Duke Energy@

August 1 1 , 201 1

Duke Energy Corporation 139 Easf Fourfh Sfreef P 0. Box 960 Cincinnati, Ohio 45201-0960

AUG ‘B ’K 2011

PUBiiL-, ::erVICE

Kentucky Public Service Commission Attn: Mr. Jeff Derouen, Executive Director 2 1 1 Sower Boulevard Frankfort, Kentucky 40602 c o[\/l i\j, 1 S S I ai\\ Dear Mr. Derouen:

Enclosed for filing are an original and ten (10) conformed copies of Duke Energy Kentucky’s (“Duke”) “Monthly Report of Gas Cost Calculations and Tariff Schedules,” for the month commencing with the September 2011 revenue month in accordance with KPSC order dated November 6, 2003 in Case No. 2003-00386. This filing is based on supplier tariff rates expected to be in effect on August 31, 201 1 and the NYMEX close on August 8, 2011 for the month of September, 20 1 1.

The above described schedules and GCA are effective with the final meter readings of District 1, September 201 1 revenue month (Le., final meter readings on and after August 31,201 1).

Duke’s proposed GCA is $5.866 per Mcf. This rate represents a decrease of $0.074 per Mcf from the rate currently in effect for August 201 1.

Very truly yours,

John Linton

Enclosure

cc: L. Schmidt

R:/tariffs/gcr/ulhp/gca monthly filingdoc

www duke-energy corn

3rd QlJARTER COVER DUKE ENERGY KENTUCKY, INC

GAS COST ADJUSTMENT CLAlJSE

QUARTERLY REPORT

GAS COST RECOVERY RATES EFFECTIVE FROM AUGUST 31,201 1 THROUGH SEPTEMBER 29,201 1

AMoUNT J DESCRIPTION UNIT

EXPECTED GAS COST (EGC) $/MCF 5 804

ACTUAL ADJUSTMENT (AA) $IMCF 0.059 $/MCF (0.004)

L SlJPPLlER REFUND ADJUSTMENT (RA)

BALANCE ADJUSTMENT (BA) $IMCF 0.007 GAS COST RECOVERY RATE (GCR) = EGC + RA + AA +BA $IMCF 5.866

EXPECTED GAS COST CALCULATION

DESCRIPTION UNIT AMOUNT -1 --

TOTAL EXPECTED GAS COST COMPONENT (EGC) $/MCF 5.804

SUPPLIER REFUND ADJUSTMENT CALCULATION I I

DESCRIPTION UNIT

CURRENT QUARTER SUPPLIER REFUND ADJ. $/MCF (0.001) PREVIOUS QUARTER REPORTED SUPPLIER REFUND ADJ. $IMCF (0.001) SECOND PREVIOUS QUARTER REPORTED SUPPLIER REFUND ADJ. $/MCF (0.001) THIRD PREVlOlJS QUARTER REPORTED SUPPLIER REFUND ADJ. $/MCF (0.001 ) SUPPLIER REFUND ADJUSTMENT (RA) $IMCF (0 004)

ACTUAL ADJUSTMENT CALCULATION

DESCRIPTION UNIT-] AMOUNT

CURRENT QUARTER ACTUAL ADJUSTMENT $/MCF (0.308) PREVIOUS QUARTER REPORTED ACTUAL ADJUSTMENT $/MCF (0.038) SECOND PREVIOUS QUARTER REPORTED ACTUAL ADJUSTMENT $/MCF 0.372 THIRD PREVIOUS QUARTER REPORTED ACTUAL ADJUSTMENT $/MCF 0.033 ACTUAL ADJUSTMENT (AA) $/MCF 0 .059

BALANCE ADJUSTMENT CALCULATION

DESCRIPTION UNIT AMOUNT '-1 -

CURRENT QUARTER BALANCE ADJUSTMENT $/MCF 0.001 PREVIOUS QUARTER REPORTED BALANCE ADJUSTMENT $IMCF 0 011 SECOND PREVIOUS QUARTER REPORTED BALANCE ADJUSTMENT $/MCF (0.003) THIRD PREVIOUS QUARTER REPORTED BALANCE ADJUSTMENT $/MCF 10.002) BALANCE ADJUSTMENT (BA) $/MCF 0.007

THIS QUARTERLY REPORT FILED PURSUANT TO ORDER NO. 8373 OF THE KENTUCKY PUBLIC SERVICE COMMISSION DATED APRIL 16, 1982.

DATE FILED: Auqust 11.201 1 BY. DON WATHEN

TITLE: VICE-PRESIDENT, RATES

Schedule I Page 1 of 4

GAS COST ADJUSTMENT DUKE ENERGY KENTUCKY

EXPECTED GAS COST RATE CALCULATION (EGC)

"SUMMARY" FOR THE EGC RATE IN EFFECT AS OF AUGUST 31,2011

DEMAND (FIXED) COSTS:

Columbia Gas Transmission Carp. Texas Gas Transmission Columbia Gulf Transmission Carp. KO Transmission Company Gas Marketers

TOTAL DEMAND COST:

PROJECTED GAS SALES LESS SPECIAL CONTRACT IT PURCHASES:

DEMAND (FIXED) COMPONENT OF EGC RATE: $7,738,128 I

COMMODITY COSTS:

Gas Marketers Gas Storage

Propane Columbia Gas Transmission

COMMODITY COMPONENT OF EGC RATE:

- OTHER COSTS: Net Charge Off (')

TOTAL EXPECTED GAS COST:

$1 7,952

2,778,245 895,375

2,223,424 307,584

1,533,500 7,738,128

10,110,07~ MCF

10,110,075 MCF $0.765 lMCF

/ 237,094

$4.963 IMCF

$0.000 /MCF $0.000 /MCF $4.963 lMCF

$0.076 /MCF

$5.804 lMCF

SCHEDULE I PAGE 2 OF 4

GAS COST ADJUSTMENT DUKE ENERGY KENTUCKY

DETAILS FOR THE EGC RATE IN EFFECT AS OF : AUGUST 31,2011

CONTRACT NUMBER EXPECTED RATE VOLUME OF GAS COST

( $ DTH) (DTH) DAYSIMTHS ( $ )

INTERSTATE PIPELINE : TARIFF RATE EFFECTIVE DATE : FSS: 2/1/2011

SST: 8/1/2011

COLUMBIA GAS TRANSMISSION, LLC

BILLING DEMAND - TARIFF RATE - FSS Max Daily Withdrawl Quan. 1.5050 39,656 Seasonal Contract Quantity 0.0289 1,365,276

BILLING DEMAND - TARIFF RATE - SST Maximum Daily Quantity 4.4510 19,828 Maximum Daily Quantity 4.4510 39,656

CAPACITY RELEASE CREDIT

TOTAL COLlJMBlA GAS TRANSMISSION, LLC - DEMAND CHARGES

INTERSTATE PIPELINE . TARIFF RATE EFFECTIVE DATE.

TEXAS GAS TRANSMISSION NOT APPLICABLE

BILLING DEMAND - TARIFF RATE - STF Max Daily Quantity Zone 4 0.3250 10,000

BILLING DEMAND -TARIFF RATE - FT Max. Daily Quantity Zone 4 0.2950 5,000 Max Daily Quantity Zone 4 0.1700 5,000

CAPACITY RELEASE CREDIT

TOTAL TEXAS GAS TRANSMISSION DEMAND CHARGES

12 71 6,187 12 473,478

6 529,527 6 1,059,053

0

2,778,245

151 490.750

151 222,725 214 181,900

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54 51 San Felipc. Suite 2500 Houston. Texas 77056

kugiist 18. 2009

Mr. James L Turner Group Executive, President S, COO 139 East Fourth Street EM025 Cincinnati, OH 45202

RE: Revision 1 to SST Service Agreement No. 79977 Discount Letter Agreement

Dear Mr Turner:

This letter shall serve as an amendment to the 5ST Service Agreement between Columbia f&is Transmission. LLC ('Transporter) and Duke Energy Kentucky, {nc. (Shipper) designated as Transporter's Contract No. 79977.

