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Power System Engineering, Inc.
Power System Engineering, Inc.
April 6, 2010
“A Guide To Smart Grid Planning”
© 2010 Power System Engineering, Inc.
Power System Engineering, Inc.
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Today’s Agenda
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• Background and drivers of the Smart Grid
• Strategic and Tactical Goals for the Smart Grid
• Developing a Smart Grid Plan specifically for your cooperative
© 2010 Power System Engineering, Inc.
Power System Engineering, Inc.
About the Presenters
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Rick Schmidt is presently leading several smart grid related projects for Co-ops and other utilities. Rick as well as other PSE staff have authored several CRN reports relating to Demand Response, AMI, Communications, and other automation technologies. His firm Power System Engineering, Inc. is the consulting/engineering firm supporting the NRECA with the Demonstration Grant. Rick has over 30 years of industry experience with the last twelve years as a consultant. Rick has an MBA from Cardinal Stritch University in Milwaukee.
Chris Ivanov is an economist in Power System Engineering’s Economic and Market Research group. He has prepared, evaluated and managed electric load forecasts, surveys and economic analyses for a wide range of clients including distribution and G&T cooperatives. His current focus is on assisting utilities with DSM studies, such as NRECA Demonstration Grant. Chris has a Masters in Applied Economics and is currently finishing his MBA.
Presenter Names: Rick Schmidt & Chris Ivanov
Power System Engineering, Inc.Web Site: www.powersystem.org
April 6, 2010
Power System Engineering, Inc.
A NRECA/CRN Webinar
“A Guide To Smart Grid Planning”
Power System Engineering, Inc.
© 2010 Power System Engineering, Inc.
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Agenda1. Background and Drivers of the Smart Grid:
“Situational Analysis”
2. Strategic and Tactical Goals – “What the Smart Grid Should Do”
3. Developing a Smart Grid Plan – “For Your Cooperative”– Technology Strategic Plan – What to deploy in what order?
– Smart Distribution
– Smart Home and Demand Response
– Security & Interoperability
– Project Management and Staffing
– DOE Smart Grid Programs
– Summary from Learning Session7
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What is a Smart Grid?
Despite all the buzz, the Smart Grid is still not well understood:
• Many pieces (doesn’t come in a box)
• Airy definitions
• Varying goals (depends who you ask)
• Reaching its potential—a big undertaking
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What is a Smart Grid?
Not a Definition, But a Start:
The Smart Grid Vision is …
… numerous communications, software/hardware systems and devices working to improve the grid’s efficiency, and promote affordable electricity and sustainability.
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What’s Driving Smart Grid Deployment?
• Increasing demands on improved reliability.
• The Northeast blackout of 2003 resulted in a $6 billion economic loss to the region. This blackout jump started national Smart Grid planning.
• Aging utility workforce.
– 40% to 50% eligible to retire within the next 10 years. Need to do more with fewer personnel.
• Increasing power demands on aging infrastructure.
• Increasing energy costs.
• Increasing regulatory demands.
• Increasing environmental concerns.
• Security – attack resistant grid.
• Renewable % increasing.
© 2010 Power System Engineering, Inc.
Power System Engineering, Inc.
Agenda1. Background and Drivers of the Smart Grid:
“Situational Analysis”
2. Strategic and Tactical Goals – “What the Smart Grid Should Do”
3. Developing a Smart Grid Plan – “For Your Cooperative”– Technology Strategic Plan – What to deploy in what order?
– Smart Distribution
– Security & Interoperability
– Smart Home and Demand Response
– Project Management and Staffing
– DOE Smart Grid Programs
– Summary from Learning Session11
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12
Strategic and Tactical Goals –What the Smart Grid Should Do
The emerging smart grid is expected to address many of the present challenges in the electrical power industry.
•Smart Grid Expectations: – Make the electric grid more reliable – More secure and resistant to malicious attacks (security)– Self healing – Reduce peak demand – Other goals…
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• Ability to explore the state of the grid at large scale and then switch to see specific details at street level.
– Rapid information about outages and power quality.
– Require less human intervention.
