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(   (!- !--p2 C meters on the condition that others would continue in the spirit of(  #     -/2 f cooperation and progress -2 K 4-"2  Meter Numbering)$( Y2 4 - PHASER to coordinate - Initially Dave Bernauda to!$!!!$    $!- !--v2 TG provide a proposal within the week to address the SCE Appendix A issue.  #  #!$!! ! -n2 B SCE conceptually ok with pre-assigned block of non-AEP numbers if!$! #   !!!( -s2 @E necessary. Other interested parties - AMT / CellNet / GTE / PHASER /'  !)$ $'!!$!!!$-G2 ( O.R.A. - Solution to be proposed by 5/26'$!!  -2 *K 4-h2 .> Joint Meets for Complex Metering / MSP Employee Qualifications )$( ) )!!!( '   2 .D SCEs!$! - !a--w2 H safety concerns and their current demand for joint meets may be reduced (  ((-q2 D or eliminated if adequate interim MSP Employee Qualifications can be (    ()!!!( '   -h2 > implemented. To address this issue, PHASER agreed to propose ( (  !$!!!$-q2 D qualifications and communicate to the other MSPs and to the UDCs. To   (( )!!$$$-/2 | be communicated by 5/26.(( -2 K 4-G2 ( Scheduling problems / missed commitments!  (( (( (82 h - Two short-term deliverables#(  - !'--2 j First h2 j> - Don Fellows to provide proposal for an alternative to Meter$ #    )- !c--n2 B Installation date as DA switch date. Mention was also made of the  $!# ) # (-v2 VG possibility of using 3 days past paperwork submission for the DA switch   #(  $!# -2  date. 2 " Second!b2 : - confusion over information flows was identified. Roger  (  ##   $- !"--n2 B B McCall of Scott, Madden (for PHASER) to document information flows)$ !)!$!!!$( (  #-v2 G prior to 5/26. It was agreed that the Meter Specific Information Flows #)!  (  #-a2 . 9 Workshop Report would be consulted as input to this task.2$#    -  XT 4  @@``@T 4@`0@T 4AG{,@T 4$$HHkk\ 4$$HHkktT 4 ET 4T 4  \ 4$$HHkkS T 4^PI@ |L <Times New RomanL <"ArialL <Times New RomanL <Times New Roman4b(bL <SymbolL <WingdingsL <Monotype SortsL <"ArialL <Times New Roman $3f3)B*  M,O,,\,PddddLdddddd M  O  \ PTdZdZUL-dZUAZQdZ M  O  \ PddddLdddddd MO\PddddLddddddP MO\PddddLdddddd MO\Pddd0dTL<K0dd0dd0d M,O,,\,Pddd0dLd0dd0dd0d MO\PL MO\PPL   ( 800t:'PbD$42dd3 5//0011h p @ p  H./04x$̙  (@ p 800b  W  b ( Pt  800b:'Pb$/: '5Objectives of This Document</,/bX0H04dd(11   b ( Pw  800bW'Pb'$Dw  51) Document, at a high level, the three meter installation processes in use by the California UDCs 2) Highlight the specific differences between the processes, including advantages and drawbacks 3) Propose a revised process that can be used by all three utilities, the ESPs and MSPs</,/  b00c4 TdZa4 TdZW4 TdZ@101   R (n 800:'Pb$QS4p["5No change to this page</,/  3bX0H04 dd(11 @ pb  H./04x$̙  (@ p 800b } D  b ( Pt  800b:'Pbl$D/: 5Contents</,/HbX0H04Hdd(11H   b ( Pw  800b5'Pb$Dw 42TdZ3 5Executive Summary 3 Process Description Scenario / Assumptions 4 Process Comparisons 5 Process Comparison Summary 10 Recommended Process 11 Going Forward 14 D/4/L bL 3bL bL 3bL bL 3bL bp0`04LTdZ4LTdZ14LTdZ4LTdZ4LTdZ4LTdZ#4LTdZ4LTdZ4LTdZ4LTdZ4LTdZ4LTdZx1h1L*LLLLLLLLLLLLLL z ^ ^  800 z   800 z ' '  800 z mx x  800 z 2  800 z + +  800@ pb  H./04x$̙  (@ p 800b # N  b ( Pt  800b:'Pbv$D/: 5Executive Summary </,/ZbX0H04Zdd(11Z   b ( Pw  800bT 'Pb$ $Dw  |5Major Recommended Changes Develop common electronic format for communication of meter information from and to UDCs SIMPLIFY MDCR process Benefits Reduction of coordination requirements at UDCs and ESP / MSPs Crucial information still provided after installation Scheduling / rescheduling reduced Pre-installation communication reduced Acceleration of electronic communication capabilities Reduced work order system programming for ESPs and MSPs Reduced record keeping training for ESP / MSP field forces Major Impacts Modification of M3 / JIS / I or C (PG&E), MI (SCE), and MDCR (SDG&E) Elimination of Appendix A process (SCE) (//^bZ^ b^ 3b^ b^ b^b^ bg^ b^b^ b"^ b^ b^ b^ b ^ b^ fb"^ b^ b004^TdZZ4^dZ4^dZ4^TdZ4^TdZ4^TdZ4^TdZ4^TdZ4^TdZ 4^TdU>4^dU64^U-dU"4^U-dU'4^U-dU64^dU94^dU;4^dU4^TdUE4^dU(4^dU(11|^ G يP #  (n 800b  (Q#}  800b:'Pb$@C dk75Step 1 UDC Provides as - is meter information to ESP / MSP with joint meet requirements Step 2 ESP / MSP notifies UDC of installation plans 1 day prior (3 days for joint meets - meter reading schedule can be taken into account) Step 3 ESP / MSP provides completion information within 3 days of installationD/4/bbRbbbbHbx0h0X4dd4dd4dd4ddN4dd(117 R (ّn 800 