tso series transmission system operation glen boyle, sr

Disclaimer

• This training presentation is provided as a reference for preparing for the PJM Certification Exam.

• Note that the following information may not reflect current PJM rules and operating procedures.

• For current training material, please visit: http://pjm.com/training/training-material.aspx

PJM©2014

http://pjm.com/training/training-material.aspx




PJM©2011 www.pjm.com 1 PJM ©2011 www.pjm.com 1

Interconnection Training Program

PJM State & Member Training Dept.

Transmission System Operations

TO1

PJM©2011 www.pjm.com 2

Agenda

• 6 modules

– Basic Theory

– Reliability, Limits, Failures

– Contingency Analysis

– Out of Merit Dispatch

– Voltage and Voltage Adjustment

– Outage Scheduling


Agenda

• Methods of Instruction

– Presentation

– Class discussion

– Exercises

– Operator Training Simulator Demonstrations

– EPRI OTS PC Simulation

– PowerWorld Simulator Demonstrations

– Videos?

– Quizzes • 3 quizzes


Agenda

• Purpose and Function of the Transmission System

– TO1-1

• System Voltage and VAR Characteristics

– TO1-2

• Distribution and Generation Shift Factors

– TO1-3


Module Objectives

• Review the purpose and function of the transmission system.

• Review basic system voltage and VAR characteristics

• Demonstrate basic distribution factor theory.

• Determine power flows utilizing system distribution factors and generation shift factors

• Introduce the concept of $/MW effect.


Transmission System Fundamentals TO1-1


Module Objectives

• List the purpose and functions of the transmission system.

• Distinguish between the transmission system, the sub-transmission system and the distribution system.

• Given a simple one-line diagram, identify the major features of the PJM transmission system including:

– Lines, buses, and generating stations


Purpose and Function of the Transmission System

• Coordinated Operation

– Single system

– Part of the Eastern Interconnection

• Reliability

• Economy

– No transmission = Distributed Generation • $$$$


PJM & PJM West 500 kV Breaker DiagramDate11/13/2002

DescriptionLayout of APS system with PJM

LayoutE.D. Colodonato

Checked

Created in Visio. All revisions should be made in Visio then copied to PPT Visio : DOC#146099 Power Point : DOC#191687

12B

12C

11B

11C

11A

10B

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5070 5071

to Possum Point

Burches

Hill

23

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41

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63

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Calvert Cliffs

62

1

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H

B

G

A

Waugh Chapel

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Brighton

5055

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L

M

H

J

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35

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65

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Peach Bottom

5012

20515

215

225

23

501

505

503

504

Keeney

51

50

5053

115

315 325

125 135

335

Limerick

225 225

2

345

355

4A

4B

5010

475

185 285

575 675

385

Whitpain

1 2 3

5030

5031

505

503502

50

5036

Red Lion

1-5

2-6 2-8

1-7 1-9

2-5

New Freedom

5-6 7-8

1

2

2 3 4

1-3

1-5

2-6

Hope Creek

3-4

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2-10

1-9

1-8

2-8 2-6

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Salem

9-10 5-6

2

1

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5037

1-3

2-3 2-5

1-5 1-7

2-7

Deans1

2

1 2 3

5021

East Windsor

T1

Smithburg

5024

5020

145

475 175

138 kV

1

1TRHS

Elroy

5028

5029

5017

5023

3-4

2

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1-2

1

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4-5

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Sunbury

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SUN N

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5005

5052

5026

5009

5016

5014

21

N S

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145 MVAR

501382 B1-92

Hunterstown

5013

#1 bank

832/985 MVA

Fall 2001 Jan 2003

Spring 2002 Jan 2003 Jan 2003

CT1 CT2 CT3 ST1

165

MW

165

MW

165

MW

335

MW

14 2

1

2

16

1 3

4 5 6

8 9

21

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Keystone

5002

43

5001

5006

1

2

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2 3

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6 7 8

Conemaugh

21

Bedington

Doubs

Meadow Brook

Black Oak

Hatfield

Pruntytown

Fort Martin

Cabot

Yukon

Wylie Ridge

Harrison

to Kammer

(AEP)

Belmont

Pleasants

54 51 55

53 52

5956

50

BA

1 3 4 2

to Loudoun

1

3

2

1

2

34

7

8

2

3

520

544

512 514

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9

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B

2

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to Mt. Storm to Mt. Stormto Morrisville

