The 4 th Korea Smart Grid Week SG Demand Response Communication Standard and Infrastructures

Transcription

1 The 4 th Korea Smart Grid Week SG Demand Response Communication Standard and Infrastructures 18 October, 2013 Korea Electrotechnology Research Institute Power Telecommunication Network Research Group Principal Researcher/Ph.D. Jae-Jo, Lee

2 Contents Demand Response Energy Policy DR System & Standards Communication Infrastructure OpenADR 2.0 Conclusions 2

3 Demand Response Changes in electric use by demand-side resources from their normal consumption patterns in response to changes in the price of electricity, or to incentive payments designed to induce lower electricity use at times of high wholesale market prices or when system reliability is jeopardized. Supply Electricity Use, no action Reducing Electricity Use during Peak Hours Shifting Electricity Use to Off-Peak Hours 3

4 Demand Response Load Shaping Energy Efficiency programs reduce overall electricity consumption, generally also at times of peak demand. Price Response programs move consumption from times of high prices to times of lower prices (real time pricing or time of use) expanded to address transmission distribution congestion management. Peak Shaving programs require more response during peak hours and focus on reducing peaks on high-system load days expanded to address transmission distribution congestion management.\ Reliability Response (contingency response) requires the fastest, shortest duration response. Response is only required during power system events. This is new and slowly developing. Regulation Response continuously follows minute-to minute commands from the grid in order to balance the aggregate system load and generation This is also very new and appears to be very promising for certain loads. 4

5 Automation Demand Response Conventional DR Approach to Smart Grid DR Utility Options Incentives Technology Utility Control Bundled Programs Customer Infrastructure Price, Reliability, and Event Signals Price, Reliability, and Event Data Model Customer Owned Technologies and Control Strategies Energy Policy DR System DR Program 5

6 Demand Response DR Programs 2010 FERC Survey Program Classifications Description Direct Load Control Sponsor remotely shuts down or cycles equipment Interruptible Load Load subject to curtailment under tariff or contract Emergency Demand Response Load reductions during an emergency event Combines direct load control with specified high price Load as Capacity Resource Pre-specified load reductions during system contingency Spinning Reserves Load reductions synchronized and responsive within the first few minutes of an emergency event Critical Peak Pricing w/control Combines direct load control with specified high price Non-Spinning Reserves Demand side resources available within 10 minutes Regulation Service Increase or decrease load in response to real-time signal Demand Bidding and Buyback Customer offers load reductions at a price Time-of-Use Pricing Average unit prices that vary by time period. Critical Peak Pricing Rate/price to encourage reduced usage during high wholesale prices or system contingencies Real-Time Pricing Retail price fluctuates hourly or more often to reflect changes in wholesale prices on day or hour ahead Peak Time Rebate Rebates paid on critical peak hours for reductions against a baseline System Peak Response Transmission Tariff Rates / prices to reduce peaks and transmission charges Source: Lawrence Berkeley National Laboratory, Demand Response Research Center, LBNL-Webinar5-DRWeb.pdf 6

7 Tariff Rate Structures for DR(Korea) Program Type Vacation Coordination Week-ahead Demand Reduction Demand Resource Market Emergency Reduction Intelligent DR Operation Period Peak hours (10~15 days of Summer) Peak hours (Reserve:4500MW) Peak hours (Reserve:4500MW) Reserve margin : Yellow (Reserve: 3000MW) Peak hours (Reserve :4500MW) Capacity Requirement Customer Type Notification Time More than 300kW More than 300kW More than 300kW More than 300kW More than 100kW Industrial Industrial Industrial Industrial Before 2 Month Last Friday ~ Yesterday Day-ahead(3 pm) ~ Day-of (3 hours) Emergency called Small size Commercial & Industrial Before 30 Min. Control Manual Manual Manual Automatic Manual/Automatic Obligation Autonomous Autonomous Autonomous Mandatory Mandatory Operator/ Aggregator KEPCO KEPCO KPX/ Load Aggregator KEPCO Load Aggregator Payment type Energy Energy Energy Capacity+Energy Capacity+Energy Pricing Method Contract Contract Price Competition by Bidding Contract Price Competition by Bidding Contacted Load 1,500,000 kw 2,000,000 kw 1,500,000 kw 1,500,000 kw 100,000 kw Payment (Won/kWh) Won/kw-day 720Won(Before a day) ~900Won(Before 3 hours)/kwh 300~1,000Won/kWh Capacity 500~1,000Won/kW.year Energy 2,500~3,000Won/ kw h Capacity 64,000Won/kW.Year Energy 543Won/kWh Source : KPX/KEPCO 7

