Page 8 - Wednesday, Augu.st 30, 2017 - The Galladn County News, Wanaw, KY NOTICE Dul<& Energy KlllUJCky. Inc. ('Ouke Ene19Y Kentucky"()( 'Col11*1Yi hereby gives notice lhat. in an lflPblion to be lied no sooner lh8n Seplembef 1, 2017, Enel!IY Keru:ky wil be seeking eppoval by fie Nllc SeM:e COnmssicin. Flri· fort. Kentucky of an adjustment of electric rates and charges proposed1obeoome ellectiYeon and aller Octet. I, 2017. The Comrrisslon has docketed lhls poceedng as Case No. 2017.oo321 . The proposed elet1Jlc rates are applicable ID tie toaowlng comrnriles: AJcmldria Elsmafe Bel!evue El1lnger Boone Colny F81M8W Bromley Fknnce Campbell County Feet Mildlel Cold Spring Feet Thomas Covington Feet Cfescent Park Grant County Ctescoot Springs Highland Heights Cfestview Independence Crestview Hills KenlOO County Crittenden Kenton Vale Dayton Lakeside Park Ory Ridge Latonia L8l<es Edgewood Cvrrtllt Rate Cus1olncr Charge E nergy Charge All kJlowatl-hoorS ProooHd Rate CUslomer Charge Energy Charge M kiowatl-hourS 8"k1e!t!el Sta!ct • Bata BS (Ellctrlc Ttdft Sbllt No. 3Q) $4. 50 per month 7. 5456c per kWh s 11.22 per monlh 8.3908e per kWh Luclow Mel>oume Newport Pl/It tils Pendlelon Col.rlty Ryland Htl!tO Silver GIOY8 Soulhgate Ta)tlrMI• Union Hillt Walton Wilder Woodawn StryJq ll Stcoodlcy DiltJ1butlon 'lolllQrilll DS !E!ectdc Idl SbMt Ho. 401 Current Bate Cus1omer Charge per month Single Phase SeMce Three Phase Serva Demand Charge First 15 kilOWatts AddiliOnal kilowatts Ene<gy Charge First 6.000 kWh Next 300 kWh/IN/ Additional kWh Propotec! Bate Cus10mer Charge por month Single Phase SeNk:e Three Phase Service Demand Charge F"rsl , 5 kilowatts Addililnal ldbwans Energy Charge Frst 6, 000 kWh Next 300 kWhfAW Addilional kWh $ 7.50 per month $15.00 per mooth $ 0.00 per kW $ 7. 75 perkW 8.1645¢ per kWh 5. 0119e pet kWh perkWh $17.14 permonlh $ 34.28 per med\ S 0.00 per kW $ 8.73 perkW 9.1917iperkWh 4.63)4e per kWh TmHf-<>a 8* fpr Stalct C D!ttrl!Mllpn" I AIM Dt !Ellctdc Tdf lhllt No. 411 Cvnwrt Ritt Cuslomer Charge Sngle Phase Three Pha'6 Primary Vottage SeMCe Demand Charge Summer On Peak kW Off Peak kW Winter On Peak kW Off Peak kW Energy Chatge Summer Metering On PGBJc kWh l ' t P. ti Off PeakkWh Wlllter On Peak kWh Off PeakkWh Frsl 1, 000 'M of On Peak billing demand at Addllional kW d On .. Prppolld Ritt BaseRale Customer Charge Single PhaSe Three PhaSe Primary Voltage Servioa Demand Charge Summer OnPeakkW Olf PeakkW Winter On Peak kW Off Peak kW Eoeigy Charge Metenng Summer On Peak kWh Off Peak kWh Winter On Peak kWh Off Peak kWh Frsl 1, 000 kW of On Peak bifr.g denWld at Additional kW of On Peak baling demand at Cu rrtnt Bate A. Winlllr Period CuSlomer Charge Single Pilate Service Three Phase SeMce Prunary Voltage Service Oemard Charge AllkW Energy Charge AllkWh Progoud Rote A. W111ter Period Customer Charge Single Phase Service Three Phase Service Primary Voltage Service $7. 50 per month $15.00 per mon1h $100.00 per month $ 12. 75 per kW $ 1.15 perkW $ 12.07 perkW S 1.15 perkW 4.2t 95e per kWh 3.6195e per kWh s 0.65 per kW. s 0.50 per kW. S 200. 00 per monlh $ 400.00 per month $ 405.00 per moolh $14. 39 per 'M $ 1. 30 perkW $13.62 perkW $1.30 perkW 4. 9875e per kWh 4. 0844e per kWh 4. 7612e perkWh 4.0844e per kWh S0. 73 per kW. s 0. 56 per 'ffl. $ 7. 50 per month $15.00 per month $100. 00 per monttl s 0. 00 per kW 6. 1524e per kWh $ 17. 14 permonth s 34.28 per month $118.78 per month $ 0. 00 per kW Demand Charge AlkW Energy Charge AllkWh 6.9947c per kWh SWooal Spotta Strdct:Rllt sp (§tctrlc Tar1ft Sbllt No. 431 Currtntllatl Customer Cf\a!ge $7. 50 per rnor#I Energy Charge 10. 0598eper kWh A chaige of S25 00 IS applicable IO eedl season IO 00\'ef in pan the cost of rec:oco iection of serw:e. fn>j)Qted Bait Cus1omer Charge $17, 14 per monlh Energy Charge 10.6568Cper kWh A charge ol $25 00 IS applicable lo each 982SOR lo IXN8f in part Ille cost of reconnection of seMce. Current Bate Optlool! Unmtltrtd Glod Strylcl ,. For $»111 Bxtd Lon· Ritt GSfl !Ellc!dc Iadtf Sheet No. 441 For loads based on a range of 54010 720 hours use per month of the rated capacity ol the conneaed equipment 8. 0723c per kWh For IOads of less thM 540 hours use per month of the rated capacity of the c:onnected 9.2947 per kWh Mi1lnum S3. 00 per F1Ked Loed Location per month. PNJIClllll Rl1I For loads besed on a range of 540 ID 720 hotn use per month ol the rated capacity of the connected equipment For loeds of less than 540 hours use per moolh of lhe rated capag1y of the conneded eqtipl1lenl Milimum $3 14 per F'IXBd Load Location per mond'I. 9. 2696e per kWh 1 o sme per ""' Stalc:l It Pdmlry Dtatrtbul!on Yot!g Mt""tlr::BlllJ!f IEltdrlc Tldlf Shllt No. 4Sl CumntRltt Custlfner Charge per month Primary Voltage ServfCe (12.5 Of 34.5 kV) Demand Cllatge NJ kiloWatt Energy Charge First 300 kWM<W Additional kWh Customer Charge per month Primary Vollag& Se!vice (12.5 Of 34.5 kV) Demand Charge AD kilowatts Energy Charge Fist 300 kWh Adlllional kWh $100.00 per month S 7. 08 perkW 5. 1068t per kWh 4. 3198¢ per kWh $118.78 per month S 6. 40 perkW parkWh 5. 1267e perkWh Dmt=OHlty Bait for Sttyict II TrwltmiHlon yobq1 .... tt (Electdc Jlritf Shllt No. 51) CVmnt 811!1 Customer Chatga per month Demand Charge SurMler Oii PeakkW Oii Peak kW Winter On PeakkW Off Peak'ffl Energy Charge All kWh Pmsioad Rite Cuslomer Charge per lTIQllth Defnard Charge Summef On Peale kW O"PeakkW Winter On PeakkW Off PeakkW Energy Ctiarge Sl.m'nel OnPealtkWh Ot!PeakkWh Winter On PeakkWh Off PeakkWh Currmt Biii 1. Adrilislra!lve Charge $500. 00 I* month S 7 flO per kW $ 1.15 perkW $ 624 parkW $ 1.15 perkW 4.2648t per kWh $500.00 per month $ 8. 46 perkW $ 1 28 per kW S 8.95 perkW s 1. 28 perkW perkWh 4. 4594c per kWh 5. 1983c per kWh 4. 4594C per kWh Rider GSS - °"*9tlol1 Support S... !Elldrtc Twt1I $llllt No. 511 The M'nirislrawe Charge atia1 be $50 plus the IPPOPMlt C\l9IOllllr ai.ve. 2. Monthly Oistrbltion P.es&Mlion Charge a. Rate OS· Secoodary Oislrllulal SeMoe b. Rate OT - Oisllb.ltlol1 SelYloe c. Rate DP - Primaty Olstrlbution Service d. Rate TT -T ransmi5Sion Se!vioe 3. Monthly Transmission Reseivallon Charge a Rate OS • Secondary OiStributlon Seivlce b. Rate OT - Otslrt>utlon Sefvice c. Rate OP - Primary Service d. Rate TT - Transmission Sefvloe 4. Month!'/ Anclllary Services Aeseivallon Charge a. Bate OS • Secondary Olstrilullon SeMce b. Rate OT - OISlrl>ullon SeMce c. Rate OP - Pnmary Dl$1ribution SefW:e d. Rale TT - Transni9Bion SeNioe Propoted Bill 1. AdminislrlliYe ChQtge $2.6853 per kW $2.47351* kW $2.nB1 per kW $0.0000 pet kVA $1 .30IM par kW $1 . 3047 per kW $1.8493 par kW $1 . 2881 per kVA S0.5240 per kW $0.5240 I* kW S0.5240 per SO 4550 I* kVA Charge lihal be S50 pU the IJIPl1lPlale Custlfner Chatge. 2. Monthly AeselvaliJn Charge a Bate OS • Secondaty Olstrilubon Service $4.8468 per kW b. Ra.le OT - Olsttilution SeMce $5 9992 per kW c. AG OP - Primlry OislJiJution Service S6 per kW d. Ram TT - Transnisalon Servioe $2. 9886 per kW RMI Timi pdc!ng-MMUI ..Atw1 Ma= 8* RD4I IE!ectdc Twttf Sbllt No. 5i) Secondary Se!vlces . .. . ... $15.00 per month Primary Serw:e ............. $100.00 per month Transtnl$sion Servlce ..• " •. $500. 00 per mon1tl Energy Oellv&ry Charge Chalge For Each kW Per Hour: Secondary SefVice ......... S0. 006053 per kW Per Hoor Primary SefVice ............ $0.005540 per kW Per Hour Trar1$1T11ssion Servk:e ....... $0. 002008 per kW Per Hour Ancillary SeMoes Ctiarge shan be applied on an hour by hour basis. Chatge F0< Each kW Per Hour ; Secondary Oellvery ...... . $0. 000760 per kW Per Hour Primary Oefivery ........... S0. 000740 per kW Per Hour Transmission Oelive!y .... $0. 000721 per kW Per Hour PrQPOMd Bata CANCELLED & WITHDRAWN CVrrlntAa!t OVERHEAD DlSIBWl.lJlctl AREA Lamp Mnual F1x1ure Oescriplion Walli • .iWIL S1andard F°IXDJl'e (Cobra Head) MelwyVapor 7, 000lumen 175 0. 193 803 1, 000 lumen (Open Aefradllr) 175 0205 853 10,000 It.men 2SO 0. 275 1,144 21 ,000 lumen 400 0. 430 1.789 Metal Halide 14.000 lumen 175 0.193 803 20,500 lumen 250 0. 275 1. 144 30,000 lumen 400 0.430 1,789 Sodium vapor 9,SOOtumen 100 0. 117 487 9, 50011.!men (Open Refractor) 100 0. 117 467 16,000 lumen 150 0. 171 711 22, 000 lumen 200 0.228 948 50 ,000 lumen 400 0. 471 1, 959 Decorative Fixtures Sodium vapor 9.500 lumen (Aeotilinear) 100 0117 487 22,000 llrnen (Aectifll188T) 200 0.246 1,023 50,000 Unen (Rec!ilinear) 400 0. 471 1, 959 50,000 lumen (Setback) 400 0. 471 1, 969 Spans of Secondary Wiring: Balri.1.d $7.11 SS. 94 $821 $1099 $7.11 $8.21 $10. 99 $7.87 $5.91 $8.58 $11.13 $1495 $9.78 $12.09 $16. 00 $23. 79 For each ncsementof 50 feetof secondlwywmg beyond the first 1501aet lromlhe pole, price per month shall be added 10 the poce par month per SlrMt lghting untl : $0. 52. UNOEAGBQUNP PISTBIBVT!ON Wlp Amua1 watn kWh 8a'U1lil F"!XIUl9 Descr1>tioo Standard Flxtt.A (Cobra Head) Mercuy Vapor 7, 000lumen 175 0.210 874 $7. 24 7,000 lumen (Open Refraclol) 175 0. 205 853 SU4 10,000UTlen 250 0.292 1.216 18.36 21.000 lumen 400 0.460 1.914 s 11.25 Metal Halide 14,000 lumen 175 0.210 874 $7.24 20,500 lumen 250 0.292 1,216 U.36 30, 000 lumen 250 0.292 1216 $11.25 Sodium Vapor 9,5001umen 100 0. 117 487 $ 7.87 9,500 lumen (Open Aefractor) 100 0117 487 $5.99 16, 000 klnen 150 0171 711 $8.SS eora-i lltll •
Transcript
\)~ Page 8 - Wednesday, Augu.st 30, 2017 - The Galladn County News, Wanaw, KY
NOTICE
Dul<& Energy KlllUJCky. Inc. ('Ouke Ene19Y Kentucky"()( 'Col11*1Yi hereby gives notice lhat. in an lflPblion to be lied no sooner lh8n Seplembef 1, 2017, ~ Enel!IY Keru:ky wil be seeking eppoval by fie Nllc SeM:e COnmssicin. Flri· fort. Kentucky of an adjustment of electric rates and charges proposed1obeoome ellectiYeon and aller Octet. I, 2017. The Comrrisslon has docketed lhls poceedng as Case No. 2017.oo321 .
The proposed elet1Jlc rates are applicable ID tie toaowlng comrnriles: AJcmldria Elsmafe Bel!evue El1lnger Boone Colny F81M8W Bromley Fknnce Campbell County Feet Mildlel Cold Spring Feet Thomas Covington Feet ~ Cfescent Park Grant County Ctescoot Springs Highland Heights Cfestview Independence Crestview Hills KenlOO County Crittenden Kenton Vale Dayton Lakeside Park Ory Ridge Latonia L8l<es Edgewood
Cvrrtllt Rate Cus1olncr Charge Energy Charge
All kJlowatl-hoorS ProooHd Rate CUslomer Charge Energy Charge
M kiowatl-hourS
8"k1e!t!el Sta!ct • Bata BS (Ellctrlc Ttdft Sbllt No. 3Q)
Currtntllatl Customer Cf\a!ge $7.50 per rnor#I Energy Charge 10.0598eper kWh
A chaige of S25 00 IS applicable IO eedl season IO 00\'ef in pan the cost of rec:oco iection of serw:e. fn>j)Qted Bait Cus1omer Charge $17, 14 per monlh Energy Charge 10.6568Cper kWh A charge ol $25 00 IS applicable lo each 982SOR lo IXN8f in part Ille cost of reconnection of seMce.
For loads based on a range of 54010 720 hours use per month of the rated capacity ol the conneaed equipment 8.0723c per kWh For IOads of less thM 540 hours use per month of the rated capacity of the c:onnected ~ 9.2947 per kWh Mi1lnum S3.00 per F1Ked Loed Location per month.
PNJIClllll Rl1I For loads besed on a range of 540 ID 720 hotn use per month ol the rated capacity of the connected equipment For loeds of less than 540 hours use per moolh of lhe rated capag1y of the conneded eqtipl1lenl Milimum $3 14 per F'IXBd Load Location per mond'I.
The M'nirislrawe Charge atia1 be $50 plus the IPPOPMlt C\l9IOllllr ai.ve. 2. Monthly Oistrbltion P.es&Mlion Charge
a. Rate OS· Secoodary Oislrllulal SeMoe b. Rate OT - Oisllb.ltlol1 SelYloe c. Rate DP - Primaty Olstrlbution Service d. Rate TT - T ransmi5Sion Se!vioe
3. Monthly Transmission Reseivallon Charge a Rate OS • Secondary OiStributlon Seivlce b. Rate OT - Otslrt>utlon Sefvice c. Rate OP - Primary ~ribution Service d. Rate TT - Transmission Sefvloe
4. Month!'/ Anclllary Services Aeseivallon Charge a. Bate OS • Secondary Olstrilullon SeMce b. Rate OT - OISlrl>ullon SeMce c. Rate OP - Pnmary Dl$1ribution SefW:e d. Rale TT - Transni9Bion SeNioe
Propoted Bill 1. AdminislrlliYe ChQtge
$2.6853 per kW $2.47351* kW $2.nB1 per kW $0.0000 pet kVA
$1 .30IM par kW $1 .3047 per kW $1.8493 par kW $1 .2881 per kVA
S0.5240 per kW $0.5240 I* kW S0.5240 per ~w SO 4550 I* kVA
The~ Charge lihal be S50 pU the IJIPl1lPlale Custlfner Chatge. 2. Monthly AeselvaliJn Charge
a Bate OS • Secondaty Olstrilubon Service $4.8468 per kW b. Ra.le OT - Olsttilution SeMce $5 9992 per kW c. AG OP - Primlry OislJiJution Service S6 1~ per kW d. Ram TT - Transnisalon Servioe $2.9886 per kW
Secondary Se!vlces ....... $15.00 per month Primary Serw:e ............. $100.00 per month Transtnl$sion Servlce ..• " •. $500.00 per mon1tl
Energy Oellv&ry Charge Chalge For Each kW Per Hour:
Secondary SefVice ......... S0.006053 per kW Per Hoor Primary SefVice ............ $0.005540 per kW Per Hour Trar1$1T11ssion Servk:e ....... $0.002008 per kW Per Hour
Ancillary SeMoes Ctiarge shan be applied on an hour by hour basis. Chatge F0< Each kW Per Hour;
Secondary Oellvery ....... $0.000760 per kW Per Hour Primary Oefivery ........... S0.000740 per kW Per Hour Transmission Oelive!y .... $0.000721 per kW Per Hour
PrQPOMd Bata CANCELLED & WITHDRAWN
CVrrlntAa!t OVERHEAD DlSIBWl.lJlctl AREA Lamp Mnual
For each ncsementof 50 feetof secondlwywmg beyond the first 1501aet lromlhe pole, the~ price per month shall be added 10 the poce par month per SlrMt lghting untl: $0.52. UNOEAGBQUNP PISTBIBVT!ON Wlp Amua1 ~ watn kW~ kWh 8a'U1lil
F"!XIUl9 Descr1>tioo Standard Flxtt.A (Cobra Head)
Spans of Seoondary Winng: For each ro'ement of 25 feet of sooondary wifing beyond the first 25 feet from the pole, lhe following price per month &hal be added 1o the pnce per month per street lighting un t $0.75. Base fuel Co6t A.II f<lowatt-houra shall be sOOjed lo a charge of $0.0238.17 per kilowatt-ho!K rellectlng the base cost of fuel. PnlQoMd Biii OVERHEAD DISTRIBUTION AREA I.an-.> Annual
(Where a 5ll9ef lighting fiiclt.re served ovemeacs rs lo be Installed on another utitity s pole on WNCti lhe Company clo8$ not have a oontact. e monllily pole chalge wllt be assessed. Spans ol Seoondary Winng: For each mcremeot of 50 feet of seoondary w1nng beyond the first 150 feet from the pole, Iha following price per month shall be added to the price per month per street lighting unit: $0.58. U!iDEBGBQIJtiD DISTRIBUTION Lamp Annual ABEA Wa.tli kWl.Uni1 kWh. ..Bal§LlJnjt
F 1Xtute Description Slandard F'IXfire (Cobra Head)
Spans of Secondaty Wiiing. For each lncrement ol 25 feet ol secondary w1nng beyond the first 25 feet from the pole, the following p0oe per monlh shal be added _, the pOoe per month per street ighting UM' $0.84. Bue Fuel Cost
The rates per unit shown above include a charge of $0.023837 per kilowatt·hour reffectlng the base cost of fuel.
