Evolving Our Grid: System Planning and Grid Modernization GRC Overview October 24, 2016
Objective and Agenda Today’s objective is to provide information and answer questions about our plan for evolving the grid as articulated in our GRC. • Setting the stage: distribution system overview • The evolving grid: drivers • Grid modernization and reinforcement Programs • Evaluating DER as cost effective alternatives • GRC details: Grid modernization and reinforcement programs – Distribution Automation – Substation Automation – Communications – IT Software – Grid Reinforcement and 4kV Programs 1
Setting the Stage: Distribution System Overview 2
Anatomy of a Distribution System Substations consist of multiple circuits feeding a large area. Multiple meters could be fed by a single This substation is transformer comprised of 14 circuits, feeding over A circuit is fed from a This transformer serves The service meter is 13,500 customers. single circuit breaker at a 8 customers the interconnection substation and feeds point between the multiple transformers utility and the customer This circuit feeds over 1500 customers utilizing This feeds a single over 150 service customer transformers. 3
Overhead Distribution Circuits In a conventional distribution circuit, power flows in one direction from the substation to the customers’ load. Closed switch Switch to another circuit Transformer Capacitor Bank Fuse Open Switch Circuit Breaker 4
T oday’s Distribution System While the system may seem straight forward when we zoom in, in reality, there are many possible configurations and operational complexity. • Radial distribution design is reconfigurable • Traditional operations are largely manual, based on predictable one-way flow of energy 5
Transmission Networks The transmission system is designed as a network to support reliability relying on multi-directional power flow. 6
SCE’s Electric Power System Components 7
SCE’s Current Reliability The industry is seeing reliability improvement year-over-year in both the duration and frequency of outages while SCE’s reliability is flat to declining . 2016 WOP* SAIDI Today, SCE makes “traditional” grid investments to maintain reliability, not improve reliability • Replacement of aging infrastructure (4kV, cable and conductor, substation equipment) • Basic automation to facilitate restoration with substation level visibility and control of grid equipment *WOP is “With Out Plan” or repair outages http://grouper.ieee.org/groups/td/dist/sd/doc/Benchmarking-Results-2015.pdf 8
Existing Grid Operations are Based on Limited Visibility BS1288 THORNWOOD S5 125415 AØ BS128 7 E D H A W K R B512 5189 2 # I RONWOOD B5 143227 RED ROCK REDHAWK S A2 2 0 / N Limited number of # 2 S T B5144 612 DEERFI ELD AV 2 / 0 O YALE AV N OAKDAL E E B5125 413 NANTES CI R #2 SPARROWHAWK C B5125414 B5125190 2/ 0 E R E B5143225 B5143226 # 2 K 0 / B512 5192 2 KUNA fault indicators #2 AØ SANTIAGO MARNE CI R 600A B5124841 2 / 0 B5143224 O D FI 05 008 X5125188 O 2 # M W V 5 124240 L 2/ 0 GS0945 WOODHOLL OW E B512 5194 POS.3 W S5124242 Y A L E L I RV I NE CENTER DR # 2 B5124 857 1 2 3 P B5125 191 B5125072 B5125073 L E MARI POSA 2 / 0 PT A K D W YAL E L P N V 5 12 42 4 0 BS09 46 A THI STL EDOWN # 2 O RCS5 9 04 7 50 CL P CØ B512519 5 V 512 4243 2 / 0 POS 1 B5124860 BS589 1 GS0948 BS12 04 CØ Y # 2 1 2 3 W A BS0117 N B5125193 A SAV ERNE CI R 2 / 0 I G H T H A W K R CØ C A S5 124254 R 2 BØ WI NDWOOD A PI NEWOOD # J BARS G SUNSET RI V ER B512 5137 0 NI GHTHAWK B5 125354 B512 5196 / 2 CØ B5125020 AØ BØ # 2 MOUL I NS CI R CØ NI GHTHAWK B514 1865 2 / 0 BS1119 Ø N STONE CREEK C # 2 B5 125138 B512 5598 NUTWOOD B5 141864 H5144613 2 / 0 W YALE L P STONEWOOD 1 2 3 B A V Ø C B512 5136 B5141866 V 5 084 580 O O # 2 T I E WI LLOWBROOK B5125021 SANDSTONE P547 8633 B5141863 GS547 4 H N D B512559 9 C I A C FC48 50 BØ 2 / 0 R R M Ø O B5125139 PENCE N MEADOWLARK B5 125600 # 2 HERON B5125070 SANTIAGO PI NEWOOD B514186 2 PARK V I STA BØ BØ 2 / 0 S S B54786 49 A 7 5 0 CL P PI NEWOOD B512 5022 G R HARV EST N # 2 B5124 752 M O B5 125140 E B5478 650 H5144614 L S5124244 PEBBL ESTONE 2 / 0 B5 125595 B512 5597 CØ BS1201 # 2 LAKETRAI L B512 5596 S5124253 S512 4247 B5 12502 3 LAKEGRASS 0 FI REBI RD H5 144615 CHERBOURG AV BS1145 2 / P I N V S5124 247 BØ T A #2 BROOKDALE CREEKWOOD I A L E BS0544 D BROOKPI NE A L R 0 9 1 1 1 4 0 Y SHOOTI NG STAR BS1202 B I A 2/ 0 B512 5402 R E W YALE LOOP 