A) Transporter and Shipper hereby agree that Section 3 of the above-referenmd Contract number shall be amended to include the following additional language:

I ) The rate for service, for the period from j1/01/09 to 3/31/10, shall include a discounted demand rate, inclusive of the base rate and all demand surcharges, of $3.963 for deliveries to the primary delivery points: KOT DEK MLI (834696) and the following primary receipt points: MRTCO - Master Receipt TCO / RP Storage Point TCO. Shipper shall also provide the then- existing Retainage and shall pay the thenexisting maximum commodity charge plus commodity surcharges as set forth in Transporter's FERC Gas Tariff from time to time.

2 ) The rate for service, for the period from 4/01/10 to 3/31/15, shall include a of the base rate and all demand

primary receipt points: MRTCO - Master TCO. Shipper shall also provide the then-

deliveries to the primary delivery points: KOT discounted d

existing Retainage and shall pay the thenexisting maximum commodity charge plus commodity surcharges as set forth in Transporter's FERC Gas Tariff from time to time.

I

3 ) The discounted rate provided in paragraph one and two above is Jimited to the Primary receiptldelivery point combinations set forlh in Appendix A Of the above-referenced service agreement. Except to the extent Federal Energ\( Regulatory Commission ("FERC") policies, rules and/or regulations, and/or- Transporter's FERC Gas Tariff provide oftiewise, for service iinder the above-referenced Service Agreement from secondary receipt points Or to secondary delivery points, in lieu of the rates set forth in Paragraph 1 above, TmSPOrter shall charge and Shipper shall pay the then existing maximrJm f&?CourSe Rate set forth in Transporter's FERC Gas Tariff from time to time

4) Notwithstanding the foregoing, the charge to be paid by Shipper and Transporter shall be no lower than the applicable total effective minimm charges or higher than the applicable total effective maximum charges as set for in Transporter's FERC Gas Tariff from time to time. Rates provided for in this Discount Letter Agreement will be adjusted as necessary so that the rate Will be no lower than the total effective minimum charges nor higher than the applicable total effective maximum charges as set forth in Transporter's FERC Gas Tariff from time to time.. I n th.e event that a rate component which was at or below the applicable maximum rate at the time this Discount Letter Agreement was executed subsequently exceeds the applicable maximum rate due to a change in Transporter's maximum rate so that such rate component must be adjusted downward to equal the new applicable maximum rate, then other rate components may be adjusted upward to achieve the agreed overall rate, SO long as none of the resulting rate components exceed the maximum rate applicable to that rate component. In the event the monthly Recourse Rate applicable to SST service is reduced to a level below $3.963 or $4..451 per Dth of Transportation Demand during the term of the above-referenced individual Semi= Agreement, the rates under the SST Service Agreement referenced above will be adjusted to the new monthly Recaurse Rate.

5 ) This discounted transportation rate shall be apportioned in accordancB with Section 20 of the General Terms and Cdnditions of Transporter's FERC Gas Tariff.

6) Shipper shall pay all then existing maximum overmn charges, if incurred, as set forth in Transporter's FERC Gas Tariff from time to time.

--

_____--..___-..--------__-I-._.. . . . . . .- .

..- - -

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If you are in agreement with the above amendment. please er.er& both originals of this Mer and return them to the Transporter at the address above, Attention Sandra Dibello

Terms agreed to this Id day of x.pp/m/;p..- , 2009

COLUMBIA GAS

Its Didctor, Cohrnercial Services

Duke Energy I 2

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3800 Frederica Street P.O. Box 20008

Owensboro, KY 42304-0008 270/926-8636

May 22,2007

Mr. Jim Heming Duke Energy Kentucky, Inc. 139 E 4th Street Cincinnati, ON 45202-4003

Re: Discount Agreemeut

Dear Jim-

Texas Gas Transmission, LL.C (Texas Gas) has reviewed the request of Duke Energy Kentucky, Xnc. (Duke) for a discounted transportation rate for the time period listed below. Accordingly, Texas Gas is willing to offer Duke the failowing discount:

Confract No.:

Rate Schedule:

Time Period:

Contract Demand:

Qualified Delivery Points:

26549

STF

November I, 2007 - March 31,2008 November 1,2008 - March 3 I, 2009 November I, 2009 - March 3 1,2010 November 1,2010 -March 3 1,201 1

10,000 MlvlBtu per day

Duke Energy OWZone 4, Meter No. 1229 Duke Energy KY/Zone 4, Meter No. 1872 1.ebanon-Columbia Gas/Zone 4, Meter No. 17 15 khanon-DominiodZone 4, Meter No. 1247 Lebanon-Texas Eas tedZone 4, Meter; No. 1859

For each unit of its daily contract demand, Duke shall pay-$,’;%%3(&iAudmg all surcharges).

Tern Gas’ minimum STF Conunodity Rate plus ACA and applicable fitel retention.

bg22(. w i 4 .o 2 g s

-- SP: 115972101 Texas Gas Transmission, LLC S.ezzc_! -- .. - ;isplay

Award No: 1951 Process Status: Pos;erf

Withdrawn: No

Affiliate Indicator: Releaser

Status: Confirmation

Bid No: 2261 Bidder: Duke Kentucky 006944672

Bidder E-mail: laura schmtdt@duke-energy coin

Bidder Contract Number: 30917

Bidder Phone: (513) 267-3169 Offer No: 3219 Releaser: Duke Ohio 006999189

Posting Datemime: 10115/2010 13.07 CCT Modified Posting DatefFime: 10/15/2010 13.07 CCT

Replacement Shipper Role Identifier: Other

Capacity Award Date/TFime: 10/15/2010 13 07 CCT

LOC Zn LOC Purp Awd Qty-Loc 1 MZ-RecelpI Locaeon 3 177

Rate Schedule: FT Release Term Start Date: 11/01/2010

Prearranged Deal: Yes Permanent Release: No

Allowable Re-release: Yes Awd Qty-K: 5,000

,

Award Terms

Release Term End Date: 03/31/2011

5000 I 5000 I

Previously Released: No

Award Recall Information

RecalllReput: Capacity recallable and reput must be taken Business Day: No

Recall Notification Period: Timely Early Evening Evening lntraday 1 lntraday 2

Award Location(s)

Start Date End Date LoclQTl Location Loc Prop 11/01/2010 Receipt PI 152451 2102 Champlin 0313112011

11/01/2010 03OlROI 1

11/01/7.010 03/31/2011

03/31/2011 1 1/01/2010 0x3 1RO 11

11/01/2010 03/31/2011

i i m i ~ o i o

-6016

Receipt PI 7580 3446 Lowry SL M2-Receipt Location 3 604

Delivery PI 16281 1715 Lebanon-Columbia Gas 4 MQ-Delivery Location

SEPipeline Segment defined by 2

S3-Pipline Segment defined by 1 Location S3-Pipeline Segment defined by 1 Location

Recto Del Pt 218394 3918 Mainline SL SI0 SL 16281 1715 LebanonColumbia Gas 4 Locations