~
Icltt!G. Llghjlng SeryJce ·Bate TL ~
Where the Company Sl.wfies energy arty, all kilowatt·houra shall be billed at 3.8066 cents per kilowatt hour; Where the Company supplies energy from e separately metered source and the Company has agreed to provide limiled mafll8nanee fol' trallie signal equipment d kllowatt-holrs shaW be billed 81 21078 oenla per klowall-hou.'. Where the Company $tWlies energy end has &gleed IO provide limited mamtenance fol' traffic signal eqtJpmenl, all kiiowalt-houfs &hall be billed at 5.9145 cents per kilowatt-hour.
The Gallatin County News, Warsaw, Ky. - Wedm9day, A ...... ..W. :?tt7 - l'agc 9 •
P!ooosed Bate Where the Company suppries energy ortJ, au kilowatt-hours shal be bled at 4.2590 cent• I* klklw3ll hour; Where the Company supplies enetgy from a separately mele<ed IOUrct ancl fie Con1>anY has egrlled 10 provide rr1ted maintenance tor traffic signal equ~en~ all kilowatt.0001'1 Shall be IJjlled at 2.3583 oenta per kbtft·hour Where the Company supplies energy and has agreed to provide llrnlled maintenance for nlllc slgnal equipment all ~1to-. watt·hOUrs shalt be billed at 6.6174 cen1S per kllowalt-hout.
Outdoor l.!ghtk>Q EQl.!IQmlnt lnd*e- - Ql-1 IE!tctdc Tutti 8b111 No. Ul
The System Charge is detennined by applying the CU1Tent l.8Yllfized Fixed Charge Rate (lFCR), to the Company s cost N purohaSlng and Installing the System. Propoad Batt There are no changes to this tariff schedule
Outdoor LW!l!tlll ..... Rm Ol (E.llc:lrlc Idl hit ftll, M>
a 2,5001umenlncandescent-Selies 148 0.148 616 $9.22 b. 2,500 lumen Incandescent- Muftlple 189 0.189 786 S 7 16 Holophane Decorative fixllJre on 17 foot fibelglass pole set'Ved undergl'Ollld w1th di'ed bOOed cable a. 10.000 lumen Mefculy Vapor 250 0.212 1.215 $11179
The cable span dlarge of S.75 per each~ al 25 lee! al secondary wimg shal be lddecl lo lh8 Rate/unit chatge for each increment ol secondary wiring beyond the first 25 feel from the pole bae.
Street light units seived overhead distribution a 2,5001umenlncandescenl 189 0. 189 786 $7.10 b. 2,500 lumen Mercury Vapor 100 0.109 45.1 $ 6.72 c. 21,000 lumen Mercury Vapor 400 0.460 1,914 $10.65 Customer owned S1eel boulevard units served underground with limited mainlenance by Company a 2.500 lumen rncandescenl-Series 148 0.148 8111 $5.44 b 2.500 lumen Incandescent- Multiple 189 O 189 788 S6 52
Base Fuel Cost The rates per ulll! shown above include $0.0238.17 per kiowatt-hour rellectirlg the base oost of tuel
Pm!!Olld Rt\t Co~owned
Boulevard units S81Ved underground a. 2,500 lumen Incandescent - Senes b 2,500 lumen Incandescent - Muttiple
Holophane Oecorati9e fme on 17 foot libefglass pole served underground willl dil'ed buried cable
Lamp watll
148 189
Annual llWAlnll kW Aat.Mlrul
. 0.148 616 $10.32 0.189 7e6 $ 801
a. 10,000 lumen Mera.ryVapor 250 0.292 1,215 $ 18.79 The cable span charge or $.84 per each lllCl'emenl of 25 feet of seoondrt wiring shal be added ID tho
RaleAmlt charge tor each increment of secondary wiring beyond the first 25 feet from the pole ba9e Street light units served overhead dis1lilution a 2,500 lumen lncandeseent b. 2.500 rumen Mercury vapor c. 21,0CIJ lumen Mercury Vapor
Customer owned Steel boulevard units set'Ved underground with limited maintenance by Company a 2,500 lumen Incandescent - Series b 2.500 lumen Incandescent - Multiple
Base Fuel Cost
189 100 400
148 189
0.189 0.109 0.460
0148 0.188
786 453 t,91ol
i16 788
s 7.9'1 $ 7.52 $1193
$609 $774
The rates per unit shown above include $0 023837 per klowatt~ rellecbng ltlt b8'e CO&t ol lut~
Cucrtnt Bate Private outdoor lighting unlls:
The lollowmg monthly charge will be assessed tor exlstlog facllttles, bul this unit will nol be av&Jtabl& to any new customers after May 15, 1973: '
OUtdoor lighting units served In underground residential distribution ereas: The following monthly chaige witt be assessed for exlSlilg ftxtures which lrdlde lamp and Uninal1 o, control ea automatlcally, with an underground seivlce wire nol to exceed 35 feet from the 8elVice point, buC tliese units\\ ;u no1 be avaJlable to new cuslomers alter May 5, 1992: •
Lamp AntUll Witt m1l.d l!Wll ~
7,0CIJ tomens Mercury, Mounted on a 17-foot Fiberglass Pole • • ••••..••..•.•. 175 0.205 1153 $14.S4
7,0CIJ lumen Merculy, Mot.llted on e 17-loot Wood Lamina1ed POie {a) .••••••... 175 0.205 !53 $'4,54
7,000 lumen Mercuiy, Mounted on a 30-foot Wood Pole. .. • .. .. • • ........... 175 0.205 1153 $1344
9,500 lumen SoOOn Vapor, TC 100 R. , , ••• , 100 O.t17 487 $1122 (a) Note: New or replacement poles are not evtlllble.
Cormted OO•I page
•
Page 10 - Wednesday, August 30, 2017 - The Gallatin County News, Warsaw, KY
Flood lighting units served In overhead distrfbullon areas: The lotlowing moothty charge will be assessed loreach existing fixture, which includes lamp and tumjnaire, comrolled automatically. mounted on a utility pole, as specified by the Company, withe span of wire not to exceed 120 feet, but these 1,1nlts will not be available after May s. 1992:
Where a slreel lighting fixture served overhead is to be installed on Bl'lOther utility's pole on which the Company does not have a contact, a monthly pole charge will be assessed.
Base Fuel Cost The ra!es per unit~ above includo SO 023837 per kilowatt-hour refleCIJng the base IXISl of fuel
Rider PPS .::frtmier Power Service Rider ~arl!I Sheet No. 101
Eacli qualifying customer's individual monthly rate calculaled for each customer for this servk:e wm be determined as follows: Monthly Service Payment= Estimated levefized Capital Cost + Estimated Expenses Where: Levelized capital Cost 1S equal to the present value of all eslima1ed capital related cash flows for a period corresponding 10 lhe llme of eng!lleerilg design and lllSta!ation of equipment lhrough Ille tenn of the contract adjusted to a pre-tax amount and converted to a uniform monthly payment for the term ol the contract. The estimated capdal cash flows sha I lndude estimated installed cost of equ1pmen1, contingency allowances, salvage value, adjustment to reflect additional supporting investment of general plant nature, and income tax tmpacts. Expenses shall equal the present wiue of es11mated expenses associated with tho support and mamte nance ot the generation and support equipmenl, ad1us1ed to a pre-tax amount and converted to a un~orm monthly payment for the term of the contract The estimated expenses shall Include administrative and general expenses, expenses for labor and matenals related to operations and maintenance lhird party expenses for aperallOns and maintenance, warranties. insurance, annual costs associated with working captfal, fuel mvemory, deprecation property lax other costs relaled lo the operaoon and suppon of the generator system installation, and income tax Impacts Tho af!cr tax cost of capttal from the Company s most reoam general rate case wm be used to coovert present values to unltonn monthly payments
MONTHLYBLL Customer's monthly bi11 lof all services under this rider wt I appear oo tlleir regular monthly eledrlc biD as a bnel!em.
PrOROled Raw; There are no proposed changes In this racier.
Current Rate:
Rider1S - TemlWMY. Service Rider lEIKtric Tariff Sbeet No. 71 l
In addlllOn IO charges for seMCe furnished under Iha appllcable standard rate the customer wi I pay n advance the following charge Estlmatecl ur.h cost ol each seivlce with supporting data to be filed With the Commission and updated annually by the utl ly. Prof}Osed Bate: Thora are no proposed changes In lhis rider
Current Batt:
Rldec X - Une Extension Policy Rider {~lQ.Jarrff Sh~t No. 721
When the estimated cost of extending the distnbullon lines 10 reach the customer's premise equals or Is less than three (3) times the estimated gross annual revenue the Company wlll make the extenSion without addtt1onal guaren· toe by the customer over that applicable rn the rate, provided the customer establishes credtt in a manner satisfactory to the Company When the estimaled COS1 of extending the distribution Unes lo reach tile customer's Pferruse exceeds three (3) times the estimated gross annual revenue the customer may be required IO guaramee for a peOOd of five (5) years, a monthly bill of one (1 J percent of the rma extension cost for residen'Jal 5elVice and two (2) percent lor non-res!dentiat servtce. When the lerrn of seivlce or credit have not been established In a manner sallsfactory to the Com~ the customer may be required to advance the esltmated cost of the I ne extensJon 111 either of tho above s11uati0ns When such advanco Is made the Company will refund, al the end of each year, for four (4) years, tweniy,fivo (25)percenl of the revenues received in any one year up to twenty-live (25) percent of the advance. ~: Thero are no proposed changes In this rider.
I When a customer elects 1he OFF PEAK PROVISION L'le monthly customer charge of the applicable Rate OS wi1 be lnaeased by an additional '!10lllhly charge of five doUars ($5 00) for each nstallecl t rn&0f-use meter In addition tho DEMAND provision ol Fiala DS shall be modif!Od to the extent that lhe bilfing demand shall be based upon lhe •oo peak period," as defiood above II. For customers who meet the Company's cniena for the installation ot a magnetic tape recording device lor bil ng, and where electric service is furnished under the provisions of either Rate DS, Service at Secondary Distribution Voltage, or Rate OP, Service at Prlmary Distribution Vottage. When a customer elects !his OFF PEAK PROVISION the applicable montnly customer charge of Rate DS or Rate DP will be increased by an addlllonal monthly charge of one hundred dollars ($100.00). ft:Dme9. Rott: When a customer elects the OFF PEAK PROVISION the monthly customer charge of the applicable Ra:e OS or DP wtll be ncreased by an additional monthly charge of five dollars ($5.00) for each Installed time-ol-use Of intelVill data recorder meter. In addition, the DEMAND pl'OVISIOn of Rate OS or DP shall be mod lied to the ox1ent that the bllllng demand shan be based upon the ·on peak period,· as def ned abo\le However, In no case shall the bl'H ng demand be less than the bdfing demand as detenmned In accordance with the DEMAND provision Of the apprrcable Rale OS 0< Aale DP, as modified.
C11r1t0l.B1tt: CHARGES
~MO..= Advanced Meter Opt·Out !AMO) • ResldentiAI I Electric Itrtff Sbeet No, 741
Residenhal customers Who elect. at any lime, to opt-out al the Company's advarn:ed mefer1ng infrastructure (AMI) system shall pay a one-t11ne fee of $100.00 and a recurnng monthly fee of $25 00. During lhe Meterlng Upgrade prof9Ct deployment phase, ii prior to an advanced meter being tnslalled at a cuslomer premise, any existing reside.o· tJal electric customer that elects 10 partlclpate lo thIS opt-out J>l'Oljram, Duke Energy Kentucky wlO not charge the onetime set·up foe, providing the res.;oontial eleclrlc customer notifies the Company of such electiOO rn advance of the advanced meter being inslalled. Those residential customers eledlng :o participate in this resklenlial opt-out i:wogram wl I be subject lo the ongoing $25 00 per month ongomg charge. Following deployment completion, any resl· dential customer who later elects lo partleipate In the Opt-Out Program win be assessed the $100 set-up fee in addition to lhe ongomg monthly cha!ge Proposed Rate: There are no proposed changes m lh1s nder.
The Demand Side Management Rate (DSMR) shall be determined in accordance with the provisions ol Rider OSM, Demand Side Management Cost Recovery Rider Sheet~. 75 of thlS Tani!. The DSMR lo be applied lo residential customer b s Is S0.007967 per kilowatt-hour A Home Energy Ass!Slance Program (HEA) charge of SO 1 O will be applied monthly to residenlial customer bills through December 2020. The DSMR to be appflecl lo non-residential distribution wvlce CUS100lef bills Is $0.002576 per ktlowatt-hOUr. The DSMR to be applied for transmission service customer bills is $0.000183 per kilowatt-hour. Pni1121111.Bi1!: There arc no proposed changes In 1h1s rider.
Current Rate:
B!.®.r.Jmf.::Jl11~\Ul..OtJlyery Point CeDiclty Ride! (EJ!letrlc Tariff Sbeet No, 791
BACKUP DELIVERY POINT (TRANSMISSION/DISTRIBUTION) CAPACITY The Company v.111 normally supply service to one prermse at one standard voltage al one dellvery point and through Oil~ meler to a Non·Aesidential Customer in ao:x>rdance with the provisions of the appllcable rate schedule and the Electrlc SeMCe Regulations Upon customer request, Company will make available to a Non·Residential Customer addltiOnal deilvery points in accordance with the rates, terms and cooalllOns of this Bider BOP NET MONTHLY BILL 1. Connectkm Fee
The Connection Fee applies only If an addmonal metering potnt 1s required and will be based on customer's mosl applicable rate SChedute.
2. Monthly ch!llges will be based on the unbundled dlstnbution and/or transmission rates of !he customer's most applicable rate schedule and lhe co111racted amount of badiup delivery point capadty.
3. The Cusiomer shall also be respoos ble for the acceleration of costs, ii any, thal would not have otherwrse been Incurred by Company absent such request for add1ti0nal delivery pomts. The terms of payrnent may be made inrtially or over a pre-determined lerm mutually agreeable to Company and Customers Iha! shall no! exceed the rt11111mum tenn In each request for S&MCe under this Aider, Company engineers wll conduct a lhoroogh review of the C\IS!omer s request and the clreul'.s ai'lected by the request The customer's capaCi!y needs wm be weighed against the capaaiy avallable on the CllCIJit. anUcipa!ed load growth on the CltCUrt, and any Mure coostrudlon plans that may be ad· vanc:ed by the request PrQgolmIB.Jlt: There are no proposed changes 1n this rider.