– Provide automatic detection of overload conditions and appropriate re-routing
• Two-way flow of electricity and information and will be capable of monitoring everything from power plants to customer performance and individual appliances.
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Strategic and Tactical Goals –What the Smart Grid Should Do
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Smarter Grid Building Blocks & Evolution
Smart Grid
AMI
Communications
System Integration
Data Management
DA.GISOMSSCADA
The foundation & layers:
Somewhat like building a cathedral.
Today’sApplications
From Strategic Communication Plan
Chronologica
l O
rder
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Connected Home (HAN)(Smart Meter, Thermostat,
Load Management & Dynamic Pricing
Home Area Network
ServerServer
Wide Area Network (WAN)Enterprise System
Communications
Shared communications network
Enterprise system Interoperability (AMI,
OMS, SCADA, CIS, GIS, Databases, etc.)
Utility Data Center
Substation Digital Equip.
TCP/IP Communications
Cap Bank Controls
Voltage Regulator Controls
AutomatedSwitch ControlsUnderground
Switching
Typical Pieces of the Smart Grid
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Agenda1. Background and Drivers of the Smart Grid: “Situational
Analysis”
2. Strategic and Tactical Goals – “What the Smart Grid Should Do”
3. Developing a Smart Grid Plan – “For Your Cooperative”– Technology Strategic Plan – What to deploy in what order?
– Smart Distribution
– Smart Home and Demand Response
– Security and Interoperability
– Project Management and Staffing
– DOE Smart Grid Programs
– Summary from Learning Session
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• Dependent on the co-op’s starting point…
– Begin by understanding the most pressing present challenges by benchmarking against peers?
• What is the present reliability situation versus peers?
• What is the present member satisfaction level?
• What is the present retail and wholesale rates situation?
• What amount of automation technology is in place now?
• Are you getting all you can out of your present technology investments?
• What is the debt to equity ratio and access to borrowing?
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What to Deploy In What Order?
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• Status quo may not be good enough!
– Many utilities will be making major investments with automation technologies that will improve reliability.
– Various other new pricing opportunities will also be introduced such as dynamic pricing and Critical Peak Pricing. Risk exists without having the core infrastructure for these services.
• Selecting a overall strategy of technology adoption will become more obvious with a decision to be:
– Leaders/innovators
– Fast-followers
– or Laggards
What to Deploy In What Order?
Nothing wrong with being a laggard if it makes good strategic sense for your co-op.
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Fourth quartile (Lowest 25% of the total group)
Third quartile (25% to 50% of the total group)
Second quartile (50% to 75% of the total group)
First quartile (top 25%)
Utility Comparison of Technology Use
Present Position Compared With Other Peer Utilities
Sample Comparison. Where is your utility?
Tec
hnol
ogy
Leve
l of
Mat
urity
Technology Maturity Use Comparison
Technology Maturity Level?
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Power System Engineering, Inc.
Developing a Technology Strategic Plan
Benchmark Customer Satisfaction
Metrics
Benchmark Customer Satisfaction
Metrics
Benchmark Reliability
Metrics
Benchmark Reliability
Metrics
Benchmark Staffing Levels
With Peers
Benchmark Staffing Levels
With Peers
Complete Business Cases for
Possible Automation Technology Selections
Complete Business Cases for
Possible Automation Technology Selections
Create Technology RoadmapCreate Technology Roadmap
Develop Plan to
Address Smart Grid Technology Roadmap
Develop Plan to
Address Smart Grid Technology Roadmap
Benchmark Customer
Rates
Benchmark Customer
Rates
Consider Various Technology ApplicationsConsider Various Technology Applications
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Present StatePresent State
GapAnalysis
GapAnalysis Transition PlanTransition Plan
Desired StateDesired State
Automation Roadmap –AMI, DA, SCADA, MWM, AVL, Others
Automation Roadmap –AMI, DA, SCADA, MWM, AVL, Others
Smart Grid ReadySmart Grid Ready
Identify High Value ProgramsIdentify High
Value Programs
CommunicationsRoadmap
CommunicationsRoadmap
ImplementationImplementation
Developing a Technology Roadmap
Smarter DatabaseSmarter Database
Distribution AutomationDistribution Automation
Need for Demand Response
Need for Demand Response
Future Automation Programs
Future Automation Programs
Current Programsand Assets
Current Programsand Assets
IdentifyBusiness Goals
IdentifyBusiness Goals
What are Industry Trends?