P:'Pb$S4p["5No change to this page</,/\ 3bX0H04\dd(11\ @ pb  H./04x$̙  (@ p 800b  f  b ( Pt  800b:'Pb$/: 6*5Process Description Scenario / Assumptions</,/*0bX0H0*40dd(11*0   b ( Pw  800b]'Pb-$w 5The process comparison in the next section reflects the following assumptions for each UDC A new interval meter will be provided by the ESP The ESP has hired an MSP other than the UDC to install and maintain the meter The UDC is not the MDMA</,/` b00 0[4`TdZ14`dZN4`dZ4`dZ(11` R (n 800:'Pb$S4p["5No change to this page</,/u 3bX0H04udd(11u48@ pb  H./04x$̙  (@ p 800b 6 N  b ( Pt  800b:'Pbv$/: 5Process Comparison</,/8bX0H048dd(118  (6p 800-:'Pb$p6q5Initiation and identification of requested meter service option Provision of metering data Job ID</,/q bh0X0@4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd(11q @ (&: 800:'Pb$`Kh5DASR</,/ bX0H04dd(11 ( (e: 800:'Pbh$@+5DASR</,/ bX0H04dd(11 ( (: 800:'Pbh$5DASR</,/ˆ bX0H04ˆdd(11ˆ  (V y 800:'Pb$ \|p5CELLNET summarizing the process differences associated with determining 50kW threshold prior to DASR submission</,/pTƈ bX0H0p4Tƈdd(11pTƈ A (&P' 800:'Pb$` ;]5Paper JIS, M3 and I or C forms provided with meter in formation Job Number on JIS</,/]ʈ b00@4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd4ʈdd(11]ʈ ] (v' 800:'Pb$f M-15Electronic MDCR provided DASR Number</,/14ψ bH08044ψdd44ψdd44ψdd44ψdd44ψdd44ψdd44ψdd44ψdd44ψdd44ψdd44ψdd44ψdd44ψdd44ψdd 44ψdd(1114ψ Y (' 800:'Pb$ 3M)-5Paper MI form provided MI Number</,/-0׈ bH08040׈dd40׈dd40׈dd40׈dd40׈dd40׈dd40׈dd40׈dd40׈dd40׈dd40׈dd40׈dd40׈dd40׈dd 40׈dd(11-0׈  (V A 800:'Pb$ $3f42dd3 5SCE MI and SDG&E MDCR forms were developed specifically for Direct Access and are 1 page each. PG&E forms (3) are output from existing systems and include non-essential information and do not provide a meter form number (data required to determine the form # is included) //@ވ b@ވ b@ވ fbQ@ވ b@ވ b@ވ bX0H04@ވdd(11@ވ z p@P @  800 H (q6X 86P00:'Pb$; 5Process Step</,/ PbX0H0 4Pdd(11 P , (q X 86P00:'Pbl$  ;5Comment </,/$bX0H04$dd(11$ z   800 z   800  (f< 86P00D#f  (h: 86P00D  (R6 86P00D : (n 86P00:'Pbz$K4h"5No change to this page</,/ 3bX0H04dd(110@ pb  H./04x$̙  (@ p 800b Z/ Z  b ( Pt  800b:'Pb$/: *5Process Comparison (continued)</,/HbX0H04Hdd(11H  يP  z p@P @  8b00 0 (q6X 86P00:'Pbp$; 5Process Step</,/ UbX0H0 4Udd(11 U , (q X 86P00:'Pbl$  ;5Comment </,/YbX0H04Ydd(11Y z   800 z   800  (f< 86P00D#f  (h: 86P00D  (R6 86P00D  (ّ6p 800 P:'Pb]$Ep6g95Provision of meter numbers Meter Installation</,/9M b004Mdd4Mdd4Mdd4Mdd4Mdd4Mdd4Mdd4Mdd4Mdd4Mdd4Mdd4Mdd4Mdd4Mdd(119M  (ّ&P 800 P8:'Pb$E`v;VH5Provides a range of meter numbers to be used. 1 - 5000 numbers providedh/X//Q bQ 3bX0H0H4Qdd@101,QQ  (ّvv 800 Pv:'PbF$E<v5Provides a range of meter numbers - specific number must be on MDCR. Assignment is prior to install. Numbers are in 9,000,000 seriesh/X/FTe b@Te 3bX0H04Tedd@101CTeCTe B (ّ 800 P:'Pb$EO*5Uses the AEP number on the meter Requires Appendix A for registration of meter numbers (AEP numbers) 2 weeks prior to installation of a meter</,/`i b00!4`idd4`iddl4`idd(11`i  (ّV"  800 Pi:'Pb9$E  5SCE Appendix A process effectively eliminates the possibility of receiving just in time inventory. SDG&E process allows for identification of detailed meter specifications prior to the installation and specific meter identification after the installation. PG&E process requires no communication of meter information until completion. Five day notification tends to encourage overscheduling and require extensive rescheduling. SCE process allows for notification via MI or other 5 day schedule such as spreadsheet. .p/`/ln b`ln bln fbln bln bln bln bWln 3b00 0Q4lndd4lndd]4lnddZ4lndd11~lnlntlnPln9ln%ln lnMlnln I (ّ& 800 P:'Pb$E`^_1u5Thursday notification for next weeks schedule via e-mailed spreadsheets - Reschedules accommodated without 5 days</,/uv bx0h0K4vdd4vdd4vdd4vdd'4vdd11v@vv v vv  (ّv 800 PY:'Pb)$EE]5Five business day notification via Electronic MDCR Reschedules accommodated without 5 days</,/]| bx0h034|dd4|dd4|dd4|dd'4|ddX1H1B| ||  (ّJ 800 P:'Pb^$EOg25Five business day notification via e-mailed spreadsheet or MI Returned w/ Schedule and AEP range Load scheduling and billing are issues that require the five days Reschedules accommodated without 5 days//8\ b\ b'\ bA\ 3b(\ b00 0;4\dd&4\ddB4\dd'4\dd118\\&\B\ \ \\ @ pb  H./04x$̙  (@ p 800b ' Z  b ( Pt  800b:'Pb$/: *5Process Comparison (continued)</,/PEbX0H04PEdd(11PE  يP z   8P00 0 (66P 8P00:'Pbp$pp\ 5Process Step</,/ bX0H0 