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ENGR 340Fall 2011
Iowa State University
Electric Power Industry Overview
James D. McCalleyHarpole Professor of
Electrical & Computer Engineering
Outline1. The electric power industry2. Control centers3. Electricity markets
2
Organizations comprising the Electric Power IndustryOrganizations comprising the Electric Power Industry• Investor-owned utilities: 239 (MEC, Alliant, Xcel, Exelon, …)• Federally-owned: 10 (TVA, BPA, WAPA, SEPA, APA, SWPA…)• Public-owned: 2009 (Ames, Cedar Falls, Muscatine, …)• Consumer-owned: 912 (Dairyland, CIPCO, Corn Belt, …)• Non-utility power producers: 1934 (Alcoa, DuPont,…)• Power marketers: 400 (e.g., Cinergy, Mirant, Illinova, Shell Energy, PECO-
Power Team, Williams Energy,…)• Coordination organizations: 9 (ISO-NE, NYISO, PJM, MISO, SPP, ERCOT,
CAISO, AESO, NBSO), 7 are in the US.• Oversight organizations:
• Regulatory: 52 state, 1 Fed (FERC)• Reliability: 1 National (NERC), 8 regional entities• Environment: 52 state (DNR), 1 Fed (EPA)
• Manufacturers: GE, ABB, Toshiba, Schweitzer, Westinghouse,…• Consultants: Black&Veatch, Burns&McDonnell, HD Electric,…• Vendors: Siemens, Areva, OSI,…• Govt agencies: DOE, National Labs,…• Professional organizations: IEEE PES …• Advocacy organizations: AEWA, IWEA, Wind on Wires…• Trade Associations: EEI, EPSA, NAESCO, NRECA, APPA, PMA,…• Law-making bodies: 52 state legislatures, US Congress
3
4
Apr 1990: UK Pool
opens
Jan. 1991: Norway launches Nordpool
Jan. 1996: Sweden in Nordpool
Oct 1996: New
Zealand NZEM
Jan 1998: PJM ISO created
Mar 1998: Cal ISO opens
Jan. 1998: Finland in Nordpool
Dec 1998: Australia
NEM opens
Nov 1999: NY ISO launches
May 1999: ISO-NE opens
Jan. 2000: Denmark in
Nordpool
Mar 2001: NETA
replaces UK Pool
July 2001: ERCOT becomes
one control
area May 2002:
Ontario IMO
launches
North America
1990 1992 2000 1998 1996 1994
Jan. 2001: Alberta Pool opens
Overseas
2002 2004 2006
Dec 2001 MISO becomes first RTO
Feb 1996 MISO formed.
April 2005 MISO Markets Launch
1996: ERCOT becomes ISO.
Jan 2002 ERCOT opens retail zonal mrket
2008 Feb 2007 SPP Markets Launch
Dec 2008 ERCOT Nodal Market
Launched
Big changes between 1992 and 2002….Big changes between 1992 and 2002….
1900-1996/2000
G G
G
G
G
G
G
G
TransmissionOperator
IndependentSystem
Operator
TransmissionOperator
TransmissionOperator
Today
G G G
G
G
G
G G
Transmission and System Operator
Vertically Integrated Utility
IndependentSystem
Operator
5
What are the North American Interconnections?What are the North American Interconnections?
“Synchronized”
6
What is NERC?What is NERC?• NERC: The North American Reliability Corporation, certified by federal government
(FERC) as the “electric reliability organization” for the United States.• Overriding responsibility is to maintain North American bulk transmission/generation
reliability. Specific functions include maintaining standards, monitoring compliance and enforcing penalties, performing reliability assessments, performing event analysis, facilitating real-time situational awareness, ensuring infrastructure security, trains/certifies system operators.