1

SL

Segment IC0 Nodh Louisiana

Segment 5W Southwesl

3.177

3.604

iasurement Basis: Million BTU's

Award Rate(s) Rate Formf'f'ype Code: Reservation charge only Reservation Rate Basis: Per day

Bidder Bid Basis: Absolute dollars and cents per unit basis

ate Identification Code Max Trf Rate Award Rate 1 I eservation $0 3142 pa. , , ~ ~ $ q Z 5 0 : :

te(s) stated include all applicable surcharges; no surcharge detail or surcharge total provided

About I Contad 1 Logc 0 Copyright 2004 - 2010 Texas Gas Transmission. LLC

https://www. gasquest.txgt.com/CapacityRelease/Award/AwardPage.aspx?Mode=Display lO/l8/2010

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jP: 1'15972101 Texas G a s Transmission, LCC

1iS.day a s

Award No: 1952 Process Status: Posted Status: Confirmation

Withdrawn: No

Affiliate Indicator: Releaser

Bid No: 2262 Bidder: Duke Kentucky 006944G72

Bidder E-mail: laura schmidl@duke-energy con1

Bidder Contract Number: 309 18

Bidder Phone: (513) 287-31F9 Offer No: 3220

Releaser: Duke Ohio 006999189

Posting DatefTime: 10/15/2010 13 13 CCT Modified Posting Date/Time: 10/15/2010 13 13 CCT

Replacement Shipper Role Identifier: Other

Capacity Award DateKime: 10/15/2010 13 13 CCT

Award Terms Rate Schedule: FT

RecalllReput: Capacity recallable and reput must be taken RecalllReput Terms- Business Day: No

Release Term Start Date: 04/01/20 1 1 Prearranged Deal: Yes

Permanent Release: No Allowable Re-release: Yes

Awd Qty-K: 5,000

lnlraday recallable

Release Term End Date: 10/31/2011

Previously Released: No

i +-

Award Location@)

Start Date End Date Loc/QTI Location LOC Prop 04/01/2011 Receipt PI 152451 2102 Champlin 10131/2011 0410112011 Receipt PI 7580 9446 Lwcy 1 o n 11201 1

Awd Qty-L.oc Loc Zn 1 Mf.-Receipt Locarion 1.815

Coc Purp

SL MZ-Receipt Localion 4.966

04/01/201 I Delivery PI 1628 1 1715 Lebanon6olumbia Gas 4 5 . m

1013112011 16281 1715 LebanonGolumbia Gds 4 LocaIlOns 04/01/2011 Segment 100 North Louisiana 1 1815 10131/2Oll Location 04101/2Oll Segmen! 5W Soulhwest SL S9Pipeline Segment defined by 1 4966 1013112011 Locaeon

MQ-Delivery Loca!ion 1013 1120 11

04/01/2011 RecloDelPt 218394 3918 Mainline SL Sm SL SBPipeline Segment defined by 2 5 OW

SsPipeline Segmenl defined by 1

- 6 o f 6 ___

3asurernent Basis Million BTU's

Award Rate(s) Rate Formmype Code: Reservation charge only Reservation Rate Basis: Per day

Bidder Bid Basis: Absolute dollars and cents per unit basis

ate Identification Code Max Trf Rate Award Rate

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eservation $0 3142 @&$yqQgc< -- le(s) stated include all applicable surcharges; no surcharge detail of surchaigetotal provided

Abaut I Cantad I Logoui 6 Copynghl2004 - 2010 Texas Gas Transmission. LLG ; . * P

https://w.gasquest .txgt.com/CapacityRelease/A wardAwardPage.aspx?Mode=Display 1011 8/2O10

SCHEDULE I PAGE 3 OF 4

GAS COST ADJlJSTMENT DUKEENERGYKENTUCKY

DETAILS FOR THE EGC RATE IN EFFECT AS OF : AUGUST 31,2011

I CONTRACT NUMBER EXPECTED RATE VOLUME OF GAS COST

( $ DTH) (DTH) DAY SlMT H S ( $ )

INTERSTATE PIPELINE : COLUMBIA GULF TRANSMISSION CORP. TARIFF RATE EFFECTIVE DATE. FTS-I. 5/1/2011

FTS-2: 5/1/2011

BILLING DEMAND -TARIFF RATE - FTS-1 Maximum Daily Quantity Maximum Daily Quantity Maximum Daily Quantity Maximum Daily Quantity

BILLING DEMAND - TARIFF RATE - FTS-2 Maximum Daily Quantity

5.4919 22,782 5.4919 17,598 5.4919 18,000 5 4919 9,000

0.9995 15.000

CAPACITY RELEASE CREDIT FOR FTS-1 CAPACITY RELEASE CREDIT FOR FTS-2

TOTAL COLUMBIA GULF TRANSMISSION CORP. DEMAND CHARGES

INTERSTATE PIPELINE : TARIFF RATE EFFECTIVE DATE I

KO TRANSMISSION COMPANY 4/1/2011

BILLING DEMAND -TARIFF RATE - FT Maximum Daily Quantity 0.3560 72,000

CAPACITY RELEASE CREDIT

TOTAL KO TRANSMISSION CO. DEMAND CHARGES

VARIOUS GAS MARKETERS FIXED (RESERVATION) CHARGES :

November - March December - February

TENASKA STORAGE SERVICE November - March

TOTAL GAS MARKETERS FIXED CHARGES

0 14,108,957 0 15 90,000

I ,000,000

5 625,582 7 676,525 5 494,271 5 247,136

12 179.91 0

0 0

2,223,424

12 307,584

0

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13,500

1,520,000

1,533,500

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KO Transmission Company, Tariffs, Rate Schedules and Service Agreements Filing Category Normal Filing Date 03/0 1/2011 FERC Docket RP11-01843-000 FERC Action Accept FERC Order delegated order Order Date 03/22/2011 Effective Date 04/0 1 /20 1 1 Status Effective Part 3, Currently Effective Rates, 2 0 0

CIJRRENTLY EFFECTIVE RATES APPLICABLE TO RATE SCHEDIJLES FTS AND ITS

RATE LEVELS - RATE PER DTH

RATE SCHED'IJLE FTS Reservation Charge '/ Maximum 1 Maximum 2 Daily Rate - Maximum 1 Daily Rate - Maximum 2

Coinrnodity Maximum Miniiiiuiii Ovei-run

RATE SCHEDULE ITS Commodity Maximum Mini iiiuiii

Base Tariff Rate

$0.3560 $0.3560 $0.0 1 17 $0.01 17

$0.0000 $0.0000 $0.01 17

$0.01 17 $0.0000

Annual Total C ti a r ge Ad,justment'/ Rate

Effective

_ _ $0.3560 _ _ $0 3.5 6 0 -- $0.01 I7 _ _ $0.01 17

$0.001 9 $0.0019 $0.001 9 $0.0019 $0.0019 $0.0 136

$0.001 9 $0.0136 $0.001 9 $0.001 9

ACA assessed where applicable pursuant to Section 1 54.402 of the Commissioii's I/

regulations and will be charged pursuant to Section 2.3 of the General Terms and Conditions at such time that initial and successive annual ACA assessiiieiits applicable to Transporter are made

'' Minimum reservation charge is $0.00

Transportation Retainage Ad.justiiient 0.94%

NOTE Uti l izing GISB staiidaids 5 3 22 and 5 3 23, Transpoitei's Rate Schedule FTS Reservation Chaige caii be coiiveited to an applicable daily late by dividing the above monthly rate by 30 4 days

8/8/2011

DUKE ENERGY KENTUCKY TOTAL RESERVATION COSTS FROM FIRM SUPPLIERS

ESTIMATED FOR EGC EFFECTIVE 9/1/201 I

TOTAL ANNUAL RESERVATION COST:

TOTAL DOLLARS $ 39,108 (1)

TOTAL ANNUAL COVERAGE:

J CITY GATE VOLUMES 14,108,957 DTH (2)

CALCULATEDRATE: $ 0.0028 - PER DTH

(1 ) Reservation charges billed by firm suppliers for 201 0 - 201 1. (2) Contracted volumes for the 2010 - 201 1 winter season.