4dd(11  , (F 6P 8P00:'Pbl$p 5Comment </,/ЎbX0H04Ўdd(11Ў z P  8P00 z ``P  8P00  (L>6P 8P00D#f  (> 6P 8P00D  (C06P 8P00D  (ّ6p 83P00 Pg:'Pb7$p6v+5Meter Installation (continued) Joint Meets</,/+Z 3b004Zdd4Zdd 4Zdd(11+Z N (ّ&Py 83P00 P:'Pb$`\;V:5 Only for IDR meters that cant be read remote or by MSP</,/: 3b00 04dd4dd4dd74dd(11: N (ّvvy 83P00 P:'Pb$<\v:5 Only for IDR meters that cant be read remote or by MSP</,/:<ȏ 3b00 04<ȏdd4<ȏdd4<ȏdd74<ȏdd(11:<ȏ u (ّ 83P00 P:'Pb$OgE5 VAR Meters IDR meters Totalizer or quantum meter Transformer loss compensation Co-Gen or bi-directional metering Other special circumstances as defined by EDISON MSP requests</,/͏ 3b004͏dd4͏dd4͏dd 4͏dd 4͏dd4͏dd4͏dd"4͏dd14͏dd 4͏dd(11͏ W (ّV"  83P00 P:'Pb$ '5 SCE has removed the requirement for VAR Meter joint meets. A s a portion of other planned analysis of meterman qualification requirements //a ba ba 3ba b00 04add4add4add4addX1H1aaa.@ pb  H./04x$̙  (@ p 800b , Z  b ( Pt  800b:'Pb$/: *5Process Comparison (continued)</,/bX0H04dd(11 z x  800 ` يP < z p8P 8  8b00 0 (i6P 86P00:'Pbp$3 5Process Step</,/ xbX0H0 4xdd(11 x , (i P 86P00:'Pbl$  35Comment </,/DbX0H04Ddd(11D z x  800  (f4 86P00D#f  (h2 86P00D  (R. 86P00D  (ّ6p 800 P:'Pb$p6X45Meter Installation (continued) Completion </,/4p bp0`04pdd4pdd4pdd4pdd4pdd4pdd4pdd4pdd4pdd4pdd4pdd 4pdd(114p < (ّ&P; 800 P:'Pb|$`;" $5VAR hour meters left in place PG&E must remove locking rings This is a business policy decisions Requires minimum of two pieces of paper (old M3, new M3). Up to five or more may be required (M3s plus Worksheet plus I or Cs) (these requirements are driven by the use of legacy systems)//B b# 3b b 3bj b< 3b004dd4dd4dd4dd4dd4ddC4dd4dd:4dd4dd11A$i=  (ّ 800 P:'PbW$35VAR hour meters removed at SCE convenience MSPs issued lock ring keys One form, Appendix F, Meter Installation Notification// b& 3bY b00+4dd4dd4dd4dd4dd4dd4dd4dd4dd54dd11")  ; (ّV 6 800 P:'Pb{$  k5SCE has modified original policy, eliminating requirement for VAR meter removal Issuance of lock ring keys simplifies the process significantly PG&E paperwork requires FedEx vs fax because of the tiny print. It also takes significantly more time to complete and track because of the number of pieces of paper and varying requirements for form completion. // b bK 3bD b b bP0@0Q4dd4dd4dd4dd@4dd4dd4dd4dd11KA  (ّD 8300 P%:'Pb$T l/"5VAR hour meters left in place MSPs issued lock ring keys (limited) One form, Service Order Completion form (currently paper)// b 3b& b 3b( b 3b(004dd4dd4dd4dd4dd4dd&4dd4dd4dd4dd94ddp1`1H(/@ pb  H./04x$̙  (@ p 800b  Z  b ( Pt  800b:'Pb$/: *5Process Comparison (continued)</,/bX0H04dd(11 ` يP < z p8P 8  8b00 0 (i6P 86P00:'Pbp$3 5Process Step</,/ ΊbX0H0 4Ίdd(11 Ί , (i P 86P00:'Pbl$  35Comment </,/TҊbX0H04TҊdd(11TҊ z x  800  (f4 86P00D#f  (h2 86P00D  (R. 86P00D 0 (ّ6p: 800 P:'Pbp$Ep6 5Meter Return</,/ Ɗ bX0H0 4Ɗdd(11 Ɗ A (ّ&P 800 P:'Pb$E`)5Ten days - paperwork required</,/Tʊ bX0H04Tʊdd(11Tʊ T (ّ 800 P:'Pb$E3$5Five days - no paperwork</,/Xڊ bX0H04Xڊdd(11Xڊ  (ّV y 800 P:'Pb$E \ay5PG&E ten day return policy provides additional flexibility. SCE and SDG&E minimal paperwork requirements reduce cost. //ߊ b9ߊ bߊ bߊ bߊ 3b.ߊ bX0H0y4ߊdd(11yߊ C (ّD 8300 P:'Pb$ET +5Five days - identification only</,/ bX0H04dd(11 z x  800ّ : (ّn 86P00:'Pbz$QK4h"5No change to this page</,/l 3bX0H04ldd(11l @ pb  H./04x$̙  (@ p 800b  V  b ( Pt  800b:'Pb~$D/: &5Process Comparison Summary</,/$bX0H04$dd(11$   b ( Pw  800bJ 'Pb $w  42TdZ3 5Each of the processes has some very positive aspects. These are listed below by UDC. Single schedule notification / schedule flexibility No need to pre-identify specific meters Ten day meter return requirements Electronic communication !! Single MDCR Single completion document Single schedule notification Lock ring keys provided No need to pre-identify specific meters Single MI Single completion document Use of AEP number for meter number Lock ring keys provided No returned meter paperwork //X< b < b< b|< b00V4<TdZ4<TdZ4<TdZ44<dZ(4<dZ"4<dZ4<dZ4<dZ4<dZ 4<dZ4<dZ4<dZ4<dZ(4<dZ4<TdZ4<TdZ 4<dZ4<dZ#4<dZ4<dZ4<dZX1H1 < <<  (}i 800D#f  ( f 800D  (D?1 800D  (bu  800:'Pb$; R5These positive features can be combined to create a significantly improved process</,/RшbX0H0R4шddX1H17шшш : (n 800:'Pbz$K4h"5No change to this page</,/L4 3bX0H04L4dd(11L4>= @ pb  H./04x$̙  (@ p 800b ; f  b ( Pt  800b:'Pb$/: 6*5Recommended Process for Meter Installation</,/*LbX0H0*4Ldd(11*L  (6pj 800:'Pb$p6M_k5Initiation and identification of