What are Industry Trends?
Available Staff Resources
Available Staff Resources
Current LimitationsCurrent
Limitations
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PSE Project Methodology
Strategic Planning Approach
• Continuous interaction with project team• Formal project management process• Best balance between technology costs and functionality• Address security, interoperability, and regulatory requirements• Risk mitigation assessment• Create the most favorable contract terms and costs• Formal testing
Strategic Planning Approach
• Continuous interaction with project team• Formal project management process• Best balance between technology costs and functionality• Address security, interoperability, and regulatory requirements• Risk mitigation assessment• Create the most favorable contract terms and costs• Formal testing
Moving Forward Towards Deployment
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1. Background and Drivers of the Smart Grid: “Situational Analysis”
2. Strategic and Tactical Goals – “What the Smart Grid Should Do”
3. Developing a Smart Grid Plan – “For Your Cooperative”– Technology Strategic Plan – What to deploy in what order?
– Smart Distribution
– Smart Home and Demand Response
– Security & Interoperability
– Project Management and Staffing
– DOE Smart Grid Programs
– Summary from Learning Session
Agenda
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Power System Engineering, Inc.
The Need for Distribution Automation (DA)• Aging Infrastructure:
– Requires enhanced monitoring for reliable service.
• Increased reliability requirements:
– Increased expectations from customers.
– CAIDI, SAIFI, SAIDI etc., used to benchmark reliability performance
• Information era demands higher power quality:
– Estimated $52 billion annually in the US lost due to poor power quality.
– Loss due to sustained interruptions of five minutes: $26 billion.
• Increased demand for power:
– High cost of peaking units, longer gestation of base load plants combined with the carbon costs as well as the negative publicity associated with fossil fuel technologies are becoming strong reasons for utilities to implement advanced DA.
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Benefits of Distribution Automation (DA)
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DAProgram
Types
Improved Reliability
Improved Performance
Indices
Increased Revenue
Reduce Losses
Improved Asset Life
Smart Switching
Conservation Voltage Reduction (CVR)
Power Factor Improvement (VAr)
Fault Indicators
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Deployment of DA - Smart Switching
• Automatically determine section of line that is experiencing problems.
• Isolate the fault to a small segment of the system thereby increasing revenue/improved reliability.– DA communicates back to dispatch, providing more
effective crew dispatching and routing.
• Makes crews more effective and productive.– Faster restoration time.
– Less patrolling time.
First, Maximize Today’s Applications
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no
Sub 1 Sub 22 4 5 6
Sectionalizing Device ---closed
Sectionalizing Device ---open
1
71
8
3
Customers 1
Customers 2
Customers 3
• When Fault A occurs, customers 2 & 3 experience“blinks” & outage.• DA detects the faulted area and then initiates network reconfiguration by opening switch 3 and closing switch 4.
Fault A
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Smart Switching
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VAr ControlWhat is Distribution VAr Control?
• VAr control corrects for Power Factor under various loading conditions. An assessment is required to determine appropriate amount of VAr correction.
• Installing both fixed and switched capacitors will achieve Power factor improvement.
Why implement VAr Control? • To improve distribution voltage profile, especially
for long feeders and variable load conditions.
• To improve customer voltage profile.
• Reduce wholesale Power Factor penalty. Capacitor Bank- Cooper Power Systems
• To reduce line losses (I2R) resulting in kWh savings and improved system efficiency.
• Can be used in conjunction with CVR.
• Dynamically dispatch VArs based on load to improve Power Factor
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Conservation Voltage Reduction - CVRWhat is Distribution CVR?
• CVR lowers system voltage under peak demand conditions resulting in lower demand. An assessment is required to determine the appropriate step(s) of voltage reduction to not impact end user ANSI voltage standard.
• Substation regulator or transformer LTC controls can be programmed to reduce voltage in step increments.
• CVR is coordinated using a SCADA system.
