be - Kentucky cases/2013-00310... · 8/9/2013 · Report of Gas Cost Calculations and Tariff...

DUKE 139 E Fourth Street

ENERGY® Cincinnati, OH 45202

August 9,2013

Kentucky Public Service CommissionAUAttn: Mr. Jeff Derouen, Executive Director G 09 2013

211 Sower Boulevard PUBLIC S:PVICFrankfort, Kentucky 40602 COMM iSS iQf\J

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 monthcommencing with the September 2013 revenue month in accordance with KPSC order datedNovember 6, 2003 in Case No. 2003-00386. This filing is based on supplier tariff rates expected tobe in effect on August 29, 2013 and the NYMEX close on August 6, 2013 for the month ofSeptember 2013.

The above described schedules and GCA are effective with the final meter readings of District 1,September 2013 revenue month (i.e., final meter readings on and after August 29, 2013).

Duke’s proposed GCA is $4.624 per Mcf. This rate represents a decrease of$0.421 per Mcf from therate currently in effect for August 2013.

Very truly yours,

Dana Patten

Enclosure

cc: L. Schmidt

R:/tariffs/gcr/uthp/gca monthly flhing.doc

3rd Quarter

DUKE ENERGY KENTUCKY, INCGAS COST ADJUSTMENT CLAUSE

QUARTERLY REPORT

GAS COST RECOVERY RATES EFFECTIVE FROM August 29, 2013 THROUGH September 27, 2013

DESCRIPTIONUNIT AMOUNT

EXPECTED GAS COST (EGC)$/MCF 4.570SUPPLIER REFUND ADJUSTMENT (RA)$/MCF (0.001)ACTUAL ADJUSTMENT (AA)$/MCF 0.091BALANCE ADJUSTMENT (BA)$IMCF (0.036)GAS COST RECOVERY RATE (GCR) = EGC + RA + +BA $/MCF 4.624

EXPECTED GAS COST CALCULATION


TOTAL EXPECTED GAS COST COMPONENT (EGC) $/MCF 4.570

SUPPLIER REFUND ADJUSTMENT CALCULATION


CURRENT QUARTER SUPPLIER REFUND AD]. $/MCF 0.000PREVIOUS QUARTER REPORTED SUPPLIER REFUND AD]. $/MCF 0.000SECOND PREVIOUS QUARTER REPORTED SUPPLIER REFUND AD]. $/MCF 0.000THIRD PREVIOUS QUARTER REPORTED SUPPLIER REFUND ADJ. $/MCF (0 001SUPPLIER REFUND ADJUSTMENT fRA) $1MCF (0.001)

ACTUAL ADJUSTMENT CALCULATION

DESCRIPTION UNIT AMOUNT

CURRENT QUARTER ACTUAL ADJUSTMENT $/MCF (0.277)PREVIOUS QUARTER REPORTED ACTUAL ADJUSTMENT $IMCF 0.001SECOND PREVIOUS QUARTER REPORTED ACTUAL ADJUSTMENT $/MCF 0,279THIRD PREVIOUS QUARTER REPORTED ACTUAL ADJUSTMENT $/MCF 0.088ACTUAL ADJUSTMENT (A) $/MCF 0.091

BALANCE ADJUSTMENT CALCULATION


CURRENT QUARTER BALANCE ADJUSTMENT $/MCF (0.008)PREVIOUS QUARTER REPORTED BALANCE ADJUSTMENT $/MCF 0.026SECOND PREVIOUS QUARTER REPORTED BALANCE ADJUSTMENT $/MCF 0.005THIRD PREVIOUS QUARTER REPORTED BALANCE ADJUSTMENT $/MCF (0.059)BALANCE ADJUSTMENT (BA) $/MCF (0.036)

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

DATE FILED: AuQust 9. 2013 BY: DON WATHEN

TITLE: DIRECTOR,Rates & Regulatory Strategy - OHIKY

Schedule IPage 1 of 4

GAS COST ADJUSTMENTDUKE ENERGY KENTUCKY

EXPECTED GAS COST RATE CALCULATION fEGC)

“SUMMARY” FOR THE EGC RATE IN EFFECT AS OF AUGUST 29, 2013

$DEMAND (FIXED) COSTS:

Columbia Gas Transmission Corp. 2,780149Columbia Gulf Transmission Corp. 1 832,968KO Transmission Company 307,584Gas Marketers 731 404

TOTAL DEMAND COST: 5,652,105

PROJECTED GAS SALES LESS SPECIAL CONTRACT IT PURCHASES: 10,125758 MCF

DEMAND (FIXED) COMPONENT OF EGC RATE: $5,652,105 I 10,125,758 MCF $0.558 IMCF

COMMODITY COSTS:

Gas Marketers $3.922 /MCFGas Storage

Columbia Gas Transmission $0000 IMCFPropane $0.000 /MCF

COMMODITY COMPONENT OF EGC RATE: $3.922 IMCF

Other Costs:Net Charge Off $17,952 I 200,166 $0090 IMCF

TOTAL EXPECTED GAS COST: $4.570 IMCF


DETAILS FOR THE EGC RATE IN EFFECT AS OF: AUGUST 29, 2013

SCHEDULE IPAGE 2 OF 4

CONTRACT NUMBER EXPECTEDRATE VOLUME OF GAS COST

f$DTH) fDTH) DAYS/MTHS ($)INTERSTATE PIPELINE: COLUMBIA GAS TRANSMISSION, LLCTARIFF RATE EFFECTIVE DATE: FSS: 2/1/2013

SST: 2/1/2013

BILLING DEMAND TARIFF RATE - FSSMax. Daily Withdrawl Quan. 1.5090 39,656 12 718,091Seasonal Contract Quantity 0.0289 1,365,276 12 473,478

BILLING DEMAND - TARIFF RATE - SSTMaximum Daily Quantity 4.4510 19,828 6 529,527Maximum Daily Quantity 4.4510 39,656 6 1059,053

CAPACITY RELEASE CREDIT0

TOTAL COLUMBIA GAS TRANSMISSION, LLC - DEMAND CHARGES 2,780,149

Columbia Gas Transmission, LLCV.9.FERC Tariff

Currently Effective RatesFourth Revised Volume No. iFSS Rates

Version 3.0.0

Currently Effective RatesApplicable to Rate Schedule FSSRate Per Dth

Base Transportation Cost Electric Power Annual Total DailyTariff Rate Adjustment Costs Adjustment Charge Effective RateRate Current Surcharge Current Surcharge Adjustment Rate

1/ 2/Rate Schedule fSSReservation Charge 3/ $ 1.509

- 1.509 0.0496Capacity 3/ 2.89- 2.89 2.89Injection 0 1.53 - -

- - 1.53 1.53Withdrawal 1.53 - - - - - 1.53 1.53Overrun 3/ 10.91 - - - - - 10.91 10.91

1/ Excludes Account 858 expenses and Electric Power Costs which are recovered through Columbia’s Transportation Costs RateAdjustment (TCRA) and Electric Power Costs Adjustment (EPCA), respectively.2/ ACA assessed where applicable pursuant to Section 154.402 of the Commission’s Regulations.3/ Shippers utilizing the Eastern Market Expansion (EME) facilities for ESS service will pay a total FSS MDSQ reservation charge of$4.130 and a total FSS SCQ capacity rate of 6.80 cents. If EME customers incur an overrun for FSS services that is providedunder their EME Project service agreements, they will pay a total FSS overrun rate of 23.44 cents. The additional EME demandcharges and EME overrun charges can be added to the applicable surcharges above to develop the EME Total Effective Rate.