requested meter service option Provision of metering data Job ID//]8 b8 3b 8 b00@48dd48dd48dd48dd48dd48dd48dd48dd48dd48dd48dd48dd48ddX1H1e888 ( ({: 800:'Pbh$5DASR</,/ bX0H04dd(11  (&P 800<:'Pb $`;42dd3  5 </,/  bp0`04dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd4dd(11   (u 800:'PbX$%XD5Electronic file of consistent structure and format DASR Number//2  b  3b  bP0@034 dd4 dd4 dd4 dd4 dd4 dd4 dd 4 ddp1`12     M (| 800:'Pb$542dd3 }5The metering data provided by the three UDCs is consistent One UDC currently using DASR # - two would need to switch </,/}8 bP0@0<48dd48dd48dd48dd48dd48dd48dd;48ddp1`1J8 8)88 z p@P @  800 H (q6X 86P00:'Pb$; 5Process Step</,/ hbX0H0 4hdd(11 h , ( qX 86P00:'Pbl$F;5Comment </,/<bX0H04<dd(11< z   800 z   800  ([ 86P00:'Pb$f+>h5Recommended Process</,/$b00 4$dd4$dd(11$ z qq  800 z   800 A (qX 86P00:'Pb$,X;)5Cost </,/D)bX0H04D)dd@101D)D) \ (|q X 86P00:'Pb$ ;,5Benefit </,/H-bX0H04H-dd@101H-H-  (3 86P00@:'Pb$4Y42dd3 5 The on-going efforts o f the three UDCs to computerize the meter data function would need to be coordinated Cost of changing MI number (SCE) and Job number (PG&E) to DASR //L1 bL1 bL1 bL1 b L1 b004L1dd4L1dd4L1dd4L1dd4L1dd4L1dd4L1dd4L1ddm4L1dd4L1dd4L1dd4L1dd4L1dd?4L1dd@101L1L1  ( 3 86P00:'Pb$%4 Yp5 All MSPs and ESPs would avoid the cost of creating multiple interfaces and training personnel to address each format One common way to identify orders - reduced system development costs at ESPs / MSPs</,/6 b0046dd46dd46dd46dd46dd46dd46dd46ddv46dd46dd46dd46ddS46ddX1H1}66V6 5 (@c 86P00:'Pbu$2z)b5UNDER DEVELOPMENT</,/3bX0H04dd(11  (EP' 836P006@ pb  H./04x$̙  (@ p 800b @5 f  b ( Pt  800b:'Pb$/: 6*5Recommended Process for Meter Installation</,/*DbX0H0*4Ddd(11*D  (6p 800B:'Pb$p642dd3 :5Provision of Meter Numbers Meter Installation </,/:H b004Hdd4Hdd4Hdd4Hdd4Hdd4Hdd4Hdd4Hdd4Hdd4Hdd4Hdd4Hdd4Hdd4Hddp1`1HHHH  ( 800o:'Pb?$%5AEP number or pre-assigned UDC number Notification on day prior to installation - three days for joint meets VAR hour meters left in place</,/0N b(00&40Ndd40Ndd40Ndd40Ndd40Ndd40Ndd40Ndd40NddH40Ndd40Ndd40Ndd1x1 0N0N0N0Nw0N  (|i 800:'Pb$LV42dd3 5Either method is acceptable - provided there is no need to pre-identify specific meters before installation (meter specifications can be provided prior to installation) Only an issue in SCE territory </,/U bP0@04Udd4Udd4Udd4Udd4Udd4Udd4Udd4Udd@101UU z p@P @  800 H (q6X 86P00:'Pb$; 5Process Step</,/ X_bX0H0 4X_dd(11 X_ , ( qX 86P00:'Pbl$F;5Comment </,/,cbX0H04,cdd(11,c z   800 z   800  ([ 86P00:'Pb$Qf+>h5Recommended Process</,/ hb00 4 hdd4 hdd(11 h z qq  800 z   800 A (qX 86P00:'Pb$Q,X;)5Cost </,/4mbX0H044mdd@1014m4m \ (|q X 86P00:'Pb$Q ;,5Benefit </,/8qbX0H048qdd@1018q8q  ( 86P00(:'Pb$E42dd3 5There should be little to no cost associated with this, although SCE Appendix A process would need to be dropped None anticipated Possible cost to SCE of removing VAR hour meter, and of reinstalling VAR hour meter in future //Ah5Recommended Process</,/b00 4dd4dd(11 z qq  800 z   800 A (qX 86P00:'Pb$,X;)5Cost </,/豋bX0H04豋dd@101豋豋 \ (|q X 86P00:'Pb$ ;,5Benefit </,/쵋bX0H04쵋dd@101쵋쵋 ` (` 86P00:'Pb$C042dd3 5Cost of keys Cost of coordinating to develop a consistent form and alter on-going electronic data gathering None anticipated </,/ bp0`04dd4dd4dd4dd4dd4dd4dd`4dd4dd4dd4dd4dd@101  (  86P00:'Pb$% O#5Fewer trips to field by UDC - reduced coordination required - less time cutting lock rings off. Improved accuracy as a result of increased field familiarity - Reduced MSP / ESP programming cost associated with developing multiple formats Reduced paperwork and increased return flexibility</,/# bx0h0a4dd4dd4dd4dd24dd(11#  ( P 836P00 5 (^SM 86P00:'Pbu$pG05UNDER DEVELOPMENT</,/3bX0H04dd(11  @ pb  H./04x$̙  (@ p 800b  K  b ( Pt  800b:'Pbs$/: 5Recommendations</,/ˋbX0H04ˋdd(11ˋ   b ( Pw  800b*'Pb$w 5Reaffirm participants desire to work toward a common process Validate the differences as identified in this draft Assign empowered individuals from each UDC and interested ESP / MSPs to design a process and information formats that can be implemented state-wide</,/ϋ b00=4ϋdZ54ϋdZ4ϋdZ(11ϋ  (1 800Ad3\/hd\&|bݻpb|b(cwB3  xyR fP!bxObject2DocumentWord.Document.6-Microsoft Word Document@   s (|! 