Why implement CVR? • For every 1% in voltage reduction, approximately 0.8% demand reduction can be achieved. This can be a significantsavings during peak demand conditions.• Switched capacitors can be used in conjunction with CVR
control to optimize CVR benefits.
• Overall Cost Reduction
Distribution Programs
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� Conservation Voltage Reduction (CVR)
� Conservation Voltage Reduction or CVR is the practice of lowering voltage on a distribution system with the objective of decreasing coincident peak demand (MW).
� Typically studies have shown that load will decrease between 0.72% - 1% for each 1% reduction in voltage
� Result: Reduce distribution system coincident peak
� Deployment Steps
� Base line your system
� Analyze & Identify
• Low voltage spots
• Voltage Vs Energy Savings
• Would VAR compensation make sense?
� Conceptual & Detail Designs
Volts
Feeder Distance (%)
Typical Profile
Desired Profile
Energy Savings Potential
CVR Applied:Peak Demand
Savings
Feeder Voltage Profile
Conservation Voltage Reduction (CVR)
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Faulted Circuit Indicators (FCI)
• Fault Indicators provide visual indication of faults that helps in quickly tracing the fault location on an electrical distribution line.
• Types:
– Overhead: Provides visual indication of overhead circuit fault.
– Underground: Usually located in underground vaults, they provide visualization of faults in underground systems. Many vendors provide a wireless interface to check the status of FCI. Notable developments include:
– a remotely-programmable overhead line indicator with wireless communications
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Smart Home and Demand Response
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1. Background and Drivers of the Smart Grid: “Situational Analysis”
2. Strategic and Tactical Goals – “What the Smart Grid Should Do”
3. Developing a Smart Grid Plan – “For Your Cooperative”– Technology Strategic Plan – What to deploy in what order?
– Smart Distribution
– Smart Home and Demand Response
– Security & Interoperability
– Project Management and Staffing
– DOE Smart Grid Programs
– Summary from Learning Session
© 2010 Power System Engineering, Inc.
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Demand Side Management Components and Definitions
“Changes in electric usage by end-use customers from the normal consumption patterns in response to changes in the price of electricity over time, or to incentive paymentsdesigned to induce lower electricity use at times of high wholesale market prices or when system reliability is jeopardized.”U.S. Department of Energy
DEMAND RESPONSEPeak Clipping & Load Shifting
DEMAND SIDE MANAGEMENT
ENERGY RESPONSE
Direct Load Control Innovative Pricing CPP
, Conservation
Less Output to Consumers
Energy Efficiency
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Direct Load Control• These are not new programs. Many cooperatives have had
these programs since the 1980s.
• Control appliances typically could be:
– Water heaters
– AC units
– Space heat
– Irrigation
• What is New with Direct Load Control? AMI will now provide two-way verifications with direct load control programs.
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Historically, load management has been provided over One-
Way VHF Radio and Commercial Paging
Technology .
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Illustrative Load Reduction Simulation
Smart Thermostat Example: 4 Degree Shift in Thermostat - on hypothetical single family home.
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Demand Side Management Components and Definitions
“Changes in electric usage by end-use customers from the normal consumption patterns in response to changes in the price of electricity over time, or to incentive paymentsdesigned to induce lower electricity use at times of high wholesale market prices or when system reliability is jeopardized.”U.S. Department of Energy
DEMAND RESPONSEPeak Clipping & Load Shifting
DEMAND SIDE MANAGEMENT
ENERGY RESPONSE
Direct Load Control Innovative Pricing CPP
, Conservation
Less Output to Consumers
Energy Efficiency
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Rate Design Options
• Load Management Rates.
• Dynamic Pricing.
– Real-Time Pricing.
– Time of Use (TOU).
– Critical Peak Pricing (CPP).
– Critical Peak Pricing w/Time of Use.
• Inverted Block Rates.
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Peak Reduction
Energy Conservation
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Dynamic Pricing
• Not necessarily real-time prices, could be pre-set TOU.
• Billing for electricity according to when it is used.
• Provides an incentive to reduce consumption during peak times, but relies on customers to take action.