• There are eight NERC regional councils (see below map) who share NERC’s mission for their respective geographies within North America through formally delegated enforcement authority
• Western Electricity Coordinating Council (WECC)
• Midwest Reliability Organization (MRO)• Southwest Power Pool (SPP)• Texas Reliability Entity (TRE)• Reliability First Corporation (RFC)• Southeast Electric Reliability Council
(SERC)• Florida Reliability Coordinating Council
(FRCC)• Northeast Power Coordinating Council
(NPCC)
7
What is FERC?What is FERC?• An independent agency that regulates the interstate transmission of electricity,
natural gas, and oil. It does the following:• Regulates transmission & wholesale sales of electricity in interstate commerce;• Reviews mergers/acquisitions /corporate transactions by electricity companies; • Reviews the siting application for electric transmission projects under limited
circumstances; • Licenses and inspects private, municipal, and state hydroelectric projects;• Protects the reliability of the high voltage interstate transmission system through
mandatory reliability standards; • Monitors and investigates energy markets; • Enforces FERC regulatory requirements through imposition of civil penalties and
other means;• Oversees environmental matters related to natural gas and hydroelectricity
projects and other matters; • Administers accounting and financial reporting regulations and conduct of
regulated companies.”• FERC does not:
• Regulate retail electricity and natural gas sales to consumers;• Regulate activities of municipals or federal power marketing agencies;• Regulate nuclear power plants (NRC does this);• Address reliability problems related to failures of local distribution facilities; • Consider tree trimmings near local distribution power lines in residential
neighborhoods8
What are ISOs?What are ISOs?• The regional system operator: monitors and controls grid in real-time• The regional market operator: monitors and controls the electricity markets• The regional planner: coordinates the 5 and 10 year planning efforts• Also the Regional Transmission Organization (RTO)• They do not own any electric power equipment! • None of them existed before 1996!
• California ISO (CAISO)
• Midwest ISO (MISO)
• Southwest Power Pool (SPP)
• Electric Reliability Council of Texas (ERCOT)
• New York ISO (NYISO)
• ISO-New England (ISO-NE)
• Pennsylvania-Jersey-Maryland (PJM)
9
Energy Control CentersEnergy Control Center (ECC):
• SCADA, EMS, operational personnel• “Heart” (eyes & hands, brains) of the power system
Supervisory control & data acquisition (SCADA):• Supervisory control: remote control of field devices, including gen• Data acquisition: monitoring of field conditions• SCADA components:
» Master Station: System “Nerve Center” located in ECC» Remote terminal units: Gathers data at substations; sends to Master
Station» Communications: Links Master Station with Field Devices, telemetry is
done by either leased wire, PLC, microwave, or fiber optics.
Energy management system (EMS)• Topology processor & network configurator• State estimator and power flow model development• Automatic generation control (AGC), Optimal power flow (OPF)• Security assessment and alarm processing
10
SubstationRemote terminal unit
SCADA Master Station
Com
mun
icati
on li
nk
Energy control center with EMS
EMS alarm displayEMS 1-line diagram 11
ECCs: EMS & SCADA
Today’s real-time market functions
SCADA
Overloads & Voltage Problems
Potential Overloads &
Voltage Problems
Breaker/Switch Status Indications
System Model Description
Telemetry & Communications equipment
State Estimator
Network Topology program
AGC
Economic Dispatch
OPF
Contingency Selection
Contingency Analysis Security Constrained OPF
Display Alarms
Updated System Electrical Model
Analog Measurements
Display to Operator
Power flows, Voltages etc.,
Display to Operator
Bad Measurement Alarms
Generator Outputs Generation Raise/Lower Signals
State Estimator Output
Substation RTUs and
power plants
EMS
12
ECCs: EMS & SCADA
More energy control centers
13
More energy control centers
14
15
Balancing authorities
Performs AGC within designated area.105 BAs in N. Am.: 67 in EI, 38 in WI, 1 in Texas.Every ISO is a BA. Not every BA is an ISO.
16
Basics of electricity markets
1. Locational marginal prices (LMPs)2. Markets compute the LMPs via an internet-
based double auction that maximizes participant benefits
3. There are 2 separate settlement processes.
17
Locational marginal prices
1. One for each bus in the network.2. Three components – see above.3. If the network is lossless, and the
transmission capacity is infinite, then all buses have the same LMP.
18
MISO and PJM balancing areas
19
RT LMPs in the MISO and PJM balancing areas
7:20 am (CST) 9/8/2011
20
RT LMPs in the MISO and PJM balancing areas
7:40 am (CST) 9/8/2011
21
Average annual locational marginal prices
22
Market clearing price
Computed as the price where the supply schedule intersects the demand schedule.
SUPPLY
DEMAND
Price ($/MWhr)
Quantity (MWhr)
23
Market clearing price
Computed as the price where the supply curve intersects the demand curve.
Price ($/MWhr)
Quantity (MWhr)
SUPPLY
DEMAND
24
Locational marginal prices
25
CAISO market design
Schedules entire “next-day” 24hr period.
Schedules interchange for entire “next-day” 24hr period, starting at current hour, optimizing one hour at a time (1 value per hr)
Computes dispatch every 5 minutes.