572 580

7 9

10

12

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2 31

200

765/500 kV

to Mountianeer

765 kV

500 kV

New Construction

transfomer

breaker

generator

capacitor

KEY

PJM West PJM

PJM West PJM

501

Steel City

51

3

1

2

2


http://www.pjm.com/documents/maps.html


Transmission Paths (Bulk Transmission)

• Purpose

– Transfer bulk power from a generation source to load centers reliably and economically

• Typical Path lengths

– Range from 1/2 mile to 180 miles in Eastern U.S. • PJM longest Dumont-Marysville 765 kv (AEP) 180 miles

• PJM shortest 5037 Hope Creek - Salem <1 Mile

– Longer in Western U.S.

– For EHV, longer path lengths is more economical



• Typical voltage values

– Transmission is generally characterized by high voltage values • 69 kV - lowest voltage considered transmission

• 765 kV - Highest voltage level used in U.S.

– Different definitions depending on company

– Above 230 Kv considered EHV


Bulk Electric System (BES)

ReliabilityFirst Corporation (RFC) adopted the definition of Bulk Electric System (BES) to include facilities 100kV and above

The new BES definition new includes facilities that used to be controlled by Member TOs

All NERC and Regional standards will apply to all BES facilities


Bulk Electric System (BES)

The Bulk Electric System (BES) within the ReliabilityFirst footprint is defined as all:* Individual generation resources larger than 20 MVA or a generation plan with

aggregate capacity greater than 75 MVA that is connected via a step-up transformer(s) to facilities operated at voltages 100 kV or higher

Lines operated at voltages 100 kV or higher

Transformers (other than generator step-up) with both primary and secondary windings of 100 kV or higher

Associated auxiliary and protection and control system equipment that could automatically trip a BES facility, independent of the protection and control equipment’s voltage level



Distribution Voltage Transmission Subtransmission

Primary Secondary

765 kV

500 kV

345 kV

230 kV

138 kV

115 kV

69 kV

34.5 kV

25 kV

14.4 kV

13.2 kV

12 kV

4 kV

480 V

120 V

Typical Voltage Values



• Applications

– Backbone of the system • ties generation to load

– Used to connect companies

– Used to connect to outside pools

– Generally controlled by ISO (Independent System Operator)

• Let’s look at common flows on the transmission system on the PC simulator! – H:\CorporateServices\Training\Powerworldcases\ExampleCases\ECAR\98FFECAR.pwb


Transmission Paths (Sub-transmission)

• General definition

– Medium voltage power transmission path underlying the bulk transmission system

• Typical voltage values

– 34.5 kV to 138 kV

• Typical path lengths

– 0.1 to 40 miles


Transmission Paths (Sub-transmission)

• Application

– Intra-company power flow paths

– Move power from one area of a company to another

– Serve larger loads


Transmission Paths (Distribution System)

• General definition

– Those power lines which supply energy to residential and commercial customers and some of the smaller industrials

• Two Typical Voltage Ranges

– Primary Distribution • 12 kV - 25 kV

– Secondary Distribution • 120 V - 480 V



• Two types of distribution systems

– Networks • Normally densely populated areas

– Radial • Normally in rural areas

• Typical path lengths

– Several pole spans to many miles

• Applications

– Supply of power to customers


Transmission Line Standards - Glossary

• ACSR – aluminum conductor steel reinforced; Bare aluminum conductors stranded

around an inner core of galvanized steel wire(s). Often used in overhead power distribution and transmission lines.

• Kcmil – a measure of conductor area in thousands of circular mills; a circular mil (Cmil)

is the area of a circle with a diameter of one-thousandth (0.001) of an inch.

• kV – kilovolt (1,000 volts)

• M – million $

• MVA – megavolt-ampere (1 million volt-amperes); a unit of apparent power in an

alternating-current circuit. A volt-ampere (VA) is the product of voltage (volts) times current (amperes). A device rated at 10 amps and 120 V has a VA rating of 1200 or 1.2 kVA or 0.0012 MVA.


