the smart grid journey at oklahoma gas and electric
DESCRIPTION
TRANSCRIPT
A collaboration of:
The Smart Grid Journey
At OGE Energy Corp
Kevin Jackson
OGE Energy Corp
• About OG&E
• Our History with SAP
• Smart Grid Program Objectives and Goals
• Meter Deployment and Billing
• Demand Response
• Remote Reconnect/Disconnect
Questions
Our Journey
3
Enogex and Centerpoint Midstream Partnership
• 8.3k miles of pipeline
• 6 processing plants
• 23B cubic feet of natural gas storage
3
OGE Energy Corporation
Electric Utility
• 9 power plants: 6.8 GW
• 778 MW - wind
• 765k customers in OK & AK
• 30k square mile service area
• 23k miles of overhead distribution lines
• 500 substations
• 1100 distribution circuits
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• Went live with R/3 January 1, 1997
o SD, PM, MM, FICO, HR, PS (2008)
• Spring 1996 delivered business requirements to SAP to develop utility specific CIS
• Spring 1997 delivery of IS-U Beta v0
o One of 6 Beta companies world wide
• Live with IS-U-CCS June 14, 1999
o IS-U v1.1B, R/3 3.0F
o 3 Month Roll Out
• Currently running ECC 6.0 EHP6
o We do not use CRM, EDM, SAP’s AMI
@
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CEO Goal Defer building more fossil fuel
generation until 2020 or beyond
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(CC) SublimeDharma on Flickr (CC) Valard LP
Additional wind generation Build transmission to deliver wind energy Increased focus on energy efficiency Deploy SmartGrid technology
• Meter Operational Savings
o Meter Reading $15M/Yr
o 300,000 reconnect/disconnect orders/yr – reduced truck rolls
o 200,000 move-in/out orders/yr – reduced truck rolls
• Net Headcount Reduction: 135
• Customer Participation Goals
o 20% penetration
o 1.3kW per customer
• Avoided Generation Cost: $287M (15 Yr NPV)
• Energy Reduction (VVO): 75 MW
• Reliability: 30% SAIDI reduction
o DA Societal Benefits $300 M/Yr
OGE Smart Grid Program Goals
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• Advanced Metering Infrastructure (AMI)
Digital meters for all customers 15 min interval reads
Remote reconnect and disconnect
2-way communications
• Demand Response (DR) Programs
Dynamic pricing
In-home technology
Customer engagement
• Distribution Automation (DA) Technologies
• Automated switching
• Volt–VAr Optimization
• Centralized control - DMS
• All enabled through integrated wide area communications
network, IT systems and supporting business processes
OG&E Smart Grid Includes
DA
DR
AMI
• February 15, 2010 –
First meter set in Norman, OK
• 200 per day at first
• Ramped up to around 2000+ per
day over a 3 year period
• Meter Deployment officially
ended in December of 2012
Meter Deployment
By the Numbers
Slide 10
2010 184,000 meters
2011 314,000 meters
Meter Deployment+
2012 299,000 meters
• Weekly Meter Deployment population file
o Population file used by meter installation vendor to plan and schedule meter deployment
• Black Out Window (Dunning disconnects and billing)
• SAP Serialization program to consume meter vendor data
• Automated meter installation program written to install meter in SAP
• Sync program to MDMS system
• Based upon what meters were installed per day, SAP generated Location
Information File which would sync with AMI system
SAP Development to Support Deployment
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• Once smart meter installed, no meter reader used
• Custom programs created to satisfy meter reading document for billing
• Normal register reads
• Demand response using daily register reads
• Calling MDMS using interval data for demand response
• Interval meter data used for complex tariffs
• Goal - no estimation to generate electric bill
• Meter Deployment plan allowed us to read and bill customers with no
interruption to billing schedule
Billing with Smart Meters
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Demand Response Background
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Quail Creek
• 25 Customers
• Acceptance
• Energy Awareness
2010 Study
• 3,000 Customers
• Reduced Peak
• Segment Results
• Acceptance
• Technology
• Dynamic Pricing
2011 Study
• 6,000 Customers
• Commercial Results
• Critical Price Results
2012
Roll-Out
• ~40 K Customers
• 70 MW
• ROI Marketing
• Penetration Testing
2012 and beyond
• 20% Penetration
• 210 MW
• New Pricing Products
• Value Added Products
New Dynamic Pricing Options Offered
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• Hours: 2 – 7pm, Monday - Friday
• Summer Season (June – September)
• Customers receive day-ahead price via
in-home display, web, text, email, voice
message
• Tariff is optional
• Customer decides how to respond &
manage consumption
Residential Variable Peak Price Tariff
Pri
ce
Time of Day
$0.46
$0.113
$0.045
12:00 a.m. 3:00 a.m. 6:00 a.m. 9:00 a.m. 2:00 p.m. 7:00 p.m. 12:00 a.m.
Customer
Demand
Line
$0.23
• Enrollment
o 3rd party portal makes web service call to SAP to verify last 4 of SSN
o Rate changed in SAP
o PCT Installation
• Daily Price Signals
o Pricing from fuels department
o SAP jobs run to store daily price
o Price signals for voice, SMS, email
72,000 sent in 1.5 hours
o AMI vendor calls SAP web service to get price
o OGE.com calls SAP via web service to get price
DR Enrollment and Dynamic Pricing
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Price Signals
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Voice Message
Home Energy Report
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MyOGEPower.com
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Smart Grid Screens in SAP
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Existing Custom Screens Modified
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VPP and Technology Impact
• Leave existing disconnect processes in place
o Existing processes included Business Workflows and programs to generate PM
orders to reconnect/disconnect service
o Programs running to look at device category to determine if the order should be
sent to the field or queued in SAP to provision remotely
• Additional considerations for Dunning
• Additional considerations for Vacancy Reconnect/Disconnect
Remote Reconnect/Disconnect
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• Ratchet volume up or down
depending on need
o Critical Operations Protector
Disconnect/Reconnect
Capabilities
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• SAP will attempt to remotely provision service
• After 2 failed attempts to provision meter, order is sent to mobile
dispatch system
o 99.3% successfully provision from SAP
• Emergency reconnect process
Successful Provisioning
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Trap Orders in
SAP Table
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• Don’t disconnect rail road crossings
o Eyes on accounts before disconnects start
• OK to start disconnects
o Table entry made when it’s okay to start letting dunning disconnects fly
• Moratorium
o Company wide, by state, by service district
• Additional requirements before disconnecting Arkansas service
Considerations for Dunning
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• Disconnect all Move-Outs that do not have a corresponding Move-In
• If existing disconnect document exists at the time of move-in
• Move-in/out reads satisfied by daily register read
Considerations for Move-In/Out
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• Nearly 800,000 meters deployed in 3 years time
• All customers billed “on-time” during meter deployment
• Demand Response growing to 120,000 planned by end of 2014
• 350,000 Remote disconnects
• 343,000 Remote reconnects
• 1 Million Move-in/Out Reads
At a glance
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