!dlrr.tn.l.8Alt:
f.Y§l_AdlYl1mtnt.Clauu • Bider FAC t~e.Jar~llttrn.uru
( 1) The monthly amounl computed under each of the rate schedules to wtuch thlS fuel clause Is appfrcable shall be Increased or (decreased) al a rate per kilowatt·hourof monthly consumption In aocordancewtlh the follOWlng formula:
Fuel Cost Adjustment= f(m) • S0.023837 perk~ S(m)
Where F tS the expense of fuel 1n the second preceding monlh and S IS the sales 1n the second preceding month, as defined below:
•
(2) Fuel costs (F) shal bo the COSI ol (a) Fossa fuel consumed the Company's plants plUs the COS! cl fuel which would have been used ri plants suflerlng loo:ed generallOn or lransmission outages, but less the cost ol fuel related lo subslltute gcneraoon plus (b) The actual lden:illable lossll and nuclear luel costs assocla'.ed with energy purchased lor reasons olher lhan idem ied In paragraph (c) of this &lb;edion, but excbfmg the cost or fuel rola'ed to purchases to substitt.1e for the lorced outages. plus (c) The net energy cost of energy purchases, exclusive of capacity or demand charges (urespectiVe of tho dcslgnatoo assigned to such transactoo) when such energy Is purchased on an economic dispatch basis Included theraln are such costs as the dlarges for economy energy purchases and the charges as a resuh of schedulod outage a such kinds of energy being purchased by the Company to substitute tor Its own higher cost onergy, and less (d) Tho cost ol tossll luel recoverod thrqugh Inter-system sales 1ncludlng the fuel costs related 10 economy energy sales and other energy sold on an economic dispatch basis (e) All luol cosls shall be based on a welghtod·average inventory costing. The cost of fossil fuel shall lnciude no Items other than the ln'IOICe price of fuel less any cash or other diS<:Ourrts. The Invoice price ol fuel Includes tho cost ol luot itseH and necessary charges for transportatiOn of fuel from the PoU1I of acquisl tJon _,tho unload1ng po1n~ ns listed In Account 151 of the FERC Unifonn System of Accounts for Publte Utllit:es and Licensees (f) As used herein lhe term "lol'ced ouiages' means all non-scheduled losses of generatloo or transmission which requ e subs' 1uto power lorn conllnuous period In excess of six (6) hours. Where forced outages are not as a result of faully equpneni, faulty manufacture faulty deSlgn, faulty lnslallallons. faulty operation, or faulty 1113intenanCO, but are Acts ol God, riot. Insurrection. or acts of the public enemy then the Company may, upon proper sho¥Mg wi!h the approval ol the Commission, Include the fuel cost ol subslitute energy 111 the edjuslmenl
(3) Sales (S) shall bed e:'!lined kilowatt-hotn as lollaNs Add
(a) et generation (b) purdla.scs (c) rnerchange in
Subtract (d) Inter-system sales Including economy energy end other energy sold on en economic dispatch basis (e) IOlal system losses
~: (1) The monthly amount COOlllJted under each of the rate schedules to which this fuel clause Is oppllcable shall be roeased or (decroased) at a rate per kilowatt-hour of monthly consurr1J{J()O In accordance with lhe follow!ng lormu!a
Fuel Cost Ad1ustmenl = fimJ. · $0.023837 per kWh S(m)
Where F Is the expense of fuel In the second proccd ng month and S rs the sales 10 the second preceding month, as defined below (2) Fuel costs tF) shall be !he cost ol
(a) Fossll fuel consumed In lhe Company s plants plus the cost of fuel which would have been used in plants su!fonng forced generation or trensrmsslOl'l outages. but less the cost ol luel related to substitute gcnorotoo, plus (b) The Bdual klcn' iable fossil and nuclear luel costs associa!ed wtlh energy purchasod for reasons other than Identified In paragraph (c) ol this subsection, but exctuding lhe COS! ol fuel relaled to purchases to substitute lor Iha lorced outages plus (c) The 001 energy cost of energy purchases excilsive of capacity or demand charges (lrrespectlve of the deslgnatoo assigned to such transaction) when such ene:gy is purchased on an economic dlspalch basis lncklded therein are such COSls os the charges for economy energy purchases nnd the charges as a result of scheduled outage such kinds of energy being purchased by the ~Y to subs!i!ute tor its own higher COSI energy nnd less (d) The cost off fuel recovered through Inter-system sales Including the fuel costs rela!ed to economy energy saJeS and other energy SOid on an ecaoomic dispatch basis. (c) The fuel-re !Cdchargos !Id credits charged ID the Company by a RegionalTransmisslonOrgarizatlOn. IQ All fuel costs shall be based on a weighted-average mventory costing The COS! of fossil fuel shaU include no 1~ other than the nvoice price of fuel less arry cash or ()(her discounts The Invoice p0ce ol fuel Includes the cost of fuel ltseH and necessary charges foe transponafion of fuel from the pom1 o1 acquisition to the unloadlng potnl as llstad in Accoont t 51 of the FERC Uniform System of Accounts lor Publlc U!ill es and lJcensecs (g) As used herein tho term 'forced outages• means an non-scheduled losses ol generatoo or transmission ~ICh require subslftute power IOl' a continuous period., excess of SOt (6) hours. Whore forced oU1ages are not as a result ol lau ty equipmenl. faulty manufacture, l3lllly design, faulty iostallations, faulty operation, or faulty ma menance, but are Acts of God, riot, lnsurrect1011, ex acts of the public enemy, then the Company may, upon proper showing, with the approval ol the Comm1ssion, 1nciude the fuel cost of subslttute energy In the ad1ustmont
(3) Sales (S) r.hall bo determined In klloWatt·hours as follows: Add
Subtract
(a) net generation (b) purchases (c) Interchange 1n
(d) n1er-system sales 11'1Cludtng economy energy nnd o\her energy sold on en economlc dlspateh baSls (e) total systen ~
Bate RS, Residential SeMce Rate OS Service at Seoondaly DistriJu1Jon \lollage Raie DP. Service at Primary Distribution Voltage Rate OT Trne-ol·Day Raio for Service at DlstributlOll Voltage Rate at, Optional Rate lor Etectn: ~ Heating Rate GS·A.. General Service Rate for Small Filled Loads Rate SP, Seasonal Sports Service Rato SL. Street Ughllng Service Rate TL. Traffic Lighting Service Rate UOLS, Unrnetorod OuldOOI Lighting Rate OI.., Outdoor Lighting Service Rate NSU, Street Lighting Service tor Non-Standard Units Rato NSP, Private Outdoor Llghllng Service for Non-Standard Uruts Rate SC, Street Lighting SeMce - Customer Owned Rate SE, Street Lighting Service Overhead Equivalent Rate TT Tuoo-ot-Oay Rate tor 5oMCe nt Transmission Voltage Olher
Alder PSM credits, reduclions to bills, are shown as posl1ive numbers without parentheses Rider PSM ch.1rges. lneteases to bl!ls are shown In parenlheses
PROFIT SHAR NG R DER FACTORS The Applicable energy charges for eledrlc 68rvtC8 sha! be incraased or decreased to tho nearest
$0 000001 per kWh to reflect the sharlng of profits on ofl-syslem power sales and ancillaly services, the net prollts on sales ol emission alowances nnd net margins on capaclty transactions related to the ecqu!s!tlon o1100% o1 EaS1 Bend unn 2
The~ will computo Its profits on ofl-system pov.'01' sales and ancillary seMCeS, profits on emission allowance sales and net margms on capacity transactJons related to the acqutslt;on ol 100% of East Bend Unit 2 In the lollowlng manner
Rider PSM Factor = ((P +A) + E + C + fl)IS whoro.
P = 8lg1b!e profits from off ·system power sales for apprteable month subject to sharing prOVISlons establlshed bythe Cornmisslon In Its Order in Ceso No. 2003-00252. dalod December 5, 2003. A = All net profits related to Its provision ol ancillary services in marl<ets adm nlstered by PJM per 1he Commissions Order In Case No 2008-00489, dated January 30, 2009.
Tho Orsi $1 m1 lion in annual profits from off-system sales and ancillary services will be allocated to ratepay11rs, wnn nny profits In excess of $1 m ion spilt 75 25. with ratepayers receiving 75 percent ond shareholders roceMng 25 pen:ent per the Commission Order 1n Case No. 201~203. dated December 22, 2010 After December 31st of eac.h year the sharing mechanism will bo resot for oll·system power sales. Each month the sharing mocha· nism WI be resel for the ancillary seMc:e profits. E = All net prol ts on sales of emission allowances are credited lo customers per Ille Commission's Order in Caso No. 2006-00172. dated December 21, 2006. C = Capacity revenue received from PJM associated with DP&L's share ol Eas1 Bond capacity lhat DP&L has commlt'.cd In PJM s base residual auctlOn ("BRA") through May 31, 2018, less the COS! Incurred by Duke Energy Kentucky to procure suflident cap3clly to meet ts obfigallons as a F"txed Resource Requirement entily under lhe ReliabBi!y AssllranoaAgroement witll PJM per the Cormlission's Order 111Case No. 2014-00201, dalod December 4 2014
The net ol cap3d!y revenue received from P JM and the capacity cost incurred by Dl;ka Energy Ken!Ucky be allocated IO ratepayers wl!h ratepayerS receiving 75 percent a.rid shareholders receMng 25 percent A = RaconcillafJon of prior period Rider PSM attulil revenue to amount calcu!ated for the period S = Current morch sales In kWh used In lhe current mooth Aider FAC ca!cu1ation..
fmmedBate: Rate GM
Rate RS, Residential Servloe Ra1e OS, Service at Secondary Distributio~ Voltage Rate DP, Service at Primary Distrtbutlon Voltiige Rate OT, Tlme-ot-Oay Ante for Selvlce at Dtstrlbutloo Vonage Rate EH, Optlonal Rato for Eleetrlc Space Heating Rate GS·A.. G1111eral Selvlce Rate lor Small Fixed Loads Rate SP, Seasonal Sports SeMCe Rate SL. Street Lighting Service Rate Tt, T relfic Lighting Sorvlco R8!e UOLS Unmetered Outdoor Lighting Rile OL. Outdoof UgtrtJng SorvlC8 Rare NSU, Street Ughllng Setvtce for Non-Standard Units Rate NSP, Private Outdoor Ughlilg Service for Non-S1andard Units Rale SC, Street lighting SeMce - CUstomer Owned Raia SE. Stree! Lighting SoMce - Ovemead EqulvaJenl Ra1e TT Tlm&d-Oay RJle lor Service at T ransrnisslon Voltage Olher
The Gallatin County News, Warsaw, Ky. - Wednesday. August 30, 2017 - Page 11
Ri!er PSM credits, reduetionS to bills, arc shown as posttNe numbers \\i'Jlout paren!hesos Rldef PSM charges. increases to bills are shown in parenlheses
PROFIT SHAR NG RIDER FACTORS On a quarterly basis, the applicable energy charges tor electric 6CIVlce shall be tncrcased or decreased 11> the nearest $0 000001 per kWh to rollect the Sharing of net proceeds as out:ioo:t In tho formula below
where
Cumnt Rate
Alder PSM Factor= (OSS + NF + CAP + REC + Rl IS x 0 90
OSS ,. Net proceeds from off system power sales NF = Nat proceeds from non-tuot related Regional TrnnsmISSJOn Organization charges and credits 110I recovered via other mechamsms CAP = Net proceeds from. P JM charges and credits as provided for in the
Commlsston's ClfdOf In Case No. 2014-00201, dated December 4 2014 capacity sales; r.apaclty purchases, capacity perfoml811Ct! croots, and capacity performance ossessmenlS
REC = Net prooeeds from the sales of renewable energy credits R = Aooonclliatlon of prior period Rider PSM aciual revenue to amount calcu latod lot the period. S = CUrrent period tales 111 kWh as used In Ille Rider FAC calculatlon
NET MONTHLY B LL CUs1omers who participate under this rkler wlD be billed for eleclrlc 68rvlce under aB applicable Wills lrdudJng all applicablo nders Green Power purchased under this OOet', wm be billed 81 the appficable Green PaNer rate lim8S the number of 100 kWh blocks the cus1omer has agreed to purchase per morl1h The Green Power rate shall be $2.00 pei 100 kWh block with a minimum monthly purchase of two 100 kWh blocks Carbon Ol!se!S purchased under lhls rider, will be billed at the appl'icablc Carbon OlfS01 r111e limes the number of Carbon Offsets the customer has agreed lo purchase per month The Carbon Offset ra!e shall be $4 00 per 500 lbs offset block PropoUcl Ra...1§: There are no proposed changes 111 this rider.
C~: AVAILABILITY Net Metering Is avallable IO ebg1ble customer-generators in the Company's selVlcc IBrrttory upon request, and on a first· come, first-served baSIS up to a cul11Uiative capacity ol 1 % of the Company s slngle hour peak load in Kentucky during the previous year Propostd Rate: There are no proposed changes In this rkjer
~.mnt..Bm:
Bad Check Charge (Elecirlc Iadn Sheet fio. 901
The Company may dlarge and oo!led a fee ol $11 00 to cover the cost of handL'ng an UflS8QJred check. where a customef tenders In payment ol an aa:ounl a ched< which upon deposit by the Company Is returned as iq>aid by the bank tor llirJ reason fmposed Rate: There are no proposed changes In tt11s rider.
Current Rate:
Charge for Reconnection~ (E!t<:tric Tar!tlSMrtti2.R.U
A. The reconnectiOn charge for seM:e which has been disconnected due to enforcement of Rule 3 shall be twenty.five dollars ($25.00). B The roconnection charge tor eeMCe which has been d1scooncctcd within tho precodlng lwelve months at the request of the customer shall be twenty·flVO dollars ($25.00) C II service IS dlscont1n11od beeause Of lraudulen! USO theroof, the Company may charge and collect In add lion to the recoonection charge of twenty·llV& dollars ($25.00) lhe expense lncurrod by tho Company by reason of such traudulont use, plus an eslimated bfil fol elOctrlcity used, prior lo tho reconnection ol SOfVICe
D. H both the gas and electric services are recoonected at one time, tho total charge &hal not cxooed lhlrty-clght dOtfars ($38.00) Ee Where elcctriC seMCe was disconnected at lhe pole because lhe Company was unable to gain access m the meter, the reconnoc00n charge shaH be Slxly·fiVe dollars ($65 00) II the gas seMCO Is also recomoded the charge man be ninety dOllars ($90.00) F II the Company receives noliCe after 2:30 pm of a customer's deslro for Bllllle day 1ems1alomerll of seMc:e and tt lhe recoonectiOO cannot be performed during normal buslness hours. the alter hour reconneetion charge for connectiOl'l shall bo 11!1 adcfrtional twenty.five dollars ($25 00) Customers Wiii be notified of the addllional $25.00 charge for reconneclion 81 lhe meter or at the pole 8l tho tmo they request same day seM:e
G ff a Company employee, whose ongmal purpose was to cfisainnecl the service has provided the customer a means to avoid d!scomet1ion, seMCe which othc!wise woold have been cfisconnected shaD remain i1tad, and no reconnection charge shaD be assessed However a collocllon charge of fifteen dollar8 ($15.00) may be assessed but orly ii e Company employee ectua!Jy malces a field vtsll to the ais:omer's premises.
fropoUcl Ba1e: A. The recoonec1ion Charge for service which has been disalnnected duo to enforcement of Ruic 3 shall be twenty.five dollars ($25.00) fo.-reconnediOnS that can be accompllshed remotely or saventy·flve dollars (S75 00) lor reconnectlons that cannot be eccomp!lshed romotcly B The recon~ charge tor service whfch has been diloonncc!ed W1th!n the precedlng twelve months el the request of tho customer shall be twenly·five dollars (S25 00) !or reconnectmi that can be accomplished ro mote!y or seventy-five dollars ($75.00) for reconnecbOnS that cannot bo accomplished remotel'f C. If seivk:e IS discontinued because al lraudulcnt use thereof, the Company mny charge and tollect n addition to tho reconnectlOI\ charge of twenty.five dollars ($25.00) tor reconnectlons that can bo acc:ompflshed remotely or seventy-five dollars ($75.00) fol reconnecuons that cannot be accompfashod romotoly the expense Incurred by the Company by reason of such lraudufenl use, plus an estimated bUI for efoctrfcity used. poor 10 the reconnection of service. D. II both the gas nnd electric services ere reconnected al ona tllllO, lhe total charge shall no1 exceed eighty· eight dollars ($88 00). E Where electric S6IVICe was disconnected al the pole beeause tho Company was unable to gain access to the meter, lhe reconnection charge shaU be one hundred lwenty.frve dollars ($125.00) II Iha gas selVlce is also reconnected lhe charge shall be ono hundred fifty dollars ($ t 50.00) F If the Company receives notice atler 2:30 p m of a customer's desire for same day re1C1Slalemen1 of service and H the reconnection cannot be perlormed during normal business hours, and the reconnection cannot be performed remotely, the altel hour reconnection charge for CX>MOCllon shalt be an additional twenty.five dollars ($25 00) CUs!Dmers wDI be notified of lhe eddrtional $25 00 charge for rec:omedlon at tho meter or at the pole 81 tho time they request same day se1ViCe G ff a~ employee, whose onginal purpose v.'BS 10 dlsconneC1 the SBf\'IC8 has provided the aistomer a means to avoid disconnectlOll service which othetvwise would have been disconnected shat remam Intact. and no reconnection charge shall be assessed However a coftectJon charge of fifty dollars ($50 00) may be as sessed. but or'iy II a Company~ actually makes a field Ylsll to lhe customers premises
Current Rate:
Rate tor Pott ~mems ot Clb!o..Itl.ml!11n.Sn1m1..- Rate CATV (This Schedule " Renamed as Rate DPA- Dittribu1fon Pole Attachment•
CE!ectr!t Terfff Sbeet No. nl
The following annual rental shall be charged for the use of each of lhe Company s poles Two-user pole; $4.60 annual rental Three-user pole $4 00 annual rental
P.m11osed Rate: The following annual rental shall be charged tor the use of each of lhe Company's poles
Rates for Purdlases from qualifying faclhtles. Purchase Rate shall be S0.0307BfKWh for all kllowatt·hours dolivorod frOSIOHd Rate: Rates for Purchases from qualifying facilities. Energy Purchase Rate shaD be S0.027645Jl<Wh for au ldlowan-hours delivered Capacity Purchase Rate shall be $3 90/kW-mon:h !or eflgible capadty u!iized by Company and approved by PJM ii Companys Rxed Resource Requirements (FAR) plan.
Cogeneratlon end Sman Power Productton..Sl!t..lnd..Pll!'cbne Tarlft=G!tlttr Ihln 100 kW (Electric Tariff Sheet No. 941
Current Rate: The Purchase Rate for all klowatt-hours deWered shall be the PJM Real-Time ~l Marginal Price tor power el Iha DEK Aggcegate pnce node lncWsive of the energy congesoon and losses charge3 tor each hour of the billing month. fmposed Rme: The Energy Purchase Rate for all kilowatt-hours delivered shall be the P JM Real· T me l.ocatlonal Marginal Prlco lor power 81 the DEK Aggregate pnce node, lnClusive of tho energy, congestJOn ond losses charges, for each hOUr of the bilfing month Capadty Purchase Rate shall be S3.90/kW-month for et1glble capactty ubllzed by Company and approved by PJM In Company's Fixed Resource Requlremenls (FRR) plan.
CwnntBl!e:
~J fmnchf•Lf.n !£!Ktr~.Ilrl!l.Shftllfo..W
There shall be added lo the customer's bill, listed as a separate Item, an amount equal to the tee now or hereafter Imposed by local legislative authorities. whether by ordinance franchise or othor means. Which tee Is based oo the gross receipts collected by the Company lrom the sale ol electrieity to customers Within the boundaries of the partlcular legisla· We aulhority. Such amount shall be added exclUSJVe~ to btlls of customers receMng &CrVlce wl1hln the territorial limlls ol the authorily Imposing the fee
Where more than one such lee IS~. each of the charges appllcable lo each CUSI01!181' Shall be added to the customers bill and 6sted separali!ly.
Where the local leglsla!lYe authori!y ~ e fla~ flXOCI BITlOUl1l on lhe Company the tee epplled to the bills of customers receiving service within the lemtorial boundaries of that authority, shaft be n the ionn of a flat c1o1ar amount.
The amoum ol such fee added ~ the customer's bill shall be dotermlncd 111 aooordance wtlh the terms of Iha Cc10uld nexl
•
Page 12- Wednesday, August 30,2017 ·The Gallatin County News, Warsaw, KY
ordinance franclliSe or olher directive lgf8ed to by the Company. P!'OJIOlfd Biii: There are no proposed changes to this rate.