Issued On: December 28, 2012 Effective On: February 1, 2013

Columbia Gas Transmission, LLCV.8.F ERC Tariff

Currently Effective Ratesfourth Revised Volume No. ISST Rates

Version 17.0.0

Currently Effective RatesApplicable to Rate Schedule SSTRate Per Dth

Base Tariff TCRA EPCA OTRA CCRM ACA Total DailyRate Rates Rates Rates Rates 2/ Effecti Rate

1/ RatV’Rate Schedule SSTReservation Charge 3/4/ S 5.092 0.335 0.065 0.066 - (5.558) 0.1827Commodity

Maximum 0 1.02 0.00 0.68 0.00 0.18 1.8$ 1.88Minimum 0 1.02 0.00 0.68 0.00 0.1$ 1.8$ 1.88Overrun 4/Maximum 0 17.76 1.10 0.89 0.22 0.1$ 20.15 20.15Minimum 0 1.02 0.00 0.68 0.00 0.1$ 1.8$ 1.88

Ot O 2. . Ot? oL

1/ Excludes Account 85$ expenses and Electric Power Costs which are recovered through Columbia’s Transportation Costs RateAdjustment (TCRA) and Electric Power Costs Adjustment (EPCA), respectively.

2/ ACA assessed where applicable pursuant to Section 154.402 of the Commission’s Regulations.3/ Minimum reservation charge is $0.00.4/ Shippers utilizing the Eastern Market Expansion (EME) facilities for Rate Schedule SST service will pay a total SST reservation

charge of $17625. If EME customers incur an overrun for SST services that is provided under their EME Project serviceagreements, they will pay a total overrun rate of 58.97 cents. The applicable EME demand charge and EME overrun charge can beadded to the applicable surcharges above to calculate the EME Total Effective Rates.

Issued On: May 1,2013 Effective On: June 1,2013

NiSource GasTransmission & Storage 5151 San Felipe, Suite 2500

Houston, Texas 77056

August 18, 2009

Mr. James L. TurnerGroup Executive, President & COO139 East Fourth StreetEM025Cincinnati, OH 45202

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

Dear Mr. Turner:

This letter shall serve as an amendment to the SST Service Agreement between Columbia GasTransmission, LLC (Transporter) and Duke Energy Kentucky, Inc. (Shipper) designated asTransporter’s Contract No. 79977.

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

1) The rate for service, for the period from 11/01/09 to 3/31/10, shall include adiscounted demand rate, inclusive of the base rate and all demandsurcharges, of $3.963 for deliveries to the primary delivery points: KOT DEKMLI (834696) and the following primary receipt points: MRTCO — MasterReceipt TCO / RP Storage Point TCO. Shipper shall also provide the then-existing Retainage and shall pay the then-existing maximum commoditycharge plus commodity surcharges as set forth in Transporter’s FERC GasTariff from time to time.

2) The rate for service, for the period from 4/01/10 to 3/31/15, shall include adiscounted demand rate, inclusive of the base rate and all demandsurcharges, of $4.451 for deliveries to the primary delivery points: KOT DEKMLI (834696) and the following primary receipt points: MRTCO — MasterFeceipt TCO / RP Storage Point TCO. Shipper shall also provide the then-existing Retainage and shall pay the then-existing maximum commoditycharge plus commodity surcharges as set forth in Transporter’s FERC GasTaritf from time to time.

COLUMBIA GAS ThAN5NIIQN • COLUMBIA GULF ThAN5MIS5IQN • CROSSROADS PIPELINE •CEN-rRAL KENTUCIcy ThANSMISSION • GRANI1s STAIt • HARDY STooE • MILLENNIUM PIPELINE

3) The discounted rate provided in paragraph one and two above is limited tothe primary receipt/delivery point combinations set forth in Appendix A of theabove-referenced service agreement. Except to the extent Federal EnergyRegulatory Commission (“FERC”) policies, rules andlor regulations, and/orTransporter’s FERC Gas Tariff provide otherwise, for service under theabove-referenced Service Agreement from secondary receipt points or tosecondary delivery points, in lieu of the rates set forth in Paragraph 1 above,Transporter shall charge and Shipper shall pay the then existing maximumRecourse Rate set forth in Transporter’s FERC Gas Tariff from time to time.4) Notwithstanding the foregoing, the charge to be paid by Shipper andTransporter shall be no lower than the applicable total effective minimumcharges or higher than the applicable total effective maximum charges as setfor in Transporter’s FERC Gas Tariff from time to time. Rates provided for inthis Discount Letter Agreement will be adjusted as necessary so that the ratewill be no lower than the total effective minimum charges nor higher than theapplicable total effective maximum charges as set forth in Transporter’sFERC Gas Tariff from time to time. In the event that a rate component whichwas at or below the applicable maximum rate at the time this Discount LetterAgreement was executed subsequently exceeds the applicable maximumrate due to a change in Transporter’s maximum rate so that such ratecomponent must be adjusted downward to equal the new applicablemaximum rate, then other rate components may be adjusted upward toachieve the agreed overall rate, so long as none of the resulting ratecomponents exceed the maximum rate applicable to that rate component. Inthe event the monthly Recourse Rate applicable to SST service is reduced toa level below $3.963 or $4.451 per Dth of Transportation Demand during theterm of the above-referenced individual Service Agreement, the rates underthe SST Service Agreement referenced above will be adjusted to the newmonthly Recourse Rate.

5) This discounted transportation rate shall be apportioned in accordance withSection 20 of the General Terms and Conditions of Transporter s FERC GasTariff.

6) Shipper shall pay all then existing maximum overrun charges, if incurred, asset forth in Transporter’s FERC Gas Tariff from time to time.

If you are in agreement with th above amendment, please execute both originals of this letter andreturn them to the Transporter at the address above, Attention: Sandra Dibello.Terms agreed to this 1(0 day of ccp nk_v- 2009.