800:'Pb$C75Issue resolution activities from 5/12 minutes and notes</,/73bX0H074dd(117 z   8300k @ pb H./04x$̙  (@ p 800b  ^ b ( Pqon 800b9 'Pb$VN."5Meter Installation Process Summary</,/" ؋bX0H0"4 ؋dd(11" ؋ Q b ( Pq9 800b'Pby$q9!5Rule 22 Working Group</,/T܋bX0H04T܋dd(11T܋  (  800 d (9 800:'Pb$Ss}p{[4(5RED Text identifies changes / additions</,/( 3bX0H0(4dd(11(P3 R@ pb$73f3ff33$7MMMe3f$7___ H./04x$̙  (@ p 800b  \ b ( Pt  8b:'Pb$/: , 5Click to edit Master title style</,/ bX0H0 4dd(11  2 b ( Pw  800b'PbZ$w R5CLICK TO EDIT MASTER TEXT STYLES First Level Second Level Third Level Fourth Level//! b b  b  bx0h0!4TdZ 4dZ 4U-dZ 4UAZ 4QdZ(11R = b ( P@ 800b:'Pbe$z  5*</,/bX0H04dd(11 = b ( P 800b:'Pbe$@  5*</,/<bX0H04<dd(11< = b ( P  800b:'Pbe$@ K  5*</,/ bX0H04dd(11 \ (v8~ 8'Pb$Av8~o, 5Scott, Madden & Associates, Inc.</,/ l bX0H0 4ldd(11 l c (c|  8:'Pb$@B K'5DRAFT PHASER Advanced Metering Services</,/'( bX0H0'4(dd@101(!( z qz  8 z w   8 j (v 86P00:'Pb$QZwb:.5Updated to reflect 5/12 meeting clarifications</,/.| bX0H0.4|dd(11.| PNM Work.pot@ pّ  H./04x$̙  (@ p 800b 2 _  b ( Pq9 800b'Pb$Dq9/#5Click to edit Master subtitle style</,/#bX0H0#4dd(11# \ b ( Pqon 800b9 'Pb$DVN, 5Click to edit Master title style</,/ bX0H0 4dd(11  x (Yo 8'Pb$EYo#H 5May 19, 1998</,/  bX0H0 4 ddX1H1     (  8  (T 800 5'Pb$9H5Scott, Madden & Associates Atlanta l Dallas l Morristown l Raleigh //"  b  b  b  b  b  b  b  b   b  b  b  b004 @dd-4 @dd(11H  * (c|  8:'Pbj$B  5 DRAFT</,/< bX0H04<dd(11<  (| 800D = b (p  800:'Pbe$  5*</,/bX0H04dd(11 = b (  800:'Pbe$ V  5*</,/bX0H04dd(11 = b (p 800:'Pbe$ V 5*</,/ bX0H04 dd(11  j (v 800:'Pb$Zwb:.5Updated to reflect 5/12 meeting clarifications</,/.V bX0H0.4Vdd(11.Vf'p@ + PH./04x$̙33  (p@ 800b  =  b ( P 800b 'Pbe$ 5*</,/& bX0H04&dd(11& = b ( P p 800b 'Pbe$,d 5*</,/x+ bX0H04x+dd(11x+  b ( P`p 800bD  b ( Pp0  800b:'Pb$ s ~R5Click to edit Master text styles Second level Third level Fourth level Fifth level</,/R0 bx0h0!40dd 40dd 40dd 40dd 40dd(11R0 = b ( P @  800b 'P#be$# @  5*</,/5 bX0H045dd(115 = b ( P  p@  800b 'P#be$#, d@  5*</,/9 bX0H049dd(119b D _VBA_PROJECT04PdPdPdPd|D4ddddddddN, $de, PowerPoint DocumentOh+'0 px   , 8 DPXHigh Level Framework Roger McCall#C:\MSOffice\Templates\PNM Work.pot Roger McCall14Microsoft PowerPoint@`!@T@<@ؿ U1G1% ?&`2 &&TNPP8Q=Pu & TNPP &&TNPP  ` j: "--  :`"Arial-. "Arial-. Times New Roman -.   2 1Times New Roman-.  672  Scott, Madden & Associates, Inc. + & "    - @1Times New Roman -.  2 nDRAFT&%& " 2 lDRAFT&%& " 92 n!PHASER Advanced Metering Services (&#% & 1  92 l!PHASER Advanced Metering Services (&#% & 1  --"Systemn-@E "-ll?--'--@H "-B--'Times New Roman -.  BL2 -.Updated to reflect 5/12 meeting clarifications#      "      Times New Roman-.  02 Objectives of This DocumentF0+**+%050%F0*0F*0Times New Roman -.  \ 2 1) \2 ;_Document, at a high level, the three meter installation processes in use by the California UDCs#(        (         #  "##Times New Roman-.  \ 2 2) \2 ;\Highlight the specific differences between the processes, including advantages and drawbacks&        "        "Times New Roman -.  \ 2 d3) \2 d;TPropose a revised process that can be used by all three utilities, the ESPs and MSPs                   .Times New Roman-.  3\(2 )_No change to this page      &TNPP &---՜.+,0 `h  4On-screen ShowH ArialMonotype SortsSymbolTimes New Roman Wingdings PNM Work.potMicrosoft Word DocumentObjectives of This Document ContentsExecutive Summary +Process Description Scenario / AssumptionsProcess ComparisonProcess Comparison (continued)Process Comparison (continued)Process Comparison (continued)Process Comparison (continued)Process Comparison Summary+Recommended Process for Meter Installation+Recommended Process for Meter Installation+Recommended Process for Meter InstallationRecommendations#Meter Installation Process Summary  Fonts UsedDesign TemplateEmbedded OLE Servers Slide TitlesObjectives of This Document 1) Document, at a high level, the three meter installation processes in use by the California UDCs 2) Highlight the specific differences between the processes, including advantages and drawbacks 3) Propose a revised process that can be used by all three utilities, the ESPs and MSPs No change to this page Contents Executive Summary 3 Process Description Scenario / Assumptions 4 Process Comparisons 5 Process Comparison Summary 10 Recommended Process 11 Going Forward 14 Executive Summary Major Recommended Changes Develop common electronic format for communication of meter information from and to UDCs SIMPLIFY MDCR process Benefits Reduction of coordination requirements at UDCs and ESP / MSPs Crucial information still provided after installation Scheduling / rescheduling reduced Pre-installation communication reduced