Smart Grid & Beyond
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The document outlines a strategic plan for the implementation of smart grid technologies, emphasizing the enhancement of reliability, consumer options, and information access regarding energy usage. It addresses the integration of advanced metering infrastructure (AMI), customer demand response programs, and efficient outage management to improve service delivery and reduce operational costs. The plan also includes partnerships and communication strategies to engage members and keep them informed about technological advancements and their benefits.
Smart Grid & Beyond
- 1. Smart Grid & Beyond Joe Jacobson Eusco Gas/Water/Electricity Metering Backend Demand Response Programs Distribution Automation and Asset Water Heaters Management and Switches Distributed Generation PHEV (Wind/Solar/Other) Charging Programmable Station Thermostats Energy Netmetering & Distributed Storage Gateways
- 2. Evolution of AMR to AMI 2‐way fixed AMI networks Remote Meter Reading Billing Schedules Off‐cycle Reads Customer‐Selected Billing Demand/ TOU/ Int. Data Benefits Power Quality Drive‐by AMR to Tamper Indication increase Outage/restoration Outside remotes & walk‐ productivity, reduce Remote Trouble‐Shooting Hand‐held by RF to eliminate risk Connect/Disconnect computers to accessibility problems reduce errors Demand Response Home Area Network Monthly Billing Cycle Support Functionality
- 3. “ PL C ” D iagram
- 4. One Utility's Approach • Apply today’s technology to today’s business issues – Increasing generation costs – Increasing need for reliable electricity – Increased consumer desire to manage energy costs – Increased interest in conservation
- 5. Strategic Plan We shall be among the industry leaders by maintaining a Technology Plan that provides for the aggressive use of proven technology to enhance reliability and member service while decreasing local operating costs. – At least three technology advances will be made each year, supported by a business plan, which will have a direct positive impact on the membership.
- 6. Our Strategic Plan • “Technology Plan” – Cross departmental 5 year technology plan • Not “Smart Grid” plan – Focused on key technologies to drive desired business outcomes. • “At least three technology advances will be made each year, supported by a business plan, which will have a direct positive impact on the membership” – AMI – SCADA – Web presentment (Google ‐ MS Hohm) – Outage status updates – Prepay
- 7. Reliability Options Information Consumption Information Outage Restoration Outage Identification Theft Detection Line Loss Analysis Blink Analysis Voltage Analysis Transformer Loading Outage RestorationPre‐Pay On‐Line Web Presentment Billing Efficiencies Theft Detection Outage Restoration Outage Identification Outage Prevention Pre‐Pay Rate Development Blink Analysis Outage Identification Real‐Time Engineering Analysis On‐Line Web Presentment Outage Restoration Real‐Time Engineering Analysis Smart Grid Technologies
- 8. Customer Connection • Reliability – Reliability of electric delivery • Options – Billing options – Rate options • Load management/Demand response • Dynamic pricing (TOU/CPP/CPR) • Information – Information on electric usage – Information on ways to conserve
- 9. Reliability • What we are doing now – Outage management (detection, restoration) – Analyzing Voltage • What we plan to do in the future
- 11. Reliability • What we are doing now – Outage management (detection, restoration) – Analyzing Voltage – Analyzing Blinks – Transformer loading • What we plan to do in the future – Real‐time engineering analysis – Systematic approach to data analysis
- 12. Options • What we are doing now – Load management – Prepay (in process) • Future possibilities – Rate Options – Interactive demand response • “Points” for demand response
- 13. Information • What we are doing now – Daily usage on back of bill • What we plan to do in the future
- 15. Information • What we are doing now – Daily usage on back of bill – Web access to consumption information (Google)
- 18. Comments Received • First, kudos for taking the lead partnering with Google to make this power data much more actionable. • GPM immediately indicated what I had long suspected, that I have a very high (>1kWh) "always on" load, probably my furnace fan and whole house air exchanger. Already running a few tests to verify. • That sounds great and what a terrific thing you did by giving us the data early! Kinda interesting to watch the power usage go down in relation to the solar data we're collecting. Thank you so much. • As you might suspect it leaves a lot to be desired for a guy like me, but it's a start. I like the data connection, and the ability to download to excel.