COLUMBIA GASTRANSMISSION,

Duke Energy tk4C

By:

Its: ________________________LAS FE’-C-

Columbia Gas Transmission, LLC V.17.FERC TariffCurrently Effective RatesFourth Revised Volume No. I Retainage Rates

Version 3.0.0

RETAINAGE PERCENTAGES

Transportation Retainage 1.957% S I +t.e t

Gathering Retainage 1.234%

I I’Storage Gas Loss Retainage 0.120% F5S ti (

Ohio Storage Gas Lost Retainage 0.110%

Columbia Processing Retainage/ 1 0.000%

1/ The Columbia Processing Retainage shall be assessed separately from the processing retainage applicable to third partyprocessing plants set forth in Section 25.3 (0 of the General Terms and Conditions.

Issued On; March 1, 2013 Effective On: April 1, 2013




CONTRACT NUMBER EXPECTEDRATE VOLUME OF GAS COST

f$DTH) (DTH) DAYS/MTHS ($)

INTERSTATE PIPELINE: COLUMBIA GULF TRANSMISSION CORP.TARIFF RATE EFFECTIVE DATE: FTS-1: 3/15/2013

BILLING DEMAND - TARIFF RATE - FTS-1Maximum Daily Quantity 4.2917 22,782 5 488,868Maximum Daily Quantity 4.2917 17,598 7 528,677Maximum Daily Quantity 4.2917 18,000 5 386,253Maximum Daily Quantity 4.2917 20,000 5 429,170

CAPACITY RELEASE CREDIT FOR FTS-1 0

TOTAL COLUMBIA GULF TRANSMISSION CORP. DEMAND CHARGES 1,832,968

INTERSTATE PIPELINE: KO TRANSMISSION COMPANYTARIFF RATE EFFECTIVE DATE: 4/1/2013

BILLING DEMAND - TARIFF RATE - FTMaximum Daily Quantity 0.3560 72,000 12 307,584

CAPACITY RELEASE CREDIT 0

TOTAL KO TRANSMISSION CO. DEMAND CHARGES 307,584

VARIOUS GAS MARKETERS FIXED (RESERVATION) CHARGES:

November-March 0.0013 12,045.572 16,104December- February 0.036 425,000 15,300

National Energy & Trade, LP (NET) November - March 1,000,000 700000

TOTAL GAS MARKETERS FIXED CHARGES 731,404

Columbia Gulf Transmission, LLC V.1.fERC Tariff Currently Effective RatesThird Revised Volume No. 1 FTS- I RatesVersion 10.0.0

Currently Effective RatesApplicable to Rate Schedule FTS-1Rates in Dollars per Dth

Annual Charge Total EffectiveRate Schedule FTS-1 Base Rate Adjustment 1/ Rate Daily Rate

(1) (2) (3) (4)Market ZoneReservation Charge

Maximum 4.2917- 4.2917 0.1411

Minimum 0.000- 0.000 0.000

CommodityMaximum 0.0109 0.0018 0.0127 0.0127Minimum 0.0109 0.0018 0.0127 0.0127

OverrunMaximum 0.1520 0.0018 0.1538 0.1538Minimum 0.0109 0.0018 0.0127 0.0127

1/ Pursuant to 18 CF. R. § 154.402. Rate applies to all Gas delivered. When transportation involves more than one zone, tate will be appliedonly one time.

Issued On: March 5, 2013 Effective On: March 15. 2013

KO Transmission CompanyEffective Date: 04/01/207 3 Status: EffectiveFERC Docket: RP13-00654-000FERC Order: Delegated Letter Order Order Date: 03/21/2013Part 3, Currently Effective Rates, 6.0.0

CURRENTLY EFFECTIVE RATESAPPLICABLE TO RATE SCHEDULES FTS AND ITS

RATE LEVELS - RATE PER DTH

Base Tariff Annual TotalRate Charge Effective

Adjustment1’ RateRATE SCHEDULE FTSReservation Charge 2/

Maximum 1 $0.3560 $0.3560Maximum 2 $0.3560 $0.3560Daily Rate - Maximum 1 $0.01!? $0.01 17Daily Rate - Maximum 2 $0.01 17 $0.01 17

CommodityMaximum $0.0000 $0.00!8 $0.00!8Minimum $0.0000 $0.00t$ $0.00l8Overrun $0.0117 $0.0018 $0.0!35

RATE SCHEDULE ITSCommodityMaximum $0.0117 $0.0018 $0.0135Minimum $0.0000 $0.0018 $0.0018

ACA assessed where applicable pursuant to Section 154.402 of the Commission’sregulations and will be charged pursuant to Section 23 of the General Terms andConditions at such time that initial and successive annual ACA assessments applicable toTransporter are made.

2/ Minimum reservation charge is $0.00.

Transportation Retainage Adjustment 0.92%

NOTE: Utilizing GISB standards 5.3.22 and 5.3.23, Transporters Rate Schedule FTS ReservationCharge can be converted to an applicable daily rate by dividing the above monthly rate by30.4 days.

DUKE ENERGY KENTUCKYTOTAL RESERVATION COSTS FROM FIRM SUPPLIERS

ESTIMATED FOR EGC EFFECTIVE 91112013

TOTAL ANNUAL RESERVATION COST:

TOTAL DOLLARS $ 16,104 (1)

TOTAL ANNUAL COVERAGE:

CITY GATE VOLUMES 12,045,572 Dth (2)

CALCULATED RATE: $ 0.0013 per Dth

(1) Reservation charges billed by firm suppliers for 2012 -2013.(2) Contracted volumes for the 2012 -2013 winter season.

DUKE ENERGY KENTUCKYTOTAL RESERVATION COSTS FROM NEEDLE PEAKING SUPPLIERS

ESTIMATED FOR EGC EFFECTIVE 91112013

TOTAL ANNUAL RESERVATION COST:

TOTAL DOLLARS $ $15,300.00 (1)

TOTAL ANNUAL COVERAGE:

CITY GATE VOLUMES 425,000 Dth (2)

CALCULATED RATE: $ 0.0360 per Dth

(1) Reservation charges billed by needle peaking suppliers for 2012 -2013(2) Contracted volumes for the 2012 -2013 winter season.