Acceleration of electronic communication capabilities Reduced work order system programming for ESPs and MSPs Reduced record keeping training for ESP / MSP field forces Major Impacts Modification of M3 / JIS / I or C (PG&E), MI (SCE), and MDCR (SDG&E) Elimination of Appendix A process (SCE) Step 1 UDC Provides as - is meter information to ESP / MSP with joint meet requirements Step 2 ESP / MSP notifies UDC of installation plans 1 day prior (3 days for joint meets - meter reading schedule can be taken into account) Step 3 ESP / MSP provides completion information within 3 days of installation No change to this page Process Description Scenario / Assumptions The process comparison in the next section reflects the following assumptions for each UDC A new interval meter will be provided by the ESP The ESP has hired an MSP other than the UDC to install and maintain the meter The UDC is not the MDMA No change to this page Process Comparison Initiation and identification of requested meter service option Provision of metering data Job ID DASR DASR DASR CELLNET summarizing the process differences associated with determining 50kW threshold prior to DASR submission Paper JIS, M3 and I or C forms provided with meter in formation Job Number on JIS Electronic MDCR provided DASR Number Paper MI form provided MI Number SCE MI and SDG&E MDCR forms were developed specifically for Direct Access and are 1 page each. PG&E forms (3) are output from existing systems and include non-essential information and do not provide a meter form number (data required to determine the form # is included) Process Step Comment No change to this page Process Comparison (continued) Process Step Comment Provision of meter numbers Meter Installation Provides a range of meter numbers to be used. 1 - 5000 numbers provided Provides a range of meter numbers - specific number must be on MDCR. Assignment is prior to install. Numbers are in 9,000,000 series Uses the AEP number on the meter Requires Appendix A for registration of meter numbers (AEP numbers) 2 weeks prior to installation of a meter SCE Appendix A process effectively eliminates the possibility of receiving just in time inventory. SDG&E process allows for identification of detailed meter specifications prior to the installation and specific meter identification after the installation. PG&E process requires no communication of meter information until completion. Five day notification tends to encourage overscheduling and require extensive rescheduling. SCE process allows for notification via MI or other 5 day schedule such as spreadsheet. . Thursday notification for next weeks schedule via e-mailed spreadsheets - Reschedules accommodated without 5 days Five business day notification via Electronic MDCR Reschedules accommodated without 5 days Five business day notification via e-mailed spreadsheet or MI Returned w/ Schedule and AEP range Load scheduling and billing are issues that require the five days Reschedules accommodated without 5 days Process Comparison (continued) Process Step Comment Meter Installation (continued) Joint Meets Only for IDR meters that cant be read remote or by MSP Only for IDR meters that cant be read remote or by MSP VAR Meters IDR meters Totalizer or quantum meter Transformer loss compensation Co-Gen or bi-directional metering Other special circumstances as defined by EDISON MSP requests SCE has removed the requirement for VAR Meter joint meets. A s a portion of other planned analysis of meterman qualification requirements Process Comparison (continued) Process Step Comment Meter Installation (continued) Completion VAR hour meters left in place PG&E must remove locking rings This is a business policy decisions Requires minimum of two pieces of paper (old M3, new M3). Up to five or more may be required (M3s plus Worksheet plus I or Cs) (these requirements are driven by the use of legacy systems) VAR hour meters removed at SCE convenience MSPs issued lock ring keys One form, Appendix F, Meter Installation Notification SCE has modified original policy, eliminating requirement for VAR meter removal Issuance of lock ring keys simplifies the process significantly PG&E paperwork requires FedEx vs fax because of the tiny print. It also takes significantly more time to complete and track because of the number of pieces of paper and varying requirements for form completion. VAR hour meters left in place MSPs issued lock ring keys (limited) One form, Service