Smart Grid Development in Ho Chi Minh City

Transcription

1 Power Grid Modernization by Smart Grid Development in Ho Chi Minh City Ho Chi Minh City, 06/2016

2 CONTENTS Introduction of EVNHCMC Power Grid Modernization by Smart Grid Development in EVNHCMC Perspectives

3 Introduction OF EVNHCMC

4 Ho Chi Minh City Overview Ho Chi Minh City: Population: over 8 Mill. Area of 2,095km 2 24 districts, 322 wards

5 Milestones 1976 Foundation of HCMC Management & Operation Department ( belong to Southern Power Company) 1981 Renamed to Ho Chi Minh City Power Department ( subsidiary of PC2) 1995 Establishment of Ho Chi Minh City Power Company ( subsidiary of EVN) 2003 Completion upgrading from 66kV to 110kV power grid 2010 Establishment of Ho Chi Minh City Power Corporation (one of five utilities of EVN) Achieved ISO 9001:2008 Certification

6 EVNHCMC Overview 220kV Lines Generation 500kV lines 500/220kV Subs. 220/110kV Subs. EVNHCMC is in charge of management, distribution and energy sales in Ho Chi Minh city with the voltage level up to 220kV. Customer 15 (22)kV lines 110/22/ 15 kv Subs. 110kV lines

7 EVNHCMC Overview Unities: 24 subsidiaries 110, 220kV Substations: 59 Employees: 7,245 Customers: 2,113,434 Revenue: 37,227 Billion VND Sale Energy: 20, Million kwh Peak load: MW

8 EVNHCMC Overview Time SAIFI Reliabilities improvement and Energy Losses Reduction 5000 Min SAIDI % Energy Losses Key points: Construction of New subs, new lines Voltage upgrading Ring circuit Live-line working Subs automation Targets to 2020: SAIFI: 1,5 time SAIDI: 150 min Energy Losses: 3,5% Solution Challenges: Reliabilities improvement Asset Management DG integration Power Quality Electrical Market Smart Grid Development

9 Power Grid Modernization by Smart Grid Development in EVNHCMC

10 EVNHCMC Smart Grid Roadmap Why Smart Grid? -Reliabilities Improvement -Investment efficiency gain -Operational cost reduction -Energy Efficiency -National Energy Security -Power Quality -Durable development -GHG emission reduction Smart Grid Structure in EVNHCMC

11 SCADA/DMS Project of new SCADA/DMS (Completion in 2016) Private protocol replaced by IEC protocol Redundancy (Main & Back-up server) Historical server GIS integration DMS function - Network Analysis - Vol/Var Optimization - FDIR - OMS - Provider: Alstom Grid

12 Operation Control Center Centralized control center Capacity: operation of 1500 substation and 3000 switchgears (reclosers, RMU) Main site in operation: August 2016 Back-up site: ongoing

13 Unmanned Substation 110kV Tan Son Nhat Unmanned Substation Pilot project (since 11/2013) Substation Automation Main & Back-up Fiber-optic Communication Automatic Fire-fighting system Security (Camera IP) Patrol team 15/59 unmanned Substation up to now Completion in 2018 (70 substations) Communication scheme for Unmanned Substation

14 Distribution Automation 1 st DAS project Overhead line system (2014) 2 nd DAS project Underground System (2014) 5 Reclosers installed on 2 feeders Mini-SCADA software datapoints 70 Reclosers - IEC /104 - Command Sequence for FDIR Communication: 3G/GPRS (not reliable) replaced by fiber optic 10 RMU within LBS motorized Mini-SCADA software datapoints - IEC /104 - Self-healing function for FDIR Communication: Wimax 2.4GHz Partner: Schneider - France

15 Distribution Automation Target: 100% miniscada deployment in 2018 ( 600 feeders) including 30% DAS - Switchgear (recloser, RMU) with Intelligent Electronic Devices - FDIR (a function of DMS) - Communication: GPRS/3G, fiber optic

16 AMR/AMI Existing AMR system Feeder in HV/MV substation Boundaries meter between District PCs Large customers Residential customer Number of meter 1, , ,000 Communication GPRS/3G, Fiber optic RF HHU Status of AMR deployment: 1. Ongoing projects (World Bank Funding): - MDMS system by Landis&Gyr (completion in 2016) - Head-End system and meters: ongoing - Communication: PLC, RF Mesh, 3G/GPRS 2. Targets: AMR system for 100% customers (2 million) in 2020

17 AMR/AMI AMI Pilot projects 1 st project: 2 distribution substations with 200 residential customers, PLC communication 2 nd project: 42 C&I customers in High Tech Park, RF Mesh 2.4 GHz and 5.8GHz communication Evaluation fin July 2016

18 Demand Response Demand Response Programs Dispatchable & Event- Based DR Programs Non-Dispatchable DR Programs Reliability Economic Economic Capacity Energy Capacity Energy Other Time Sensitive Pricing Optional Binding Mandatory Curtailment (OBMC)* Direct Load Control (DLC)* Interruptible Load (IL)* Voluntary Emergency Demand Response Program (VEDRP) Dispatchable Demand Response Program (DDRP)* Curtailable Load Program (CLP) Demandside Bidding / Auction (DSB)* Industrial Demand Response Program (IDRP)* Critical Peak Pricing (CPP)* Dynamic Peak Pricing (DPP)* Mandatory Maximum Demand Program (MMDP)* Peak Time Rebate Program (PTRB)* * indicates other possible DR programs (not formally proposed for Vietnam)

19 Demand Response Objective of Demand Response: Reduce stress on specific parts of system Improve responsiveness, flexibility and control of existing networks Defer upgrade investments by removing or shifting demand peaks on MV/LV networks Obtain visibility of primary users beyond sub-station Pilot project in 2015: CLP and VERDP events for 14 customers (commercial and industrial)

20 Geographic Information System (GIS) 100% GIS from HV to LV level (2 milion customers) Applications: - Portal GIS for network patrol - Specific Maps for: Energy Losses management Outage management Network design Operation

21 Communication

22 Perspectives

23 Perspectives Full Smart Applications in small areas - 5 components interconnected and data exchange in real time Model of Typical Smart Grid in 4 zones Unmanned Subs AMR/AMI Distribution Automation Demand Response GIS Infrastructure for Electrical Market ESB and CIM model Asset Management & Conditional Based Maintenance

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