8/5/2013

ChevronColumbia (Mainline)

Total

BPColumbia (Mainline)

Total

ConocoColumbia (Mainline)

Total

BG EnergyColumbia Backhaul (Leach)

Total

ShellColumbia (Mainline)

Total

OccidentialColumbia (Mainline)Columbia (Mainline)

Thtal

sequentColumbia (Mainline)

Total

NextEraColumbia (Mainline)Columbia (Mainline)

Total

Duke Energy KentuckyGas Resources

Supply Portfolio - November 2012 - March 2013Reservation Fees

Dth oer Day. Total Reserv. TotalNov Dec Jan Feb Mar Volume Fee Cost

Base Fixed 6,000 6,000 6,000 6,000 6,000 906,000 $00000 $0.00906,000 $0.00

Base FOMI 0 4,000 4,000 4,000 0 360,000 $00000 $0.00360,000 $0.00

Base Fixed 5,000 5,000 5,000 5,000 5,000 755,000 $00000 $0.00755,000 $0.00

Swing GD Col Appl.+.05 18,000 18,000 18,000 18,000 18,000 2,718,000 $00025 $6,795.002,718,000 $6,795.00

Swing GD 23,972 14,772 14,872 13,672 24,072 2,767,172 $00020 $5,534.342,767,172 $5,534.34

Base FOMI 1,800 3,000 2,900 4,100 1,700 404,400 $00000 $0.00Swing Argus+.0050 10,000 10,000 10,000 10,000 10,000 1,510,000 $00000 $0.00

1,914,400 $0.00

Swing GD 10,000 10,000 10,000 10,000 10,000 1,510,000 $00025 $3,775.001,510,000 $3,775.00

Base FOMI 0 4,000 4,000 4,000 0 360,000 $00000 $0.00Swing GD+.0050 5,000 5,000 5,000 5,000 5,000 755,000 $00000 $0.00

1,115,000 $0.00

ITotal Firm Supply 12,045,572 $ 16,104.34

25 Day Peaking Service (North)Sequent (Zone 1) GD+0.29 5,000 5,000 5,000 450,000 $00100 $4,500.00Twin Eagle (Lebanon) GD+.10 12,000 12,000 12,000 1,080,000 $00100 $10,800.00

1,530,000 $15,300.00

Kentucky “Faux” StorageNET (1) Fixed 20,000 20,000 20,000 20,000 20,000 1,000,000 $0.00

(1) Must take a total of 1,000,000 Dths. Price based on average of Mich Con FOMI for Apr 12--Oct 12.Reservation fee of $122,500/month to be paid each month beginning April 2012 through October2012.

ITotal Duke Energy Kentucky 14,575,572 $31,404.34

Supply Portfolio 2012-13-Revised for Fuel Changes.xlsx 24 Fees

•NE.T Date:

Transacton Confirmation #:

February 19, 2013

181831

Transaction Confirmation forImmediate Delivery

This Transaction Confirmation is subject to the Base Contract between Seller and Buyer dated April 26, 2004.The terms of the Transaction Confirmation are binding unless disputed in writing within 2 Business Days ofreceipt unless otherwise specified in the Base Contract. For any issues regarding the confirmations please contact ContractAdministration at (713) 800-1961, (713) 800-1985 or via email at [email protected].

BUYER:SELLER:Duke Energy Kentucky, Inc.

National Energy & Trade, LP139 East Fourth St.5847 San Felipe StreetEX460Suite 1910Cincinnati, OH 45202Houston, TX 77057

Attn: Steve NiederbaumerAttn: Greg TrefzPhone: 513-287-3076Phone: 713-800-1912Fax: 513-27-2123— 2’7.-c.f211 Fax: 713-871-0510

Commodity Price: The average of the Inside FERCs Gas Market Repo,t price located under the heading ‘Upper Midwest”,the row titled “Mich Con city-gate”, and the column heading ‘Index” for the 7 months beginning April 2013through October 2013.

Payment Terms: Duke shall pay Commodity Price for the full SQ as per the terms of the NAESB agreement when the gas iscalled upon and delivered during period beginning November 1, 2013 and ending Match 31, 2014.

Delivery Period: Begin: November 01, 2013 End: Match 31, 2014Maximum Daily Quantity (Max DQ): 20,000 MMBtuidayMinimum Daily Quantity (Mm DQ): 0 MMBtulday, however, any volume greater than 0 must be dispatched inincrements of I 000 MMBtuldaySeasonal Quantity (SQ): 1,000,000 MMBtus

Delivery Pointf): Duke’s Springboro inter-connect with ANR or TETCO

Scheduling: Duke shall notify NET of its election by 8:00 am. Central Time on the business day Prior toflow. Duke shall not be required to take gas on a ratable basis over weekends and holidays.

Buyer: Duke Energy Kentucky, Inc. Seller:By:

By:

Title: f%ø(.L.’C-.Title:

hate:Date: February 19, 2013

•.NET Date:

Transaction Confirmation #:

February 19, 2013

181832

Transaction Confirmation forImmediate Delivery

This Transaction Confirmation is subject to the Base Confract between Seller and Buyer dated April 26, 2004.The terms of the Transaction Confirmation are binding unless disputed in writing within 2 Business Days ofreceipt unless otherwise specified in the Base Contract. For any issues regarding the confirmations, please contact ContractAdministration at (713) 800-1961, (713) 800-1985 or via email at [email protected].

BUYER:SELLER:

Duke Energy Kentucky, Inc.National Energy & Trade LP139 East Fourth St.5847 San Folipe StreetEX460Suite 1910Cincinnati, OH 45202Houston, TX 77057

Attn: Steve Niederbaumer Attn: Greg TrefzPhone: 513-287-3076Phone: 713-800-1912Fax: 513-257-2123 187’1.,a Fax: 713-871-0510

Delivery Period: Begin: April 01, 2013 End: October 31, 2013

Associated with supply deal under confirm #1 81 831.

Monthly Demand $0.10 times the SQ ($100,000/month) to be paid each month beginning April 2013 throughCharge: October2013.

Seller: N, onal orgy & Trade, LP

By:-.

Title: VICE PRE I - NET GENERAL PARTNERS LLC

Buyer: Duke Energy Kentucky, Inc.

Title:VP2ai /€QL.4 /L €,$

‘v/zo,/)ate:Date: February 19, 2013

GAS COMMODITY RATE FOR SEPTEMBER, 2013:


GAS MARKETERS:WEIGHTED AVERAGE GAS COST @ CITY GATE ($/Dth) (1):DUKE ENERGY KENTUCKY FUELDTH TO MCF CONVERSIONESTIMATED WEIGHTING FACTOR

GAS MARKETERS COMMODITY RATE

PROPANE:ERLANGER PROPANE INVENTORY RATEGALLON TO MCF CONVERSIONESTIMATED WEIGHTING FACTOR

PROPANE COMMODITY RATE



1.900%1.0136

100.000%

1957%

GAS STORAGE:COLUMBIA GAS TRANS. - STORAGE INVENTORY RATECOLUMBIA GAS TRANS. FSS WITHDRAWAL FEECOLUMBIA GAS TRANS. SST FUELCOLUMBIA GAS TRANS SST COMMODITY RATEKO TRANS, COMMODITY RATEDUKE ENERGY KENTUCKY FUEL 1.900%DTH TO MCF CONVERSION 1.0136ESTIMATED WEIGHTING FACTOR 0,000%

GAS STORAGE COMMODITY RATE - COLUMBiA GAS

$00721$00526

$00153$00853$00170$0.00 18$00848$00619

$6.4595

$37971 $/Dth$3.8692 $/Dth$39218 $/Mcf$39218 $/Mcf

$3.922 $IMcf

$43451 $/Dth$43604 $/Dth$44457 $/Dth$44627 $/Dth$4.4645 $/Dth$45493 $/Dth$46112 $/Mcf$00000 $/Mcf

$0.000 $IMcf

$044920 $/GaIIon$69087 $)Mcf$00000 $/Mcf$0000 $IMcf

15 380.000%

(1) Weighted average cost of gas based on NYMEX prices on 8/6/13 and contracted hedging prices.