R:\Procurement&Admin\lSchmidt\EGC\EGC Backup Data\Duke KY Reservation Cost from Firm Suppliers & Peaking.xls

8/8/20 1 1

DUKE ENERGY KENTUCKY TOTAL RESERVATION COSTS FROM NEEDLE PEAKING SUPPLIERS

ESTIMATED FOR EGC EFFECTIVE 9/1/2011

TOTAL ANNUAL RESERVATION COST:

TOTAL DOLLARS $ $2,250.00 ( 1 )

TOTAL ANNUAL COVERAGE:

90,000 J DTH (2) I

CITY GATE VOLUMES

CALCULATED RATE: $ 0.0250 PER DTH

(1 ) Reservation charges billed by needle peaking suppliers for 201 0 - 201 1 (2) Contracted volumes for the 201 0 - 201 1 winter season.

R:\Procurement&Admin\lSchmidt\EGC\EGC Backup Data\Duke KY Reservation Cost from Firm Suppliers & Peaking.xls

SCHEDlJLE I PAGE 4 OF 4

GAS COST ADJUSTMENT DUKE ENERGY KENTIICKY

DETAILS FOR THE EGC RATE IN EFFECT AS OF : AlJGUST 31,2011

-___

GAS COMMODITY RATE FOR SEPTEMBER, 2011:

GAS MARKETERS. WEIGHTED AVERAGE GAS COST @ CITY GATE ($/Dth) (1). $4.7474 $/Dth DUKE ENERGY KENTUCKY FUEL 3.400% $0.1614 $4.9088 $/Dth DTH TO MCF CONVERSION 1.0111 $0.0545 $4.9633 $/Mcf EST1 MATED W El G HTl N G FACTOR 100.000% $4.9633 $/Mcf

GAS MARKETERS COMMODITY RATE $4.963 $/Mcf

GAS STORAGE :

COLUMBIA GAS TRANS. FSS WITHDRAWAL FEE

COLUMBIA GAS TRANS SST COMMODITY RATE KO TRANS, COMMODITY RATE DUKE ENERGY KENTUCKY FUEL 3.400°/0 DTH TO MCF CONVERSION 1.0111

COLUMBIA GAS TRANS. - STORAGE INVENTORY RATE

COLUMBIA GAS TRANS. SST FUEL 2.229%

EST1 MATED WE I G HTI N G FACTOR o.aooo/, GAS STORAGE COMMODITY RATE - COLUMBIA GAS

PROPANE : ERLANGER PROPANE INVENTORY RATE

$5.551 5 $0.0153 $5.5668 $0.1241 $5.6909 $0.0303 $5.72 12 $0.0019 $5.7231 $0.1946 $5.9177 $0.0657 $5 9834

$0.000 $0.0000

$/Dth $/Dth $/Dth $/Dth $/Dth $/Dth $/Mcf $/Mcf $/Mcf

$0.44920 $/Gallon GALLON TO MCF CONVERSION 15.38 $6 4595 $6.9087 $/Mcf EST1 MATED WE I G HTI N G FACTOR 0 000% $0.0000 $/Mcf

PROPANE COMMODITY RATE $0.000 $/Mcf

(1) Weighted average cost of gas based on NYMEX prices on 8/8/11 and contracted hedging prices

3rd QUARTER

SCHEDULE li GAS COST ADJUSTMENT CLAUSE

SUPPLIER REFUND ADJUSTMENT DUKE ENERGY KENTUCKY, INC

DETAILS FOR THE THREE MONTH PERIOD ENDED MAY 31, 201 I

DESCRIPTION UNIT AMOUNT

SUPPLIER REFUNDS RECEIVED DURING THREE MONTH PERIOD March 1 201 1 THROUGH MAY 31. 201 1

INTEREST FACTOR (REFLECTING 90 DAY COMMERCIAL PAPER RATE)

REFUNDS INCLUDING INTEREST ( $14,278.93 x 0.9990 )

DIVIDED BY TWELVE MONTH SALES ENDED AUGUST 31, 2012

CURRENT SUPPLIER REFUND ADJUSTMENT

$ 14,278.93

0.9990

14,264.65

MCF I O , 188,360

$

$/MCF (0.001)

DETAILS OF SUPPLIER REFUNDS RECEIVED DURING THE THREE MONTHS ENDED MAY 31, 201 1

DESCRIPTION UNIT AMOUNT

SUPPLIER

Tennessee Gas Pipeline Company - April 1,201 1

TOTAL REFUNDS APPLICABLE TO THE CURRENT GCA

RAlJ

3rd QUARTER SCHEDULE 111

GAS COST ADJlJSTMENT CLAUSE DUKE ENERGY KENTUCKY, INC

ACTUAL ADJUSTMENT DETAILS FOR THE THREE MONTH PERIOD ENDED MAY 31, 201 1

DESCRIPTION UNIT MARCH APRIL MAY 1 SUPPLY VOLUME PER BOOKS

PRIMARY GAS SUPPLIERS UTILITY PRODUCTION INCLUDABLE PROPANE OTHER VOLUMES (SPECIFY) ADJlJSTMENT

MCF MCF MCF MCF

1,261,596 513,036 389,348 0 0 0 0 0 0

(7,403) ., (9,115) 2,998

1,254,193 503,921 392,346 TOTAL SUPPLY VOLUMES MCF

SUPPLY COST PER BOOKS

PRIMARY GAS SUPPLl ERS SPECIAL PURCHASES CREDIT INCLUDABLE PROPANE OTHER COSTS (SPECIFY): GAS COST UNCOLLECTIBLE MANAGEMENT FEE X-5 TARIFF TRANSPORTATION SERVICE "UNACCOUNTED F O R GAS COST CREDIT LOSSES - DAMAGED LINES TRANSPORTATION TAKE-OR-PAY RECOVERY SALES TO REMARKETERS

6,939,493 2,666,141 2,298,934 0 0 0 0 0 0

5,037 (79,719) (26,558) (63,375) (63,375) (63,3 75)

0 0 0 0 0 0 0 0 0 0 0 (881) 0 0 0 0 0 0

TOTAL SUPPLY COSTS $ 6,796,399 2,576,208 2,239,715

SALES VOLUMES

,JURISDICTIONAL

OTHER VOLUMES (SPECIFY). NON-JURISDICTIONAL

MCF MCF MCF

1,362,233.0 845,186.7 433,065.0 0.0 0.0 0.0 0.0 0.0 0.0

1,362,233.0 845,186.7 433,065.0 TOTAL SALES VOLUMES MCF

UNIT BOOK COST OF GAS (SUPPLY $ I SALES MCF) LESS: EGC IN EFFECT FOR THE MONTH

$/MCF $lMCF

4 989 3.048 5.172 5.768 5.296 5.582

DIFFERENCE TIMES: MONTHLY .JURISDICTIONAL SALES

$lMCF MCF

(0.779) (2.248) (0 410) 1,362,233.0 845,186.7 433,065.0

(1,061,179.51) (1,899,979.70) (1 77,556.65) EQUALS MONTHLY COST DIFFERENCE $

NET COST DIFFERENCE FOR THE THREE MONTH PERIOD $ (3,138,715.862 -

TOTAL COST USED IN THE CURRENT AA CALCULATION $ (3,138,715.86)