8 Communication Infrastructure ISO/IEC The ISO/IEC Standard, Information technology - Telecommunications and information exchange between systems - Power line communication (PLC) - High speed PLC medium access control (MAC) and physical layer (PHY) - Part 1: General requirements The ISO/IEC Standard was published early in July, 2009 and available on both IEC and ISO website from that time on. ISO/IEC was developed in the ISO/IEC JTC1 and went through the process defined in the ISO/IEC JTC1 Directives and the every rules defined in the ISO/IEC JTC1 shall be applied to ISO/IEC

9 ISO/IEC High speed PLC MAC/PHY ISO/IEC Specification of PHY Value Time slot duration 7 symbol Regulations related Organizations Frequency Bandwidth Korea Communications Commission 2.15 ~ 23.15MHz Bandwidth used 2.15 ~ MHz Delimiter length 12 symbol Tone space(=25mhz/256) kHz Symbol block length 16 symbol Sampling frequency 50MHz Frame header byte 20 byte Modulation Technology DPSK-based DMT IFFT interval [Tfft] Symbol rate 512 sample khz Frame body block header byte Maximum competitive window size 12 byte 512 time slot Payload speed at physical layer 24Mbps modulation DBPSK, DQPSK, D8PSK Contention window coefficient 8 time slot Importance field Smart Grid Home Network MAC Parameters Symbol period Value usec/symbol Periodic contention window duration Collision recovery duration 1000 time slot 252 symbol 9

10 Deployment Schedule KEPCO, Korea Electric Power Company, started massive installation of smart meter with PLC module of ISO/IEC in Phase 1 Phase ~2007 BPL AMI pilot service for 1,500 low voltage residential customers 2 cities : Dajeon, Daegu 2007 ~ 2008 Final verification stage Expansion of AMI pilot Service for total 6,500 low voltage residential customers 5 cities : Daejeon, Daegu, Gosung, Uijungbu, soonchun) Phase 3 (Final) 2008~ 2017 Nationwide commercial Deployment AMI system for total 22 million low voltage residential customers : 56,000 house : 500,000 house ~ 2015 : 10 million house - by 2020 : 22 million house 10

11 PLC Deployment in Korea (2010) PLC Deployment in Korea (2010) 12 point [77,916] 6 point [38,958] 3 point [19,479] 11 point [71,423] 3 point [19,479] 9 point [58,437]] 8 point [51,944] 4 point [25,972] 7 point [45,451] 5 point [51,944] 3 point [19,479] 6 point [38,958] Total : 77 [500,000] 11

12 AMI Communication Structure KEPCO BPLC AMI System Backbone Network HFC (Hybrid Fiber Coax), CDMA, etc Access Network Meter Reading Center Binary CDMA High voltage Powerline PLC signal Low voltage Powerline DCU (Data Concentration Unit) Digital meter PLC modem Digital meter PLC modem 12

13 Smart Meter and DCU Devices for BPLC network Digital Meter Provides power consumption and power information (valid/invalid power level, power rate with time, etc ) Remote inspection with the built-in PAU Power utility AMR Unit(PAU) Removable PLC Module for G-Type Digital Meter Digital Meter PAU(PLC) Data Concentration Unit(DCU) Registration and Management : Digital meters of Premises Collect power consumption from Digital meters Transfer collected data to Meter Reading Center Data Concentration Unit 13

14 DR System Traditional DR Source: Lawrence Berkeley National Laboratory, Demand Response Research Center, PEC_training_S1f.pdf 14