• Requires integration of capable metering, billing, device automation, communications and data management systems, i.e. early stage smart grid.
• End goal is to better align the cost of producing electricity with the retail price charged to customers.
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Real Time Pricing• Pricing structure that charges hourly real-time prices for
consumption based on some index or market-clearing price.
– Provides a “transparent” price signal to customers.
– Very complex and difficult to explain.
– Has typically only been made available for large C&I loads.
– Does encourage and can be effective at causing load reductions during high cost hours.
– However, complexity may preclude behavior modification.
– Have to play by market rules.
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Critical Peak Pricing
• Rate structure that prices peak capacity or energy costs into “critical” peak hours.– Consumers notified ahead of peak.
– Peak hours predetermined, i.e. 4-hour window.
– Typically 40-80 hours per year.
– Retail per kWh price may be 4-6x higher than standard rate.
– Could be provided as a rebate (carrot) vs. charge (stick).
– Can include or exclude Time-of-Use.
– Increase success/efficiency if coordinated with power supplier.
– Are typically offered as voluntary or pilot programs.
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Critical Peak Pricing - Rate Structure
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Published in the January 2008 NRECA CRN Report, AMI: Value Beyond Meter Reading
Example of CPP Rate Design
Rate PeriodPresent Rate (per kWh)
New Rate (per kWh)
% of Annual Time on Each New Rate
Off Peak
$0.08
$0.065 85%
Peak $0.09 14%
Super Peak $0.25 1%
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Smart Thermostat Programs? Similar to CPP. Enables a utility to inform customers about a near-
term/impending "peak" or critical period, in which the customer will begin throttling up the thermostat during the hot summer days. The goal is not to shut off the air-conditioning but to adjust the timing.
Why do it? Primary reason: financial and cost avoidance. It has been introduced for some of
the same reasons as direct load control was introduced at utilities years ago –shift energy use off the peaks to the extent as possible.
Smart Thermostat Programs
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Cellnet+Hunt ecoMeter
Energate Pioneer
PRI Home Energy Controller
Ambient Energy Orb The Energy Detective
Aclara IHD
SRP M-Meter
Energy Monitoring TechnologiesEUT-200Greenwire
Energy Monitor
Power Cost Display (ECSI)USCL EMS 2020
Kill-A-Watt
Cent-a-Meter
Brultech EML-2020
Some Available In-Home DisplaysRefer to CRN’s report on Determining the Effectiveness of In-Home Energy Use Displays for more information on this.
Itron Aztech
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Web Portals – For Home Automation
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Google cites figures showing that regularly viewing real-time energy use will prod people to cut electricityby 5 to 15% on average through behavioral changes.
Refer to CRN’s Tech Surveillance Article “Home Automation Networks: Will a Clear Winner Emerge?
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• Use of a web site that contains energy efficiency and various forms of Time of Use Pricing announcements.
– This can be in place of a Home Display Unit, Load Management Switch, Smart Thermostat, etc.
Web Portals – Home Automation
Password Protected Public Web Site
Home
S e rv e rS e rv e r
Enterprise System
(AMI – Demand Response Manager &
Databases, etc.)
Utility Data CenterCo-op Web Site
Standard Internet
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Historical Consumption and
Price Data
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1. Background and Drivers of the Smart Grid: “Situational Analysis”
2. Strategic and Tactical Goals – “What the Smart Grid Should Do”
3. Developing a Smart Grid Plan – “For Your Cooperative”– Technology Strategic Plan – What to deploy in what order?
– Smart Distribution
– Smart Home and Demand Response
– Security & Interoperability
– Project Management and Staffing
– DOE Smart Grid Programs
– Summary from Learning Session
Agenda
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48
NIST• NIST - National Institute of
Standards & Technology Second draft for commenting February 2010
– Power plants, substations and control centers, distribution system, servers, software systems field IEDs, meters, all the way from the home to the data centers “end to end”.
– “Essential to the reliable operation of critical assets”.
