DTE Initiatives. August 13, 2007

Transcription

1 DTE Initiatives August 13, 2007

2 Demographics DTE s Largest Operating Subsidiaries are the following: Detroit Edison 2.2 million customers in Southeastern Michigan 11,080 megawatt generation capacity Company uses coal, nuclear fuel, natural gas and hydroelectric pumped storage to generate electricity Transmission (>=120 kv) owned and operated by International Transmission Company (ITC) Sub-transmission (40 kv and 24 kv) Distribution (13.2 kv, 8.32 kv and 4.8 kv) 13.2 kv radial network 8.32 kv radial network 4.8 kv radial and looped network Michigan Consolidated Gas Co. Engaged in the purchase, storage, transmission, distribution and sale of natural gas to approximately 1.3 million customers in Michigan DTE Energy has 10,845 employees Proprietary and Confidential 2

3 NETWORK MANAGER Implementation Detroit Edison s implementation of the Integrated NETWORK MANAGER includes: EMS products include: SCADA Network Applications (Contingency Analysis, Dispatcher Load Flow, State Estimator) DMS products include: Restoration Switching Analysis (RSA) Fault Locating Unbalanced Load Flow (UBLF) Phase Angle Check Proprietary and Confidential 3

4 Benefits Technology Benefits Redundant systems to improve system availability Operation Benefits Reduce CAIDI Restore customers quicker Use manpower more efficiently Provides System Operators with more information before making operating decisions Corporate Benefits Improved Customer Satisfaction Reduced Costs Proprietary and Confidential 4

5 Five Substation Model Proprietary and Confidential 5

6 EMS and DMS for a Common Substation Proprietary and Confidential 6

7 Ability to Pass Fault Current Data from EMS to DMS EMS collects fault data from relays in field. EMS then forwards the feeder fault current measurements to DMS DMS uses feeder fault current measurements from EMS to analyze Based on the impedances and fault current measurements, DMS presents possible locations for the fault to the power system operator Benefits Reduced outage duration (i.e., improved CAIDI) Reduced wind-shield time for crews (i.e., $$$) Specially beneficial for long feeders Proprietary and Confidential 7

8 Ability to Pass State Estimator Results from EMS to DMS EMS state estimator (SE) passes voltage magnitude and voltage angle information of upstream network to DMS. State estimator information is used by DMS in its unbalanced load flow analysis as the starting conditions. Increases accuracy of parallel switching operations. Valuable for Operations personnel to be able to view the voltage across the phases before closing a switch. Angle difference used by UBLF represents the true angular difference in the field Angular difference is closely related to real power flow Proprietary and Confidential 8

9 Ability to Pass State Estimator Results from EMS to DMS EMS State Estimator 12.1 kv -1.8 deg 12.1 kv deg Proprietary and Confidential 9

10 Ability to Pass State Estimator Results from EMS to DMS UBLF Source Results Proprietary and Confidential 10

11 Ability to Pass State Estimator Results from EMS to DMS SE Interface Points Proprietary and Confidential 11

12 DTE Energy reads over 4 million meters every month Overlap territory Electric only territory Gas only territory Meters, 000 Gas Electric Total Overlap ,765 Electric Only 0 1,777 1,777 Gas Only Total 1,307 2,768 4,075 Inside 34% 14% 20% Outside 66% 86% 80% Reading Technologies Today Electric Handheld Keyed-in Handheld Radio Ind./Comm. Telephone Gas Handheld Keyed-in Handheld Hexagram Probed Proprietary and Confidential 12

13 Overview of RF AMI technology RF RF LAN LAN Radio-equipped meters Collector/Concentrator Meter Private Private or or Public Public IP IP WAN WAN Master Station MDM and Utility Systems Proprietary and Confidential 13 Illustration courtesy of Itron Systems