3rd Quarter

GAS COST ADJUSTMENT CLAUSE

DUKE ENERGY KENTUCKY, INCSUPPLIER REFUND ADJUSTMENT

DETAILS FOR THE THREE MONTH PERIOD ENDED May 31, 2013

SCHEDULE II


SUPPLIER REFUNDS RECEIVED DURING THREE MONTH PERIODMarch 1, 2013 THROUGH May 31, 2013 $ 0.00

INTEREST FACTOR (REFLECTING 90 DAY COMMERCIAL PAPER RATE) 0.9980

REFUNDS INCLUDING INTEREST ( $0.00 x 0.9980 ) $ 0.00

DIVIDED BY TWELVE MONTH SALES ENDED August 31, 2014 MCF 10,202,345

CURRENT SUPPLIER REFUND ADJUSTMENT $/MCF 0.000

DETAILS OF SUPPLIER REFUNDS RECEIVED DURING THE THREE MONTHS ENDED May 31, 2013


SUPPLIER

TOTAL REFUNDS APPLICABLE TO THE CURRENT GCA $ 0.00

RAU

3rd Quarter

GAS COST ADJUSTMENT CLAUSE

DUKE ENERGY KENTUCKY, INCACTUAL ADJUSTMENT

DETAILS FOR THE THREE MONTH PERIOD ENDED May 31, 2013

SCHEDULE III

DESCRIPTION UNIT MARCH APRIL MAY

SUPPLY VOLUME PER BOOKS

PRIMARY GAS SUPPLIERSUTILITY PRODUCTIONINCLUDABLE PROPANEOTHER VOLUMES (SPECIFY) ADJUSTMENT

TOTAL SUPPLY VOLUMES

SUPPLY COST PER BOOKS

PRIMARY GAS SUPPLIERSSPECIAL PURCHASES CREDITINCLUDABLE PROPANEOTHER COSTS (SPECIFY):GAS COST UNCOLLECTIBLEMANAGEMENT FEEX-5 TARIFFTRANSPORTATION SERVICE UNACCOUNTED FORGAS COST CREDITLOSSES - DAMAGED LINESTRANSPORTATION TAKE-OR-PAY RECOVERYSALES TO REMARKETERS

TOTAL SUPPLY COSTS

JURISDICTIONALNON-JURISDICTIONALOTHER VOLUMES (SPECIFY):

TOTAL SALES VOLUMES

UNIT BOOK COST OF GAS (SUPPLY $1 SALES MCF)LESS: EGC IN EFFECT FOR THE MONTH

DIFFERENCETIMES: MONTHLY JURISDICTIONAL SALES

EQUALS MONTHLY COST DIFFERENCE

NET COST DIFFERENCE FOR THE THREE MONTH PERIOD

TOTAL COST USED IN THE CURRENT .AA CALCULATION

DIVIDED BY: 12 MONTH PROJECTED SALES ENDED August31, 2014

MCF 1,711,881 596,771 291,095MCF 0 0 0MCF 0 0 0MCF (10,755) (19,083) (24,518)

$$$

$$$$$$$$

1,701,126 577,688 266,577

7,365,442 2,944,149 1,570,6460 0 00 0 0

(25,687) (12,581) (5,721)(13,862) (13862) (13862)

0 0 00 0 00 0 0

648 0 00 0 00 0 0

$ 7,326,541 2,917,706 1,551,063

MCF

$/MCF$/MCF

$/MCFMCF

1,695,959.0 1,125,463.50.0 0.00.0 0.0

1,695,959.0 1,125,463.5 407,373.7

4.320 2.5924.359 4.586

(0039) (1.994)1.695,959.0 1,125,463.5

$ (66,142.40) (2,244,174.22) (517,771.97)

$

$

(2828,088,59)

(2,828088.59)

MCF 10.202,345

MCF

SALES VOLUMES

MCFMCFMCF

407,373.70.00.0

3.8075.078

(1.271)407373.7

EQUALS CURRENT QUARTERLY ACTUAL ADJUSTMENT $/MCF (0.277)

3rd Quarter

SCHEDULE IVGAS COST ADJUSTMENT CLAUSE

DUKE ENERGY KENTUCKY, INCBALANCE ADJUSTMENT

DETAILS FOR THE TWELVE MONTH PERIOD ENDED May 31, 2013


RECONCILIATION OF A PREVIOUS GAS COST VARIANCE

GAS COST DIFFERENCE TO BE RECOVERED FROM OR (RETURNED TO) CUSTOMERSWHICH WAS USED TO COMPUTE THE “AA” EFFECTIVE June 1. 2012 $ (2,434773.51)

LESS: AMOUNT RECOVERED (RETURNED) BY THE M OF $ (0.233) /MCFAPPLIED TO TOTAL SALES OF 9,998,900 MCF(TWELVE MONTHS ENDED May 31, 2013 ) $ (2329,743.76)

BALANCE ADJUSTMENT FOR THE “AA” $ (105,029.75)

RECONCILIATION OF A PREVIOUS SUPPLIER REFUND

SUPPLIER REFUND AMOUNT TO BE DISTRIBUTED TO CUSTOMERS WHICHWAS USED TO COMPUTE THE “RA” EFFECTIVE June 1,2012 $ (14.256.08)

LESS: AMOUNT DISTRIBUTED BYTHE “RA” OF$ (0.001) IMCFAPPLIED TO TOTAL SALES OF 9,998,900 MCF(TWELVE MONTHS ENDED May 31, 2013 ) $ (9,998.86)

BALANCE ADJUSTMENT FOR THE ‘RA” (4,257.22)

RECONCILIATION OF A PREVIOUS BALANCE ADJUSTMENT

AMOUNT TO BE RECOVERED FROM OR (RETURNED TO) CUSTOMERS WHICHWAS USED TO COMPUTE THE ‘BA’ EFFECTIVE June 1,2012 $ 576,207,02

LESS: AMOUNT RECOVERED (RETURNED) BY THE “BA’ OF $ 055 /MCFAPPLIED TO TOTAL SALES OF 9,998.900 MCF(TWELVE MONTHS ENDED May 31, 2013 ) $ 549,939.49

BALANCE ADJUSTMENT FOR THE “BA” $ 26,267.53

TOTAL BALANCE ADJUSTMENT AMOUNT $ (83,019.44)