- 19. Information • What we are doing now – Back of bill (daily) – Web access to consumption information (Google) – Use hourly meter data on bill questions • What we plan to do in the future – Multiple options for web access (Google/Microsoft/Others) – Additional information on bill
- 20. Some Tools: • www.youtube.com/watch?v=6Dx38hzRWDQ &NR=1 • www.youtube.com/user/MicrosoftHohm#p/u /18/JO2DwoJohp8 • www.youtube.com/user/MicrosoftHohm#p/a /u/2/l_EcDjnzSe8
- 21. Let’s Start Now? • www.theenergydetective.com/ted‐5000‐faq.html • www.theenergydetective.com/ted‐5000‐live‐ Demo.html • www.navetas.com/technology/interactive‐ house‐demo.aspx
- 22. Impossible? • "Alice laughed: "There's no use trying," she said; "one can't believe impossible things." • "I daresay you haven't had much practice," said the Queen. "When I was younger, I always did it for half an hour a day. Why, sometimes I've believed as many as six impossible things before breakfast.“ • Alice in Wonderland.
- 23. Keys to Success • Company wide technology plan – Focused on fundamental business issues • Partnerships – We don’t have internal resources to do everything – We’ve relied upon other cooperatives and technology partners • Communication without overselling – Let members know what your doing – Don’t oversell the impact
- 24. Summary • Our Approach to Smart Grid – Apply today’s technology to today’s business environment • Smart Grid Member Impact – What does smart grid provide our members? • Reliability • Options • Information
- 27. Time of Use Rates and Load Control
- 29. HAN Architecture, Communications FlexServer Tower Direct (future U‐SNAP opt.) Thermostat Display Sensus Backend RNI 30 Amp 5 Amp U‐SNAP Load Switch Load Switch Radios Group Broadcast to Endpoints… TGB transmits DR commands in 10 sec (7X redundancy)
- 30. HAN, User Experience ‐ HTTPS ‐ Web HAN Displays Web Portal & Mobile Water & Gas Monitor Use & Rate Tier Set Daily Alerts (Use/Cost)
- 31. DR – TOU & Load Control TOU Rates: • Current TOU Rate HAN devices listen for “their” meter 100 Colors
- 32. In Home Display • Supports TWACS® Outbound Communications • 2 Line by 16 Character LCD Display • Audible and Visual Alert Indicators • Multi‐Lingual Support • Simple Sealed Design for Easy deployment • Will Support – Prepayment – Regular Billing – Demand Response Notification – General Messaging
- 33. Prepayment Displays Account Balance 02-21-06 2:55AM Balance: $81.92 Avg. Daily Usage $2.37 Used Yesterday $2.76 Used This Month $67.93 Used Last Month Less Than 4 Days $139.93 Remaining
- 34. Demand Response Notification Rate Peaks Pending Peak 6-21-06 2:30 PM Active Peak $0.37692/kWh
- 35. General Messaging General Messaging Tornado Warning Until 7 PM Redman County Schools Closed Have a Happy 4TH of July! Cut-off Pending Make Purchase Broadcast or Single Point Addressable
- 36. Demand Response • Direct Load Control – Unobtrusive Control and Cycling – No customer over‐ride 975 MW of Instantaneous Load Relief (FPL, 1995) • Critical Peak Pricing Notification – TOU Rates with CPP Days • Advance Alerts with Pricing – Customer decision to participate • Programmable Thermostat – Interface to 3rd party thermostats via ZigBee™ HAN solution. – Customer over‐ride allowed
- 38. FPL Load Control Event Predicted Demand Profile SYSTEM LOAD (MW) Normal Load More Generation Lost Control System re‐SCRAM Generation Lost Restoration System SCRAM Suspended 80 Minute Restoration Time-out Started Restoration Started TIME OF DAY 975 MW of Instantaneous Load Relief (FPL, 1995)
- 39. DRU Key Features • Intelligent Comfort – Monitor average on/off times to provide profiles of individual devices – Allow load for a percentage of average on time • Intelligent Outage Recovery – Power Interrupt feature Continues load shed after an outage • Cold Load Pick‐up – Prevents demand spikes as devices are brought back on‐line. • Autonomous Load Control – Provides 2 Under Frequency (UF) and 2 Under Voltage (UV) set points. • Each UV/UF set point contains trip and clear thresholds • Utility can control set points per substation • DRU’s can be programmed to react as needed ‐> e.g. shut‐off devices, simply monitor • System Diagnostics – Tamper Detection – Hardware & Firmware Diagnostics
- 40. Demand Response – Strategy Definitions • Define your strategies and delivery points • Examples: – SCRAM • 100% Everything until stop command – Water Heaters • 20% Water heaters – LC Level 1 • 20% A/C • 50% Water heaters • 100% Irrigation – LC Level 2 • 50% A/C • 80% Water heaters • 100% Irrigation
- 41. Meter Outage info. • As a “front end” to existing Outage Management Systems • To get a fast data response from specific TWACS transponders. – Specific TWACS transponders can be: • Individual meter(s). • Random selections below specific protective devices • Entire Feeders • Quickly identify the extent of an outage – 30‐40% of individual calls have power at meter (Internal Trouble) – Targeted “Pings” can “traverse” the distribution network to identify which devices are without power • Verify that all meters affected by an outage have been restored – Especially beneficial in large storm restorations. – Crews complete an area before they move on. • Clear “nested outages” while crew is still on site.
