudearHydro (Total system)Solar (Total System)Total 538

579,477

579,477

12

(25)390,685

390,572

537,521

537,521

815

82,S63

23,660

23,6S3

I,ID0,782

3,758

1,104,54D

19S,006

2,517

200,523

48495051

52

Coal ol Reagents Consumed (5)Aftlf sortie

LimestonesoruenlsUreaTotal

82,09719.14364,078

165,319

$334,988867,807254,IGS

1,457,425

$59,945197,261

118,661

375,887n~lDales smfmnu may not adfl lo totals shmm d s lo rcundng.

schedule exduses sf-transit, terminal and tolling agreement edk Ily.

Can mmsv 0 ene ca ntsAWh a e no computes wnen owtv endor nei gene ra eon h n agama.

Fuel cost information on this repon dms nol rellect Intenompany shadng ot lust-misled merger savings oenmen Duke Energy carollnac srfd Duke Energy pmgfessLee snd wayne oll num u associated mlh Inventou ccncumptlc shown on schedule 6 to wayne.

No. D e s c r i p t i o n

1

2

3

4

5

6

7

8

9

1 0

C o a t o f F u e l P u r c h a u d ( $ )

C o a l

Oil Gas-CC Gas-CT

Total

Average Coat of Fuel Purchaud (~BTU

Coal

Oil

Gas-CC

Gas-CT

Weighted Average

Coat of Fuel Bumed ($)

11 Coal

12 Oil-CC

13 14 15 16

17

18 19 20 21 22

23 24

25 26 27

28 29 30 31


Gas· CT

Nudear

Total

Average Coat of Fuel Bumed (~BTU) Coal Oil-CC

Oil • Steam/CT Gas-CC Gas-CT

Nudear Weighted Average

Average Cost of Generation (Cll<Wh)

Coal Oil-CC


Gas-CT

Nudear

Weighted Average

Bumed MBTU's 32 Coal

33 Oil -CC

34 Oil • Steam/CT 35 Gas-CC

36 Gas-CT

37

38

Nudear

Total

Net Generation (mWh)

39 Coal

40 Oil -CC

41 Oil· Steam/CT

42 Gas· CC

43 Gas· CT

44 45 46 47

Nudear Hydro (Total System)

Solar (Total System)

Total

Cost of Reagents Consumed ($)

48 Ammonia

49 Limestone

50 Sorbents

51 Urea

52 Total

Brunswick

Nuclear

46.440

$46,440

2,169.08

2,169.08

8,734,759 $8,734,759

62.96 62.96

0.65 0.65

13,874,357 13,874,357

1,343,781

1,343,781

Blewett CT

100,536

$100,536

1,765.14

1,765.14

42.07

42.07

5,696

5,696

239

239

Duke Energy Progress Fuel and Fuel Related Cost Report

June 2016

Wayne County

CT

16,396

406,808 $423,204

1,594.94

294.07 303.67

3,838

406,808

$410,645

1,799.60

294.07

296.39

21.81

3.55

3.57

213

138,335

138,548

18

11,474

11,492

Darlington

CT

303,611 $303,611

324.67 324.67

8,706

303,611

$312,318

1,776.79

324.67

332.24

3.D1

3.15

490

93,514

94,004

(160)

10,084

9,924

Smith Energy Complex

CC/CT

17,066,755

5.381,126 $22,447,882

336.08 335.73 336.00

5,455 17,066,755

5,381,126

$22,453,337

1,677.31

336.08 335.73

336.06

19.26 2.34 3,87

2.59

325 5,078,156 1,602,793

6,681 ,274

28 729,270 138,938

868,236

$30,371

30,371

Harris

Nuclear

4,810.416 $4,810,416

67.75 67.75

0.71

0.71

7,099,805 7,099,805

676,975

676,975

Cumtnt

Month

$21,038,330 1,144,312

44,874,266 7,091,980

$74, 148,887

332.50 1,059.26

374.45 333.29 360.87

$48, 780,848

2.928 1,105,977

44,874,266 7,091,980

17,018,469 $118,874,467

333.27 2,126.74 1,170.18

374.45

333.29 63.70

213.96

3.53 24.94 14.68

2.64 3.85 0.67 2.03

14,637,022 138

94,513 11,984,042 2,127,876

26,715,994 55,559.585

1,380,836 12

7,531 1,699,332

184,155 2,558,277

27,700

11,525 5,869,369

$425,304 1,147,165

392,434 64,078

2,028,982

Schedule 5 Page 2 of 2

Total 12 ME

June2016

$398,596,613 17,988,751

561,527,735 132,560, 767

$1,110,673,867

330.04 1,106.04

402.18 355.20 371 .04

$361,200,810 518,868

17,151,099 561,527,735 132,560,767 199,346,949

$1,272,306.229

330.73 2,092.86 1,421 .08

402.18 355.20

63.28 211 .21

3.56 24.08 18.82

2.88 3.91 0.66 1.98

109,212,890 24,792

1,206,905 139,619,751

37,319,804 315,016,875 602,401,017

10,159,019 2,155

91,113 19,488,003

3,391,717 30,289,238

625,897 90,828

64,137,970

$2,994,567 8,994,183 3,954,724 1,059,282

17,002,755

Duke Energy ProgressFuel end Fuel Related Coal Report

June 2015

Schedule 5

I'age 2 of 2

Line

No. DescrlpdonCost of Fuel Purchased (8)