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Six Steps to Security Compliance1. Follow the NIST “Smart Grid Security Strategy and
Requirements” Feb 2010 Draft Report
2. Based on the above NIST document, create a cyber-security policy for your Co-op
3. Identify critical assets and assess risks.
4. Deploy protective measures.
5. Monitor and manage networks on a regular basis to ensure compliance
6. Also plan for disaster recovery.
– NIST: National Institute of Standards and Technology 49
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1. Understanding the regulatory environment
2. Assessing assets, deciding what’s important
3. Developing policies
4. Developing procedures
5. Training
6. Providing physical security
7. Perimeter protection
8. Malware protection
9. Software security
10. Financial and legal tools
11. Monitoring
12. Audit
13. Planning for failure
14. Reviewing and revising to keep everything current
Elements of Cyber Security Plan
And Testing, Testing and More Testing50
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Integration of Applications
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Smart Database Architecture
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CPP TOU AMI
SCADAFault
RecordingDemand Response
Smart Thermostat
Auto Sectionalizing
Volt/VAr Control
Databases of Field Applications
Distribution Automation
Enterprise Integration of Applications
OMSCISDAAMIEMS GIS
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NIST: Long Term View of Interoperability & Security
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1. Background and Drivers of the Smart Grid: “Situational Analysis”
2. Strategic and Tactical Goals – “What the Smart Grid Should Do”
3. Developing a Smart Grid Plan – “For Your Cooperative”– Technology Strategic Plan – What to deploy in what order?
– Smart Distribution
– Smart Home and Demand Response
– Security & Interoperability
– Project Management and Staffing
– DOE Smart Grid Programs
– Summary from Learning Session
Agenda
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Project Management• More projects fail due to poor project management
than technology shortfalls.
• Smart Grid projects are often more complex than single technology deployments due to:
– Needs for a greater amount of integration.
– The needs to add more sophisticated databases.
– Multiple departments are often working together.
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Project Management MethodologyThe project management office (PMO), as defined by the Project Management Institute, is “an organizational body or entity assigned various responsibilities related to the centralized and coordinated management” of projects. The primary function of the PMO is to support project managers by:
1.Managing shared resources across all projects.
2.Establishing project management methods, standards and best practice.
3.Demonstrating leadership – coaching, training, and oversight.
4.Monitoring compliance to establish standards, policies and procedures.
5.Establishing standardized tools, templates, and documentation repository.
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Project Managers Must
• See the big picture.
• Clearly document realistic and balanced costs, schedule, and objectives.
• Manage project scope and balance of cost, schedule, and objectives.
• Maintain management support.
• Motivate team.
• Leverage team skills.
• Maintain quality targets.
• Manage risks and respond quickly to problems.
• Manage schedule.
• Watch budget and costs.
• Review milestones.
• Assure attention to detail.
• Manage major contracts.
Most importantly - achieve accurate and timely communications among
the project team.57
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Agenda
1. Background and Drivers of the Smart Grid: “Situational Analysis”
2. Strategic and Tactical Goals – “What the Smart Grid Should Do”
3. Developing a Smart Grid Plan – “For Your Cooperative”– Technology Strategic Plan – What to deploy in what order?
– Smart Distribution
– Smart Home and Demand Response
– Security & Interoperability
– Project Management and Staffing
– DOE Smart Grid Programs
– Summary of Learning Lessons
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• Investment Grants
– 100 utility projects were selected across the US.
– $3.4 Billion in funds.• Projects split between:
– AMI projects.
– Demand Response.
– Distribution Automation.
– Others
• Demonstration Grants
– 32 utility projects.
– $877 million in funds:• Advanced Distribution
• Demand Response
• Hybrid Vehicle
• Smart Home
• Others
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DOE Smart Grid Programs
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NRECA Demonstration Grant Winner• Enhanced demand and distribution management regional
demonstration - Install and operate of a suite of diverse smart grid technologies and aggregate the data from 23 rural electric cooperatives across 10 states.
• Technologies will include over 130,000 meters.
• Over 18,000 demand response switches.
• Nearly 4,000 in-home displays or smart thermostats and others.
• Voltage sensors and fault detectors.
• The demonstration data will be centralized for all sites and include studies on total demand, distributed energy resources, peak pricing, customer appliance control, and self-healing technologies.