14 Smart electric meter Characteristics Every meter will Have 2-way communications with the DTE computer systems. Be capable of 2-way communications with in-home devices such as smart thermostats and in-home displays. Be able to be reprogrammed remotely over the AMI network, and will be able to accept new firmware enhancements remotely over the AMI network. Be capable of recording 2 channels of 15 minute, 30 minute, or 60 minute interval data. Transmit outage information when the meter loses power, and when power is restored. Be able to record the voltage at the meter on programmed intervals. Be able to transmit on-demand readings of kwhr usage and voltage at the meter when requested by an operator of the AMI system. Be capable of supporting Time-Of-Use rates and Net Metering. Be capable of storing 40 days of metering data consisting of 2 channels of 60 minute interval data. Be capable of performing self diagnostics, and transmitting error messages if a failure is detected. Be capable of transmitting tamper alarms to the DTE computer systems. A percentage of the residential meters will have a remote controlled disconnect/reconnect switch. DTE Energy will be installing Smart Meter technology With their AMI installation Illustration courtesy of Elster Systems Proprietary and Confidential 14

15 Current meter data flow Regulated C&I Service Electric Choice Regulated Mass Market MV-RS MV-90 APC Joint Meter Reading ARCS CMS Res. & Comm. Billing Utility Data Store Special Rate Calculations Customer Self-Service MV-WEB Load Profiling Industrial Billing Legend: Interval data & requests Register data & requests Billing determinants Financial data Meter configuration data Meter & financial data Financials LODESTAR Proprietary and Confidential 15 Retail Access Suppliers

16 Future Flows Regulated Mass Market Electric Choice Regulated C&I Service AMI Master Station Meter Data Management Enterprise Service Bus Residential and Commercial Billing Industrial Billing Retail Access System Credit and Collections Outage Management Demand Management Customer Self Service Asset Management Joint Meter Reading Customer Meter Web Services Field Work Order Management Distribution Planning Load Research & Regulatory Rate Design Transmission Planning Proprietary and Confidential 16 Unaccounted Energy Management

17 Conclusions AMI is going to transform many of our processes across DTE Energy which will require close collaboration of technology projects Complete Installation will encompass all meters and an elapsed 5 years AMI will be the enabling infrastructure for customer focused driven benefits Enabling IT infrastructure will be built incrementally as AMI network maturity grows and meters are installed A New AMI Technology group will emerge tasked with: How to operate the system How to use the data throughout our enterprise Proprietary and Confidential 17

18 DOE Phase 1 & 2 - Complete Department of Energy DER Aggregation Communication, Control, and Sale Proprietary and Confidential 18

19 Present Problem Distributed Energy Resources (DER) located on the electric distribution system are not effectively utilized Electric utilities do not have a way to use DERs as a resource option to support the electric distribution system Parallel operation Standby operation DER asset owners do not have the means to participate in the energy market Generator and T&D utility communication relies on private networks Proprietary and Confidential 19

20 Technical Challenges Aggregate multiple small DERs within an ISO Register DERs in the market Market the DERs Move from a dedicated central system operation center (SOC) to a distributed SOC Need a secure and inexpensive communication system Manage potential loss of communication Trading facilitation with the energy market Modeling tools to manage the electric distribution system Proprietary and Confidential 20

21 DOE DER Aggregation Projects DOE DER Phase 1 Proof of Concept UPCSC Universal Protocol Converter and System Control PI real-time database Tagging procedures DOE DER Phase 2 Start, control output, stop, aggregate and sale 1st to ever sell Demand Response into MISO Market SSL Security Utility Centered Aggregation Stick and Wires quantified before sale Proprietary and Confidential 21

22 Communication Architecture Day Ahead Business Model DR SOC MISO Internet Merchant Operation Center (Detroit Edison) Internal Dedicated Link Day Ahead Request for Day Ahead Forecast Economic Algorithm Next day hour by hour offer Receipt of acceptance Hour by hour control Settlement ICCP, Web Services Internet (VPN) ICCP Internet (SSL) Energy Aggregator (DR-SOC) Internet (SSL) DER Site DER Site Controller DG DG Detroit Edison System Operations Center DEW PI Server SCADA Distribution Circuits Day Ahead Communication by the utility to the generators Next day hour by hour forecast may or may not be in place. The energy Power Flow for overload& low voltage aggregator has full DG constraints & requirements communication to all Load and DG level by hour generators through the Participation in Proprietary Market Display and Confidential internet. 22 DG