CoalOg

Gas - CCGas - CTTotal

BrunswickNuclear

46,440

$46,440

SI4wegCT

Wayne CountyCT

16,398

406,808$423,204

DargngtonCT

303,61 I

$303,611

$1111th EnergyCorrtpleu

CC/CT

17,066,7555,381,128

$22,447,882

Httrrls

Ntrcl4erCurfetdMonth

$21,038,3301,144,312

44,874,2667,091,980

574,148,887

Total 12 ME

June 201 6

$398,596,61317,96E751

561,527,735132.560,767

$1,110,673,867

676

910

Average Cost of Fuel Purchased (S/MSTU

CoalOrl

Gas ~ CCGas - CT

Weighted Average

2,169.08

2,169.08

1,594.94

294.07303.87

324 6T

324.67

336.58335.73336.00

332.501,059.26

374.45

333 29360 87

330.04I,ID6.04

402.18355.20371.04

11

12

13

14

15

1617

Cost ot Fuel Burned (3)

CoalOg-CCOil ~ Steam/CTGas - CCGas - CTNudearTotal

8.734,759

$8,734,759

100,536

$100.538 $410.645

S,7os

303,611

$312.318

5,45517,066,7555,381,126

$22,453,337

4,810,416$4,810,416

$48,780,84S2,928

1,1 05,97744,874,266

7,091,98017,018,469

$118,874,467

$361,200,81051 8,868

17,151,099561,527,735132,560,767199,346.949

$1,272,306,229

13

192021

222324

Average Cost of Fuel sumad (c/IrlgTU)

CoalOII - CCOil - Steam/CT

Gss - CCGas - CT

NudearWeighted Average

1,785.14

1,765.14

1,799 60

294 07

296.39

1,776 79

332.24

1,677.31

336.08335.73

67.7567.75

333.272,126.741,170.18

374.45333 2963 70

213 96

330.732,092.861,421.08

402.18355 2063.28

211 21

25262728293031

Avemge Cost at Generation (s/kWh)CoalOti-CCOil - Steam/07Gas - CC

Gav ~ CT

NuclearWeighted Average

0.65065

42.07

42 07

21.81

3.55

3.57

3.01

315

19.262 343.87

2.590 71

0.71

3.5324.9414.682.643.850.672 03

3.6624.0818.822.883.91

0.661.98

323334

353837

38

394041

424344454647

Burned MSTU's

CoalOg - CCOil - Steam/CTGas- CC

Gas - CTNudearTotal

Nel Genemtlon (mWh)

CoalOil - CCOrl ~ Steam/CTGas - CCGas - CTNudearHydro (Total System)Solar (Total SYstem)

Total

13,874,35713.874,357

1,343,7SI

1,343,781

5,696

239

239

213

138,335

138,548

18

11,474

11,492

490

93,514

(160)

10.084

9,924

3255,078,156I,NI2,793

6,681,274

28729,270138,938

868,236

7,099,8057,099,805

676,975

676,975

14,637,022138

94,51 3I 1,984,0422,127.876

28,71 5,994

55,559,585

1,380.836I2

T,531

1,699,332184,155

2,558,27727,70011,525

5,8$},369

109,212,89024,792

1,206,905139,619,75137,319,804

315,016,875502,401,017

10,159,0192,155

91,11319,488,0033,391,71 7

30,289,238625,89790,828

64,137,970

48495051

52

Coal ol Reagents Consumed (5)AmmoniabmestonsSomennureaTotal

$30,371

30,371

$425,3041,147,165

392,43464,078

2,028,982

32,994,5678,994,1833.954.7241,059,282

17,002,755

Coal Data :

1 Beginning balance

2 Tons received during period

3 Inventory adjustments

4 Tons burned during period

5 Ending balance

6 MBTUs per ton burned

7 Cost of ending inventory ($/ton)

on Data: 8 Beginning balance

9 Gallons received during period

10 Miscellaneous use and adjustments

11 Gallons burned during period

12 Ending balance

13 Cost of ending inventory ($/gal)

Gas Data: 14 Beginning balance

15 MCF received during period

16 MCF burned during period

17 Ending balance

Llmestonell.lme Data: 18 Beginning balance



21 Tons consumed during period

22 Ending balance


Duke Energy Progress Fuel Iii Fuel-related Consumption and Inventory Report

June 2016

Weatherspoon Lee Sutton Robinson

653,496

111,137

(234) 87,029

677,370

2.18

~

4,049,551

4,049,551

2,727,460

9,611 2,717,849

3.02

2,689,451

2,689,451

Detail amounts may not add to totals shown due to rounding.

Schedule excludes in-transit, terminal and tolling agreement activity.

Gas is burned as received; therefore, inventory balances are not maintained.