Order Completion form (currently paper) Process Comparison (continued) Process Step Comment Meter Return Ten days - paperwork required Five days - no paperwork PG&E ten day return policy provides additional flexibility. SCE and SDG&E minimal paperwork requirements reduce cost. Five days - identification only No change to this page Process Comparison Summary Each of the processes has some very positive aspects. These are listed below by UDC. Single schedule notification / schedule flexibility No need to pre-identify specific meters Ten day meter return requirements Electronic communication !! Single MDCR Single completion document Single schedule notification Lock ring keys provided No need to pre-identify specific meters Single MI Single completion document Use of AEP number for meter number Lock ring keys provided No returned meter paperwork These positive features can be combined to create a significantly improved process No change to this page Recommended Process for Meter Installation Initiation and identification of requested meter service option Provision of metering data Job ID DASR Electronic file of consistent structure and format DASR Number The metering data provided by the three UDCs is consistent One UDC currently using DASR # - two would need to switch Process Step Comment Recommended Process Cost Benefit The on-going efforts o f the three UDCs to computerize the meter data function would need to be coordinated Cost of changing MI number (SCE) and Job number (PG&E) to DASR All MSPs and ESPs would avoid the cost of creating multiple interfaces and training personnel to address each format One common way to identify orders - reduced system development costs at ESPs / MSPs UNDER DEVELOPMENT Recommended Process for Meter Installation Provision of Meter Numbers Meter Installation AEP number or pre-assigned UDC number Notification on day prior to installation - three days for joint meets VAR hour meters left in place Either method is acceptable - provided there is no need to pre-identify specific meters before installation (meter specifications can be provided prior to installation) Only an issue in SCE territory Process Step Comment Recommended Process Cost Benefit There should be little to no cost associated with this, although SCE Appendix A process would need to be dropped None anticipated Possible cost to SCE of removing VAR hour meter, and of reinstalling VAR hour meter in future Significant reduction in inventory, materials management and record keeping requirements if Appendix A no longer required Reduced need for rescheduling, greater flexibility to meet customers needs Reduced MSP work on UDC equipment - Reduced meter installation cost. UNDER DEVELOPMENT REVISED Recommended Process for Meter Installation Meter Installation (continued) Completion Meter Return UDC issues lock ring keys One common completion format used by all UDCs, with optional unique fields if necessary for UDC specific requirements Ten Days - List of UDC Meter Numbers and corresponding DASR #s to serve as receipt Would only affect PG&E All UDC completion forms currently require similar information in three different formats UDC meter # and DASR should be sufficient for identification. Process Step Comment Recommended Process Cost Benefit Cost of keys Cost of coordinating to develop a consistent form and alter on-going electronic data gathering None anticipated Fewer trips to field by UDC - reduced coordination required - less time cutting lock rings off. Improved accuracy as a result of increased field familiarity - Reduced MSP / ESP programming cost associated with developing multiple formats Reduced paperwork and increased return flexibility UNDER DEVELOPMENT Recommendations Reaffirm participants desire to work toward a common process Validate the differences as identified in this draft Assign empowered individuals from each UDC and interested ESP / MSPs to design a process and information formats that can be implemented state-wide Issue resolution activities from 5/12 minutes and notes Meter Installation Process Summary Rule 22 Working Group RED Text identifies changes / additions   !"#$%&'()*+,-./0123456789:;<=>?@ABCDEFGHIJKLMNOPQRSTUVWXYZ[\]^_`abcdefghijklmnopqrstuvwxyz{|}~      !"#$%&'()*+,-./0123456789:;<=>?