15 DR System Automated DR An information exchange model to facilitate communication of price and reliability signals Receipt of external signal initiates preprogrammed response strategies by end user 15

16 DR System DR Simplified Source: Lawrence Berkeley National Laboratory, Demand Response Research Center, LBNL-Webinar5-DRWeb.pdf 16

17 DR System Auto DR Logic Source: Direct versus Facility Centric Load Control for Automated Demand Response, Grid Interop 2008, Koch,E., Pietto, M 17

18 Standardization Electric Vehicle IEC IEC 61970, IEC Smart Grid IEC IEC DNP3 IEEE1547 Open O&M OAGIS SAE J2836 SAE J2931 SAE J2953 IEC IEC TC 59 IEC TC61 IEC TC 100 OpenADR ZigBee SE SEP 2.0 OpenHAN ANSIC.12 BACnet ITU-T SG15 ITU-T SG16 ITU-T SG19 ISO TC20 Open GIS Home Network JTC1 SC6/SC25/SC27 18

19 Standardization OpenADR 2.0 Standards (OpenADR Alliance) 19

20 OpenADR 2.0 Open Automated Demand Response (OpenADR) provides a non-proprietary, open standardized DR interface that allows electricity providers to communicate DR signals directly to existing customers using a common language and existing communications such as the Internet. 20

21 OpenADR 2.0 OpenADR 1.0 OpenADR 2.0 Limited number of vendors No certification program Geared towards local DR programs Not a national or international standard Limited to basic DR application Large ecosystem of vendors Test tool, test plan & certification Flexible to adjust to most DR programs Based on OASIS standard Expanded architecture to include pricing, telemetry and other services 21

22 OpenADR 2.0 Separation into 2 implementation classes Simple implementations looking to transfer DR event and price information. Low end devices (e.g. thermostats) OpenADR 2.0a profile Higher end implementations adding more complex event and price processes as well as feedback and additional services (e.g. EMS, BAS) OpenADR 2.0b profile 22

23 OpenADR 2.0 OpenADR 2.0 Profiles Energy Interoperation 1.0 OpenADR 2.0 B Profile EiEvent EiOpt EiReport EiRegistrer Party A Profile Simple EiEvent A profile is targeted at limited resource devices and simple DR applications B profile is targeted at robust devices and sophisticated DR applications 23

24 VENs and VTNs Two actors in OpenADR communication exchanges Virtual Top Nodes (VTN) Transmit events other nodes Virtual End Nodes (VEN) Receive events and respond to them Control demand side resources Pair-wise interaction patterns No peer to peer communication 24

25 VENs and VTNs A VEN typically has one VTN in a relationship A VTN has one or more VENs in a relationship A VEN may have relationships with one or more VTNs (different programs) 25

26 OpenADR 2.0 Transport Protocols Simple HTTP: Using standard http command. Ideal for pull clients, possible for push but firewall issues need to be taken into account XMPP: Used in messengers and many other social communication tools. Excels for push applications and fast DR. Pull also possible Simple HTTP or XMPP for VEN, both mandatory for VTN 26

27 OpenADR 2.0 Security Standard Security: TLS with server and client side certificates High Security: Standard Security + XML signatures to increase non-repudiation Standard Security mandatory, High Security optional 27

28 OpenADR

29 OpenADR 2.0 Web Service like logical request-response services Event Service Send and Acknowledge DR Events Opt Service Define temporary availability schedules Report Service Request and deliver reports RegisterParty Service VEN Registration, device information exchange Each service has a single common endpoint XML Payloads Root element defines service operation 29

30 OpenADR 2.0 Services Usage Scenario 30

31 Conclusions Demand Response Services DR Policy Intelligent DR Communication Infrastructure Power Line Communication Standard Protocol OpenADR 2.0 Smart Appliances DR service 31

32 Questions and Answers Korea Electrotechnology Research Institute Power Telecommunication Network Research Group Principal Researcher/Ph.D. Jae-Jo, Lee