The oil inventory data for Wayne reflects the common usage of the on tank used

for both Wayne and lee units.

73,781

(4,967)

68,814

2.77

Schedule& Page 1of3

Asheville

126,443

34,619

46,230

114,832

25.42 80.63

3,221,440

(3,115) 64,016

3,154,309 1.95

286,082

286,082

24,330

98

2,112

22,316

36.08

Duke Energy ProgressFuel 8 Fuel-related Consumption and Inventory Report

June 2016

Schedule 6

Page I of 3

Une No. Description Weslherspoon Lee Sullen Robinson Ashevgle

Coal Data:Beginning balanceTons received during psriadInventory adjustmentsTons burned during periodEnding balanceMBTUs per ton burnedCost ol ending inventory (Sfton)

126,44334,619

46,230114,832

25.4280.53

8

9

10

11

12

13

Og Data:Beginning balanceGallons received during periodMiscellaneous uss and adjustmenlsGallons burned during period

Ending balanceCost of ending inventory (Wgal)

653,496111,137

(234)87,029

677,3702.18

2,727,460

9,611

2,717,8493.02

(4,967)

68,8142.77

3,221,440

(3,115)64,016

3,154,3091.95

14

15

16

17

Gas Data:Beginning balanceMCF received during penodMCF burned during periodEnding balance

4,049,5514,049,551

2,689,4512,669,451

286,082286,082

UmeslonafUme Dale:18 Beginning balance19 Tons received during period

20 Inventory adjustments21 Tons consumed during period

22 Ending balance23 Cost of ending inventory (5/ton)

24,330

2,112

22,31 6

36.08

~N

Detail amounts may not add to totals shown due to rounding.

Schedule excludes in-transit, terminal and tolling agreement activity.

Gas Is homed as received; therefore, inventory balances are not maintained.

The oil inventory data for Wayne regecls Ihe ccmmon usage of the og tank usedfor both Wayne and Lee units.

Coal Data: 1 Beginning balance




5 Ending balance



Oil Data: 8 Beginning balance



11 Gallons burned during period

12 Ending balance

13 Cost of ending inventory ($/gal)

Gas Data: 14 Beginning balance

15 MCF received during period

16 MCF burned during period

17 Ending balance

Limestone/Lime Data: 18 Beginning balance




22 Ending balance


Duke Energy Progress Fuel & Fuel-related Consumption and Inventory Report

June 2016

Roxboro Mayo Brunswick Blewett

1,310,065 731,857 216,520

440,917 91,332 1,085,668 640,525

25.67 23.49 84.98 82.99

349,437 259,149 168,829 758,767 411,906 236,808 15,516

(15,161) (5,115) 276,266 197,949 40,541 469,916 292,893 184,345 718,226

1.37 1.37 2.99 2.48

90,198 20,908 13,005 5,685

25,259 6,506

77,944 20,087 31.77 25.69

Schedule& Page 2 of 3

Wayne County

11,866,235 7,450

1,548

11,872,137 2.48

133,693 133,693

Duke Energy ProgressFuel Ik Fuel-related Consumpgon and Inventory Aeport

June 2015

Schedule 6

Page 2of 3

Line No. Description Roxboro Mayo Brunswick

Coal Data:

Beginning balanceTons received during period

Invenlory adjustmsntsTons homed during period

Ending balanceMSTUs per lon burned

Cost of ending inventory ($/ton)

1,310,065216,520

440,917I,D85,MB

25.6784.98

731,857

91,332640,525

23.4982.99

8

9

ID

11

12

13

Og Data:Beginning balanceGagons received during periodMiscellaneous use and adjustmentsGallons burned during periodEnding balanceCost of ending inventory ($/gal)

349,437411,906(15,161)278,286469.916

1.37

259,149236,808

(5,115)197,949292,893

1.37

168,829

15,516

184,3452.99

758,767

40,541

718,2262.48

11,866,2357,450

1,548

11,872,1372.48

14

15

16

17

Gas Dale:Beginning balanceMCF received during periodMCF burned during period

Ending balance

133,693133,693

18

19

2021

2223

Limestone/Ume Data:Beginning balanceTons received during penodInventory adjustmentsTons consumed during period

Ending balanceCost of ending inventory ($/ton)

90,19813,005

25,25977,944

31.7T

20,9085,685

6,50620,087

25.69

Inventory adjustments


5 Ending balance


7 Cost of ending inventory ($flan)

011 Data:

8 Beginning balance 10,159,331



11 Gallons burned during period 3,561

12 Ending balance 10,155,770 13 Cost of ending inventory ($!gal) 2.44

Gas Data:

14 Beginning balance

15 MCF received during period 91,051 16 MCF burned during period 91,051

17 Ending balance

Limestone/Lime Data:

18 Beginning balance




22 Ending balance

23 Cost of ending inventory ($flan)

Duke Energy Progress

Fuel & Fuel-related Consumption and Inventory Report

June 2016

Smith Energy Complex Harris

7,875,552 282,475

2,323 7,873,229 282,475

2.35 2.99

6,502,465 6,502,465

Current Month

2,168,365

251,139

578,479

1,841,025 25.30

84.02

38,395,952

782,817

(28,592) 682,844

38,467,333

2.42

13,752,293

13,752,293

135,436 18,788

33,877

120,347

31.56

Schedule&

Page3of3

Total 12 ME June 2016

1,453,186

4,856,342 (95,406)