- 42. New AMI Module Info. • Demand Data – Billing (monthly) and daily demand 30 and 60 Minute Rolling Demand – Variable length and type • 15, 30 or 60 minute 3 0 • Block or rolling – Time and Date stamp 6 0 – Remotely reset • Power Quality 3:00 3:15 3:30 3:45 4:00 4:15 4:30 4:45 5:00 – Voltage snapshots – PQ data via user‐defined registers – Power outage counts (blink count) – Momentary and sustained outage Outage Info Momentary Sustained counts and cumulative duration • Threshold configurable: 1‐7 minutes Frequency Count Count • Default: 5 minutes – Outage time/date stamp and Duration Time Time duration information for 12 most recent Sustained outages
- 43. Distribution Asset Analysis Provides hourly view of loading conditions – historical and forecasted – at any point on a distribution network • Reduce device overloads and failures • Improve timing and precision of capital investments • Improve phase balancing and circuit utilization • Improve voltage regulation and capacitor placement • Improve asset sizing and consistency • Identify high line losses • Target customers for load control
- 44. Reclosers 200+ Recloser controls DNP‐RTM Cooper Form 4C, Form 6 & ABB PCD 2000 SCADA‐Xchange Benefits • Reduced SAIDI/MAIFI/CAIDI • Provides valuable data for planning and asset management • Reduced O&M cost • Support DNP & 2179 protocols
- 45. ® Scada‐Mate Switch – PEPCO Reduced SAIDI and CAIDI Obtain valuable load data for planning and asset management Rapid and easy to deploy Fast, reliable two‐way communication PowerVista browser tools to create alarms/status via e‐ mail, pager, text message
- 46. Faulted Circuit Indicator Solutions Underground Overhead Dispatch Crews Directly to Faults Improved Customer Satisfaction Significantly Reduced Outage Time Reduce O&M costs
- 47. Capacitor Banks Capacitor Automation Project Improve reliability & efficiency DNP 3.0 controls Two‐way communications Central control with fallback to local Reduce capital and O&M costs More than 2200 banks QEI eCAP‐9040 Telemetric DNP‐RTM
- 48. Capacitor Banks Improved reliability Central control when required Reduced O&M expenses Deferred capital expenditures Eliminated manual switching of seasonal banks Better asset management
- 49. Power Reliability Installed on 700+ feeders Single phase voltage monitors Reliability Reporting S/W - Pinpoints outages - Creates PUC Reports - SAIDI/MAIFI Reports by: - Feeder - Substaion - Area/state
- 50. Voltage Regulators – Substation and Line Benefits DR (conservation voltage reduction) Optimize system for peak load periods Obtain better planning information Receive immediate notification of regulator issues
- 51. Distributed Generation Monitor and control Reduced peak demand Reduced time needed to get all generators “online” DSCADA/DMS/SCADA/EMS support
- 52. Demand Response Rolling Hills Rolling Hills Mankato, KS Irrigation load shedding Reduced coincidental peak Two‐way communications Significant improvement over time/temperature systems Benefits: Reduced peak demand Lower energy costs Fast ROI
- 53. Voltage/Outage Monitoring 330+ Delivery Points Monitor momentary and permanent outages Instant notification of OV/UV events Benefits Improved response time Better communication with member coops
- 54. Questions? Thank you! Joe