CUrrl!Jt Ritt:
Uodggynd RM!dlntll! Dlltrlbut!gn Pollcy=Bl!I uop.e (Ellctdc Tlrtff bit No· Ill
Silgle Famly Houses. A. S2.15 per front foot tor all prrnaiyext8llSIOllS. Prima!y ex1enSIOOonprivate property will bechargedS2.16per linear trench loot, and B An ~al $2.00 per linear treoch fool shall be chalyed where extremely roclcy cond"l1ions 818 encounterad, such oonditions being dellned es lirneslone °' olll8( hard stratified materiel in a continooos volume al at least one CIAlic yard or more which cannot be r8ITlOY8d using ordinary excavation equipmert.
Mufti..FwlyUMs The.-e shall be no charge om where extl8mely roclcy cond"lllons 818 encountered, then the $2.00 per linear lreoch fool, 8$ Staled and defined allove, shall be charged.
PrPJ)Olld 8"': Single Famiy Houses.
A. $2.15 per fronl foot for aQ pnmary extensions. Primary el1nion on private property wm be charged $2.15 per lnear trench loot; and B. An add'Jtiooal $2.00 per linear trench fool shall be charged where extremely roclcy conditions are encountered, such conditions being defined as kmeslone or other hard stratified material In a conmuous volume al at least one cubic yard °' more which oannot be removed using ordmary excavation equipment.
Muttl-Famtly Units. There shaU be no charge mllll whece extramely rocky conditions are encountered, then the $2.00 per linear trench loot, as staled and denned aboYe, shall be charged.
Targeted Underground for Service lmproYement Notwlttis1andln the above charges and upon Kentucky Public $e(vk:e Commission approval, Company wtn walve above ctwges, maintail, and take ownership ot costorner S8MC8 llnes and equipment (curb, property line, or service lateral to lh8 meter base) to and Including lh8 electric meter. This provision applies only to Company designated 1nstallalioos Identified to Improve the resiliency of 6elVioe lo the customer
CumntRltl: The ctwges shall be the <lfference betWeen the Company's estimalld cog1 lo provide an underground system and the ~'s estimated cost to provide an OYefhead system. In adcition lo lhe differential clwge, Iha t)lowing provisions 818 applicable: Sing!& Famly Houses Of MIJlli.fanily Units.
The cuslomer may be requi1'11d lo provide Iha necessary trenching. badcfiling ~II system (~ required) and 11anSformer pads in place to ~·s apecificabolis.
Commercial and Industrial Units The CUSlomer shalt·
Special Situations
a) Provide lhe necesaty trenctlflg and backflling~ b) fumish, fnslal (concrete, if 1"8C(Ured), own and mailtaln al primaiy andlor secondaJy conduit sys tem (with spates, if reqtlfed) on private property meeting applicabje codes and Company's apeoifica bons:and c) Provide lhe lranSfoml81 pad and &eCOndety condudotS
In those sttuations where Ille Company consldera Ille pad-mounted transformer lnstalations unsuilable, the cust0018f shal provide Ille vault de6igned to meet National Eleclrlc Code, olher applicable codes, and C01'f1l3ny spectticabons, lhe conduit to the vault area and the &eCOndety cable to Ille transformer terminals The ~ny shall provide the transf011T1ers, the pnmary vautt Wl'll'lg and make the secondary connection to the transformer tennilals. In large multiple cable Installations, the cusoner shall provide the cable, provide and instaR the step bus mounted in Ille vauH, and malce necessary cable connections to the slep bu$ lo the Company's apecffications. The Company shall provide and Install connections from the transformer terminals to the step bus. The customer shall extend the bus duct into the vault to the Company's specifications. The Company shall provide and lnstal connecdons from Iha transformer tenninals lo the bus duct.
PrQSIOlld Ritt: The charges shaH be the ciffervoce between the Company's estimaled C06I to provide an underground system and the Company's estimated c:osl to provide an overhead system. ln adcition to the cfdfefential charge, Iha following prOVISions ant appf1C8ble: Single Family Houses or Mufti.Family Units.
The customer may be required to provide the nec&$$8ry trenching, bllckf11ing, conduit system (if required) and transformef pads In place to Company's speciflcations.
Commercial and Industrial Units. The CUS1omer shall:
Special Situations
a) Provide Iha necessary trenching and backfilling: b) Furnish, lnslaU (conct818, H required), own and maintain all pnmary and/()( secondary conduit sys tern (with spares. tt required) on private property meeting applicable codes and Company's specifica lions and c} Provide the tran&lormef pad and secondary conductors
In tho&e sftua1ions where the Company considers the pad-mounted translormer Installations unsuitable, the customer shaQ provide the vault deSigned lo meet National Eledric Code, other applicable codes, and Company specifications. Iha oooduit lo the vaoll area and Iha secondl!ly cable to Iha IJan&former terminals. The Company shal prOV10e the transformers, the pnmary vautt winng and make the secondary conneeoon to the transformer len'Tlilals. In large multiple cable Installations, Iha cust>me< she.I proW!e the cable, provide and install the step bOS mounted In the vault, and make neQ8SSllly cable coonectiona to Iha step bus to the Company's specifications. The Company shall provide and iostaH col108CbonS from the transformer lemlinals IO the step bus. The CIJSIOlnef shall extend the bus duct Into the vault to Iha Corr4>any's speoifica!ions. The Company shall provide and ll'lSlaD connectionS from the transformer terminals to the bus duel Targeted Undergf04.lld lot SeMoe "11lrovemenl Notwrthstanding Iha above charges S'ld upon Kentucky Public Service Commission apptO\laJ, ~ny will w81Ve above charges, maWltaln, and take OW!l81'Ship of customer service lines and equipment {curb, property Hne, or service lateral to lhe met« base) to and Including the eleclric meter. Ths provision appfies od.y to Company dflSlgnated lnstallallons Identified lo improve the resiliency al siaM:e to the customer.
BA.5ELINE CHARGE The Baseline Charge is ~ of Customer's currently monthly usage, and Is designed to achieve bill
neutrality With the CU810mef's standard offer tariff H no~ in elecUicity usage pattern OCCIJ'S Qess applicable program charges). The Baseline Charge 18 calcUlated at 1he end of lhe billing period and changes each biliog period to maintain bUI neutrality fOf a Customef's CSL
The Baseline Charge wtlt be calculated as lollows · BC : (Standard Bill 8 CSL) Where. BC = Ba9eline Charge Slandard Bill 0 CBL = Customer's bll for a specific month on Iha appbcable Rate
Schedule includllg applicable S1andard Contract Ridet9 u*1g the CBL to eslablish f18 applicable biting detarmmants. The CSL shall be ad"JUSled to reflect appllcable metemg adjuStrnenlS Llldet 1he Ra!& Schedule. All applicable
ridefs shall bee~ from the calculation al the Baseline Charge. PRICE QUOTES
The Company wll send lo CUSIOmer, wtlhin two hours alter Iha wtx>lesale pnces are published by P JM each day, Price O\loles 1o be charged the next day Such Price Quoin shal incklde f18 app1Cab1e Conlnodty Chmge, the Energy OeliYery Charge and ht Ancllaty Services Charge.
The Company may send more than 008-day·ahead Price Quotes for weekends and holidays Identified In ~ny's tariffs. The Company may revise these pnces Iha day before !hay become elfecllve
The Company Is not responsible lot lailure ol Customer ID receive and act upon the Price Ouol8S It Is Cuslome<'s r8Sj)Ol'ISibjlhy to Inform Company of any faJkn lo reoaive the Pnce Quotes the day before 1hey become effective. COMMODITY CHARGE The CorMiodlly Charge is a charge'°' geneia11on. The applicable hourly Commodity Charge (Credit) shal be appjied on an hour by hour basis to CuS1Dmer's inctemenlal (decremeotal) usage from lhe CBL.
Charge (Cteclit) F04' Each kW Per Hour From The CSL:
Where:
For kWht above the CBLI , CCI : MVGI x LAF for kWh1 below the CBLt , 00 • MVGt x 80% x LAF
I.AF
.. MVGI ..
loss edjustmerlt factor 1.0530 tor Rate TS 1.0800 lot Aa1e DP 1.1100 for Rate OS Market Value Of Generation As Oelennined By Company for hour t
The MVGt will be based on 1he expected marl<el poce of capacily and energy for the next day. The expected marl<et price shall be the PJM Real-rime Total Locational Marginal Price for power at the DEK Aggregate pnce node, inclusive al the energy, congestion and losses charges, for each hour. The kW per hour 11'1Cf8m8ntal or dea8mental usage from the CBL shall be adjusted IO reflect applicable metering adjust· ments oodet' Iha standard Rate Sc:hedWe. ENERGY DELIVER CHARGE
Chalge (Cteclrt) For Each kW Per Hour From The CSL Secondaly Service ................................................. $0.006053 per kW Per Hour Pnrnaiy Se!Vic& ................................................... $0.()()55.40 per kW Per Hour Transmission Service ........................................... $0.002008 per kW Pe< Hour
ANCIUARY SERVICES CHARGE Charge (CreOI) For Each kW Per Hour From The CSL
Secondary Detlvely ................................................... $0.000760 per kW Per Hour Primary Oelivety ....................................................... $0.000740 perkW Per Hour Transmission OelNery ................................................ S0.000721 per kW Per Hour
PROGRAM CHARGE Company Will provide lnlemet based communication software lo be used to provide Customer with the Price Quotes Customer Will be responsible for providing ils own Internet access. A charge al S 183.00 per billing period per site shal be added IO customer·s bll IO cover Iha additional !Jilting, administrative, and cost of communieal Ing the hourly Price Ouo1es associated With the RTP Propn.
P!JlllOlld Rllo: BASELINE CHARGE
The Basetloe Charge Is ildependent of Cumner's currently monthly usage, and is desigoed to achieve biU neutrality With Iha Customer's standard offer tariff ii no c:f1ange in eleClnctty usage pattern occurs (less appicable program charges). The Baseline Charge Is calculated at Iha end ol lhe billing period and changes each biing penod to maintain bil neutrality for a CllSIOmer'a CBL.
The Baseline Charge will be calcula1ed as follows: BC: (Standard Bill @ CSL) Where:
BC = Baseline Charge Standard Bill@ CSL = Customer's bill tor a specific month on Iha applicable Rate
Sdledule Including applicable Standard Contract Riders usuig the CBL lo eslablish the applicable billing determ11ants. . The CSL shall be adjusted to rel!ecl applicable metenng adJUslmeols under the Rate Schedule. All applicable riders shall be exeluded from the ~lrulatiOl'l ol the Baseline Charge PRICE QUOTES
The Company will send to Customer, wilhlll ™3 hours after lhe wholesale pnces are published by PJM each day, Price Ouotes to be charged the nex1 day. Such Price Ouotes shall Include the applicable Commodity Charge, the Energy Oeltvery Charge and the Ancillary SeMCeS Charge.
The Company may send more than one-day·ahead Price Quotes for weekends and holldays identified In Company's tariffs The Company may r9V!se these prices Iha day before they become effective
The Company is not responsible tor !allure of Customer to r8C8Ml and act upon lhe Price Quotes. It is Cuslomer's responsibility lo Inform Company ot any failure to receive the Price Quotes Ille day before they become elfectlve. COMMODITY CHARGE The Cormnodity Charge Is a charge for generation. The applicable hoU!ly Commodity Charge (Credrt) shall be applied on an hour by hour basis to Customer's Incremental {decremental) usage lrom the CSL.
Charge (Credit) FOf Each kW Per Hour From The CBL.
Where:
F04' kWh! above the CBLI , CC1 = MVGt x LAF FOf kWh! below the CBlt , 00 = MVGI x 80% x LAF
LAF = loss adjusbnent factor 1 .0530 for Rate TT 1.0800 for Rate OP and Rate OT 1 1100 for Rate OS
MVGt = Market Value Of Generat10n As Oetemuned By Company for hour t The MVG! will be based on the expected market price of capacity and energy for the nex1 day. The expected market pnce shall be the PJM Day· Ahead Total Locational Marginal Price for power at the OEK Aggregate pnce node, inclusive ot Iha energy, congestion and losses charges. for each hour. The kW per hour Incremental or decremental usage from the CSL shall be ad1us1ad to reflect applicable metenng adjustments under the standard Rate Schedule. ENERGY DELIVER CHARGE
Charge (Credit) For Each kW Per Hour From The CBL Secondary Se!vice ................................................ S0.015412 per kW Par Hour Primary Service ......... ..... . .................................... $0.012471 per kW Per Hour Transmission Service . .... .. ... ... ... .. .... .. .... .• ..... $0.006472 per kW Per Hour
PROGRAM CHARGE Company will provide ln1ernel based communication software to be used to provide Custome< with the Price Quotes. CuS1omer will be responsible for providing its own Internet access. A charge of $183.00 per billing period per srte shall be added to Customer's bill to cover the additional billing, admlrnstratlve, and cost of communicating the hourly Price Quotes associated with the RTP Program.
Meter Data ChirgD-Rate MDC llbla Schedule Renamed 11 Meter Data Charges !or Enhanced Usage Data Servtces-Rato MDCI
IElectrjc Tarltt Sheet No. 1011 Current Bite: Electronic monlhly interval data with graphical capabifity
accessed via the Internet (En.focus™) Pl'OOOHd Rate: Electronic monthly Interval data wi1h graphical capability
accessed VJa the Internet wrth (EPOT!I)
$20.00 per month
$20.00 per month
Duke Energy Kentucky proposes the following new rate and rider schedules: Rate LED, LED Outdoor Lighting, Rider DC!, OistrlbutiOn Cspltal Investment Rider, Rider FTR, FERC Transmission Cost Roooncillation Rider, and Rider ESM Environmental Surcharge Mechanism. As 1ndlcated above, the following schedules are proposed to be eliminated· Rate RTP-M (Real llrne Pricing - Markel Based Pricing), Rate OL (Outdoor Lighting Service), and Rate NSP {Private Outdoor Lighting for Non-Standard Units).
Computed in accordance with the following charges: 1. Base Rate AU kWh $0.041936 per kWh The rale shown above includes a charge of S0.023837 per kilowatt-hour reflecting the base cost al fuel. 2. Applicable Riders The folloWing riders are applieable pursuant to the specific terms contained Within each rider Sheet No. 76, Rider ESM, Environmental Surcharge Mechanism Rider Sheet No 80, Rider FAC, Fuel Adjustment Clause Sheet No. 82. Alder PSM, Profit Sharing Mechanism Sheet No 12S Ride< DCI, OiSl!ibulion capital Investment Rider Sheet No. 126, Rider FTR, FERC TransmtSSion Cost Reconcillat10n Rider 3. Monthly Mam191'1ance, FIXture, and Pole Charges· L Fll\lll'M PtrilnHP«llonlll Bill1g Type ~ lnlllal lamp Mcn!t( FlxlKe ~
Roof work Brian Rose took advantage of Saturday's good weather by fixing
the roof of his home on Main St. in Glencoe. Rain from Tropical Storm Harvey may arrive in the area by this weekend so it's a good idea to make sure all leaky roofs are patched. Photo by Kathleen Niece
Obituaries Clyde Smith
Warsaw resident Clyde Smith died Tuesday. August 22, at The Villa in Georgetown. Ohio. He was 79.
Mr. Smith worked as a truck driver for many years.
He Ls survived by three sons, Roger Lee Smith, Terry Allen Smith and Dennis Clyde SmHh; Lwo daughters. Sheila
Senior Center
Schedule The Gallatin County
Senior Center is open to all seniors, 60 and older. and disabled citizens of Gallatin County. Ct's located at 400 Third Street, Warsaw. The center serves breakfast and lunch daily.
Lunch entrees may be beef or turkey stew, Salisbury steak, beef patties. chili. pork chops, country ham and beans. meatloaf, chicken, etc.
Activities may include Bible study. crafts, nutritional programs, informational programs. and health programs.
Many games are always availab]e. The Center provides activities only, and is not medically staffed. Seniors who attend must be self reliant.
To reserve a hot meal, seniors should call 24 hours in advance at 859-567-2J 18, or drop by. Coffee and pastries are served each <lay. Wednesday, Au~ust 30: 8:30 a.m., Breakfast 9 a.m., Cards, games 9:30 a.m., Sit and Be Fit 10:30 a.m .. Pakino 12 noon. Lunch 12:30 p.m., Walk.Around the Block Thursday. August 3 J: 8:30 a.m .. Breakfast 9 a.m., Cards/Socializing 9:30 a.m., Yoga 10:30 a.m., Bunco (medicare and medicaid updates) 12 noon, Lunch
Rae Smith and Diane Collins; three brothers. Charles Ray Smith. Roy Smith and Donnie Smith; nine sisters. Margaret Lawson, Alene Ivey. Glorene Looper. Phyllis Dunn. Lillian Brewer. Evalee Dial. lrene Foley. Carldene Creech and Regina Gail Austin: 11 grandchildren and 16 great-grandchildren.
Howard Smit~ and two sisters, Ella Jean Lawson and Melinda Kay King.
Visitation was held Saturday, August 26. from 12 noon until 2 p.m. at Garnett-New-McDonaJd Funeral Home in Warsaw. The funeral service was conducted immediately following visitation. Burial was at Warsaw Cemetery.
He was preceded in death by his wife, Helen Smith: one brother,
Memorials are suggested to the Alzheimer's Foundation.
We've stocked two stores with beautiful antiques, collectibles and furniture including dining room tables and chairs, coffee tables, sofa tables, end tables, hutches, curio cabinets, roll top desks and rocking chairs. Check us out over the Labor Day weekend and save l 0% off your entire order with coupon.
--------- ---- -, I I
Labor Day Sale at
Cinaerella 's .'Attic Take 10 % off entire order
: Good Aug. 31, and Sept. l, 2 and 4, 2017 only.
L ___ ~u~p:s:t :u~on~ ___ ~ Open J 0 a.m. to 5 p.m.