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NRECA DOE Demo Grant Summary
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Ty
pe
s
ParticipantsIHD/WP
Pilots
DR over
AMI (water
heater &
AC direct
load
control)
Interactive
Thermal
Storage
Smart
Feeder
Switching
Advanced
Volt/Var
Control
CVR
AMI
(DR
Program)
MDM
(DR
Program)
Comm
(DR & DA
Program)
SCADA
(Front
End
Master
System)
Adams Electric Co-op, IL X X X X X X X X
Adams-Columbia Electric Co-op, WI X X X X
Clarke Electric Co-op, Inc., IA X X X X X X X
Consumers Energy, IA X X X X
Corn Belt Power Co-op, IA X X X
Calhoun Co. ECA X X
Grundy Co. REC X
Humboldt Co. REC X X
Iowa Lakes EC X
Midland Power Co-op X
Prairie Energy Co-op X X
Delaware County Electric Co-op, Inc., NY X X X X
Flint EMC, GA X X
Kaua'i Island Utility Co-op, HI X X X X X
Menard Electric Co-op, IL X X X X
New Hampshire Electric Co-op, NH X X X X X
Nolin RECC, KY X X X X X X X X
Owen Electric Co-op, Inc., KY X X X X X X X X
Prairie Power, Inc., IL X X
Salt River Electric Co-op Corp., KY X
Snapping Shoals EMC, GA X X X X X X
United REMC, IN X X X X X X X
Washington-St. Tammany Elec. Co-op, LA X X X X X
Act
ivit
ies
Enabling TechnologiesDistribution Automation Demand Response (DR)
© 2010 Power System Engineering, Inc.
Power System Engineering, Inc.
Share Results with the Industry
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Sample of Hypothetical Demonstration Results
© 2010 Power System Engineering, Inc.
Power System Engineering, Inc.
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Agenda
1. Background and Drivers of the Smart Grid: “Situational Analysis”
2. Strategic and Tactical Goals – “What the Smart Grid Should Do”
3. Developing a Smart Grid Plan – “For Your Cooperative”– Technology Strategic Plan – What to deploy in what order?
– Smart Distribution
– Smart Home and Demand Response
– Security & Interoperability
– Project Management and Staffing
– DOE Smart Grid Programs
– Summary from Learning Session
Power System Engineering, Inc.
© 2010 Power System Engineering, Inc.
Power System Engineering, Inc.
Summary From Learning Session
1. Each co-op can create their own Definition of their Smart Grid Plan
2. Create a plan - what to deploy in what order – Business Cases
3. Select Programs – New DA, Demand Response, Substation Automation, get more out of present systems – AMI, GIS, other
4. Seek benefits with advanced integration and comply with new cyber security mandates.
5. Learn from others
6. Deploy with a solid project management plan
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© 2010 Power System Engineering, Inc.
Power System Engineering, Inc.
CRN Smart Grid Related Reports• CRN and the Smart Grid
– go to www.cooperative.com/crnand select Resources, CRN Guides, CRN & The Smart Grid”.
• AMI: Beyond Meter Reading
• Guide to Down Line Automation
• Communication Infrastructure for Electric System Automation
• Turning Data Into Useful Information, Problems and Potential Solutions for Electric Cooperatives
• Communication Technologies for SCADA, AMR, Mobile Radio, and Distribution Automation
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© 2010 Power System Engineering, Inc.
Power System Engineering, Inc.
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PSE would like to thank you for your time and the opportunity to speak at this event.
Rick Schmidt
VP, System Design and Communications
Direct: 608-268-3502
Mobile: 608-358-5661
Email: [email protected]
Christopher Ivanov
Economic Analyst
Direct: 608-268-3516
Mobile: 608-335-7858
Email: [email protected]
Website: www. powersystem.org
Thank You.
Power System Engineering, Inc.
© 2010 Power System Engineering, Inc.
Power System Engineering, Inc.
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© 2010 Power System Engineering, Inc.
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Want more?
2010 CRN SUMMITTheme: The Smart Grid for Co-ops
June 29 & 30
New Orleans
Find out more: www.cooperative.com/CRN