DIVIDED BY: 12 MONTHS PROJECTED SALES ENDED August 31, 2014 MCF 10,202,345

EQUALS: CURRENT QUARTER BALANCE ADJUSTMENT $/MCF (0.008)

Revised Tariff Schedules

KY.P.S.C. Gas No. 2Eighty-Ninth Revised Sheet No. 10

Duke Energy Kentucky, Inc. Cancelling and Superseding4580 Olympic Blvd. Eighty-Eighth Revised Sheet No. 10Erlanger, Kentucky 41018 Page 1 of 2

INDEX TO APPLICABLE GAS TARIFF SCHEDULES AND COMMUNITIES SERVED

BillingSheet Effective Effective Date

No. Date per Order

SERVICE REGULATIONSService Agreements 20 01/04/10 01/04/10

Supplying and Taking of Service 21 01/04/10 01/04/10Customer’s Installation 22 01/04/10 01/04/10Company’s Installation 23 01/04/10 01/04/10Metering 24 01/04/10 01/04/10Billing and Payment 25 01/04/10 01/04/10Deposits 26 01/04/10 01/04/10Application 27 01/04/10 01/04/10Gas Space Heating Regulations 28 01/04/10 01/04/10Availability of Gas Service 29 01/04/10 01/04/10

FIRM SERVICE TARIFF SCHEDULESRate RS, Residential Service 30 08/29/13 08/29/13 (T)Rate GS, General Service 31 08/29/13 08/29/13 (T)Reserved for Future Use 32Reserved for Future Use 33Reserved for Future Use 34Reserved for Future Use 35Reserved for Future Use 36Reserved for Future Use 37Reserved for Future Use 38Reserved for Future Use 39Reserved for Future Use 40Reserved for Future Use 41Reserved for Future Use 42Reserved for Future Use 43Rate ERAS, Full Requirements Aggregation Service 44 01/04/10 01/04/10Reserved for Future Use 45Reserved for Future Use 46Reserved for Future Use 47Reserved for Future Use 48Reserved for Future use 49

TRANSPORTATION TARIFF SCHEDULERate IT, Interruptible Transportation Service 50 01/04/10 01/04/10Rate FT-L, Firm Transportation Service 51 01/04/10 01/04/10Reserved for Future Use 52Rate SSIT, Spark Spread Interruptible Transportation Rate 53 01/04/10 01/04/10Reserved for Future Use 54Rate AS, Pooling Service for Interruptible Transportation 55 01/04/10 01/04/10Reserved for Future Use 56Rate GTS, Gas Trading Service 57 01/04/10 01/04/10Rate IMBS, Interruptible Monthly Balancing Service 58 01/04/10 01/04/10Rate DGS, Distributed Generation Service 59 01/04/10 01/04/10

Issued by authority of an Order of the Kentucky Public ServiceCommission dated, 2013 in Case No. 2013-00

Issued: ,2013Effective: August 29, 2013Issued by James P. Henning, President

KY.P.S.C. Gas No. 2Eighty-Ninth Revised Sheet No. 10

Duke Energy Kentucky, Inc. Cancelling and Superseding4580 Olympic Blvd. Eighty-Eighth Revised Sheet No. 10Erlanger, Kentucky 41018 Page 2 of 2

INDEX TO APPLICABLE GAS TARIFF SCHEDULES AND COMMUNITIES SERVED (Contd.)

Sheet Billing Effective Effective DateNo. Date per Order

RIDERSRiderX, Main Extension Policy 60 01/04/10 01/04/10Rider DSM, Demand Side Management Cost Recovery Program 61 01/04/10 01/04/10Rider DSMR, Demand Side Management Rate 62 05/01/13 05/01/13Reserved for Future Use 63

Reserved for Future Use 64Reserved for Future Use 65Reserved for Future Use 66Reserved for Future Use 67Reserved for Future Use 68Reserved for Future Use 69

GAS COST RECOVERY RIDERSGas Cost Adjustment Clause 70 01/04/10 01/04/10Reserved for Future Use 71Reserved for Future Use 72Reserved for Future Use 73Reserved for Future Use 74Reserved for Future Use 75Reserved for Future Use 76Rider GCAT, Gas Cost Adjustment Transition Rider 77 08/29/13 08/29/13 (T)Reserved for Future Use 78Reserved for Future Use 79

MISCELLANEOUSBad Check Charge 80 01/04/10 01/04/10Charge for Reconnection of Service 81 01/04/10 01/04/10Local Franchise Fee 82 01/04/10 01/04/10Curtailment Plan 83 01/04/10 01/04/10Rate MPS, Meter Pulse Service 84 01/04/10 01/04/10Reserved for Future Use 85Reserved for Future Use 86Reserved for Future Use 87Reserved for Future Use 88Reserved for Future Use 89


Issued: ,2013Effective: August 29, 2013Issued by James P. Henning, President

KY.P.S.C. Gas No. 2Eighty-Fourth Revised Sheet No. 30

Duke Energy Kentucky, Inc. Cancelling and Superseding

4580 Olympic Blvd. Eighty-Third Revised Sheet No. 30

Erlanger, Kentucky 41018 Page 1 of 1

RATE RSRESIDENTIAL SERVICE

APPLICABILITYApplicable 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 BILLThe Net Monthly Bill is determined as follows:All gas is billed in units of 100 cubic feet (CCF).

Customer Charge per month: $16.00

Delivery Gas CostRate Adiustment Total Rate

Plus a commodity Charge for

all CCF at $037213 plus $04624 Equals $083453 t

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 CHARGEPayment 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 pIus 5%, is

due and payable.

SERVICE REGULATIONSThe 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 ServiceCommission dated —, 2013 in Case No. 201 3-00_

Issued: —‘ 2013Effective: August 29, 2013Issued by James P. Henning, President

KY.P.S.C. Gas No. 2Eighty-Fourth Revised Sheet No. 31

Duke Energy Kentucky, Inc. Cancelling and Superseding4580 Olympic Blvd. Eighty-Third Revised Sheet No. 31Erlanger, Kentucky 41018 Page 1 of 1

RATE GS

GENERAL SERVICEAPPLICABILITY

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 ofdelivery 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 certificatedhomeowners associations, businesses, and federal, state, and local governments. The Company may declinerequests for service under this tariff due to gas supply limitations.

NET MONTHLY BILLThe 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 CostRate Adjustment Total Rate

Plus a Commodity Charge forall CCF at $020530 Plus $04624 Equals $06677 (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 billsor other charges, will be billed in accordance with the number of billing months in the meter reading interval.

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

TERM OF SERVICEOne year, terminable thereafter on ten (10) days written notice by either customer or Company.

SERVICE REGULATIONSThe 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 theKentucky Public Service Commission as provided by law.