4,373,097

1,841,025

24.97 84.02

36,008,111

11,785,532

(312,701) 9,013,609

38,467,333

2.42

170,830,546

170,830,546

98,419

267,985 11,405

257,462 120,347

31.56

Duke Energy ProgressFuel 8 Fuel-related Consumption and Immntory Repoh

Juris 2016

Schedule 6

Page 3 of 3

Line No. Darg tonSmith Energy

Complex HarrisCurrentMonth

Total 12 MEJUINI 2016

Coal Data:Beginning balanceTens received during periodInventory adjustmentsTons burned dunng penodEnding balanceMBTUs par ton burnedCost of endrng inventory ($/ton)

2,168,365251,139

578,4791,841,025

25.3084.02

1,453,1864,856,342

(95,406)4,373,0971,841,025

24.9784.02

8

9

1011

12

13

Og Data:Beginning balanceGallons reaeived during period

Miscegeneaus use and adjustmentsGallons burned during periadEnding balanceCost ol ending inventory ($/gal)

10,159,331

3,561

10,155,7702.44

7,875,552

2.3237,873,229

2.35

282,475

282,4752.99

38,395,952782,817

(28,592)882,844

38,467,3332.42

36,008,11111,785,532

(31 2,701)9,013,609

38,467,3332.42

14

15

16

17

Gas Data:Beginning balanceMCF received during periodMCF burned during periodEnding balance

91,051

91,051

6,502,4656,502,465

13,752,29313,752,293

170,830,5461 70,830,546

18

19

2021

2223

Umestone/Lime Date:Beginning balanceTons received during periodInventory adjustmenlsTons consumed during periadEnding balanceCost of ending inventory ($/ion)

135,43618,788

33,877120,347

31.56

98,419267,985

11,405

257,462120,347

31.56

M A Y O

R O X B O R O

A L L P L A N T S

D U K E ENERGY PROGRESS

A N A L Y S I S OF C O A L P U R C H A S E D

J U N E 2 0 1 6

TYPE

SPOT

CONTRACT

ADJUSTMENTS

TOTAL

SPOT

CONTRACT

ADJUSTMENTS

TOTAL

SPOT

CONTRACT

ADJUSTMENTS

TOTAL

SPOT

CONTRACT

ADJUSTMENTS

TOTAL

Q U A N T I T Y O F

T O N S D E L I V E R E D

34,619

34,619

216,520

216,520

251,139

251,139

$

$

DEUVERED COST

(11,258) 2,384,107

101,065 2,473,915

1,864 315,368

317,232

16,059,742 2,187,441

18,247,183

(11,258) 18,445,712 2,603,875

21,038,330

Schedule7

DELIVERED COST PER TON

68.87

71.46

74.17

84.27

73.45

$ 83.77

DUKE ENERGY PROGRESS

ANALYSIS OF COAL PURCHASED

JUNE 2016

Schedule 7

STATION TYPEQUANTITY OF

TONS DELIVEREDDELIVERED

COSTDELIVERED

COST PER TON

ASHEVILLE SPOTCONTRACT

ADJUSTMENTS

TOTAL

(11,258)34,619 2,384,107

101,065

3,6 9 73,915

68.87

71.46

MAYO SPOT

CONTRACT

ADJUSTMENlS

TOTAL

1,864315,368

317,232

ROXBORO SPOT

CONTRACT

ADJ USIM ENTS

TOTAL

216,520

216,520

16,059,7422,187,441

18,247,183

74.17

84.27

ALL PLANTS SPOTCONTRACTADJUSTMENTS

TOTAL

(11,258)251,139 18,445,712

2 693 675

5, 39 $ 2163633

73.45

83.77

A S H E V I L L E

M A Y O

R O X B O R O


A N A L Y S I S OF C O A L Q U A L I T Y R E C E I V E D

J U N E 2 0 1 6

PERCENT

M O I S T U R E

PERCENT

ASH

H E A T

V A L U E

6.31

5.76

6.37

11.53

8.15

8.81

12,237

13,120

12,655

Schedule&

PERCENT

SULFUR

1.37

2.92

2.12


ANALYSIS OF COAL QUALITY RECEIVED

3UNE 2016

Schedule 8

STATIONPERCENT

MOISTURE

PERCENT

ASH

HEAT

VALUE

PERCENT

SULFUR

ASHEVILLE

MAYO

ROXBORO

6.31

5. 76

6.37

11. 53

8.15

8.81

12,237

13,120

12,655

1.37

2. 92

2.12

/ C O N T R A C T

S U L F U R C O N T E N T O/o

G A L L O N S R E C E I V E D

T O T A L D E L I V E R E D C O S T

D E L I V E R E D C O S T / G A L L O N

B T U / G A L L O N

V E N D O R

S P O T / C O N T R A C T

S U L F U R C O N T E N T O/o

G A L L O N S R E C E I V E D

T O T A L D E L I V E R E D C O S T

D E L I V E R E D C O S T / G A L L O N

B T U / G A L L O N

N o t e :