10,188,360.0 DIVIDED BY: 12 MONTH PROJECTED SALES ENDED AUGUST 31, 2012 MCF

EQUALS CURRENT QUARTERLY ACTUAL ADJUSTMENT $/MCF (0.308)

AAU

3rd QUARTER SCHEDULE IV

GAS COST ADJUSTMENT CLAUSE DUKE ENERGY KENTUCKY, INC

BALANCE ADJlJSTMENT DETAILS FOR THE TWELVE MONTH PERIOD ENDED MAY 31, 201 1

DESCRIPTION LJNIT AMOUNT

RECONCILIATION OF A PREVIOUS GAS COST VARIANCE

GAS COST DIFFERENCE TO BE RECOVERED FROM OR (RETURNED TO) CUSTOMERS WHICH WAS USED TO COMPUTE THE "AA" EFFECTIVE JUNE 1, 2010

LESS: AMOUNT RECOVERED (RETURNED) BY THE AA OF $ 0.104 /MCF APPLIED TO TOTAL SALES OF 10,450,494 MCF (TWELVE MONTHS ENDED MAY 31, 201 1 )

BALANCE ADJUSTMENT FOR THE "AA'

RECONCILIATION OF A PREVIOUS SUPPLIER REFUND

SUPPLIER REFUND AMOUNT TO BE DISTRIBUTED TO CUSTOMERS WHICH WAS USED TO COMPUTE THE "RA EFFECTIVE JUNE 1. 2010

LESS: AMOUNT DISTRIBUTED BY THE "RA" OF $ (0.002) /MCF APPLIED TO TOTAL SALES OF 10,450,494 MCF (TWELVE MONTHS ENDED MAY 31, 2011 )

BALANCE ADJUSTMENT FOR THE "RA'

RECONCILIATION OF A PREVIOUS BALANCE ADJUSTMENT

AMOUNT TO BE RECOVERED FROM OR (RETURNED TO) CUSTOMERS WHICH WAS USED TO COMPUTE THE "BA EFFECTIVE JUNE 1, 2010

LESS: AMOUNT RECOVERED (RETURNED) BY THE "BA" OF $ APPLIED TO TOTAL SALES OF 10,450,494 MCF

(0.007) /MCF

(TWELVE MONTHS ENDED MAY 31, 2011 )

BALANCE ADJUSTMENT FOR THE "BA'

TOTAL BALANCE ADJUSTMENT AMOUNT

DIVIDED BY. 12 MONTHS PROJECTED SALES ENDED AUGUST 31, 2012

$ 1,105,600.23

1,086,851.36

18,748.87

(21,689.91)

(20,900.98)

(788.93)

$ (79,221 "61)

$ - (73,153.45)

$ (6,068.1 6)

$ 11,891.78

MCF 10,188,360

EQUALS: CURRENT QUARTER BALANCE ADJUSTMENT $/MCF 0.001

Revised Tariffs

KY P S C . Gas No 2 Sixty-Fourth Revised Sheet No . 10 Cancelling and Superseding Sixty-Third Revised Sheet No . 10 Page 1 of 2

Duke Energy Kentucky. Inc 4580 Olympic Blvd Erlanger. Kentucky 41018

INDEX TO APPLICABLE GAS TARIFF SCHEDULES AND COMMUNITIES SERVED

SERVICE REGULATIONS Service Agreements ...........................................

Supplying and Taking of Service ......................................... Customer's Installation ...................................................... Company's Installation ....................................................... Metering ............................................................. Billing and Payment .................... . . . . . . . . . . . . . . . . Deposits . . . . . . . . . . . . . . . . . ..........................

.......................................

..................................... Availability of Gas Service ......................................

. FIRM SERVICE TARIFF SCHEDULES Rate RS, Residential Service ................................................ Rate GS, General Service ............................................... Reserved for Future Use ................................ Reserved for Future Use ............... Reserved for Future Use ........................................................ Reserved for Future Use .............................................. Reserved for Future Use ................................ Reserved for Future Use ......................... Reserved for Future Use .................................................. Reserved for Future Use .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Reserved for Future Use ............... Reserved for Future Use ............... Reserved for Future Use I I I I ......................................... Reserved for Future Use., .................................................... Rate FRAS, Full Requirements Aggregation Service ............... Reserved for Future Use ......................... Reserved for Future Use ... Reserved for Future Use .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Reserved for Future Use ................................................ Reserved for Future use ...............................................

.........................

...... . . . . . . . . . . . . . . . . . . .

....................

....................

......................

TRANSPORTATION TAR1 FF SCHEDULE Rate IT. Interruptible Transportation Service ........................ Rate FT-L, Firm Transportation Service . . . . . . . . . . . . . . . . . . . . . . . . . . . Reserved for Future Use ................................ Rate SSIT, Spark Spread Interruptible Transportation R Reserved for Future Use ............................................... Rate AS, Pooling Service for Interruptible Transportation . . . . . Reserved for Future Use ..............................................

Rate IMBS, Interruptible Monthly Balancing Service . . . . . . . . . . . Rate DGS, Distributed Generation Service ...........................

Rate GTS, Gas Trading Service ......................... ....

Sheet No .

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 48 49

50 51 52 53 54 55 56 57 58 59

Billing Effective

Date

0110411 0 0 1104110 0 1104110 01 104110 01 1041 1 0 0 1104110 01104110 0 110411 0 0 1104110 0 1104110

0813111 1 0813 1 11 1

0 0 110411

0 11041 10 0 0 110411

0 1 I0411 0

0 1 1041 1 0

0 1104110 0 1104110 01104110

Effective Date per Order

0 1 i0411 0 01 104110 0 1 10411 0 01 104110 01104110 0 1104110 01 I04110 01104110 0 1104110 0 0 110411

08131111 (T) 08131111 (T)

01 I04110

0 0 110411 0 1104110

01104110

01104110

0 1104l10 0 1 10411 0 0 0 110411

Issued by authority of an Order of the Keiitucky Public Service Coininissioii dated

Issued: Effective: August 31. 201 1 Issued by Julie Janson. President

KY P S.C Gas No 2 Sixty-Fourth Revised Sheet No 10 Cancelling and Superseding Sixty-Third Revised Sheet No 10 Page 2 of 2

Duke Energy Kentucky, Inc 4580 Olympic Blvd Erlanger, Kentucky 41018

INDEX TO APPLICABLE GAS TARIFF SCHEDULES AND COMMUNXIES SERVED IContd.1

Sheet Billing Effective Effective Date No. Date per Order

RIDERS Rider X, Main Extension Policy Rider DSM, Demand Side Management Cost Recovery Program Rider DSMR, Demand Side Management Rate. I .. I I , _ I I " I " I I .

Reserved for Future Use " _ _ I I I I I I I I I I ~ ~ l . I ~ . ~ . . . _ _ , I . . . . . _ I I . I _ I _ I . I I . _ I . .

Reserved for Future Use ... 1 1 1 .. I " ._ ._ , , . . I ............II..I_.I.I.I. Reserved for Future Use . I I _ . l I I I 1 . _ I _ _ _ . _ . _ . . . " I I I " " I 1 _ _ I . . . . . . . . . . I Reserved for Future Use. " " " " " " " " " " " . " ......, " " . ." . " " " , " ̂ ^ . . .

Reserved for Future Use .. " " . " ^ ^ . .