Thursday, Friday & Saturday and Labor Day
202 Washington Street Warsaw, KY 41095
www .cinderellasantiques.com
The Gallatin County News. Warsaw, Ky. - Wednesday, Ao.gust 30, 2017 ·Page 13
Help the Hurricane Victims! Please donate: Canned Goods, Hygiene Products,
Diapers, First Aid Equipment, Toilet Paper, Toothbrushes and other Non-Perishable Items at the
Dorman Drop Box located in the
Dorman Products Main Office 25 Dorman Drive, Off US 42, Warsaw, Ky 41095
Open 8:30 • 4, Monday - Friday
For more info, call 859/283-4820 or see the Dorman Facebook Page
(Working In Conjunction With Matthew 25 Ministries)
The appllcabte energy or demand cnarge for electric service shall be Increased or decreased to the nearest $0.000001 per kWh or $0.01 per kW to recover the reveriue requirement associated Wllh Incremental distribution capital costs incurred by the Company. This Rider shall be adjusted perlOdically to recover amounts authorized by the Commission. Rate Group Rate RS, Residential Servioe Rate EH Optjonal Rate lor Electric Space Heating Rate GS·FL, Optional General Service Rate !or Small FiKed Loads Rate SP, Seasqnal Sports Seiv!ce Rate SL. Street Lighting Sel'lioe Rate Tl, Traffic Lighting Service Rate UOLS. Unmetered Outdoor Lighting Rate NSU, Street Lighting SeNice for Non·Standard Units Rate SC, S1reet Lighting Service - Customer OWned Rate SE, Street Lighting Service- Overhead Equivalent Rate LED, LED Outdoor Lighting 8echic Service
Rate OS, Service at Secondary Distribution VOitage Rale DP, Service al Primary Dlstnbution Voltage Rate OT. Tlme-of·Day Raia for Service at Distribution Voltage - Primary Rate OT, 11me-of-Day Rate tot SeMce at Distribution Vohage - Secondary
Proposed Rate: RIDER FTR FACTORS Rate Group Rate RS, Resfdent1al Service Rate OS, Service at Secondary Distrlbulloh Voltage Rate DP. Service at Primary Distrlbution Voltage Rate DT. Time-of-Day Rate tor Service at Distribution Vollage Rate EH, Optmnal Rate for Electric Space Heating Rate GS·Fl, General Service Rafe tor Small Fixed Loads Rate SP, Seasonal Sports Seivlce Rate SL, Street Lighting Service Rate TL. T raftic Lighting Service Rate UOLS, Un,netered Outdoor Ughll119 Rate NSU, Street Lighllng Service for Non-Standard Units Rate SC, Street Lighting Service - Customer OWned Rate SE, Street Lighting SelVice - Overhead Equivalent Rate LEO, LEO Street Lighting Service Rate TI, iime-of-Day Rate f0t Service at Trans11ussion Voltage Other
In addition, Duke Energy Kentucky proposes to change text of the lollowlng tariffs: Sheet No. 24 Service Regulations Section V - Metering, Sheet No. 25 Smvice Regulations Section VI - Bllfing and Payment. Sheet No. 98 Eleclriclly Emergency P1ooedures for Long· Term Fuel Shortages, and Sheet No. 100 Emergency Bectric Procedures. f '4 ..,..JL M ~"""J•t11.W....,.,....(u1 .~ • """'"
The foregoing ratas reflecl a proposei:J Increase- in eleotric revenues Of approxlrnately $48,846,213 or 14.96% over current total electric revenues to Duke Energy Kentucky. The estimated amount of increase per cus1omer class is as follows: Raia RS, Resldentral Service: Rate OS, Service at D1stnbut1on Voltage: Rate OT, Tlme-ol·Day Rate tor Service at Distribution Voltage: Rate EH, Optional Rate for Electnc Space Heating: Rate SP, Seasonal Sports Service: Rate GS-Fl, General Service Rate for Small Fixed Loads: Rate DP, Service at Primary Distribution Voltage. Rate TI, 1ime-of·Day Rate for Service at Transmission Voltage: Rate SL, Street Lighting SelVice: Rate TI, Trafllc Lighting Service: Rate UOLS, Unmetered Outdoor Ughllng Electtic Service: Rate NSU, Street Lighting Service tor Non-Standard Unrts. Rate SC, Street Lighting Service-customer Owned: Rate SE. Street Lighting Service-Overhead Equivalent: Bad Check Charge: Charge for Reconnectlon of Service (eleclrlc only): Rate DPA, Rate for OistnbU1ion Pole Attachments: Local Franchise Fee: Rate UDP·R, Underground Residential Distribution Policy· Rate UDP·G, General Underground Distribution Policy: Rate ATP, Experimental Real lime Pricing Program: (subset or other schedules)
Rate MDC, Meter Data Charges:
$22,855,269 or 17.36%; $13, 198,789 or 14.30%; $10,516,009 Ot 13.31%: $91,708or 14.23%, $3,343or 1141%, $86,768 or 14.38%; S167,667or17.57%; $1,416,419or11.12%; $159,847or11.87%; $8,413 or 11.75%; $24,006or11.7t%; $7,352 or 11.88%; $435or 11.72%; $22,650 or 1 t .85%; SOor0.0%: SOor0.0%. $60, 176 or 35.0%; SOor0.0%; $0or0.0%; $0or0.0%: $87,538or 14.87%:
$0or0.ll%.
The average monthly bill for each customer class to Which the proposed rates wlll apply will Increase approximately as follows: Raia RS, Residential Service: Rate OS. Service at Dlstributioh Voltage: Rate OT. Time-or-Day Rate for Service at Distribution Voltage: Rate EH, Optional Rate lor Electric Space Heating: Rate SP. Seasonal Sports Sel'lice: Rate GS-FL, General Service Rate for Small Fixed Loads: Rate DP, Service at Primary Distribution Voltage; Rate TI. Time-of-Day Aa1e for Service at Transmission Voltage: Rate SL. Street Ughling Service: Rate TI. Traffic lighting Service: Rate UOLS, Unmetered Outdoor Lighting Elactric Service: Rate OL-E, Outdoor Lighting Equipment Installation: Rate NSU, Street Lighting Service for Non-Standard Units: Rate SC, Street Ughung Seivlce·Customer Owned: Rate SE, Street Lighting Service-Overhead E.quivalent: Bad Check Charge: Charge for Reconnection of Setvlce (electric only). Rate DPA. Rate fot Distribution Pofe Attachments: Rate ATP. Experimental Real Time Pricing Program: Rate MDC, Meter Data Charges:
$15.17or17.1%; $114.53or14.3%; $3,848.79or13.5%; $98.45 or 15.8%; $18.59or11.7%; $8.29or14.9%; $3,269.80 or 17.9%; $7,973.24 or 10.7%; $1.15or11.8o/o; $0.09 or 12.0%: $0.27 or 12.0"lo; $0or0.0%; $0.88 or 11.9%; $0.21 or 11.7%; $0.92or11.9%; SOor0.0%; SO or 0.0"..t.; S1.53or35.0%; $1,887.21or15.6%; SOor0.0%.
The rates contained In lh1s notiee are the rates proposed by Duke Energy Kentucky; however. the Kenb,lcky Public Service Commission may ordet rates to be charged that differ from the proposed rates contained In this notice, Such action may result ln rates for consumers other than the rates in this notice.
Any corporation, assoctalfon, body pol111c or person with a substantial lnteres1 in the matter may, by written request wtthln thirty (30) days after publlcalion of this notice of the proposed rare changes, reques! leave to intervene; intervention may be granted beyond the thirty (30) day period for good cause shown. Slltb motion shall be submitted to the Kentucky Public Service Comm1ss1on, P. 0. Box 615, 211 Sower Boulevard, Frankfort, Kentucky 40602-0615. and shall set forth lhe grounds for the request Including the stat11s and Interest of the party. If the Commission does not receive a written request for intervention within thirty (30) days ol lhe initial publ1cat1on lhe Commission may take rmal acllon on the applicat10n.
lnterveno1s may Obtain copies of the application and other fiffngs made by the Company by contacllng Ms. Minna Rolfes-Adkins at 139 East Fourth Street, Cincinnati, Ohio 45202 or by telephone at (513) 287-4356. A copy of the application and other filings made by the Company is available for public Inspection through the Commission's website at http://Dsc.ky goy. at the Commission's office al 211 Sower Boulevard, Frankfort, Kentucky, Monday through Friday, 800 am. To 4:30 p.m., and at the lollowlng Company offices: 4580 Olymprc Boulevard. Erlanger. Kentucky 41018. Comments regarding the application may be submitted to the Public Service Commission through lls website, or by mail al the following Commission address.
For further information conlact:
PUBLIC SERVICE COMMISSION COMMONWEALTH OF KENTUCKY P.O.BOX615 211 SOWER BOULEVARD FRANKFORT, KENTUCKY 40602·0615 (502) 564-3940
DUKE ENERGY KENTUCKY 4580 Ol YMPIC BOULEVARD ERLANGER. KENTUCKY 41018 (513) 287-4315
•
~ 8- w--,..Sepamber6,2Dl7 -The C..U.tia County News, Wmaw,KY
NOTICE
Duke Energy Ken!IJ:ky, Inc ('!Me Energy Kentuctty" or "Company") hereby gives notiJe that, in an applicalion to be filed no soonar1han ~ 1, 21)17, ~ Energy Kentucky wll be~ approval by Ille Public S8IVice Commission, Frank· fort. Kf!fllUC:ky al an ~rl elec:llic rates and cbalges proposed to become ellective ~and slier Oc.tiJer 1,2017. The ComnlSSioo bas dDdaed 1hls poc.eediflg as case No. 2011-00321
The proposed eiedrk: rall!S 111& appli:able lo 1he loDowlng oommunities: Alexanchl Elsmere Sellewe Etlanger 1Elcnle Qdty FIWWIW Broml!y Flofence C8n1Jld Counly Fort Mitchel °'*'Spring Fortllonas Covingbl Fort W191t Qescent Paric Grant COonty Oascenl 6prip ~ Heighls CresMew lndepaldarQI CresMsw tills KenlDn County Qitllnjen Ken1Dn Vale Daylarl Lakeside Par!< Dry Ridge Lama Lakes Edgewood
CqmnlQsmnet ChaNe EllllllW Charge
Al kilawatt-hcus Jlropwd Riii Custonu Charge ~()age
A Clamge of $25.00is appif:allle IO 8U'I Wt:lo mver in part Ille COS1 al 1111Dal8dir.vl of servi:e. ,......._ ~Cleva $17.14 permmh Ell8lgy Clwge 10.6568cper kWh A clll!!JB di $25.00 IS appiallJkt ID .:It wi \:>cover in pa11he am ofracameaioo of service.
Cl!rnqtJWt
Oplkql U!!n1*tld Qmml SloloeB* For SmWI Rad Lan ·Riii GS.fl.
Jl5!et;trtr Ictrr.Sbeet No. 441
For loads bad on a l'1l1g8 cf 540 ID 720 hours use per monl1 ol lhe nd8d capacity of lhe ameclBd equipnelt '8.(J72Je per kWh For lmtB ol less1hml 540 tors use per monlh of tte raled aipacly c:A ll»c:rmdlld ~ 9.29U per kWh Mininun: S3.00 per Rad l.mS l.ocali:Jn per month.
Propo9!!d Ritt fOf loads based on a range of 540 1o 72C hours U9e per monttl of :the r&led capacity of the oonnedad equ1pmen1 for loadsol less than 540 hours use per monlh of h rated capaaty of lhe IQllMlded equipment Minimum: $3.14 per Fixed Load U1Cation per month.
Primary Voltage SeM:e (12.5 CJ( 34.5 kV) Demand Chaige
Alklowatt Energy~
Fll'Sl 3001CWM<W Adodional kWh
pmqgwiftllo Cuslomer Charge per month
PrimaJy VollBge Seivioe (12.5 Of 34.5 kV) Demand Charge
Al kilOWalls Energy Charge
First 300 kWh AQditional kWh
$100.00 per monlll
$ 7.08 perkW
5.1008¢ pee' kWh 4.31 ~ per l!Wh
$118.78 per mcnh
$ 8.40 pet kW
611595& per kWh s 121m: per kWh
T1!ftoHlly Batt tor 91mcut Dwr' 'm Vr"• a. TT !fMtlfJldTf Sheet Ho. 51)
C!mnlBate Custona Chalge pennonth Demard Cl1arge
Summer On PeakkW Ollf'eakkW
Winter On PeakkW Off Peak kW
Enetgy Charge AllkWh
PJlll!!Hd Rile CuSlaner Charge per month
Demand Charge Simmer On Peak kW OllPeakkW
Wln1er On PeakkW Oii Peak kW
Eneigy Chl1!ge Sllnmef OnPeakkWh Oii Peak kWh
Winlaf On PeakkWh Off PeakWJll
CumntBllC 1. Adminlslralive Charge
SS00.00 per monlh
$ 780 per kW $ 1.15 perkW
$ 62-4 perkW $ 1.15 perkW
42648c per kWh
SS00.00 per month
S 8.46 perkW S 1.28 perkW
s 8.95 perkW $ 1.28 perkW
5.4454t per kWh os94c per kWh
5.1983C perkWh .C.459-lc par kWh
Rldlr GSS-Gll•llllon Support s.¥iclt (£llctric Tll'ltl Slwlt No. HI
The Administrative Cl1arge shall be S50 plus the appopi81e O"'*"'-Qwge. 2. Monthly Distribution Resemllion Charge
a Rate OS - Secondaly OislribcJbon Service b. Rat& DT - Distdbu6on Service c. RalB DP-P.rimary Dl$1rb.ition SemC11 d. Raia TI - Transmission SeMoe
3. Monthly Traosmission Reservation ~ a Rate OS • Secandaty Dislrilution Service b. Rale OT - OlslTbJlicl1 Service c. f1ale DP - Primary Distiibulion Service d.. Rate TT - Transmi&sionSe!vice ... Monthly Ancillaly Services Reservalion Charge a. Rall! OS • Secandaly DisttbJ10I Senrioe b. Rate OT - Dis1ribu1ion Servlae c. Rale DP -Primlly Dl5ll'ilub Service d Rate TI - Tranmnlsslon Service
PIVJIOl!!!f Rate 1 Adminialrative ~
$2.5853 per kW SU735 per WI S2. 7781 iper JIW :S0.0000 par iltVA
$13:194 per kW $1.3047JllrkW $1 JM93 per kW $1.21161 per WA
SD.52ol0 per kW $D.52CO perkW $0.5240 per kW S0.4550 per WA
The Adrni11is11a11w Chalpt:shalbe SSO pus tie~ Cusllll19 CJ*Qe 2 Monthly Resel'ialtln Charge
a Rate OS· Seconda!y Oislribu!b1 Senice b. Rate'DT - Olslrilulion SeMce c. Ram DP - Primary Distlilullon Service d. Ride TT - Tmnsmission Service
$4:84t'lll per kW SS.9992 per kW $6.1"84 per kW $2.9666 per kW
Sooood8ry 'Services-··- $15 00 per l1D1l1 PnmarY Service.- •. ·---..$100.00 per monlh
"Transmssion SeM:e_ . .:ssoo.oo permonlh Energy Detively Charge Charge For Each kW Per Hour:
Secondary Servir.e •.•.• _ .. .$0.ooB053 per kW Per tbir iPrimaiy Se!Vic:e.--··-.. $O.oo5540 per kW Per Hour Transmission Serme.........$0.002008 per kW P8' Hour
Ancillary Se!vicas Charge shall be .appfied on an hour by how basis. Charge Foe Eaoh kW Per ltlllr.
Secondaly Dafivary_ ....$(1.000760 per kW Par Hour Pnmary DeWveey ··-·-··.SO 000740 per kW Per HOU! Transmission Dellvaly •• ..$0 000721 per kW Pel' Hour
'Ml8l1I a street lighting fhc1ura S8Mld Wlllhead ls ID be installed on ardle< dlilY's pall on .ncn .. c..mw-r d1181 llOI haV1Ja wnlBd, a monthly .pole char!1e wUI be essessed.
Spaos of SeCXlndary Wiring: fOI' each increment ol 50 leel of SlllXllllay Milg .beymd Ille &at 150 Jeet trxrn ... pole.1he tibing price per ITlll1lh shaft be .ilklBd to lhel>Qllll par llDllh Jiii' straet ighq unit .$0.52. LINQEAGAQUND DISTBIBUJJON Lq >muaJ
Prqp;p1 Bate wt1n 11e Com!*1Y SlqJlies aagy rriJ, 11 ldbatt.ta.n shit tie blllad 11 '2590 ans per lilkMlm.tor. wi..111e Coqiany'qiplias erwgy .1n11n a ...-11e1r l!llllnd .1111m1 am Ille Coqimty tm .-i m llO'idl lilNlld °*"8llln(8fer1rallic sip! equipnenl, 11 kilowa1l.fDn llhll be blled ll2.3S83 c.is,. kloal<hcu. Where the~ .supplies «llllVY and Im agraed ID provide imlled maim am b tralfic llgnll equipmd. 'II .. wa1l-hlus .... be bled al 6.6174 mnls per lclowllt~.
Clmd8* AJkWh
' '"* MkWh
s 7'81 t ts ltWh
°'*Ml.igMng ....... ' 7 p> tM QkE lfhrtrtr]d llMt Np. Al
BoulMrd ums 9l!lwd UOOelgrtU1d L 2,500 lumen lncandescenl - Series b 2,500 lulnen D:alidaslail -.Wllple HakJplal! Daalillllle flldllre on 17 bit filll!gllllS pole awed wdaijJOiilld with dir8d luied cable
Ol**3or191lir11 anls--inundllgnlund..-.i~: The fabingmonlNydagewiltll.....t:lor~ ildlms"8idlialll_and .......... ..,.,.....,,9! .. 11idetg1ouudtaW11,..natt1...il5111t:tnmlle...-._t.a._1llilB• not be mlllll8 ti new Qlllml9s lllWllllllJ~ ffll2:
~ ~
.wan iW4d ~ Ba\bt 7,000 Unl!ns Man:my. Mam1led an a
17 Joo! F.l>ergllss Pola • - ••• -. - - ••.•.• - 7 175 0.205 853 $1U4 7,000 llnlrl Mllaly. Malnld an a
Page JO· Wednesday, September 6, 2017 ·The Gallatin County News. Warsaw, KY
Flood lighting units served In overhead dlsllibutlon areas: The following monthly charge wfll be assessed IOI' each existing Hx1ure, which Includes lamp and lummlre, conlroUed automatically, mounted oo a uhTrty pole as specified by the Company, with a span of wire not to exceed 120 feel, bu! lhese units will not be available after May 5, t992;
Where a street lighling fucture served overhead ls to be installed on another utility's pole on which the Company does not have a oontacr a monthly pole charge will be assessed.