$

$

$

$


ANALYSIS OF OIL PURCHASED

JUNE 2016

BRUNSWICK

Selma Tank Farm

Contract

0

15,516

46,440

2.99

138,000

WAYNE

Selma Tank Farm

Contract

0

7,450

16,396

2.20

138,000

MAYO

Greensboro Tank Farm

$

$

$

$

Contract

0

236,808

329,564

1.39

138,000

WEATHERSPOON

Petroleum Traders

Contract

0

111,137

174,313

1.57

138,000

ROXBORO


Contract

0

411,906

$ 572,841

$ 1.39

138,000

Sampling charges of $4,242 for the Asheville station and detention charges of $515 for the Robinson station are excluded.

Schedule9


ANALYSIS OF OIL PURCHASED

3UNE 2016

Schedule 9

BRUNSWICK MAYO ROXBORO

VENDOR

SPOT/CONTRACT

SULFUR CONTENT e/o

GALLONS RECEIVED

TOTAL DELIVERED COST

DELIVERED COST/GALLON

BTU/GALLON

Selma Tank Farm

Contract

15,516

46,440

2.99

138,000


Contract

236,808

329,564

1.39

138,000


Contract

411,906

572,8'}1

1. 39

138,000

WAYNE WEATHERSPOON

VENDOR

SPOT/CONTRACT

SULFUR CONTENT o/o

GALLONS RECEIVED

TOTAL DELIVERED COST

DELIVERED COST/GALLON

BTU/GALLON

Selma Tank Farm

Contract

7,450

16,396

2. 20

138,000

Petroleum Traders

Contract

111,137

174,313

1.57

138,000

Note:Sampling charges of$4 242 ibr the Asheville station and detenbon charges of$515 for the Robinson station are mduded.

Duke Energy Progress Page 1 of7

Power Plant Performance Data Twelve Month Summary

July, 2015 - June, 2016 Nuclear Units

Net Unit Generation Capacity Capacity Equivalent Name (mWh) Rating (mW) Factor(%) Availability(%)

Brunswick 1 7,246,802 938 87.95 87.77

Brunswick2 8,147,954 932 99.53 99.51

Harris 1 8,346,216 928 102.39 99.82

Robinson 2 6,548,266 741 100.60 96.48

UnitName

Brunswick 1

Brunswick 2

Harris 1

Robinson 2

NetGeneration

(mWh)

7,246,802

8,147,954

8,346316

6,548,266

Duke Energy ProgressPower Plant Performance Data

Twelve Month SummaryJuly, 2015- June, 2016

Nuclear Units

CapacityRating (mW)

938

932

928

741

CapacityFactot'%)

87.95

99.53

10239

100.60

Schedule 10Page 1 oft

EquivalentAvailability (%)

87.77

99.51

99.82

96.48

P r o g r e s s

P o w e r P l a n t P e r f o r m a n c e D a t a

T w e l v e M o n t h S u m m a r y

J u l y , 2015 t h r o u g h J u n e , 2016

C o m b i n e d C y c l e U n i t s

N e t G e n e r a t i o n

C a p a c i t y

U n i t N a m e

( m W h ) R a t i n g ( m W )

L e e E n e r g y C o m p l e x IA 1 , 3 2 0 , 2 3 5

196

L e e E n e r g y C o m p l e x 1B 1 , 3 3 1 , 2 2 9

195

L e e E n e r g y C o m p l e x I C 1,359,041

197

L e e E n e r g y C o m p l e x

S T I

2 , 4 8 2 , 2 2 9

3 7 8

L e e E n e r g y C o m p l e x B l o c k T o t a l 6 , 4 9 2 , 7 3 4

9 6 7

R i c h m o n d C o u n t y C C 7 1 , 2 4 1 , 5 6 3

172

R i c h m o n d C o u n t y C C

8 1 , 2 3 1 , 6 1 0 170

R i c h m o n d C o u n t y C C S T 4 1 , 3 9 5 , 0 7 4 169

R i c h m o n d C o u n t y C C

9

1 , 4 1 9 , 8 1 2 193

R i c h m o n d C o u n t y C C 10 1,417,002 193

Richmond County CC ST5 1,855,137 248

Richmond County CC Block Total 8,560,198 1,146

Sutton Energy Complex IA 1,335,200 198

Sutton Energy Complex 1B 1,407,020 198

Sutton Energy Complex STI 1,695,005 265

Sutton Energy Complex Block Total 4,437,225 662

Units in commercial operation for the full month are presented. Pre-commercial or partial month commercial operations are not included.