18 00 S5124247 O 7 5 0 CL P BS1576 L AKESI DE MI DDL E SCHOOL H B514 4616 N STONE CREEK S P 5 5 8 6 4 8 6 #2 BROOKDALE B5 125071 B5142974 S5 124252 2 / 0 PINTAI L BØ S I BS1228 H O V R B5142 973 O T I N V 512 4246 ADAPTABLE #2 B5142 981 I N E KUNA GS0915 BØ BØ G C E L R FI 05 2 4 5 S N T T SANTIAGO 1 2 3 4 B51429 77 T A R E 2/ 0 R C Ø POS.1 ADAPTABLE D R B514 2972 B5125 403 R A # 2 E YAL E L OOP FI 05 032 B5142975 B51429 82 LAKEV I EW BS1203 G POS.4 B5 142976 B5125 404 2/ 0 WI L D ROSE B5142 983 1/ 0 J CN B5 142592 B5143093 # 2 B5 142590 BØ BØ B5142980 B5142591 HAZEL WOOD 2 / 0 M5142280 B5143 455 B51429 41 BS176 6 BØ # 2 J 280A B5143456 Fault Indicators 1 2 3 4 EASTMONT B5143094 EL DERGL EN 2/ 0 CØ S5142281 W BØ L 1/ 0 J CN I L A K A S B Ø D W E S H W O O 2 H O O B5143457 D B5143049 B5143477 AL SACE CI R # R E D O B5 143123 BØ B5142942 2 / 0 CØ R I ALDERGROV E P5 3 8 5 5 8 6 E YAL E L P B5143 048 V B5143050 N I # 2 E SPRI NGWOOD P5 3 8 5 5 8 5 ELDERGL EN BØ B5143 478 C E B514 3047 N T 2 / 0 B5 143857 BS1654 FC4 19 8 7 5 0 CL P ALDERWOOD E R B5143122 D 1/ 0 J CN R S5142 285 B5145 064 AØ # 2 BØ ASHBROOK B51434 75 CØ S 5 1 4 3 0 5 8 L ORRAI NE BS1881 0 S5 143058 B5143472 2 / B5142 943 B5 142743 BS1580 E B5 143124 T B5143476 B51438 55 V CØ R O AL DERWOOD BØ # 2 G S51422 86 WI LL OWGROV E O D 1/ 0 J CN C L L R 1/ 0 J CN CRESTHAV EN O U O 2 CL P S2291 W D C B5142 744 S5 142291 2/ 0 R E B514345 8 S T B514 3470 BS1687 B51438 56 B5142745 P5644 122 CØ P5644 119 B514 3473 CØ # 2 B5143624 1 2 3 Operational Requirements Current Level of Visibility Supporting Equipment Power flow Three phase circuit and SCADA (various technologies), visibility and transformer loading at RTUs, outage, distribution, and estimation substation energy management systems Fault location General fault location upon “Manual” fault indicators, smart inspection, customer call, meter some smart meter analytics Voltage 1- phase distribution voltage 1-phase from capacitor banks or monitoring remote control switches, smart and status meter indication 9
Distribution System Limitations The grid was not designed to meet the demands of today and the future. • Distribution communication system will reach full saturation beginning in 2018 – Additional automation after full saturation could lead to inaccuracies and slow the system down – Technology developed 20 years ago • Need granular visibility to advance our planning and operating capabilities – Current operations (voltage regulation), fault location based on estimation methods • Safety and reliability exposure – E.g., overstressed circuit breakers – Increased complexity to operate and switch distribution system circuits due to variable and intermittent power flows 10
The Evolving Grid: Drivers 11
Key Drivers to Evolve the Grid “This traditional system was not designed to meet many emerging trends, such as greater adoption of relatively low inertia generation sources, growing penetration of distributed generation resources, and the need for greater resilience. As described in several recent studies, a modern grid must be more flexible, robust, and agile. ” -- DOE Quadrennial Technology Review, 2015 As distributed resources are added to the grid, Increasingly operating characteristics of the grid are changing complex grid leading to increased complexity. State Energy and Grid modernization supports state policy objectives Environmental to increase energy from renewables and decrease Policy greenhouse gas emissions. Customers have more choices and are increasingly Customer Choice adopting DERs and have higher expectations for and Reliability reliability for their electronic-dependent lives. 12
Key Driver: Increasingly Complex Grid As distributed energy resources are added to the grid, operating characteristics of the grid are changing, leading to increased complexity. 100% 7% • Peak Time for Distribution Circuits Load and Generation Output Percentage of Circuits 6% 80% PV do not typically coincide 5% • The grid needs to accommodate this available 60% 4% power for the benefit of the customer and the 3% 40% grid 2% 20% 1% 0% 0% 7:00 8:45 10:30 12:15 14:00 15:45 17:30 19:15 21:00 Circuit Peak Gen Output • Shaded areas show 3-phase reverse powerflow and intermittent output from PV from an actual circuit, this appears as one-way flow to operators • Operators need visibility to power flow magnitude and direction 13
Recommend
More recommend