23 PI Process Book General Display Real Time Day Ahead Proprietary and Confidential 23

24 GridApp (Advanced Grid Applications Consortium) is a partnership of electric utilities and the United States Department of Energy (DOE), convened and coordinated by Concurrent Technologies Corporation (CTC). GridApp mission is to transition best technologies and best practices to support grid modernization into broad use by consortium member utilities. This multi-company consortium focuses on High-Impact Technologies for electricity distribution and transmission, including: sensors, communications, information technologies, power electronics, smart systems, and system integration. Proprietary and Confidential 24

25 Utility Members American Electric Power - DTE Energy Exelon Corporation - FirstEnergy Idaho Power - PPL Electric Utilities Portland General Electric - Salt River Project Southern California Edison - Southern Company Membership Options: Charter Member Sponsor Member Proprietary and Confidential 25

26 GridApp Projects Exelon - Substation in a box Utility Automation & Engineering T&D Project of the Year Award AEP - Mess Network Radio PGE - Standby Power using customer generation SCE Phase Measurement Unit (PMU) FirstEnergy Autonomous Storm Detector FirstEnergy Utility Zinc Battery Idaho Power Capacitor Control System Southern Co Legacy Device Module DTE - Ground Fault Jumper test for Idaho Power DTE - S&C TripSaver DTE Coordinated Control Proprietary and Confidential 26

27 GridApp Project S&C TripSaver DTE is involved in a pilot project to test the S&C TripSaver Dropout Recloser. TripSaver Dropout Recloser: 1 st operation: allows 5 seconds to reclose 2 nd operation: locks out 50K and 100K fuse curves Project Scope: Electrically test 2 beta units in DTE high voltage lab Physically test a beta unit at an Overhead Lines Center of Excellence Install 6 beta units on high outage laterals in the territory. Analyze the results of the project and write a report Proprietary and Confidential 27

28 GridApps One of the selected fuse points for demonstration and it s outage statistics GridSense Wolfhill Proprietary and Confidential 28

29 LineTracker Sensing & Detection Adaptive Sensing & Event Recording I & V sensors adapting to line conditions Auto-Event Capture Thresholds Fault Current Power Off Power On Time Stamped Data Event Capture 60-second Event profile Pre, fault & post measurements Protection and outage measurements 12-cycles of Fault waveform Load & Temperature Trending Proprietary and Confidential 29

30 LineTracker 900 MHZ & RDN Demonstration Project Located in NW Area Located in SE Area Located in SW Area Located in NE Area Wireless communications via Cellular or Satellite VPN Tunnel ICCP Gateway Edison SCADA Server located at DTE-GEMS in Farmington Hills G-Server ICCP Gateway Ethernet Load Data & Fault Data NW Planning Eng SE Planning Eng NE Planning Eng SW Planning Eng Proprietary and Confidential 30

31 GridApp Project Milford Coordinated Control Demonstrate Coordinated Control Released capacity 6.4% average (max 11%) with DG Release capacity 2.5% without DG Smart agent at the substation Collects all circuit measurements Calculates circuit conditions Dispatches all active devices on the circuit Expected results: Circuit level analysis quantifying the benefits in losses, capacity release, reliability in real time. Sub DG Proprietary and Confidential 31

32 Model-based, Hierarchal Control Coordinated control using capacitors, load tap changers, voltage regulators, distributed resources and switching devices Use feed-forward control to provide optimized setpoints for control devices Use local feedback to ensure control devices meet set-point, more robust against communication failures Proprietary and Confidential 32

33 Milford Feeder DG Substation Coordinated Control 1 LTC 2 BiDir Vreg 3 Caps 8 Reclosers 1 Generator Proprietary and Confidential 33

34 Benefits Retrofit for data and control All fault sensing merged with outage calls Fault Locating & Notification including recommendations for reconfiguration together with protection coordination assessment Momentary faults will be located Better circuit modeling Smarter coordinated local control which can also be used for planning purposes Loss savings based on Var Control loss savings ($ 40K loss saving per substation) Released capacity $ 10K in capital cost better utilization 2.5% = approx 1 year project deferral ($50K) Proprietary and Confidential 34

35 Next Steps Where are we going from here? Integrate all the previous technologies into the DMS Allow control for the system operators from same workspace Begin DSM Using the AMI infrastructure to control temperature and other aspects of the customers premise Locate and negotiate rates to utilize customer owned generation Proprietary and Confidential 35