Schedule 10 Page 2 of7

Capacity Equivalent Factor(%) Availability(%)

76.64 92.93

77.68 93 .04

78.43 95.73

74.68 83.00

76.45 89.69

82.16 91.75

82.34 92.13

93.89 91 .92

83 .77 93.65

83.60 93 .08

85.04 89.06

85.06 91.92

76.73 92.96

80.86 93 .70

72.75 92.29

76.37 92.82


Twelve Month SummaryJuly, 2015 through June, 2016

Combined Cycle Units

Schedule 10Page 2 ofr

Unit Name

Lee Energy Complex

Lee Energy Complex

Lee Energy Complex

Lee Energy Complex

Lee Energy Complex

Richmond County CC

Richmond County CC

Richmond County CC

Richmond County CC

Richmond County CC

Richmond County CC

Richmond County CC

1A

1B

1C

ST1

Block Total

ST4

10

ST5

Block Total

Sutton Energy Complex 1A

Sutton Energy Complex 1B

Sutton Energy Complex ST1

Sutton Energy Complex Block Total

Net Generation(mWh)

1,320,235

1,331,229

1,359,041

2,482,229

6,492,734

1,241,563

1,231,610

1,395,074

1,419,812

1,417,002

1,855,137

8,560,198

1,335,200

1,407,020

1,695,005

4,437,225

CapacityRating (mW)

196

195

197

37$

967

172

170

169

193

193

24$

1,146

198

198

265

662

CapacityFactor (%)

76.64

77.68

78.43

74.68

76.45

82.16

82.34

93.$9

83.77

83.60

85.04

85.06

76.73

$0.86

72.75

76.37


92.93

93.04

95.73

83.00

$9.69

91.75

92.13

91.92

93.65

93.08

89.06

91.92

92.96

93.70

92.29

92.82

Units in commercial operation for the full month are presented.Pre-commercial or partial month commercial operations are not included.

N a m e

M a y o 1

R o x b o r o 3

R o x b o r o 4

D u k e E n e r g y P r o g r e s s




I n t e r m e d i a t e S t e a m U n i t s

N e t

G e n e r a t i o n C a p a c i t y C a p a c i t y

( m W h ) R a t i n g ( m W ) F a c t o r ( % )

1 , 9 2 4 , 0 1 5 735 29.81

1 , 4 2 5 , 2 3 4 6 9 4 2 3 . 3 8

1 , 6 4 8 , 4 7 2 7 0 3 2 6 . 6 8

U n i t s in c o m m e r c i a l o p e r a t i o n f o r the full m o n t h a r e p r e s e n t e d .

P r e - c o m m e r c i a l o r p a r t i a l m o n t h c o m m e r c i a l o p e r a t i o n s are n o t i n c l u d e d .

E q u i v a l e n t

A v a i l a b i l i t y ( % )

8 7 . 0 3

7 0 . 8 7

89.01




Schedule 10Page 3 of 7

Intermediate Steam Units

Unit Name

Mayo 1

NetGeneration

(mWh)

1,924,015

CapacityRating (mW)

735

CapacityFactor (%)

29.81


87.03

Roxboro 3 1,425,234 694 23.38 70.87

Roxboro 4 1,648,472 703 26.68 89.01


2015 t h r o u g h J u n e , 2016

N e t

G e n e r a t i o n

( m W h )

2 , 7 7 3 , 7 8 1

B a s e l o a d S t e a m U n i t s

C a p a c i t y

R a t i n g ( m W )

672

C a p a c i t y

F a c t o r ( % )

4 7 . 0 0

U n i t s in c o m m e r c i a l o p e r a t i o n f o r t h e full m o n t h are p r e s e n t e d .

P r e - c o m m e r c i a l o r p a r t i a l m o n t h c o m m e r c i a l o p e r a t i o n s a r e n o t i n c l u d e d .

E q u i v a l e n t


8 8 . 7 0

Schedule 10 Page4 of7


Twelve Mouth SummaryJuly, 2015 through June, 2016

Schedule 10Page 4 ofr

Baseload Steam Units

Unit Name

Roxboro 2

NetGeneration

(mWh)

2,773,781

CapacityRating (mW)

672

CapacityFactor (%)

47.00


88.70


N a m e

A s h e v i l l e

A s h e v i l l e 2

R o x b o r o





O t h e r C y c l i n g S t e a m U n i t s


C a p a c i t y C a p a c i t y

( m W h ) R a t i n g ( m W ) F a c t o r ( % )

6 0 3 , 6 8 7 191

3 6 . 0 0

6 4 6 , 1 3 8

188 39.11

1 , 1 9 7 , 7 3 6

3 7 9

3 5 . 9 4

U n i t s in c o m m e r c i a l o p e r a t i o n for the full m o n t h are p r e s e n t e d .

P r e - c o m m e r c i a l o r p a r t i a l m o n t h c o m m e r c i a l o p e r a t i o n s a r e n o t i n c l u d e d .