Pole QescrJotion ~ ~ Wood
30foot W30 $434 35 foot W35 $440 401oot W40 $527
Basa Fuel Cost The mies per unit shown above indude SO 023837 per kilowatt-llOl.lr reflecting the base cost of fuel
Each qualifying customer's individual monthly rate calculated for each customer for this sel'Vk:e will be determined as follows. Monthly Service Paymem:: Estimated Levelized Capital Cost + Estimated Expenses Where Levehzed Capital Cost tS equal to !ho p.-osent value of all es! mated capital related cash flows for a perk>d correspoocling 10 the tlme ol eng1neer.ng desJgrJ and Installation ol equipment through the term ol the contract, aojUSted to a pre-tax amount and converted to a uniform monthly payment for the term of the contract The estimated capital cash flows shal lncklde estimated ins!alled cost ol aqu pment, conlingency alloWances salvage value, adjustment to reflect add tional suppo111ng investment of general plant nature, and Income tax impacts. Expenses shall equal the present value ol esumated expenses a~ wrth the supPOrt and mainle nance of the generation and supporl equipment, adJUS!ud to a pre-tax amount and converted to a uniform monthly payment for the term ol lhe conrract. The esllmated expenses shall inctude administrative and general expenses, expenses lor labor and materials related 10 opera!lons and maintenance thlrd party expenses lor operations and maintenance, warranties, Insurance, annual costs associated with working capllal, luel inventory depreciation property lax other costs related to the operation and suppon of the generator system installatiOn and lneome tax impacts. The aftet 1ax cost of capi!al from tho Cornpa'l)' s most recent geoeraJ rate case W1D be used to convert present values to uniform monthly paymentS
MONTHLY Bill Customer's monthly bt1l for all &eMCeS under this rkler wlD appear on their regular monthly electrlc bill as a line Item.
fropoud Bate: There are no proposed changes in this rider.
Current Rate:
~ServtceRld1r (;~tdc Ierlff ShSl!l No, 71l
In addition to charges for service furnlShed under the applleabte standard rate the customer Will pay in advance the foflowing charge. Estl!Tlaled un4t COS1 of each service wtth supporting data to be filed with the CommiSSl()n and updated annually by the utility. Proposed Rate: There are no proposed changes in tms nder
Curr11nt Bate:
Rider X - Line Exteaajoo Pghcy Rider (E!Ktrlc Tariff Sh11111 No. 721
When the estimated cost ot extending the distribution hnes lo reach the customer's premise equals or Is less than three (3) times 1he estimated gross annual revenue the Company will make the extension WllhOul add'rt1onal guaran· 100 by the customer over that appllcable In the rate, provided the customer establlsnes credit In a mannt!f satisfactory lo the Company. When Iha estlmated cost of extending the diStlibu!IOO fines to reach the customers prermse exceeds three (3) times the estimated gross annual revenue. the customer may be requtred to guaramee for a period of five (5) years, a monthly bill of one (1) percent Of the line extellSJOn cost for residential seMCe and two (2) percent lor non-residential service When the term of sel'VICe or crecfd have no1 been established In a manner satisladory 10 the Company the customer may be requ red to advance tile estimated cost of lhe line extension in ellher of the above S1tuat100S When such advance IS made the Company W1D refund, al the end ol each year, for tour (4) years, twenty-five (25) percent of the revenues raceived in any one year up to twenty-live (25) percent of the advance. Pr2~tt: There are no propOSed chariges In this rider
I When a customer elects the OFF PEAK PROVISION the monthly customer charge of the applicable Rate OS will be Increased by an addit10nal monthly charge of five do ars ($5.00) for each installed tirn&of·use meter In adcfilion, the DEMAND prOV!SIOO of Rate OS shall be modllled to the exient Iha! lhe billing demand shall be based upon the •on peak period; as defined above IL For customers who meet the Co!Tlpany s cntena lor tho lnstattallon of a magneuc tape recording device lor billing. and where electnc service is furnished under tho provisions of etther Rate OS Service at Secondary D1Stribut1on Voltage or Rate DP, Service at Pnmary 01strlbutloo Voltage When a customer elects thts OFF PEAK PROVISION, the applicable monthly customer charge of Rate OS or Rate OP will be increased by an add1!1onal monthly charge of one hundred dollars ($100.00). Proimltd. Ratg: When a customer elects !he OFF PEAK PROVISION, the monthly customer charge of the applicable Rate DS or DP wlll be increased by an additional monthly charge of five dollars ($5.00) for each Installed ~me-of-use or interval data recorder meter. In addition. the DEMAND prov1Slon of Rate DS or DP shall be modified to the extent that the bclfing demand shal be based upon the "on peak period; as defined above. However, In no case shal lhe bi mg demand be less than the bl llng demand as detennlned in accordance with the DEMAND provtSiOn of the applicable Rate OS or Rate DP. as modified.
Cuu,nt Bate: CHARGES
Bider AMO - Adyance<I Mette Opt-Out IAMO) • Resid11Dtial Wectrlc I1rlff Stint No, 741
Residential customers who elect, a1 any time. to opl-out of the Company's advanced metenng infrastructure (AMI) system shall pay a one-time fee of $100.00 and a recurring monthly fee ol $25.00. During the Metering Upgrade proiect deployment phase. 11 prior to an advanced meter being installed at a customer premise, any existing residen· rial etec!rtc customer Iha! elects to participate In this opt-cul program, Duke Energy Kentucily will nol charge the one· lime set·up fee, providing the residential electnc cuSlomer notifies the Company of such election In advance of the advanced meter betng installed Those residentJal customers electing to participate In this residential opt-out program will be subject to the ongoing $25.00 per month ongoing charge. Following deployment completion. any resldentlal customer who later elec!s to partidpate In the Opt-Out Program wlll be assessed Ille S100 set-up fee m addition 10 the ongomg monthly charge. frgpoud Rate: There are no proposed changes in this rider
The Demand Sida Management Rate (OSMR) shall be determined In accordance with the provisions ol Rider DSM, Demand Side Management Cost Recovery Rider Sheet No. 75 of this Tanlf. The OSMR to be applied to resldenllal customer b ts Is S0.007967 per kilowatt·hour A Home Energy Assfstance Program (HEA) charge of so 10 W1U be applied monthly to residentlal QISIOmer billS through December 2020 The OSMR IO be applied lo non-resldential diSlribulion servtce customer bills IS so 002576 per kllowatt-oour. The OSMR IO be applied for tranSfll!SSIOn SeM:e wstomer blils 1s S0.000183 per klJOY;a:t-hour ~: There are no proposed changes In this rider
C11!'ItJll.R1111:
Rider BOP- B~MJtDtHverv Point Capacity Ride!'. tE!tmlillrllf Sh11et No. 79)
BACKUP DELIVERY POINT (TRANSMISSION/DISTRIBUTION) CAPACITY The Company will normally supply service to one premise al one standatd vottage at one delrvery point and through one meter to a Non-Reskientlal Customer In acoordance with the proviSIOl1S of lhe apprrcable rate schedule and the Electric: Service Regulations. Upon customer request, Company wlll make available to a Non-Rasiden!lal Customer addrtional de r;ery pomts en aocon:lance With the rates, 1enns and condi'tions ol lhls Rider BOP NET MONTHLY Bill 1 Connec'Jon Fee
The ConnectlOn Fee appfies only 11 an additional metenng pomt Is required and,,. H be based on customer's mosl applicable rate schedule
2. Monthly charges will be based on the unbundled distribution and/or transmiSsion rates of the customer's most applicablo rate schedule and tne contracted amount of backup delivery point capacity.
3. The Customer shall also be responsible tor the accelera1ion of costs, if any. that would not have ot11erwise been incurred by Company absent such request for additional delivery points.. The terms of payment may be made Initially or over a pre-<letemlined term mutually agreeablo 10 Company and Customers that shall not exceed the minimum term. In each request for service under this Rider Company engineers wUI ainclud a thorough revl8W of Iha customer's request and the QfCUlls affecled by the request The customer s capacity needs will be weighed against the capacity available on the cirCult anticipated load growth on the arcuit. and any Mure constructiOn plans that may be ad· vanced by the request Proposed Rate: There are no proposed changes 1n this rider
~1m11nt 8111:
EJ.lt!Adjuatment Clouse • Rid« FAC (~~IirltlS!tmN2.JOl
(1) The monthly amounr computed under each ol the rate sctiedules to wh1cll thls fuel clause 1s applicable shall be increased or (decreased) at a rate per kilowatt-hour of monthly consumptiorl in accordance with thefollowlng formula:
Fuel Cost Adjustment= fim) • $0.023837 per kWh • S(m)
Where F IS the expense ot fuel tn the second precedlng momh and S IS the sales tn the second precedmg month. as defined betow.
(2) Fuel COSIS (F) shall be Iha cost of (a) Fossil fuel consumed In the Company s plants plus tile cost ol luel wtlich would have been used in plants su!lerfng lon:ed generallOn or transmission OU!ageS, but l9Ss the cost of fuel related to substitute generatloo plus (b) The actual lden!iflable 1ossD Md nuclear fuel cos1s associated wtth energy purchased for reasons Olher than Identified In paragiaph (CJ of this subsection, but exclud1119 the cost of luel related IO purchases to substltute for Ille forced ou1ages: plus (c) The net energy cost of eneigy purchases, exclusive of capacity or demand charges (1r1espectlve ol lhe deslgnatlon assigned lo such lranSaCOOn) l'ltleo such energy is purchased on an econom1e dispatch basis Included thoretn ere such costs as the charges for economy energy purchases and the charges as a resuh of scheduled outago, all 6UCh kinds of energy being purchased by the Company to subst1Me for its own hlghor cost energy, and less (dJ Tho cost of fossil luel recovered through imer·system sales Including the luel costs related co economy energy sales and olher energy sold on an economic dispatch basis. (e) All fuel oosts shall be based oo a weighted-average inventory costing. The cost of fossil fuel shall Include no rtems other than the lnvolce pnce of fuel less any cash or other discounts. The Invoice pocc of fuel includes lhe cost of ruel itsett and nece<>sary charges for transportation of fuel trom the point of acqulsl tion to tho unloading point. es listed In Account 151 of the FERC UntfOflll System of Accounts for Public Utffities end Uoenscos. (I) As used herein, the term "forced outages' means an non-scheduled losses of generation or transmiSSJOn which requ re subslnute power fore continuous period rn excess of SIX (6) hours Where torced outages are not as a result ol faulty~~ faulty maflllfacture, laulty deSign. laurty instaDatiOlls. faulty operatkm, or faulty ma ntenanco, but are Acts of God, riot insumlcbon. or acts of !he public enemy, then tho Company may, upoo proper showing, with the l!llJlfOVal of Iha Commissloo, indudelhe fueloost ol substitute energy •n the adjustment.
(3) Sales (S) shall be determined 111 kifowatt·hours as follows. Add:
(a) ne1 generatlorl (b) purchases (c) terchange In
Subtract (d) Inter-system sales Including economy energy and other energy sold on an economlC dJSpatch basis (e) total gystem losses
~liAtl: (I) Tho monthly amount computed under each ol the rate schedules to which this fuel clause is applicable shall be 1ocrcased or (decreased) at a rate per kilowatt-hour of monlhly consumptlOO in accordance with tho following formula
Fuel Cost Adjustment = .E[mJ_ • S0.023837 per kW71 S(m)
Where Fis 1he expense ol fuel in the second preceding month and Sis lhe sales rn the second preceding month, as defined below· (2) Fuel costs (F) shall be the cost or·
(a) Fossrl fuel consumed in the Company's plants plus the cost of fuel which 'NOuld have been used In plants su!letfng forced goneration or transmission oU!ages, 001 less the cost of fuel related tosubstiMe generation, plus (bl The actual Identifiable fossll and nuclear fuel costs associated wtth energy purchased for reasons olher than identified in paragraph (c) of this subsection, 001 exducHng the cost of fuel related IO purehases to substitute for the forced outageS; plus (c) The net energy oost ol energy purchases, exciUsive of capacity or demand charges QrrespectNe or the designation assigned to S1JCh trensactiOn) wtien such energy IS purchasad on en economic diSpetch basis Included there n are such COS1S as the charges for economy energy purchases and the charges es a result of scheduled outage. all such kinds ol energy being purchased by the ~ 10 substitute for l1S own hgher cost energy and less (d) The cost or fossil fuel recovered through rnter-system sales including the fuel COS1S related to economy energy sales and other energy sold on an economic dispatch basis. (e) The luekelaled charges end cradlls chaiged to the Company by a Reglonal Transmission Organization. (Q All fuel COs1s 6hall be based on a weighted·average inventory costing The cost ol lossil fuel shaft include no items other than the invoice pnce ol luel less any cash or other diScoums. The Invoice p!lce of !uel includes the cost ol luel itself and necessary charges for transportation of fuel from the point ol acqufsition to the unloodrng point, es 1is18d In Account 151 of the FERC Uniform System of Accounts for Public U11 11les and Ucensees (g) As used herem, the term "forced outages" means all non-scheduled losses of generation or transmisSJOn which require substllute power lor a conbnuous period In excess of six (6) hours. Where forced outages are no! as a rosuM of taulty equipment, faulty manufacture, faulty design, laJJHy 1nstalla1ions, faulty operation, or taulty ma1ntenenoe but are Acts of God, riot. tnsunectioo, or acts of the public enemy, then the Company may, upon proper showing, Will'I the approval of the Commission, include the fuel cost of subsl1tU1e energy In the edjUStrnent.
(3) Sales (S) shall be detemttned in kilowatt-hours as follows: Add
(a) net generation (b) purchases (c) Interchange n
Subtract (d) llllar-sys:em sales Including economy energy and other energy sold on an economic dispatch baSIS (e) Iola! system losses
Rider PSM - Ott§ymm Power Sain and EmjSl!OQ Allowance Sales Profit Sharlogj!Kl!lnilm !Electric Tariff Sheet No· 82!
C\11m11 Rate:
Ame Groun
Bate BS Resldentlal SeMCe Rate OS, SeMCe at Secondary Distrlbution Voltage Rate OP Service at Prtrnar; Oistrlbu1ion Voltage Rate OT. Tune-of-Oay Rate lor Service at OIS!rlbution \loltage Rate EH, Optional Rate for Electrlc Spaoo Heating Rate GS·FL General Service Rale for Small Fixed Loads Rate SP, Seasonal Sports SeNICe Rate SL Street Lignhng Service Rato TL. Traffic Lighting Service Rate UOLS, Unmotered Outdoor Lighting Rate OL, Outdoo1 Lighhng Servioe Rate NSU. Slteet UghUng Service for Non-Standard Uni1s Rate NSP, Pnvato Outdoor Lighting Service for Non-S1andard Units Rate SC, Street Llghung Seivice - Customer Owned Rate SE, Street Ugh!ing Service - Overhead Equivalent Rate TI Time-of·Day Ra1e for SeMCO at Transmission Voltage Other
Rider PSM crecfrts reductions lo b s, ere shown as positive nombera without parentheses Alder PSM charges increases to bills. are shown In parentheses
PROFIT SHARING RIDER FACTORS Tho ApplCablo energy charges tor eledric service Shaft be inCreased or decreased to the nearest
S0.000001 por kWh to rolfcct the sharing of profrts oo off-system power sales and ancillary &eMCeS, the net profits on sales d emlSSlon a!owances and net margins on cepadty transactions related to the &Gqulslilon of 100% ot Easl Bend Unit 2.
The Company will compute Its profits on oll·system power sales and tlllCl'llary services, profits on emission allowanc:e sales. and net margins on capacity transactions related to the acquisition of 100% of East Bend Urut 2 in the followtng manner
where Rider PSM Factor= ((P +A) + E + C + R)IS
P "' Eh91ble profits from olf·syslem power sales for applic:able momh subject to &haring provisions eslablished by the Commissron in its Order in Case No. 2003..()()252, dated December 5, 2003. A = All not profils related to its provision of ancillary services 1n markets administered by PJM per the CommlsslOO's Order in Case No. 2()()8.00469, dated January 30, 2009.
Tho first Sl million In annual profile from off-system sales and ancillary services will be allocated 10 ratepayers. with any profits 1n excBSS of $1 milUon splH 75:25, with ratepayers receiving 75 percent end shereholdeis receiving 25 percent per the Commission Order in case No. 2010-00203, dated December 22, 2010. Alter December 31st of each year, tha 6hanng mechanism will be reset for off-system power sales. Each month the sharing mecha· nlsm wfll be reset for the llllC11iary service prolrts. E = AU net profits on sales ol emission allowances are cre<frted to customers per the Comm1ss100's Order in Case No. 2006-00172, dated December 21, 2006. C = Capacity revenue received from PJM associated wilh DP&L's share of Easl Bend capac!ty tha1 DP&L has committed In PJM s base residual audoo iSRAl lllrough May 31. 2016. less the cost Incurred by Duke Energy Kentucky to proa.ire sufflae!'ll capacity to meet Its obfigauons as a Fixed Resource Requirement entily under tr.a Reliabl ty Assurance Agreement with PJM per the ComnVssion's Order in case No 2014-00201, dated December 4,2014
The nel of capacily revenue received from P JM and the capaaty COS1 incutred by Duke Energy Kentucky WI be ellocated to ratepayers, wllh ratepayers receMl19 75 percent and shareholders receMng 25 percenL
R = RecooclliallOn ol prior period Rider PSM actual revenue 10 amount cek:ulated for 1he period S = Current month sales ln kWh used In the current month Rider FAC calculaoon.
~.Rm; Bate Grouo
Rate BS, Residentlal Servicc Rate OS, Service et Secondary Dis1ribtJtioo Voltage Rate OP, Service at Primary Distribution Voltage Rate OT, Tirno-of·Oay Rate IOI' Service at Dlstri001ion Vottage Rate EH, OpliorlaJ Rate for Electric Space Heating Rate GS·FL, Genernl Service Rate for Small Fixed Loads Rate SP, Seasonal Sports SeNice Rate SL. Street Lighting Service Rate TL, Traffic Ughhng Service Rate UOLS, Unmetered OUtdOOI' Lighting Bale OL. OutdOOr UghUog Serv100
Rate NSU, Slteel Lighling Service for Non-Standard Units Rate NSP, Prrvate Outdoor Ughtlig Servico for Non·S!endard Units Rafe SC, Streel Ughtlng Service - Cus1omer Owned Rate SE, Sltee! Lighting Service - Ov8ltlead Equtvalent Rate n Tmie-ol·Day Rate for Selvlce at Transmission Voltage Other
The Gallatin County News. Warsaw, Ky.· Wednesday, September 6. 2017. Page 11
Rider PSM credits, reductk>ns to bl!Js, are shown es posltiVO numbers without parenlhe9es. Rider PSM charges, Increases IO bills, are shOWn In parentheses
PROFIT SHARING RIDER FACTORS On a quarterly basis the appficable energy charges for electric servlc:o shaD be Increased or decreased to tne nearest $0.000001 per kWh to reflect the sharing of not proceeds es outfllled tn the lormila below.
where.