Reserved for Future Use . . .. " " " " . . . " . . . . . . .." Reserved for Future Use ... . . . , ._I I , " .II ... ... ... ... . , , ..

GAS COST RECOVERY RIDERS Gas Cost Adjustment Clause Reserved for Future Use Reserved for Future Use Reserved for Future Use Reserved for Future Use Reserved for Future Use Reserved for Future Use Rider GCAT, Gas Cost Adjustment Transition Rider Reserved for Future Use Reserved for Future Use

MISCELLANEOUS Bad Check Charge Charge for Reconnection of Service Local Franchise Fee Cu rta i lmen t Plan Rate MPS, Meter Pulse Service Reserved for Future Use Reserved for Future Use Reserved for Future Use Reserved for Future Use Reserved for Future Use

60 0 I io411 0 01 104/10 61 0 1 I0411 0 0 1104/1 0

63 64 65 66 67 68 69

62 07/01/11 071aiii I

70 71 72 73 74 75 76 77 78 79

80 81 82 83 84 85 86 87 88 89

01104110 01/04/10

(T) 0813111 1 08/31/1 1

0 1 /04/10 0 1 I0411 0 0 1/04/10 0 1 /04/10 0 1 I0411 0 01 /04/10 0 1 /04/10 01104/10 0 110411 0 0iia4110

Issued by authority of an Order of the Kentucky Public Service Coininissioii dated

Issued: Effective: August 31, 201 1 Issued by .Julie Janson, President

KY.P.S.C. Gas No. 2 Sixtieth Revised Sheet No. 30 Cancelling and Superseding Fifty-Ninth Revised Sheet No. 30 Page 1 of 1

Duke Energy Kentucky, Inc. 4580 Olympic Blvd. Erlanger, Kentucky 41 01 8

RATE RS RESIDENTIAL SERVICE

APPLICABILITY Applicable to firm natural gas service, which is comprised of commodity gas supply and local delivery service, required for all domestic purposes in private residences, single occupancy apartments, and common use areas of multi-occupancy buildings, when supplied at one point of delivery where distribution mains are adjacent to the premises to be served.

NET MONTHLY BILL The Net Monthly Bill is determined as follows: All gas is billed in units of 100 cubic feet (CCF).

Customer Charge per month: $1 6.00

Delivery Gas Cost Rate Adiustment Total Rate

Plus a commodity Charge for all CCF at $0.37213 plus $0.5866 Equals $0.95873 (R)

Plus, all delivered gas shall be subject to an adjustment per CCF as set forth on Sheet No. 62, Rider DSMR, Demand Side Management Rate.

The “Customer Charge” shown above shall be the minimum amount billed each month.

The “Gas Cost Adjustment“ as shown above, is an adjustment per 100 cubic feet determined in accordance with the ”Gas Cost Adjustment Clause” set forth on Sheet No. 70 of this tariff.

When bills are rendered less frequently than monthly the time related units such as cubic feet blocks, minimum or other charges, will be billed in accordance with the number of billing months in the meter reading interval.

LATE PAYMENT CHARGE Payment of the Net Monthly Bill must be received in the Company’s office within twenty-one (21) days from the date the bill is mailed by the Company. When not so paid, the Gross Monthly Bill, which is the Net Monthly Bill plus 5%, is due and payable.

SERVICE REGULATIONS The supplying of, and billing for, service and all conditions applying thereto, are subject to the jurisdiction of the Kentucky Public Service Cornmission and to Company’s Service Regulations currently in effect, as filed with the Kentucky Public Service Commission, as provided by law.

Issued by authority of an Order of the Kentucky Public Service Commission dated in Case No.

Issued:

Issued by Julie Janson, President

Effective: August 31, 201 1

KY.P.S.C. Gas No. 2 Sixtieth Revised Sheet No. 31 Cancelling and Superseding Fifty- Ninth Revised Sheet No. 31 Page 1 of 1

Duke Energy Kentucky, Inc. 4580 Olympic Blvd. Erlanger, Kentucky 41018

RATE GS

GENERAL SERVICE APPLICABILITY

Applicable to firm natural gas service, which is comprised of commodity gas supply and local delivery service, required for any purpose by an individual non-residential customer at one location when supplied at one point of delivery where distribution mains are adjacent to the premises to be served. This schedule is also applicable to non- metered natural gas commodity supplies and local delivery service for street lighting to such entities as certificated homeowners associations, businesses, and federal, state, and local governments. The Company may decline requests for service under this tariff due to gas supply limitations.

NET MONTHLY BILL The Net Monthly Bill is determined as follows: All gas is billed in units of 100 cubic feet (CCF)

Customer Charge per month: $47.50

Delivery Gas Cost Rate Adiustment Total Rate

Plus a Commodity Charge for all CCF at $0.20530 Plus $0.5866 Equals $0.7919 (R)

Plus all delivered gas shall be subject to an adjustment per CCF as set forth on: Sheet No. 62, Rider DSMR, Demand Side Management Rate for non-residential service

The "Customer Charge" shown above shall be the minimum amount billed per month

The "Gas Cost Adjustment," as shown above, is an adjustment per 100 cubic feet determined in accordance with the "Gas Cost Adjustment Clause" set forth on Sheet No. 70 of this tariff.

When bills are rendered less frequently than monthly the time related units such as cubic feet blocks, minimum bills or other charges, will be billed in accordance with the number of billing months in the meter reading interval.

LATE PAYMENT CHARGE Payment of the Net Monthly Bill must be received in the Company's office within twenty-one (21) days from the date the bill is mailed by the Company. When not so paid, the Gross Monthly Bill, which is the Net Monthly Bill plus 5%, is due and payable.

TERM OF SERVICE One year, terminable thereafter on ten (1 0) days written notice by either customer or Company

SERVICE REGULATIONS The supplying of, and billing for, service and all conditions applying thereto, are subject to the jurisdiction of the Kentucky Public Service Commission, and to Company's Service Regulations currently in effect, as filed with the Kentucky Public Service Commission as provided by law.

Issued by authority of an Order of the Kentucky Public Service Commission dated in Case No.

Issued: Effective: August 31, 201 1 Issued by Julie Janson, President

KY.P.S.C. Gas No. 2 Twenty-First Revised Sheet No. 77 Cancelling and Superseding Twentieth Revised Sheet No. 77 Page 1 of 1

Duke Energy Kentucky, Inc. 4580 Olympic Blvd. Erlanger, Kentucky 41 01 8

RIDER GCAT

GAS COST ADJUSTMENT TRANSITION RIDER

APPLICABILITY Applicable to all customers served under Rate FT-L after the effective date of this tariff who paid gas supply costs through the Company’s Gas Cost Adjustment (GCA) mechanism during the twelve month period immediately preceding the date on which the customer began receiving service under Rate FT-L.

GCA TRANSITION RIDER A charge or credit shall be applied to all volumes transported pursuant to Rate FT-L in order to pass throiigh to former GCA customers the Company’s quarterly Actual Adjustment (AA), Balance Adjustment (BA), and Supplier Refund and Reconciliation Adjustment (RA) costs or credits during the first twelve months that the former sales customer participates in the Company’s firm transportation program.

The amount of this charge or (credit) shall be $ $0.0062 per 100 cubic feet. This rate shall be in effect during the month of September 201 1 through November 201 1 and shall be updated quarterly, concurrent with the Company’s GCA filings.