O p e r a t i n g


7 7 . 7 6

9 3 . 6 6

9 9 . 3 9




Other Cycling Steam Units

Schedule 10Page 5 of 7

Unit Name

Asheville 1

Asheville 2

Roxboro 1

603,687

646,138

1,197,736

191 36.00

188 39.11

379 33.94

Net Generatioa Capacity Capacity(mWh) Rating (mW) Factor (%)

OperatingAvailability (%)

77.76

93.66

99.39


P r o g r e s s


Twelve M o n t h S u m m a r y


C o m b u s t i o n T u r b i n e S t a t i o n s


C a p a c i t y

( m W h ) R a t i n g ( m W )

I 1 2 , 2 4 7

343

-133

59

6 5 , 2 8 7

808

R i c h m o n d C o u n t y C T 2 , 9 3 3 , 6 7 2

838

S u t t o n C T

-563

W a y n e C o u n t y C T 3 1 2 , 0 3 I

W e a t h e r s p o o n C T 245

U n i t s in c o m m e r c i a l o p e r a t i o n f o r the full m o n t h a r e p r e s e n t e d .

P r e - c o m m e r c i a l o r p a r t i a l m o n t h c o m m e r c i a l o p e r a t i o n s are n o t i n c l u d e d .

67

903

143

O p e r a t i n g


9 3 . 2 9

97 . 63

9 4 .2 7

8 6 . 1 3

9 2 . 7 2

9 1 . 4 9

9 6 . 9 0



Twelve Month SummaryJuly, 2015 through June, 2016Combustion Turbine Stations

Schedule 10Pageoof7

Station Name

Asheville CT

Blewett CT

Darlington CT

Richmond County CT

Sutton CT

Wayne County CT

Weatherspoon CT

Net Generation(mwh)

112,247

-133

65,287

2,933,672

-563

312,031

245

CapacityRating (mW)

343

59

808

&38

67

903

143

OperatingAvailability (%)

93.29

97.63

94.27

86.13

92.72

91.49

96.90


T i l l e r y

W a l t e r s



Twelve M o n t h S u m m a r y


H y d r o e l e c t r i c S t a t i o n s


C a p a c i t y

( m W h )

R a t i n g ( m W )

88,771 2 7 . 0

9 , 0 7 2 4 . 0

2 0 5 , 6 1 8

8 4 . 0

3 2 2 , 4 3 6 113 . 0

O p e r a t i n g


Availability(%)

78.21

49.23

98.20

72.99



Hydroelectric Stations

Schedule 10Page 7 oft

Station Name

B lewett

Marshall

Tillery

Walters

Net Generation(mWh)

88,771

9,072

205,618

322,436

CapacityRating (mW)

27.0

4.0

84.0

113.0

OperatingAvailability ('/e)

78.21

49.23

98.20

72.99

M e r g e r - R e l a t e d Fuel Savings

Schedule 11 Month Ending: June 2016 Dollars reported In ($)

Gross Savings Allocated Savings DE Progress

DE Carolinas DE Progress Combined DE Carolinas DE Progress SC Retail portion

1 Joint Dispatch $ 2,135,908 $ 284,669 $ 2,420,577 $ 1,469,893 $ 950,684 $ 89,281 2 Coal Blending 533,175 533,175 323,392 209,783 19,701 3 Coal Procurement 1,450,892 854,295 2,305,187 1,397,556 907,631 85,238 4 Coal Transportation 1,310,573 2,405,887 3,716,460 2,240,702 1,475,758 138,592 5 Reagent Procurement & Transportation 176,712 103,607 280,319 170,065 110,254 10,354 6 By-products 131,250 70,930 202,180 122,635 79,545 7,470 7 Natural Gas Capacity 182,521 182,521 110,710 71,811 6,744 8 Natural Gas Trading 35,954 35,954 21,807 14,147 1,329 9 Nuclear Fuel 9,800 9,800 5,947 3,853 362

10 Other Fuel-related

$ 5,966,785 $ 3,719,388 $ 9,686,173 $ 5,862,708 $ 3,823,465 $ 359,072

Resource ratio % 60.72% 39.28% 100.00%

Allocation% 9.39%

Twelve Months Ending: June 2016

Gross Savings Allocated Savings DE Progress


1 Joint Dispatch $ 34,744,603 $ 5,753,481 $ 40,498,084 $ 23,955,992 $ 16,542,092 $ 1,748,290 2 Coal Blending 31,934,854 31,934,854 19,132,606 12,802,248 1,360,864 3 Coal Procurement 18,927,014 17,119,110 36,046,124 21,662,080 14,384,044 1,549,201 4 Coal Transportation 15,689,773 13,740,823 29,430,596 17,603,734 11,826,862 1,234,344

5 Reagent Procurement & Transportation 2,621,436 1,237,609 3,859,045 2,318,384 1,540,661 166,530 6 By-products 3,508,333 (536,867) 2,971,466 1,776,618 1,194,849 126,234 7 Natural Gas Capacity 22,469,636 22,469,636 13,402,390 9,067,246 945,350 8 Natural Gas Trading 431,448 431,448 257,317 174,131 18,415 9 Nuclear Fuel 9,800 147,628 157,428 96,281 61,147 6,527