Current Rate:
AXie: PSM Facto< = (OSS + NF + CAP + REC+ R) IS x 0.90
OSS Net proceeds from off·system power sales. NF " Net proceeds from non-fuel related Reg100al Transmission Orgamzatioo charges and cred11s not recovered via other mechan1Sms CAP : Net proceeds trom: P JM charges end credits as provided lor in the
Commission's Orderrn Case No 2014-00201, dated December4 2014; capacity sales; capa<;lty purchases: capacity performance credits; and capacity performance assessments
REC = Ne! proceeds from the sates ol renewable energy credtls. R = Recooohat1on of prior period Rider PSM ec1ual revenue to amount celcu lated for the period. S = Current period 68les in kWh es used ln lhe Rider FAC calcutetron.
Rider GP - OllM. Entr:gy).GQGRE~N .K~ ~~
(Electric Tariff Sheet No. 881
NET MONTHLY Bill Customers \\tic participale under this rider wUJ be billed for electric service under ell eppticable lari!!s includlng an appflcable riders. Green Power purchased under this rider. Will be billed et the applicable Groen Power rate bmes the runbef of 100 kWh blocks the customer has agreed to purchase per month The Graen Power rate shall be S2.00 per 100 kWh block with a minimum monthly purchase ol two 100 kWh blocks. Carbon Offsets purcllased under tilts rider, wUI be billed at Iha app icable Carbon Offset 111'.e times the number of Carbon Offsets the customer has agreed to purchase per month The Carbon Offset rate shall be $4 00 per 500 lbs oflse1 block frgposed 811.t: There are no proposed changes 1n this rider.
~urrent Rote: AVAILABILITY
fll<ltr NM - Net~~ (ElegtdtltclflShHt.tio.J9J
Net Metering IS available to eligible customer-generators In lho Company's service terrrtory, upon request, and on a f11St· come, tirst·served basis up to a cumulative capacity of 1 % of the Company's single hour peak load in Kentud<y during the previous year. P~: There are no proposed changes in this rider.
~:
Bad Chg Cb1mt !Electric Tariff Sbeettio • .901
The Company may charge and coll8cl a fee of $11 00 to rnver Ille COSI of handling an unsecured check, where a customer tenders in payment or an aa:ount a ch9Ck which upon deposit by the Company is retumed es unpaid by the bank lot 8l'fo/ reason. ProDOSeC! Rate: There are no proposed changes m this rider.
Current Bate;
Charge tor Reconnection o1 Seatce (Electr!c Tariff Sheet No, 91)
A The reconnection charge for seMCe which hes been disconnected due co enforcement of Rule 3 shall be twenty·f1ve dollars ($25.00). B. The reconnectoo charge for service whrch hes been d11connected within tho preceding twelve monlhs at the request of the customer shall be twenty·hve dollars ($25 00). C. If seMce Is dlscontinued because ot fraudulent use thereof, the Company may chargo end collect in addition to the reconnecllOO charge of twenty·flve dOllars ($?.5.00) the expense tncuned by the Company by reason o1 SUch fraudulent use. plus an estimated bill for eleclricity used, prior to the reconnection of service. D. II both Che gas and electric services are reconnected al one time, tho IOtal charge shell not exceed lhlrty·elgh1 dollars ($38.00). E Where electric service was disconnec1ed a1 the pole because the eorr.>any was unable to gain access to lhe meter, the reconnechon charge shan be sixty· five dollars ($65 00). If the gas service ls also reconnected the charge shall be ninely dollars ($90.00). F If !he Company receives notice after 2:30 p.m of a customer's desire tor same day rernstatement of service and if the reconnection cannot be per1ormed during normal business houc's, tho alter hour reconnection charge for connection shaff be an additional twenty·five dollars ($25 00) Customers wlft be OOl!fled of the addnional $25.00 charge for reconnectlOO at the meter Of at the pole al the Ume they request same~ &erVice. G If a Company employee, whose origrnal purpose was to dlSCOllned the service, has provided the cuslomer a means lo avoid cisconnection, service Which olhelwlso would have been disconnected shall remam Intact, and no recoooection charge shaD be assessed. However, a coUoction charge of fifleen dollars ($15.00) may be assessed, but only ii a Company employee actually makes a field visit to tho customer's prermses.
Propoffd Rota: A. The reconnectlon Charge for service which has been d'ISCOMCC!ed due to enforcement or Rule 3 shall be twenty.five dollars ($25 00) lor reconnectJons Iha! can bo accomplished remotely or seventy.five dOllars ($75.00) for recoonectloos that cannot be ~ished remolely B. The reconnection charge for service which haS been disconnected withrn tho preceding twelve months at ttie request ol lhe customer shall be twenty·liVe dollars ($25 00) for roconnec11ons Iha! can be accomfiished re motely Of seventy-five dollars ($75.00) for reconnections that cannot be accompfished remo!ely C H selVice is discontinued becao:;e of fraudulent use thereof, the Company may charge and coOect n add1tron to the reconnection charge ot twenty·frve dollars ($25.00) for recoonoctlons that can be eccompfished remotely or seventy·five dollars ($75.00) tor reconnoctions that cannot be accomplished remolElly, the expense incurred by the Company by reason of such fraudulent use. plus an estimated bill for eloctrictty used, prior to the reconnection of service. D. If both the gas and electric servJces are reconnected 01 one time, the total charge shall not exceed eighty· eight dollars ($88.00). E. Where electric service was disconnected at the pole becalJSC 1he Company was unable IO gam access to the meter. the reoonnectron charge shaU be one hundred twenty five dollars ($125.00). If the gas sorvice is also reconnected the charge shall be one hundred filly dollars ($ 150.00) F. tt the Company recerves 001ice after 2·30 p m. of a customer's desire for same day reinstatement of selVk:e and 1f Ille reconnecllOn cannot be performed during normal buslness hours, and 1he reconnection cennol be performed remotely, lhe after hour reconnectlOfl charge for connecllon shal be en add tlonal twenty..frve doffar8 ($25.00). Customers wll be notlfled ol lhe additional $25.00 charge lor reconnection at the meter or 81 the pole at the lime they request same day service G Ha Company emp!Oyee, l'ltlose original purpose was to d'ISCO.'llleCI the SOMce, has provided the customer a means to avoid <isconnection, service v.tiich Olherwise would have been disoonnected shal remain Intact, and no reconneaion chargo shall be assessed. However, a coflcc!lon charge of filly dollars ($50.00) may be as sassed 001 ~ n a Company employee aaua1ly makes a field visit to the cus+.omer 's premises
Cu.rmrt .B.ttt:
Rate for Pole Atlgb!!!t1J11.o1Clblt . .Ttlevlllon Sytt91Jl1 • 811e CAlY !This Scheclu!e If Renamed u Bate DPA - PfJtrlbutlon Pole Atllchments
!Electric Tarlft Sheet No. 921
The following annual rental shall be charged for the use of each ol the Company's poles. Two·US0f pole: $4.60 annual rental Three-user pole: $4.00 annual rental
PrQposed Rate: The following annual rental shall be charged for the use of each or the Company's potes·
CulTlf!t Batt: Bates tor Purchas011 from qualifying facilities. Purchase Rate &hall be S0.03078/kWh for all kllowatt·hours delivered ProROHd Rate: Rates for Purchases from qualifying lacilities. Energy Purchase Rate shall be S0.027645A<Wh for eK kilowatt-hours delrvered Cspacity Purchase Aale shall be $3 90r\W·mon1h for efigibte capeclty utilized by Company end approved by PJM ui Company's FIX9d Resource Requirements (FRR) plan
Cogeneratlon and Small eoYter Production Sale aoct.Purrout Iadtt:.Greettr Ibln.l®.kW I Electric Ildff Sheet No, Hi
Current Rate: The Purchase Rate lor aD kilowatt-hours delivered shall be the PJM fleal. Time Locational Marginal Price for power at tne DEK Aggregate pnce node, inclusive CJ! the energy, congestion and losses charges for each hour of lhe billing month. Proposed Rate: The Energy Purchase Rate for all kliowa!Hiours delivered shall be the P JM Reel-Time loca!lonal Marginal Price 1or power at the DEK Aggregala pcice node, inclusive of lhe energy congcs1IOl1 and losses charges. for each hour ol the billing month Capacity Purchase Bate shall be $3.90/kW·rnortth for ellg1ble capac;ty ul ized by Company and approved by PJM In Company's Fixed Resource Requiremems (FAR) plan.
Current Bate:
~obJu£tt lElectric T1rt!tShtttliuSl
There shad be added lo the customor's bill, listed as a separate item, an amount equal lo the fee now or herealtef Imposed by locaf legislative authorities, whether by ordinance, lraochlso or othor means, which I ed oo the gross receipts collected by Ille Company from the sale of electriclty to custol'll8fs wiltiin !he boundaries of h perticuler legisla· live authority. Suell amount shall be added excluS1Vety to bills of customers receMng se!Vlce Within lhe territorial lim~s ol Ille authoo1y imposing the fee.
Where more than one S1Jch fee is imposed, each of the cllarges epp1iCab1e lo each customef shall be added to the customer's bill and listed separately.
Where the local legiSlalive authority imposes a Ila!, fixed amount on !he ~. the lee epp&ed to the bils of customers receiving service within lhe territorial boundanes ol lhal authority, shal be in the lorm of a flat dolla! amount.
The amount of such lee added to the customer's bll shall be detemiined m acoordance wllh the 1erms ol lhe <:ontiuld next
•
Page 12 - Wednesday, September 6, 2017 - The Gallatin County News, Warsaw, KY
ordinance, franchise or olller directive agreed to by the Company. Proposes! Batt: There are no proposed changes to thlS rate.
CUrrent Rate:
Undergrou!!d Bealdent!al Distribution Pollcx.fllll UDP.ft IE!ectctc Tariff Sheet No. 98)
Single Family Houses. A. S2.15 per front foot !or all primary extensions. Primary extension on private property will be charged $2, 15 per linear trench foot; and B. An additional $2.00 per linear trench foot shall be charged where extremely rocky conditions 1118 encountered, such conditions belng defined as limestone or other hard stratified material m a conlinuous volume of at least one cubiC ya!d or more Which cannot be removed osmg ordmmy excavation equipment
Multi-Family Units. There shall be no ohar99 ~where extremely rocky conditions are encountered, then the $2.00 per linear trencll foot, as stated and defined abOve, shall be charged.
ProDOSld Rate: Single Family Houses
A. $2 .15 per front foot for all primaty extensions. Primary extension on private property Will be charged S2. 15 per linear trench foot; and a. An addttional $2.00 per linear tranch foot shall be charged where extremely rocky conditions are encountered such conditions being defined as limestone or other hard stratified material In a continuous volume or al least ooi: cubic yard or more which cannot be removed using ordinary excavation equipment
MulHamily Units. There shall be no charge~ where extremely rocky conditions are enoountered, then the $2.00 per &near trench foot, as stated and defined aboYe, shall be charged.
Targeted Underg10U11d for Service rmprovement No~1ths1andlng 1he aboYe Charges and upon Kentucky Public Service Commission awrova1, Company wlR 1'.9'a!Ve above charges, mamla1n, and take ownen;hip of customer seMoe llnes and equipment (curb, property line, Of service lateral to the meter base) to and including 1he eleetrlC meter. This provision applles only to Company designated installellons Identified to improve the reslHency of servl08 to the cuslomer.
The charges shall be the dlffetence between the Company's estimated co&t to provide an un<;lefground system and the Company's estimated cost to provide an overhead system. Jn addition to th& differential charge. the following provisions are applleable: Single Family Houses or Multi-Family Units.
The customer may be required to provide the necessary tranclllng, backfiling, conduit system (if required) and transformer pads in place to Company's specifications.
Commercial and Industrial UnitS. The customer shall:
Special Situations
a) Pl'O'Jtde lhe necessary trenchlng and backfilling, b) Fumlsh, install (concrete, if required), own and maintain an primary and/01 secondary conduit sys tem (wah spares, if required) on private property meeting applicable codes and Company's speotfica tions:and c) P1ovide the transformer pad and secondary conductors.
In those sftuallons where Ille Company considers the pad-mounted transfonner lnstallallons unsuitable, Ille cust~er shall provide the vault designed to meel National Electric Code, other appllcable codes, and Company spec11lcatlons, lhe conduit to the vault araa and the secondary Cllble lo the transformer terminals. The Company shall provide the transformers, the primary vault wiring and make the secondary connection to the transformer termlnals. !n large multiple cable lnstallaUons. the customer shall provide lh&cable, provlde and install the step bus mounted 1n the vault. and make necessary cable connections to the step bus lo the Company's specifications. The Company shall provide and lns1all connectJons from ltie transformer terminals to the step bus. The clJSlomer shall extend the bus duct into the vault to the Company's specificatiolls. The Compeny shall provide and Install connections from the transformer terminals to lhe bus duct.
Proposed Bate: The charges shall be the difference between the Company's estlmaled cost to provide an underground system and the Company's estimated cost to provide an overhead syst~. In addition to the differenUal charge, the foUowing provisions are applicable: Single Family Houses or Multi-Family Untts.
The customer may be required to provide the necessary irenchlng, backf1Ding. condutt system (if required) and transtormer pads in place to Company's specif1C81ioos.
Commercial and Industrial Units. The customer shall
Special Situations
a) Provide the necessary trenching and backfilling; b) Fumlsh. Install (concrete, 1f required), own end maintain au primaty and/or secondary conduit sys lam (with spares, ~ requited) on private property meeting appHcable codes and Company's speciflce tions;and c) Provide the transformer pad and secondary conductors.
In those Situations where the Company considers the pad-mounted translormer installations unsuitable, the cuslomer shalt pro~ide the vault designed to meet National Electric Code, other appllcable eodes. and Company specifications. the cor.dui1 to the vault area and Ille secondary cable to the transformer terminals. The ~ny shall provide the transformets, lhe primary vault wiring and make the second8ly connection to the transformer termlnals In large multiple cable installations, lhe customer shall provide the cable, ptovide end install the step bus ~nted in the vault, and make necessary cable connections to the step bus to the Company's spedficabons. The Company shall provide and install connecbons froni lhe transformer terminals to lhe step bus. The customer shall extend the bus duct into the vault to Ille Compeny's specifications. The Company shall provide and Install connections rrom the transformer terminals 10 the bus duct. Targeted Underground for Selvioe Improvement Notwithstanding the abOVe charges and upon Kentuoi<y Publie Service Commlsslon approval, Co•ny will waive above charges. malntaln, and take ownershlJ>of CIJS!omer service lines and equipment (curb, property line, or seMOO lateral to the meter base) to and lnclllding the eleclric meter. This provfSIOn applies only to Company designated Installations klenlif!ed to Improve the resiliency of Service to the customer.
CU!Tlfll Rate:
Beal Time Pdclng Promm· Batt RIP !Electric Iadff Sheet No, 991
BASELINE CHARGE The Baseline Charge is independent of customer's curren1ly monthly usage, and is designed to aclllf!Ve bbl
neutrality wilh 1he Customer's standard offer tariff n no change In eleetricity usage pattem occurs (less appllcable program charges). The Baseline Charge Is calculated at the end of the billing penod and changes each 1:111ing period to maintain bill neutranty for a Customer's CBL
The Baseline Charge will be calculated as follows: BC = (Standard Bill @ CBL) Where: BC : Baseline Charge Standard Bill @ CSL = Customer's bill for a apecifte month on the applicable Rate
Schedule Including applicable Standard Contract Riders using the CSL to establiSh the applicable bUllng determinants. The C8l shall be adjusted to reftect applicable metering adjuslmenls under 1he Bate Schedule. All applicable
riders shall be excli.Jdad from the calculation of the Baseline Charge. PRICE QUOTES
The Company will send to Cuslomer, Within two hours afte< the wholesale prices are published by PJM each day, Price Quotes to be charged the next day. Such Price Ouotes shall include the applicable Commodity Charge, the Energy Oellveiy Charge and the Ancillary Services Charge.
The Company may send more than one-day·ahead Price Quotes for weekends end holidays ldenlifled In Company's tarttfs. The Company may revise these priees the day before llley becOme elfec:tive.
The Company is not responsible for !allure of Customer to receive and act upon the Price Quotes. It is Customer's responsibility to Inform Compeny of any failure to receive the Price Quotes Ille day before they become effective. COMMODITY CHARGE The Commodity Charge Is a charge for generation The applicable hoor1y Commodity Charge (CredH) Shalt be applied on an hour by hour basls lo Customer's incremental (decremental) usage from the CBL
Charge (Credit) For Each kW Per Hour From The CBL:
Where.
For kWht above the CSL! , CCI ::: MVGt x LAF For kWht below the CBU • CCI : MVGt )( 80% x LAF
LAF
MVGt
:::
:;
:::
:;
loss ad/uslment factor 1.0530 for Rate TS 1.0800 for Ra1E1 DP 1.1100 for Rete OS Market Yalue Of Geneiation As Determined By Company for hoof t
The MVGt wlll be based on the expacted market price of capacity end energy for the next day. Tue expected market price shall be the PJM Real· lime Total Locatl0081 Marginal Price for power at the DEK Aggregate price node, inclusive of the energy, congestion end losses charges, for each hour. The kW per hour incremental or decremental usage from the CBL shall be adjusted to reflect applicable metenng adjust· ments under the standard Rate Schedule. ENERGY DELIVER CHARGE
Charge (Cred~) For Each kW Per Hour Frorn The CBL Sec:ondary Service ................................................. $0.006053 per kW Per Hour Primary Service .......... ... .. ............ .......... ....... ...... $0.005540 per kW Per Hour Transmission Service ........ .... ........... ................... ..• $0.002008 per kW Per Hout
ANCILLARY SERVICES CHARGE Charge (Credtt) For Each kW Per Hour From The CBL
Secondary Delivery ..................................................... $0.000760 per kW Per Hour Primary Delivery....................................................... $0.000740 per kW Per Hour Transmissloh Oehvery .. ...................... • . .. .............. $0.000721 per kW Per Hour
PROGRAM CHARGE Company will provide Internet based communlcallon software IO be used to provide Customer with the Pliee Quotes. Customer will be responsible for providing its own Internet access. A charge of $183.00 per billing period per Site shall be added to Customer's bill to cover the additional bHll!lg, administtatlve, and cost of oommunical mg the hourly Pnce Quotes associated with the ATP Program.