Issued by authority of an Order of the Kentucky Public ServiceCommission dated —‘ 2013 in Case No. 2013-00_

Issued: , 2013Effective: August29, 2013Issued by James P. Henning, President

KY.P.S.C. Gas No. 2Twenty-Ninth Revised Sheet No. 77

Duke Energy Kentucky, Inc. Cancelling and Superseding4580 Olympic Blvd. Twenty-Eighth Revised Sheet No. 77Erlanger, Kentucky 41018 Page 1 of 1

RIDER GCAT

GAS COST ADJUSTMENT TRANSITION RIDER

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

GCA TRANSITION RIDERA charge or credit shall be applied to all volumes transported pursuant to Rate FT-L in order to passthrough to former GCA customers the Company’s quarterly Actual Adjustment (AA), BalanceAdjustment (BA), and Supplier Refund and Reconciliation Adjustment (RA) costs or credits duringthe first twelve months that the former sales customer participates in the Company’s firmtransportation program.

The amount of this charge or (credit) shall be $0054 per 100 cubic feet. This rate shall be in effect (R)

during the month of September 2013 through November 2013 and shall be updated quarterly, (T)

concurrent with the Company’s GCA filings.


Issued: —‘ 2013Effective: August 29, 2013Issued by James P. Henning, President

DUKE ENERGY KENTUCKYSUPPLEMENTAL INFORMATION

FOR THE EXPECTED GAS COST (EGC) RATE CALCULATIONOF THE GAS COST RECOVERY RATE

LN EFFECT AS OF AUGUST 29, 2013

3rd Quarter

DUKE ENERGY Kentucky, Inc.USED FOR GCA EFFECTIVE August 29, 2013COMPUTATION OF THE INTEREST FACTOR JUNE 2012 0.18FOR THE GCA CALCULATION ON SCHEDULE II JULY 2012 0.16

AUGUST 2012 0.19TWELVE MONTHS ENDED June 30, 2013 SEPTEMBER 2012 0.12BLOOMBERG REPORT (90-DAY COMMERCIAL PAPER RATES) OCTOBER 2012 0.19

NOVEMBER 2012 0.21INTEREST RATE -0.0037 DECEMBER 2012 0.17

JANUARY 2013 0.17PAYMENT 0.083166 FEBRUARY 2013 0.15

MARCH 2013 0.17ANNUAL TOTAL 0.9960 APRIL 2013 0.00

MAY 2013 0.00 1.71JUNE 2013 0.00 1.71MONTHLY INTEREST (0.000306)

AMOUNT 1

PRIOR ANNUAL TOTAL 1.71

PLUS CURRENT MONTHLY P 0.00

LESS YEAR AGO RATE 0.18

NEWANNUALTOTAL 1.53

AVERAGE ANNUAL RATE 0.13

LESS 0.5% (ADMINISTRATIVE (0.37)

DUKE ENERGY COMPANY KENTUCKYDETERMINATION OF TOTAL SUPPLY COST

MONTH OF March 2013

TOTALAMOUNT

DESCRIPTION WIP ROUNDED

PRIMARY GAS SUPPLY COST $current month estimate B1 7,412,637.77adjustments from prior month B2 (50,365.98)Interruptible Transportation monthly charges by Gas Supply - PF C 3,170.35 7,365442

LESS: RATE SCHEDULE CF CREDITcurrent month 0.00adjustments 0.00 0

PLUS: INCLUDABLE PROPANEa/c 728-3 Erlanger 02 0.00 0

PLUS: GAS COST UNCOLLECTIBLE E (25,687.00) (25,687)

LESS: X-5 TARIFF 0.00 0

LESS Tenaska MANAGEMENT FEE F 13,862.00 (13,862)

LESS: TOP TRANSP. RECOVERIES 0.00 0

LESS: GAS LOSSES - DAMAGED LINES G 647.90 648

0.00adjustments 0,00 0

LESS: GAS COST CREDIT 0.00 0

LESS: FIRM TRANSPORTATION ADJUSTMENTScurrent month 0.00adjustments 0.00 0

TOTAL SUPPLY COSTS 7,326,541

ACCOUNTING ENTRY FOR DEFERRAL ONLY AMOUNT

ACCOUNT - 191990/191400 (66,142.40)ACCOUNT 805-10 66,142.40

PURCHASED GAS ADJUSTMENT SCHEDULEIII

COMPANY NAME: DUKE ENERGY COMPANY KENTUCKY

ACTUAL ADJUSTMENT

DETAILS FOR THE MONTH March 2013

MONTHPARTICULARS UNIT WIP March 2013


Primary Gas Suppliers MCF BI 1,711,881Utility Production MCF 0Includable Propane MCF Dl 0Other Volumes (Specify) - Previous Month Adj. MCF B2 (10,755)

TOTALSUPPLY VOLUMES MCF 1,701,126


Primary Gas Suppliers S Al 7,365,442Includable Propane $ 0Gas Cost Uncollectible $ Al (25,687)Other Cost (Specify) - Gas Cost Credit $ 0

- Unacctd for Transp. $ 0-CFCredit $ 0- X-5 Tariff $ 0- CMT Management Fee $ Al (13,862)- Losses-Damaged Lines $ Al 648- Gas Sold to Remarketers $ 0- TOP Transp. Recoveries $ 0

TOTAL SUPPLY COST $ Al 7,326,541

SALES VOLUMES

Jurisdictional MCF H l,695,959MNon-Jurisdictional MCFOther Volumes (Specify) - MCF

_____________________

TOTAL SALES VOLUME MCF 1,695,959.0

UNIT BOOK COST OF GAS (SUPPLY $1 SALES MCF) $/MCF 4.320LESS: EGC IN EFFECT FOR MONTH $IMCF H 4.359

DIFFERENCE $/MCF (0.039)TIMES: MONTHLY JURISDICTIONAL SALES MCF 1,695,959.0

MONTHLY COST DIFFERENCE $ (66,142.40)

DUKE ENERGY COMPANY KENTUCKY

March 2013

AppliedMCF Sales W/P Amount $IMCF

GAS FUEL ADJUSTMENT BILLEDEGC 1,695,959.0 H 7,393,33390 4.35938245RA H (27,266.22)AA H (49,780.41)BA H (6,711.22)

TOTAL GAS COST RECOVERY(GCR) 7,309,576.05

TOTAL SALES VOLUME 1,695,959.0LESS: NON-JURISDICTIONAL SALES 0.0

JURISDICTIONAL SALES 1,695,959.0

PROOF OF UNRECOVERED PURCHASED GAS COST ENTRY

SUPPLIER COST - CURRENT MONTH 1,695,959.0 7,326,541.00 4.31999889UNRECOVERED PURCHASED GAS COST 16,361.99ROUNDING(ADD/(DEDUCT)) 650.50