10 Other Fuel-related $ 130,336,897 $ 37,461,784 $ 167,798,681 $ 100,205,401 $ 67,593,280 $ 7,155,754

Total-to-date: June 2016

Target Gross Savings Allocated Savings DE Progress


1 Joint Dispatch $ 318,955,000 $ 123,863,600 $ 80,667,187 $ 204,530, 787 $ 124,213,855 $ 80,316,932 $ 8,822,666 2 Coal Blending 259,800,000 166,260,162 166,260,162 101,209,594 65,050,568 7,205,906 3 Coal Procurement 45,950,000 57,935,628 57,921,700 115,857,328 70,378,705 45,478,623 5,059,871 4 Coal Transportation 30,395,000 47,812,755 41,395,524 89,208,279 54,123,961 35,084,318 3,882,774 5 Reagent Procurement & Transportation 12,800,000 9,705,638 4,759,490 14,465,128 8,790,987 5,674,141 627,121 6 By-products 4,129,015 5,350,721 9,479,736 5,740,675 3,739,061 412,899 7 Natural Gas Capacity 16,900,000 73,825,654 73,825,654 44,219,814 29,605,840 3,199,114 8 Natural Gas Trading 2,000,000 1,725,792 1,725,792 1,049,924 675,868 74,579 9 Nuclear Fuel 62,300 7,397,198 7,459,498 4,636,729 2,822,769 317,697

10 Other Fuel-related 6,662,997 6,662,997 4,179,784 2,483,213 296,963 $ 686,800,000 $ 491,983,541 $ 197 ,491,820 $ 689,475,361 $ 418,544,029 $ 270,931,332 $ 29,899,591

Dtrke Energy PfognmsMerger-Related Fuel SavingsMonth Endings

Dogam reported in (S(

June 2016

Gross Savings Agocated Savmgs

Schedule 11

DE Pfogmss

1 Joint Dispatch2 Coal Blending

3 Coal Procurement4 Coal Transportation5 Reagent Procurement & Transportation6 By-products7 Natural Gas Capacity

8 Natural Gas Trading9 Nuclear Fuel

10 Other Fuel-related

DE Carolinas

2,135,908533,175

1,450,8921,31D,573

176,712131,250182,52135,954

9,800

5,966,785 S

DE Pfogfest

284,669 5

854,2952,405,887

103,60770,930

3,719,388 S

Combined

2,420,577533,175

2,305,1873,716,460

280,319202,180182,52135,9549,800

9,686,173

DE Carolinas

1,469,893323,392

1,397,5562,240,702

170,065122,635110,71021,807

5,947

5,862,708

DE Progress

950,684209,783907,631

1,475,758110,25479,54571,81114,1473,853

3,823,465

SC Retail portion

89,28119,70185,238

138,59210,3547,4706,7441,329

362

359,072

Resource ratio N

Agocation N

60.72% 39.28%

9.39N

Twelve Months Ending: June 2016

DE Carolinas

Gross Savings

DE Progress Combined DE Carognas DE pl'ogfass

Allocated Savings OE Progress

SC Retail portion

1

2

3

4567

8

910

Joint DispatchCoal BlendingCoal ProcurementCoal TransportationReagent Procurement & TransportationBy-productsNatural Gas CapacityNatural Gas TradingNuclear Fuel

Other Fuel-related

5 34,744,603 531,934,85418,927,01415,689,7732,621,4363,508,333

22,469,636431,448

9,800

5,753,481 5

17,119,11013,740,8231,237,609(536,867)

147,628

40,498,08431,934.85436,046,12429,430,596

3,859,0452,971,466

22,469,636431,448157,428

5 23,955,99219,132,60621,662,08017,603,7342,318,3841,776,618

13,402,390257,317

96,281

5 16,542,09212,802,24814,384,04411,826,862

1,540,6611,194,8499,067,246

174,13161,147

1,748,2901,360,8641,549,2011,234,344

166,530126,234945,350

18,4156,527

S 130,336,897 3 37,461,784 3 167,798,681 3 100,205,401 5 67,593,280 7,155,754

Total-toutatm June 2D16

Target

DE Caro lines

Gross Savings

DE Progress Combined DE Carolinas DE Progress

Allocated Savings DE Pfogress

1

2

3

45

67

89

10

Joint DispatchCoal BlendingCoal ProcurementCoal TransportationReagent Procurement 8 TransportationBy-productsNatural Gas CapacitY

Natural Gas TradingNuclear Fuel

Other Fuel-related

318,955,000259,800,000

45,950,00030,395,00012,800,000

16,900,0002,000,000

123,863,600 5166,260,16257,935,62847,812,7559,705,6384,129,015

73,825,6541,725,792

62,3006,662,997

491,983,541 5

80,667,187 5

57,921,70041,395,5244,759,4905,350,721

7,397,198

197,491,820 3

204,530,787166,260,162115,857,328

89,208,27914,465,128

9,479,73673,825,654

1,725,7927,459,4986,662,997

689,475,361

124,213,855101,209,59470,378,70554,123,961

8,790,9875,740,675

44,219,8141,049,9244,636,7294,179,784

416,544,029

80,316,93265,050,56845,478,62335,084,318

5,674,1413,739,061

29,605,840675,868

2,822,7692,483,213

270,931,332

8,822,6667,205,9065,059,8713,882,774

627, 121

412,8993,199,114

74,579317,697296,963

29,899,591