Proposed Rate: BASELINE CHARGE
The Baseline Charge is independent of Customer's currenuy monthly usage, and Is designed to achieve biU neutrarrty with the customer's standard otter tariff ii no change in electricity usage pattern oocurs (less applicable program cllerges) The Baseline Charge Is catculaled at the end of the billing period and changes eacf1 billing penod to mamtain bill neutrality for a Customers CSL
The Baseline Charge Will be caJculated as follows: BC= (Standard Bill @ CBLI Where:
BC = Baseline Charge Standard Bill @ CBL = Customer's bill for a specific month on Ille appftea.ble Rate
Schedule Including appllc~le Standard Contract Riders using the CBL to eslabfish the applicable billing determinants. The CBLshall be adjusted lo reflect applicable metering adjustments under ttie Rate Schedule All applicable
riders shall be excluded from the caloutation of the Baseline Charge, PRICE QUOTES
The Company will send to customer, within two hours after the wholesale prioes are pubrlShed by PJM each day, Price Quotes to be charged the next day. Such Price Quotes shall include the applicable Commodity Charge, the Energy Delivery Charge and the Ancillary Services Charge.
The Company may send more than one-day-ahead Price Quotes fOI weekends and holidays identified in Company's tariffs. The Company may revise these prices the day before they become effective.
The Company Is not responsible for failure of Customer to receive and act upon the Price Quotes. It is CUstomer's responsibilrty to inform Company of any failure to receive Ille Price Quotes the day before they become effective. COMMODITY CHARGE The Commodity Charge Is a charge for generation. The applicable hourly Commodity Charge (Credll) shall be applied Oh an hour by hoUr basis to Customer's lncremenlat (decremental) usage from the CBL.
Charge (Credh) For Each kW Per Hour From The CBL·
Where:
For kWh! above the CBLI , CCt = MVGt x LAF For kWht below the CBU , CCt = MVGt x 80% x LAF
LAF = loss adjustment factor 1.0530 for Rate TT
= 1.0800 tor Aate DP and Aate OT = 1.1100 for Rate OS
MVGt = Market Value Of Generation As Oetenrnned By Company for hour t The MVGt will be based on lhe expected mar1<et price of capacity and energy for the next day, The expecled market price shall be the PJM Day· Ahead Total Locational Marginal Pnce for power at the OEKAggregate pace node, inclusive of the energy1 congestion and losses charges. for each hour The kW per hour Incremental or decfementel usage from the CBL shall be adjusted IO reflect applicable metering adjustments under the standard Rate Schedule. ENERGY DELIVER CHARGE
Charge (Credtt) For Each kW Per Hour From The CBL Secondary Service ........................................... • ...... ,. S0.015412 per kW Per Hour Primary Service ......................................... , ....... ........ $0.012471 per kW Per Hour Transmlssion Service .................................................. $0.006472 per kW Per Hour
PROGRAM CHARGE Company will provide Internet based oommunica~on software to be used to provide Customer with the Pnce Quotes. Customer will be responsJble for providing its own Internet access. A charge of $183,00 per billing period per stte shall be added to Customer's bill to cover the additional billlng, administrative, and cost of communicating the hourly Price Quotes asSOciated with the RIP Program.
Meter Data Charges-Rate MDC Obis Schedule BenamecS u Meter Data Charges for Enhanced Usage Data Serv!ces·Rate MOC)
(Eleg!rlc Tad ft Sheet No. 101) current Rato: Electronic monthly interval data with graphical capability
accessed via the Internet (En·FOCl.ls"") eropoeed Bate:
$20 00 per month
Electronic monthly interval data with gtaphical capability accessed via the Internet with (EPO™) $20.00 per month
Duke Energy Kentucky proposes the following new rate and rider schedules: Rate LED, LEO Outdoor Lighting, Rider DC!. Dfslrlbution Cspltal Investment Rider, Rider FTR, FERC Transmission CoSt Re<:oncillatiOn Rider. and Rider ESM, Environmental Surcharge Mechanism. As lndlcaled above, the following schedules are proposed to be eliminated· Rate RTP·M {Real Time Pricing - Market Based Pricing), Rate OL (Outdoor Lighting Se<vi<:e), and Rate NSP (Private Outdoor Ughtlng for Non-Standard Units).
Propoad Bate: NET MONTHLY BILL
Rate LED- LED Outdoor Area Lighting Rate (Electric Tariff Sbeet No, 64\
Computed in accordance with the following charges: 1. Base Rate All kWh $0.041936 per kWh The rate shown above Includes a charge of $0.023837 per kilowatt-hour reflecilng the base cost of fuel. 2. AppliCable Riders The following riders are applicable pursuant IO the specific terms contained witllln eaeh rider: Sheet No 76, Aider ESM, Environmental Surcharge Mechanism Rider Sheet No. 80. Rider FAC, Fuel Adjustment Clause Sheet No 82, Rider PSM, Profit Sharing Mechanism Sheet No. 125, Rider DCI, Olstnbution Ca.pita! lnvestm!lOI Rider Sh~t No. 126, Rider FTA, FERC Transmission Cost Reconciliation Rider 3. Monthly Maintenance. Axture, and Pole Charges: Lflxtu!M 8illng l'ype
Hard working man Jayce Webster, 3, of Warsaw, is already a hard working young man.
Here, he works to clean condensation off his High St. front door. Help· ing him was his sister, Kensley, l . Photo by Kelley Warnick
Planting by the Signs
by Phil Case
Remainder of September Moon in dark phase for
below-ground producers thru Sept. 19; outstanding planting for the rest of today (Wednesday): no planting, Thursday and Friday; outstanding planting, Sept. 9-10; Sept. 11-12. bean sign; outstanding planting, Sept. I 3-14; no planting. Sept. 15-17; plant flowers, Sept. 18-19, 21; moon in light phase for above-ground producers Sept. 20 through Oct. 4; Ember Days, Sept. 20. 22-23, no planting; outstancting planting, Sept. 24; so-so planting Sept. 25 through Oct. I Last column of year
lt seems as if it was just last week we were talking about being patient. not planting in wet ground. waiting until after the danger of frost had passed ... and things such as those . . . at the beginning of the 2017 gardening season.
Now it's time to wrap it up for 2017 unless you are planting in hot beds or a greenhouse. The only veggies we can plant now in the unprotected garden. according to Home Gar-
dening in Kentucky, are leaf lettuce. radishes and spinach since they can withstand frost and colder weather.
While it's still warm and we're still harvesting. we know fall's just around the comer as is evidenced by fewer daylight hours and cooler temperatures. Clean up your garden
But before you stick your gardening tool~ in the back of the shed and service the tiller for winter: Remove spent plants from your garden and discard them.
The easiest thing for the tired gardener to do is just leave the plants where the last frost zaps them and worry about cleanup next spring. That. however, allows insects and diseases to winter over and be all set for yoar spring planting.
Talce just a little time and get the 2017 plants off your garden plot. Your 2018 garden will appreciate the extra effon! Last colu11m of 2017
This is my final Planting by the Signs column forthis year. There· s little sense in taking up space and time to
keep telling you what you know-only leaf lettuce. radishes and spinach can be planted now.
1 hope you've had a good year in the garden and you've at least given planting by the phases of the moon and signs of the zoctiac a try. T always appreciate your feedback and questions.
To that end, if you have questions 1 can help you with, save my contact information and be in touch. My monthly overview in the River Times will continue to appear-except in January when there is no River Times!
l hope you have a great fall. Thanksgiving, Christmas and New Year's and I will see you here on the pages of the Gallatin County News in January when it's time to talk about plowing - and then planting peas in February.
And. of course, I hope to see you around town. too. Be in touch
You may email me at pcase2l [email protected]: call or text 502-682-5995. My Facebook page that is devoted exclusively to planting by the phases and signs is PlantingByTheSigns.net and my Twitter handle is @
plantingbysigns, note I.here is no ''the'' in the Twitter account. lnformation for the next day is posted there on lhe afternoon before.
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859-581-5516 or 1-877-790-2233 plummerbankruptcy.com
lk
The Gallatin County News, Warsaw, Ky. - Wednesday, September 6, 2017 - Page 13
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Proposed Rider PCJ - Distribution Capital lnvestmem Rider (Electric Tariff Sheet No. 125}
~: CHARGES
The applicable energy or demand charge for electric service shall be increased or decreased to the nearest $0.000001 per kWh or $0.01 per kW to recover !he revenue requirement associated with incremental dislribubon caprtal costs incurred by the Company. ThlS Rider shall be adjusted penodically to recover amounts aulhoOzed by !he Commission. Rate Group Rate AS, Residential Service Rate EH1 Optional Rate ror Electnc Space Healing Rate GS.FL, Optional General Service Rate for Small Axed loads Rate SP, Seasonal Sports Service Rate SL Street Lighting Service Rate TL, Traffic Lighting Service Rate UOLS, Unmetered Outdoor Lighting Rate NSU, Street Lighting Service for Non·Standard Units Rate SC, Street Lighting Service - customer Owned Rate SE, Street Lighting Service - Overhead Equivalent Rate LED LEO Outdoor Lighting Electric Service
Rate OS. Service at Secondary Distribution Voltage Rate DP. SeMCe at Pomaiy 01stnbution Voltage Rate DT. TimEK>f-Oay Rate lor Servl(:e at 01stributlon Voltage - Primaiy Rate OT, Tlme-of·Oay Rate for SeMce at Distribution Vottage - Secondary
Proposed Rate: AIDER FTA FACTORS Rate Group Rate AS. Residential Service Rate OS, Service at Secondary Distribution Voltage Rate DP, Service at Primary Distribution Voltage Rate OT, 11me-ot·Day Rate for Service at DJstnbution Voltage Rate EH, Optional Rate for Electric Space Heating Rate GS.FL, General Service Rate for Small Fixed Loads Rate SP, Seasonal Sports Service Rate SL, Street Ughbng Service Rate TL Traffic Lighllng Service Rate UOLS. Unmetered Outdoor Lighting Rate NSU, Street Lighting Service for Non-Standard Units Aale SC, Street Ugh1ing Service - Customer Owned Rate SE, Street Lighting Service - OVerhead Equivalent Rate LED, LED Street Lighting Service Rate TI. Time-of·Day Rate for Service at Transmission Voltage Other
In addition, Duke Energy Kentucky proposes to change text of the following tanffs: Sheet No. 24 Servic9 Regulations Section V - Metering, Sheet No. 25 Service Aegulatlons Section VI - Biiiing and Payment, Sheet No. 98 Eloctric;lty Emergency Pr6ced\Jres for Long;Term Fuel St'iottages, and Sheet No. 100 Emel"gency Eleotnc Procedures.
The fotegotng rates reflect a proposed Increase 1n electric revenues ol approximately $48,646,213 or 14.96% over current total electric revenues to Duke Energy Kentucky. The estimated amount of increase per customer class is as follows: Rate RS. Residential Service! Rate OS, Service at OistrlbutiOn VOitage: Rate OT. Tlme-of·Day Rate for SeMce at Distribution Vohage: Rate EH, Optional Rate ror Electric Spate Healing: Rate SP. Seasonal Spor1s Service: Rate GS·FL. General Service Rate Tor Small Fixed Loads: Rate DP, Service at Primaiy OistributJon Vottage: Rate TT, lime-of-Day Rate for SeNlce at Transmission Vollage. Rate SL. Street Lighllng Service: Rate TL, Traffic Lighting Service: Rate UOLS, Unmetered Outdoor Lighting Electric Service: Rate NSU, Street Lighting Service Tor Non-Standard Units: Rate SC, Street Lighting Service-Customer Owned: Rate SE. Street Lighting Setvice-Overhead Equivalent: Bad Check Charge: Ctia1ge for Reconnection of Service (electric only)· Rate OPA, Aale for Distnbution Pole Attachments: Local Franchise Fee: Rate UD?·R, Underground Residential Distribution Poli~; Rate UDP·G, General Underground Distribution Policy. Rate RTP, Experimental Real 11me Pricing Program: (subset of other sc~edules)
Rate MDC, Meter Data Charges:
$22,855.269 or 17 36%; $13,198,789or1 ... 30%; $10,516,009 or 13 31%; $91, 708 or 14.23%: $3.343 or 11.41 %; $86,768 or 14.38%: $167,667 or 17.57%; $1.416,419or11.12%; $159,847 or 11.87%; $8,4130111.75%; $24,00Sor 11.71%; $7.352 or 11.86%; $435 or 11.72%; $22.6500111.85%: $0or0.0%; $0or0.0%; $60,176 or35.0%; SOor0.0%; $0010.0%; SOor0.0%; $87,538 or 14.87%:
SOorO.O%.
The ave~ge monthly bill for each customer class to which the proposed rates will apply Will Increase approximately as follows: Rate RS, Residential Service: Rate OS, Service at Distribution Voltage: Rate OT, Time·ol·Day Rate for Service at Distribution Voltage: Rate EH, Optional Rate for Electric Space Healing Rate SP, Seasonal Sports Service: Rate GS-FL, General Serv1Ce Rate for Small FIXed Loads: Rate DP. Service at Primary Distribution Voltage; Rate TT, Time-of-Day Rate for Service at TransmtsS1on Voltage. Rate SL Street Lighting Service; Aa1e TL, Traffic Lighting Service: Rate UOLS, Unmetered Outdoor Lighting Eleciric Service: Rate OL-E, Outdoor Lighting Equipment lnstallalion. Rate NSU, Street Lighting Service for Non·Standard Units: Rate SC, Street Lighting Service-Customer Owned: Rate SE, Street Lighting Service-overhead Equivalent: Bad Check Charge: Charge for Reconnection of Senlice (elecrnc only): Rate DPA, Rate tor Distribution Pole Attachments: Rate RTP. Experimental Real lime Pricing Program: Rate MOC, Meter Data Charges·
$15.17or17.1%, $114.53or14.3%; $3,848.79 or 13.5°'..; $98.45or 15.8%· $18.59or 11.7%; $8.29 or 14.9%: $3.269.60 Of 17.9%; $7,973.24 or 10.7%: Sl.15 Orl1 8%. $0.09or12.0%. $0.27or12.0%, $0or0.0%; so.aaor 11.9%, S0.21 or 11.7%, $0.92or 11.9%, $0 or O.Oo/o; $0 01 O.Oo/o; $1.53 or 35.0%; $1.887.21 or 15.6%; $0or0.00,o
The rates contained in this ootice are the rates proposed by Duke Energy Kentucky; however, the Kentucky Public Service Commission may order rates to be charged tllat differ from the proposed rates contained in this notice. Such action may resull in rates for consumers other than the rates rn this notice.
Any corporation, association, body politic or person with a SlJbslantial interest in the matter may, by written request within 1hirty (30) days after publlcat10n of thts notice of the proposed rate changes. request leave to intervene; intervention may be granted beyond the thirty (30) day period for good cause shown. Such motion shall be submitted to the Kentucky Public Service Commission, P. 0. Box 615, 211 Sower Boulevard, Frankfor1, Kentucky 40602-0615, Md shall set forth the grounds for the request including the status and interest of the party. If the Commlsslon does not receive a written request for intervention within thirty (30) days of the initial pubRcatloo the Commission may take final actlon on the application.
lntervenors may obtain copies of the application and other filmgs made by the Company by contacting Ms Minna Aoltes-Adkins at 139 East Fourth Street, Clncionab, Ohio 45202 or by telephone at (513) 287-4366. A copy of the applfcation aod other filings made by the Company 1s available for public Inspection through the Comm1SSion's website at hllo:t{Qsc,k,y.gov, at the Commission's offioe at 211 Sower Boulevard, Frankfor1. Kentucky, Monday through Fnday, 8:00 am. To 4:30 p.m .. and at the following Company offtces: 4580 Olympic Boulevard, Erianger, Kentucky 41018. Comments regarding the appfication may be sublllilled to the Pvbflc Service Commission through 1ts websi1e, or by mad at the following Commission address.
For further mfonnation contact
PUBLIC SERVICE COMMISSION COMMONWEALTH OF KENTUCKY P. 0. BOX 615 211 SOWER BOULEVARD FRANKFORT, KENTUCKY 40602-0615 (502) 564-3940
DUKE ENERGY KENTUCKY 4580 OLYMPIC BOULEVARD ERLANGER, KENTUCKY 41018 (513) 287-4315
•
rqt 10• W ..... J,~ 1.>,a11 • lDe._..mml\..Olllll;JMWS,·W..W,l\.I
poadl m ,_ opoclllc altllllioa. Wbca oon· slderia1 the options for ,_ ........... 111ollllt thla1 )'OU need IO do is ..... 1acyouraoil1e1Llf you have ADI takea soil Nmplel wlllH• the pml tlne)'Ollll,)'UUneedto coiled new - before mllldaa adec:illoa.
Prom the soil tal ... aul11, determine whit, if aaydlm,, 11 Umltlaa. In temaohollpH, the min· lmwn value depeoda on the type arr ..... )'OU ... producina. IC lt'a 11fa1Ca aad the pH 11 below 6D. you abould apply lime. A.....-lqumembture llllllllycantolcrllesoil pH c1owa to about S.8 1ad 1 pure _. ayllem .,.-ycan aodow• to pH S.!I bef°"' ylekb are atreded.
Similar-can be mode for plloopboius. (P) and pollllium (K) nUbltloo, wllh llfolf1 re· quhins 111o .- lad,,... -...i-1r-. roqulrin; Ibo laat.
Tho Unlvcnlty of Kentudty Colleae or Aariculturo recom1110rub P appllcDtlom 111ttlna
when the soil tal P level drops below liO pounds per ..,. lad ·K when soil lest K drops below JOO pouada per aero for .,.....aadleaumeo.IC you are arowlns alfalfa, we ......,mend 1ppllcotlons for K levcla below 4.lC> pouada per ocre.
If aoll test levda .,. above ti- oumben, the llkeUboad of a yield respo11111 to additloml Pud/orK fertWzeris atranely low. But if you want to be sure chat P alld K.,. ADI limit· Ina, apply Ce11111un u --·If )'OU
usume 101De risk dmt P lad K ml1bt mluce yield, you miPI allow soil tat 1e .. 11 to decline 6ull1er. Prom .... 11 plct raa.rcb, we bow dmt ~soil teal p drvpl .... low 30 pounds per ..,. llld/or loll tett K drops below 2IJO ......... per acn:, 1 yidd rapoue to odded Certillzor 11 lilldy, lherd'cmo; those would be the mlnlmum tol.,... llble levcla.
la lenns of nitrva•• (N) oppilcllliom, U'a a llnle Ille In tho aeuon to be puttlaa any N down. Of coune, Ill thu information ia pmty much useleaa without soil tat cloto. And Coll '• a .,...1 lime to loll test.
- Dirt ...... ...,. Dne H ... , G• 1o11ac-11-Apatr.-Aptmn.n.