TOTAL GAS COST IN REVENUE 7,343,553.49

TOTAL GAS COST RECOVERY(GCR) 7,309,576.05LESS: RA (27,266.22)

BA (6,711.22)

PLUS: COST OF NON-JURISDICTIONAL SALES

7,275,598.61

UNRECOVERED PURCHASED GAS COST ENTRY 16,361.99LESS: M (49,780.41)

MONTHLY COST DIFFERENCE 66,142.40EXTENDED MONTHLY COST DIFFERENCE 66,792.90

ROUNDING 650.50

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MONTH OF April 2013

TOTALAMOUNT

DESCRIPTION ROUNDED

PRIMARY GAS SUPPLY COST $current month estimate BI 3,036,089.98adjustments from prior month B2 (91,069.74)Interruptible Transportation monthly charges by Gas Supply - PN C (871.60) 2944,149

LESS: RATE SCHEDULE CF CREDITcurrent month 0.00adjustments o.oo 0

PLUS: INCLUDABLE PROPANEa/c 728-3 Erlanger D2 0.00 0


LESS: X-5 TARIFF 0,00 0




0.00adjustments 0.00 0



TOTAL SUPPLY COSTS 2,917,706


ACCOUNT - 191990/191400 (2,244,174.22)ACCOUNT 805-10 2,244,174.22



ACTUAL ADJUSTMENT

DETAILS FOR THE MONTH April 2013

MONTHPARTICULARS UNIT WIP April 2013


Primary Gas Suppliers MCE BI 596,771Utility Production MCF 0Includable Propane MCF Dl 0Other Volumes (Specify) - Previous Month Adj. MCF 82 (19,083)

TOTAL SUPPLY VOLUMES MOE 577,688


Primary Gas Suppliers $ Al 2,944,149Includable Propane $ 0Gas Cost Uncollectible $ Al (12,581)Other Cost (Specify) - Gas Cost Credit $ 0

- Unacct’d for Transp. S 0- CF Credit S 0- X-5 Tariff $ 0- CMT Management Fee $ Al (13,862)- Losses-Damaged Lines $ Al 0- Gas Sold to Remarketers S 0- TOP Transp. Recoveries S 0


SALES VOLUMES

Jurisdictional MCF H 1,125,463.5Non-Jurisdictional MCFOther Volumes (Specify) - MCF

____________________

TOTALSALES VOLUME MCF 1,125,463.5

UNIT BOOK COST OF GAS (SUPPLY $/SALES MCF) $/MCF 2.592LESS: EGC IN EFFECT FOR MONTH 5/MCF H 4.586

DIFFERENCE $/MCF (1.994)TIMES: MONTHLY JURISDICTIONAL SALES MCF 1,125,463.5

MONTHLY COST DIFFERENCE S (2,244,17


April 2013

AppliedMCF Sales WIP Amount $IMCF

GAS FUEL ADJUSTMENT BILLEDEGC 1,125,463.5 H 5,161,314.19 4.58594543RA H (18,097.60)AA H (33,464.36)BA H (4,398.77)


TOTAL SALES VOLUME 1,125,463.5LESS: NON-JURISDICTIONAL SALES 0.0

JURISDICTIONAL SALES 1,125,463.5


SUPPLIER COST - CURRENT MONTH 1,125,463.5 2,917,706.00 2.59244836UNRECOVERED PURCHASED GAS COST 2,210,709.86ROUNDING(ADD/(DEDUCT)) (566.03)



BA (4,398.77)


5,082,857.09

UNRECOVERED PURCHASED GAS COST ENTRY 2,210,709.86LESS: AA (33,464.36)

MONTHLY COST DIFFERENCE 2,244,174.22EXTENDED MONTHLY COST DIFFERENCE 2,243,608.19

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TOTALAMOUNT

DESCRIPTION W(P ROUNDED

PRIMARY GAS SUPPLY COST$current month estimate BI 1,674,994.68

adjustments from prior month B2 (104,543.30)Interruptible Transportation monthly charges by Gas Supply- PF C 194.79 1,570646

LESS: RATE SCHEDULE CF CREDITcurrent month 0.00adjustments 0.00 0

PLUS: INCLUDABLE PROPANEa/c 728-3 Erlanger D2 0.00 0


LESS: X-5 TARIFF 0.00 0




0.00adjustments 0.00 0



TOTAL SUPPLY COSTS 1,551.063


ACCOUNT - 191990/191400 (517,771.97)ACCOUNT 0805002 517,771.97



ACTUAL ADJUSTMENT

DETAILS FOR THE MONTH May 2013

MONTHPARTICULARS UNIT WIP May 2013


Primary Gas Suppliers MCF BI 291,095Utility Production MCF 0Includable Propane MCF Dl 0Other Volumes (Specify)- Previous Month Adj. MCF 82 (24,518)

TOTAL SUPPLY VOLUMES MCF 266577


Primary Gas Suppliers $ Al 1570646Includable Propane $ 0Gas Cost Uncollectible $ Al (5,721)Other Cost (Specify) - Gas Cost Credit $ 0

- Unacct’d for Transp. $ 0-CFCredit $ 0- X-5 Tariff $ 0- CMI Management Fee $ Al (13,862)- Losses-Damaged Lines $ Al 0- Gas Sold to Remarketers $ 0- TOP Transp. Recoveries $ 0


SALES VOLUMES

Jurisdictional MCF H 407,373.7Non-Jurisdictional MCFOther Volumes (Specify) - MCF

TOTAL SALES VOLUME MCF 407373.7

UNIT BOOK COST OF GAS (SUPPLY $1 SALES MCF) $/MCF 3.807LESS: EGC IN EFFECT FOR MONTH $/MCF H 5.078

DIFFERENCE $/MCF (1.271)TIMES: MONTHLY JURISDICTIONAL SALES MCF 407373.7

MONTHLY COST DIFFERENCE $ (517,771.97)


May 2013

AppliedMCF Sales WIP Amount $IMCF

GAS FUEL ADJUSTMENT BILLEDEGC 407,373.7 H 2,068,461.94 5.07755395RA H (6,553.32)AA H (12,695.71)BA H (1,547.62)


TOTAL SALES VOLUME 407,373.7LESS: NON-JURISDICTIONAL SALES 0.0

JURISDICTIONAL SALES 407,373.7


SUPPLIER COST - CURRENT MONTH 407,373.7 1551,063.00 3.80746965UNRECOVERED PURCHASED GAS COST 505,076.26ROUNDING(ADD/(DEDUCT)) (373.03)



BA (1,547.62)


2,039,564.35

UNRECOVERED PURCHASED GAS COST ENTRY 505,076.26LESS: AA (12,695.71)

MONTHLY COST DIFFERENCE 517,771.97EXTENDED MONTHLY COST DIFFERENCE 517,398.94

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