( I

Issued by authority of an Order of the Kentucky Public Service Commission dated Case No.

in

Issued:

Issued by Julie Janson, President

Effective: August 31, 201 1

DUKE ENERGY I<ENTl-JCI<Y SUPPLEMENTAL, INFORMATION

FOR THE EXPECTED GAS COST (EGC) RATE CALCULATION OF THE GAS COST RECOVERY RATE IN EFFECT AS OF AUGUST 3 1,20 1 1

3rd QUARTER

DUKE ENERGY Kentucky, Inc. USED FOR GCA EFFECTIVE COMPUTATION OF THE INTEREST FACTOR FOR THE GCA CALCULATION ON SCHEDULE II

AUGUST 31,201 1

TWELVE MONTHS ENDED JUNE 31,201 1 BLOOMBERG REPORT (90-DAY COMMERCIAL PAPER RATES)

INTEREST RATE -0.0019

PAYMENT 0.083248

ANNlJAL TOTAL 0.9990

MONTHLY INTEREST (0.000 158)

AMOUNT 1

PRIOR ANNUAL TOTAL 4.12

PLUS ClJRRENT MONTHLY RATE 0.24

LESS YEAR AGO RATE 0.60

NEW ANNUAL TOTAL 3.76

AVERAGE ANNUAL RATE 0.3 1

LESS 0.5% (ADM I N ISTRAT WE) (0.19)

JUNE 201 0 JULY 201 0 AUGUST 2010 SEPTEMBER 2010 OCTOBER 2010 NOVEMBER 2010 DECEMBER 2010 JANUARY 201 1 FEBRUARY 201 1 MARCH 201 1 APRIL 2011 MAY 201 1 JUNE 201 I

0.60 0.42 0.29 0.30 0.30 0.31 0.39 0.32 0.30 0.34 0.33 0.22 4.12 0.24 4.36

08/05/11

DlJKE ENERGY COMPANY KENTUCKY DETERMINATION OF TOTAL SllPPLY COST

MONTH OF March 2011

DESCRIPTION

PRIMARY GAS SUPPLY COST current month adjustments IT monthly charges entered by Gas Supply

LESS: RATE SCHEDULE CF CREDIT current month adjustments

PLIJS: INCLUDABLE PROPANE a/c 728-3 Erlanger

PLUS: GAS COST UNCOLLECTIBLE

LESS: X-5 TARIFF

LESS TENASKA MARKETING VENTURES MANAGEMENT FEE

LESS: TOP TRANSP. RECOVERIES

LESS. GAS LOSSES - DAMAGED LINES

adjustments

LESS: GAS COST CREDIT

LESS: FIRM TRANSPORTATION ADJUSTMENTS current month adjustments

TOTAL SUPPLY COSTS

ACCOUNTING EN TRY FOR D E F E R R A L , X Y

ACCOUNT 191-40 ACCOUNT 805-10

TOTAL AMOUNT

ROUNDED

$ 6,990,579.24

(51,680.23) 594.44 6,939,493

0.00 0.00 0

0.00 0

(79,7 19.00) (79,719)

0.00 0

63,375 00 (63,375)

0.00 0

0 00 0

0.00 0.00 0

0 00 0

0.00 0.00 0

6,796,399

AMOUNT

(1,061,179.51) 1,061,179 51

0810511 1

P U R C H A S E D G A S A D J U S T M E N T SCHEDlJLE 111

COMPANY NAME: DUKE ENERGY COMPANY KENTUCKY

A C T U A L A D J U S T M E N T

DETAILS FOR THE MONTH March 2011

PARTICULARS UNLT.

SUPPLY VOLUME PER BOOKS

Primary Gas Suppliers MCF Utility Production MCF Includable Propane MCF Other Volumes (Specify) - Previous Month Adj MCF

TOTAL SUPPLY VOLUMES MCF

SUPPLY COST PER BOOKS

Primary Gas Suppliers Includable Propane Gas Cost Uncollectible Other Cost (Specify) - Gas Cost Credit

- Unacct'd for Transp. - CF Credit - X-5 Tariff - CMT Management Fee - Losses-Damaged Lines - Gas Sold to Remarketers - TOP Transp Recoveries

TOTAL SUPPLY COST $

SALES VOLUMES

Jurisdictional Non-Jurisdictional Other Volumes (Specify) -

MCF MCF MCF

TOTAL SALES VOLUME MCF

UNIT BOOK COST OF GAS (SUPPLY $ I SALES MCF) $lMCF LESS: EGC IN EFFECT FOR MONTH $lMCF

DIFFERENCE $lMCF TIMES. MONTHLY JURISDICTIONAL SALES MCF

MONTH March 2011

1,261,596 0 0

(7,403)

1.254.193

6,939,493 0

(79,719) 0 0 0 0

(63,375) 0 0 0

6,796,399

1,362,233 0

1,362,233.0

4 989 5.768

(0.779) 1,362,233.0

(1,061,179.51) MONTHLY COST DIFFERENCE $

GAS FUEL ADJUSTMENT BILLED EGC RA AA BA

TOTAL GAS COST RECOVERY(GCR)

DUKE ENERGY COMPANY KENTUCKY

TOTAL SALES VOLUME LESS. NON-JURISDICTIONAL SALES

JURISDICTIONAL SALES

March 201 1

Applied MCF Sales Amount

oa/o511 I

$IMCF

1,362,233 0 7,857,896.84 5 768394 13 (6,ai I “50) 26,313 91

(16,304.61)

7,86 I ,094.64

1,362,233.0 0.0

1,362,233.0

PROOF OF UNRECOVERED PURCHASED GAS COST ENTRI

SUPPLIER COST - CURRENT MONTH 1,362,233 0 6,796,399.00 4.989 16044 UNRECOVERED PURCHASED GAS COST I ,087,493.42 ROUND I NG(ADD/( DEDUCT)) 318.34

TOTAL GAS COST IN REVENUE 7,884,210.76

TOTAL GAS COST RECOVERY(GCR) LESS: RA

BA

PLUS: COST OF NON-JURISDICTIONAL SALES

UNRECOVERED PURCHASED GAS COST ENTRY 1,087,493.42 LESS: AA 26,3 13.9 1

MONTHLY COST DIFFERENCE 1,061,17951 EXTENDED MONTHLY COST DIFFERENCE i,o6 i ,497.85

ROUNDING 318.34

08/05/1 1

DlJKE ENERGY COMPANY KENTUCKY DETERMINATION OF TOTAL SUPPLY COST

MONTH OF April 2011

DESCRIPTION

PRIMARY GAS SUPPLY COST current month adjustments IT monthly charges entered by Gas Supply

LESS: RATE SCHEDULE CF CREDIT current month adjustments

PLUS: INCLUDABLE PROPANE alc 728-3 Erlanger

PLCJS: GAS COST UNCOLLECTIBLE

LESS: X-5 TARIFF

LESS TENASKA MARKETING VENTURES MANAGEMENT FEE

LESS. TOP TRANSP. RECOVERIES

LESS. GAS LOSSES - DAMAGED LINES

adjustments

LESS: GAS COST CREDIT

LESS: FIRM TRANSPORTATION ADJUSTMENTS current month adjustments

TOTAL SUPPLY COSTS

ACCOUNTING ENTRY FOR DEFERRAL ONLY

ACCOLJNT 19 1-40 ACCOUNT 805-10

TOTAL AMOUNT -~ ROUNDED

$ 2,723,883 87

(51,12845) (6,614.05) 2,666,141

0.00 0.00 0

0.00 0

(26,558 00) (26,558)

0 00 0

63,375 00 (63,375)