@ABCDEFGHIJKLMNOPQRSTUVWXYZ[\]^_`abcdefghijklmnopqrstuvwxyz{|}~    $Root EntryRoman-. p{;Q2)&@ Text_Content ;\Highlight the specific differe processes, including advantages and &ks&SummaryInformation  (     PowerPoint Document"(Times New Roman -X.DocumentSummaryInformation8\2 d;TPropose d prPersistentStorage Directoryand MSPs8    Current User         .Object2w Roman-.  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Roger McCall՜.+,0@Hlt | Scott, Madden & Associates  Oh+'0  0 < H T`hpxFCd Normal.dotAME1Microsoft Word for Windows 95@F#@/@=-@vDw% FMicrosoft Word Document MSWordDocWord.Document.69qMicrosoft (R) PowerPoint (R) Windows _ܥhW et t  1#X{"NItems resolved or scheduled for work Joint Meets - Ernie Lewis of SCE agreed to eliminate joint meets for Kvar meters on the condition that others would continue in the spirit of cooperation and progress Meter Numbering - PHASER to coordinate - Initially Dave Bernauda to provide a proposal within the week to address the SCE Appendix A issue. SCE conceptually ok with pre-assigned block of non-AEP numbers if necessary. Other interested parties - AMT / CellNet / GTE / PHASER / O.R.A. - Solution to be proposed by 5/26 Joint Meets for Complex Metering / MSP Employee Qualifications SCEs safety concerns and their current demand for joint meets may be reduced or eliminated if adequate interim MSP Employee Qualifications can be implemented. To address this issue, PHASER agreed to propose qualifications and communicate to the other MSPs and to the UDCs. To be communicated by 5/26. Scheduling problems / missed commitments - Two short-term deliverables First - Don Fellows to provide proposal for an alternative to Meter Installation date as DA switch date. Mention was also made of the possibility of using 3 days past paperwork submission for the DA switch date. Second - confusion over information flows was identified. Roger McCall of Scott, Madden (for PHASER) to document information flows prior to 5/26. It was agreed that the Meter Specific Information Flows Workshop Report would be consulted as input to this task. Multiple formats for information communication - Ernie Lewis to lead UDC effort to develop common formats and communication method by 5/26. Commitment is to develop common completion format, but the group will also strive to develop a common format for initial provision of meter information. Other UDC contacts are Terese Acua (SDG&E) and Sue Sponsel (PG&E). Items still to be addressed: Ensure All Parties Apprised of Work to be Completed Address MSP Switching !20 I} ' s t u]c]^c% } ) ] s t #  4h  4 K@Normala "A@"Default Paragraph Font @ Header ! @ Footer !)@ Page Numbertt  t @1Times New Roman Symbol &Arial"h{% %&fz%% ;Z  w&WordMicrosoft Word     --"Arial- A2 $ Items resolved or scheduled for work(  #- !55-Symbol-2 vK 4-2 z  Joint Meets )h2 z> - Ernie Lewis of SCE agreed to eliminate joint meets for Kvar! # !$! (   (!- !--p2 C meters on the condition that others would continue in the spirit of(  #     -/2 f cooperation and progress -2 K 4-"2  Meter Numbering)$( Y2 4 - PHASER to coordinate - Initially Dave Bernauda to!$!!!$    $!- !--v2 TG provide a proposal within the week to address the SCE Appendix A issue.  #  #!$!! ! -n2 B SCE conceptually ok with pre-assigned block of non-AEP numbers if!$! #   !!!( -s2 @E necessary. Other interested parties - AMT / CellNet / GTE / PHASER /'  !)$ $'!!$!!!$-G2 ( O.R.A. - Solution to be proposed by 5/26'$!!  -2 *K 4-h2 .> Joint Meets for Complex Metering / MSP Employee Qualifications )$( ) )!!!( '   2 .D SCEs!$! - !a--w2 H safety concerns and their current demand for joint meets may be reduced (  ((-q2 D or eliminated if adequate interim MSP Employee Qualifications can be (    ()!!!( '   -h2 > implemented. To address this issue, PHASER agreed to propose ( (  !$!!!$-q2 D qualifications and communicate to the other MSPs and to the UDCs. To   (( )!!$$$-/2 | be communicated by 5/26.(( -2 K 4-G2 ( Scheduling problems / missed commitments!  (( (( (82 h - Two short-term deliverables#(  - !'--2 j First h2 j> - Don Fellows to provide proposal for an alternative to Meter$ #    )- !c--n2 B Installation date as DA switch date. Mention was also made of the  $!# ) # (-v2 VG possibility of using 3 days past paperwork submission for the DA switch   #(  $!# -2  date. 2 " Second!b2 : - confusion over information flows was identified. Roger  (  ##   $- !"--n2 B B McCall of Scott, Madden (for PHASER) to document information flows)$ !)!$!!!$( (  #-v2 G prior to 5/26. It was agreed that the Meter Specific Information Flows #)!  (  #-a2 . 9 Workshop Report would be consulted as input to this task.2$#    -