26
Electricity “two settlement” markets
Day-Ahead Market(every day)
Real-Time Market(every 5 minutes)
Energy & reserve offers from gens
Energy bids from loads
Internet system
Which gens get committed, at roughly what levels for next 24 hours, and settlement
Internet system
Energy offers from gens
Energy bids from loads
Generation levels for next 5 minutes and settlement for deviations from day-ahead market
Generates 100 mw; paid $100.
Generates 99 mw; pays $1.
27
Day-ahead LMPs in ISO-NE balancing areas
For hour ending 11:00 am (EST) 9/8/2011
28
RT LMPs in the ISO-NE balancing areas
10:25 am (EST) 9/8/2011
29
RTAncillary service prices in ISO-NE bal areas
10:25 am (EST) 9/8/2011
Regulation clearing price is $5.11/MW.
Load Zones: Connecticut (CT), Southwest CT (SWCT), Northeast Massachusetts/Boston (NEMABSTN)
TMSR=10min spinning rsrvTMNSR=10min non-spinning rsrvTMOR=30min operating rsrv
30
How does wind participate in markets?
“Old” approach #1•Participates in day-ahead energy•Does not participate in AS or RT•Wind generates what it can•No deviation penalties•Paid based on computed LMP without wind, Point X below•Marginal unit backed off to compensate
Demand schedule without wind
Demand schedule with wind
Supply schedule
Quantity (MWhr)
Price ($/MWhr)
Point X
Point Y
“Old” approach #2•Participates in day-ahead energy•Does not participate in AS or RT•Wind generates what it can•No deviation penalties•Paid based on computed LMP with wind, Point Y below•Marginal unit backed off to compensate
31
How does wind participate in markets?
“New” Midwest ISO approach: Dispatchable intermittent resource (DIRs)
• Participates in day-ahead energy• Makes offer into RT market like any other
generator. But one unique DIR feature:• Instead of capacity max offered in by other generation
resources, the forecasted wind MW is used as the operation capacity maximum
• Units missing “schedule band” of 8% on either side dispatch instruction for four consecutive 5-min periods are penalized.
•What are implications?
32
How does wind participate in markets?
What are implications? Wind is dispatchable! Forecasting is key!•DIRs are expected to provide rolling forecast of 12 five-minute periods for the Forecast Maximum Limit.•If forecast not submitted in time, MISO forecast is used.•Each 5 minute dispatch optimization uses Forecast Maximum Limit based on the following order
1. Participant submitted Forecast for the interval•Must be less than or equal to the Feasibility Limit•Must have been submitted less than 30 minutes ago
2.MISO Forecast•Must be less than or equal to the Feasibility Limit•Must have been created less than 30 minutes ago
3.State Estimator
33
How does wind participate in markets?
34
Midwest ISO’s wind forecasting accuracy?
35
Why is DIR beneficial?1. DIRs are more likely to reduce output when LMP is
negative because dispatch will instruct them to reduce; there are penalties for not following dispatch.
2. Inclusion of the DIRs in the RT dispatch will give SCED more flexibility to manage constraints. Therefore, there will be fewer manual curtailments:
• Benefits wind for increased MWhrs produced• Benefits to system because wind offers low
36
Why is DIR beneficial?
37
Very fresh information!From: Amanda Brower [mailto:[email protected]] Sent: Tuesday, September 13, 2011 2:30 PMTo: [email protected]; [email protected]; [email protected]; [email protected]: [MISO] DIR Workshop II - Date Changed to October 17
Dear Stakeholders,The date of the Dispatchable Intermittent Resource (DIR) Workshop has changed to October 17, 2011, from 11:00 am to 5:00 pm ET. This workshop will be available from MISO Carmel or St. Paul facilities as well as by dial-in/webcast and recorded.
The purpose of this workshop is to expand on the information from the first workshop and give experiences since DIRs were implemented on June 1, 2011. Subject matter experts will be on hand to discuss different aspects of participation by DIRs, including communications, forecasting, operations, markets, and settlements. We encourage participants involved in DIR registration and operation to attend this workshop.
Registration is required by October 13 and may be accessed from the MISO website (www.misoenergy.org) directly via the URL below or from the Stakeholder Center tab by selecting: Committees, Work Groups, and Task Forces > Calendar > October 17 > Dispatchable Intermittent Resource (DIR) Workshop II
https://www.misoenergy.org/Events/Pages/DIR20111017.aspx