Smart Grid Panel Presentation
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1 Smart Grid Panel Presentation Robert J. Thomas Cornell University PSerc Summer Workshop Lake Tahoe, CA August 4, 2008
2 Smart Grid Values (Why are we doing this?) Some reasons A more reliable grid - power where and when users need it with a quality they value A more secure grid - able to withstand natural and manmade attacks w/o blacking out or exorbitant recovery costs A more economic grid - a grid that supports fair market design that results in fair prices and adequate supply A more efficient grid - promotes investment, reduces electrical losses, promotes efficient power production and power usage, and improved asset utilization An environmentally friendly grid - reduced environmental impact thorough improved and/or adoption of new generation, transmission, distribution, storage, and consumption
3 Smart Grid Characteristics Enable active participation by consumers by giving consumers new information, control, and by giving operators willing consumers as a resource. Accommodate all generation and storage options by seamlessly integrating all option types and sizes through plug and play Enable new products, services and markets by linking buyers and sellers and supporting new electricity markets from home energy management to market operations across regions Provide power quality for the digital economy at various levels and at different pricing Optimize asset utilization and operate efficiently to deliver the desired functionality at minimum cost Anticipate and respond to system disturbances by continuous monitoring, self-assessment, and automatic reconfiguration for maximum resiliency in the fact of uncertain disturbances either natural or manmade
4 The Underlying Enabler monitoring and communication Currently the communication system is SCADA with little or no two-way communication with consumers possible
5 SCADA - Architecture Basic elements are sensors which measure the desired quantities Current Transformers CTs measure currents and Potential Transformers PTs- measure voltages. Today there is a whole new breed of Intelligent electronic devices (IEDs) These data are fed to a remote terminal unit (RTU) The master computer or unit resides at the control center EMS
6 Control Communication Architecture From a presentation by D. Whitehead, Communication and Control in Power Systems, tcip summer school, June, 2008
7 Legacy Intra Substations Communications A large amount of serial communication EIA-232, EIA-422/485 Media Type Copper and Fiber Optics Various Data Rates As slow as 300 bits/sec and as fast as 115k bits/sec Modern Intra Substations Communications Ethernet Media Type Copper and Fiber Optics Various Data Rates 10/100 MB, 1GB
8 Vision: End-to-End Trust Provisioning for Power Grid Monitoring and Control Ethernet / IP-Network (Secure, Real-time, Monitored) Control Center Level ISO Ethernet / IP-Network (Secure, Real-time, Monitored) Coordinator Level Backup Data Private IP-Based Network (Secure, Real-time, Monitored) Smart Gateway/Hub Private IP-Based Network (Secure, Real-time, Monitored) Network Level Private IP-Based Network (Secure, Real-time, Monitored) Metering and Load Control IED IED IED Smart Gateway/Hub Local HMI IED IED IED IED DFR Ethernet / IP-Network (Secure, Real-time, Monitored) Substation Level Sensor/Actuator Level From a presentation by Klara Nahrstedt, TCIP Trusted Networked Cyber-Infrastructure, June,
9 Smart Grid
10 Markets, reliability and the smart grid What can markets do with a ubiquitous communication system?
11 Transaction Management Transaction Information System (TIS) Non-SCADA information Used by both purchasing and selling entities, including utility generation, to arrange for interchange transactions by buying and/or selling energy and capacity and recording the transaction by transmitting the information required in the Interchange Transaction Request template (generally referred to as the tag ) to the appropriate control areas Control areas assess and approve or deny interchange transactions based on reliability criteria and adequacy of interconnected operations services and transmission services The TIS supports scheduling of interchange at multiple time standards and tracks individual interchange schedules so that during a ramp the actual ramped MW level of the schedule is known Transaction modifications - Purchasing-selling entities that reallocate (aggregate or split) an interchange transaction submit new interchange transaction(s) to displace modified transaction(s). If modified while in progress, the transaction is terminated and a new transaction entered for the remainder of the transaction period
12 One problem The data from the TIS is used by the ISO s to clear the market (I.e., determine generation dispatch and the prices generators will be paid and the amount loads will pay). A DC OPF with proxy limits is usually used with a sequential AC power flow analysis checking scheme to ensure reliably operation. Some of the dispatches that result from a linearized (DC) OPF might not be feasible due to violation of constraints that were not considered No science-based method to choose the best set of proxy limits The choice of proxy limits can result in a large deviation from the solution obtained from an AC OPF - especially the price part of the solution.
13 Example: Voltage Stability P V<θ Note that V and P are related. Placing a limit on V automatically places a limit on P P,Q V In this simple case, P is an exact proxy for V P
14 An example of limits and pricing 1 2 Case 4: Voltage + Q limit Voltage problem $10 Case 3: Individual flow limit 4 $50 200MW Case 2: Cutset flow limit Example from Alvarado Converting System Limits to Market Signals IEEE PES, May 2003 w/ mods by Thomas 3 Case 1: Cutset flow limit Line reactance's are all 0.1pu
15 Some Proxy Limit Options 1) Declare bus 4 to be a load pocket and limit the imports into bus 4 by limiting the total flow across the 2/4 and 3/4 interface; 2) Limit the imports into bus 4 by controlling the flows across the 1/2 and 1/3 interface; 3) Limit the imports into bus 4 by limiting any one line, such as limiting the flow on line 1 (from 1 to 2); 4) Directly impose a limit on the voltage at bus 4 along with a limit on the reactive power that can be supplied by bus 4.
16 Locational Prices and Dispatch LMP s for each case Dispatch for each case Case Case Case Case Case Case Case Case4 * * Note: The dispatch remains the same but what a load pays (in this example) is vastly different depending on what limit is chosen.
17 Phasor Measurements and Locational Marginal Pricing min p," C( p) st p - p d - f(") = 0 " n = 0 V i p " i p i f (") p d i
18 We know that the LMP at bus i is given by : " i = #C( p( p d )) #p d i (the system cost to deliver one more MW But L(p,") = C(p) + # T (p $ p d $ f (")) + # 0 " n and %L %p = %C %p + #T = 0 to bus i) So, knowing v and theta means we know p and if we know C we can compute LMP directly for the current operating point
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