0 00 0

0 00 0

0 00 0.00 0

0.00 0

0 00 0 00 0

2,576,208

AMOUNT-

(1,899,979 70) 1,899,979.70

0810511 1

P U R C H A S E D G A S A D J U S T M E N T SCHEDULE 111

COMPANY NAME: DUKE ENERGY COMPANY KENTUCKY

A C T U A L A D J U S T M E N T

DETAILS FOR THE MONTH April 201 1

MONTH PARTlC U LARS -- April 201 1

SUPPLY VOLUME PER BOOKS

Primary Gas Suppliers MCF 5 13,036 Utility Production MCF 0 Includable Propane MCF 0 Other Volumes (Specify) - Previous Month Adj. MCF (9,l 15)

TOTAL SlJPPLY VOLUMES MCF 503,921

SUPPLY COST PER BOOKS

Primary Gas Suppliers Includable Propane Gas Cost Uncollectible Other Cost (Specify) - Gas Cost Credit

- Unacct'd for Transp - CF Credit - X-5 Tariff - CMT Management Fee - Losses-Damaged Lines - Gas Sold to Remarketers - TOP Transp Recoveries

2,666,141 0

(26,558) 0 0 0 0

(63,375) 0 0 0

TOTAL SlJPPLY COST

SALES VOLUMES

Jurisdictional Nan-Jurisdictional Other Volumes (Specify) -

MCF MCF MCF

2,576,208

845,186.7

TOTAL SALES VOLUME MCF 845,186.7

UNIT BOOK COST OF GAS (SUPPLY $ I SALES MCF) 3 048 LESS EGC IN EFFECT FOR MONTH $IMCF 5.296

DIFFERENCE $/MCF (2 248) TIMES. MONTHLY JURISDICTIONAL SALES MCF 845,186.7

$/MCF

MONTHLY COST DIFFERENCE $ (1,899,979.70)

08/05/11 DUKE ENERGY COMPANY KENTUCKY

April 201 1

GAS FUEL ADJUSTMENT BILLED EGC RA AA 0A

TOTAL GAS COST RECOVERY(GCR)

TOTAL SALES VOLUME LESS: NON-JURISDICTIONAL SALES

JURISDICTIONAL SALES

Applied MCF Sales Amount $INIcF

845,186.7 4,476,263 34 5 296 18289 (4,293 91) 37,136.85

( 1 0,312.39)

4,498,793.89

845,186 7 0.0

845,186.7

PROOF OF UNRECOVERED PURCHASED GAS COST ENTRY

SUPPLIER COST - CURRENT MONTH 845,186.7 2,576,208 00 3 04809340 UNRECOVERED PURCHASED GAS COST 1,937,l 16 55 ROUNDING(ADD/(DEDUCT)) 75.64

TOTAL GAS COST IN REVENUE 4,513,400.19

TOTAL GAS COST RECOVERY(GCR) LESS: RA (4,293 91)

BA (10,312.39)

4,498,793 89

PLUS. COST OF NON-JURISDICTIONAL SALES

4,5 13,400.19

UNRECOVERED PURCHASED GAS COST ENTRY 1,937,l 16 55 LESS. AA 37,136.85

MONTHLY COST DIFFERENCE 1,899,979 70 EXTENDED MONTHLY COST DIFFERENCE 1,900,055.34

ROUNDING 75.64

08/05/11

DUKE ENERGY COMPANY KENTUCKY DETERMINATION OF TOTAL SUPPLY COST

MONTH OF May 201 1

DESCRIPTION

PRIMARY GAS SUPPLY COST current month adjustments IT monthly charges entered by Gas Supply

LESS: RATE SCHEDULE CF CREDIT current month adjustments

PLUS: INCLUDABLE PROPANE a/c 728-3 Erlanger

PLUS. GAS COST UNCOLLECTIBLE

LESS: X-5 TARIFF

LESS TENASKA MARKETING VENTURES MANAGEMENT FEE

LESS: TOP TRANSP. RECOVERIES

LESS: GAS LOSSES - DAMAGED LINES

adjustments

LESS: GAS COST CREDIT

LESS: FIRM TRANSPORTATION ADJUSTMENTS current month adjustments

TOTAL SUPPLY COSTS

ACCOUNTING ENTRY FOR DEFERRAL ONLY

ACCOUNT 19 1-40 ACCOUNT 805- 10

TOTAL AMOUNT

ROUNDED

$ 2,286,288.84

12,254.93 390.17 2,298,934

0 00 0.00 0

0 00

5,037 00

0.00

63,375 00

0.00

(881 14)

0 00 0.00

0 00

0 00 0 00

0

5,037

0

(63,375)

0

0

0

2,239,715

AMOUNT

( 1 77,556 65) 177,556.65

08/05/1 1

P U R C H A S E D G A S A D J U S T M EN'T SCHEDULE 111

COMPANY NAME: DUKE ENERGY COMPANY KENTUCKY

A C T U A L A D J U S T M E N T

DETAILS FOR THE MONTH May 201 1

MONTH PARTICULARS - UNIT Mav 201 1

SUPPLY VOLUME PER BOOKS

Primary Gas Suppliers MCF 389,348 Utility Production MCF 0 Includable Propane MCF 0 Other Volumes (Specify) - Previous Month Adj MCF 2,998

TOTAL SUPPLY VOLUMES MCF 392,346

SUPPLY COST PER BOOKS

Primary Gas Suppliers Includable Propane Gas Cost Uncollectible Other Cost (Specify) - Gas Cost Credit

- Unacct'd for Transp - CF Credit - X-5 Tariff - CMT Management Fee - Losses-Damaged Lines - Gas Sold to Remarketers -TOP Transp. Recoveries

TOTAL SlJPPLY COST

SALES VOLUMES

Jurisdictional Non-Jurisdictional Other Volumes (Specify) -

MCF MCF MCF

2,298,934 0

5,037 0 0 0 0

(63,375) (88 1 )

0 0

2,239,715

433,065.0

TOTAL SALES VOLUME MCF 433,065.0

UNIT BOOK COST OF GAS (SUPPLY $ I SALES MCF) 5.172 LESS. EGC IN EFFECT FOR MONTH $IMCF 5.582

$/MCF

DIFFERENCE $IMCF (0.410) TIMES: MONTHLY JURISDICTIONAL SALES MCF 433,065.0

MONTHLY COST DIFFERENCE $ (1 77,556.65)

08105/1 1 DlJKE ENERGY COMPANY KENTUCKY

May 201 1

Applied MCF Sales Amount $IMCF

GAS FUEL ADJUSTMENT BILLED EGC RA AA BA

TOTAL GAS COST RECOVERY(GCR)

TOTAL SALES VOLUME LESS. NON-JURISDICTIONAL SALES

JURISDICTIONAL SALES

433,065 0 2 4 1 7,520.1 1 5 58234932 (2,187 98) 20,351 96 (5,256.98)

2,430,427.1 1

433,065.0 0.0

433,065.0

PROOF OF UNRECOVERED PURCHASED GAS COST ENTRY

SLJPPLIER COST - CURRENT MONTH 433,065 0 2,239,7 15 00 5 17 177560 UNRECOVEREDPURCHASEDGASCOST 197,908 6 1 ROlJ N D I NG(AD D/( D EDU CT)) 248.46

TOTAL GAS COST IN REVENUE

TOTAL GAS COST RECOVERY(GCR) LESS. RA

BA

2,437,872.07

2,430,427 11 (2,187 98) (5,256.98)

PLUS. COST OF NON-JURISDICTIONAL SALES

2,437,872.07

UNRECOVERED PURCHASED GAS COST ENTRY 197,908 6 1 LESS. AA 20,351.96

MONTHLY COST DIFFERENCE 177,556.65 177,805.1 1 EXTENDED MONTHLY COST DIFFERENCE

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