Overhead Transmission Line Standards

Overhead Lines

Voltage Conductor Size (kcmil) Right of Way Width

Range

Typical Normal Rating

(MVA)

Order of Magnitude

Installation Cost per

Circuit Mile (Millions)

69 kV 556 ACSR 60 - 90 ft. 85 $ 0.300 / mile

115 kV 795 ACSR 90 - 130 ft. 175 $ 0.450 / mile

138 kV 1033 ACSR 100 - 150 ft. 250 $ 0.700 / mile

230 kV 1590 ACSR 100 - 160 ft. 650 $ 0.950 / mile

345 kV 2167 ACSR 140 - 160 ft. 1650 $ 1.5 / mile

500 kV 2493 ACSR 160 - 200 ft. 2700 $ 1.8 / mile

765 kV

1351 ACSR (4 conductor

bundled) 200-250 ft. 4000 $ 2.5 / mile


69 kV Line

Conductor Size 556 ACSR

Right of Way 60 – 90 ft.

Normal MVA Rating 85 MVA

Cost per Circuit Mile $ 0.300 M / mile

Structure Type Single Pole, Steel or Wood


Double Circuit 115 kV Lines





Structure Type Single Pole, Steel or Wood


Double Circuit 138 kV Lines





Structure Type Single Pole, Steel


230 kV Line





Structure Type Wood H-Frame, Steel


345 kV Line




Cost per Circuit Mile $1.5 M / mile

Structure Type Wood H-Frame, Steel


500 kV Line

Conductor Size 2493 ACSR (bundled)




Structure Type Lattice Tower, Steel


756 kV Line

Conductor Size 1351 ACSR (4 conductor

bundled)




Structure Type Lattice Tower, Steel


Underground Cable Standards

Underground

Cables

Voltage Cable Size

(kcmil)

Right of Way

Width

Typical

Normal

Rating (MVA)

Order of

Magnitude

Installation

Cost per

Circuit Mile

(Millions)

69 kV

1500 Copper

High Pressure

Oil Filled Pipe

Type cable

N/A* 119 $ 1.2 / mile

115 kV

1500 Copper

High Pressure

Oil Filled Pipe

Type cable

N/A* 180 $ 1.5 / mile

138 kV

1500 Copper

High Pressure

Oil Filled Pipe

Type cable

N/A* 200 $ 1.8 / mile

230 kV

2500 Copper

High Pressure

Oil Filled Pipe

Type cable

N/A* 406 $ 4.0 / mile

345 kV

2500 Copper

High Pressure

Oil Filled Pipe

Type cable

N/A* 627 $ 6.0 / mile

*Assumed to be installed in existing roadway right-of-ways; minimum access

requirements and respective clearances to adjacent underground utilities would apply


Voltage PJM (Miles)

PJM Mid-

Atlantic (Miles)

PJM WEST (Miles)

PJM SOUTH (Miles)

69 kV 8,014 4,618 3,290 106

115 kV 4,485 2,127 22 2,336

138 kV 16,310 1,744 14,502 64

230 kV 7,456 4,669 351 2,436

345 kV 7,228 232 6,995 N/A

500 kV 4,919 2,900 882 1,137

765 kV 2,110 N/A 2,110 N/A

Underground Cable Standards



• Exercise TO1-1.1


Features of the Transmission System

• Generating Stations

– Source of the power (Car out of driveway)

• Transmission Lines

– Path of power flow (Freeway)

– Naming Conventions vary by company • Number, Terminals, Voltage Level



• Buses

– Points of connection (Cloverleaf)

– Many breaker configurations • Straight

• Ring

• Breaker and a half

• Double bus/double breaker

Buses



• Circuit Breakers

– Switch to interrupt the flow of current in a circuit (Car accident or police stop)

• Transformers

– Used to transform voltage from one level to another (on-ramp or off-ramp)

Circuit Breaker



• Other Devices

– Phase angle regulators

– Disconnects

– Capacitors

– Reactors

• Exercise TO1-1.2

– Use PJM 500 kV one-line on following slide…..


Summary

• List the purpose and functions of the transmission system.

• Distinguish between the transmission system, the sub-transmission system and the distribution system.

• Given a simple one-line diagram, identify the major features of the PJM transmission system including:

– Lines, buses, and generating stations


System Voltage and VAR Characteristics

TO1-2


Lesson Objectives

• Identify situations which may cause the system voltage to drop below accepted standards.

• Identify situations which may cause the system voltage to rise above accepted standards.

• List the MVAR sources and sinks on the power system.

• Explain how system capacitance supplies MVARS to the system.


Lesson Objectives

• Define Surge Impedance Loading and state its significance to system operation.


System Voltage Characteristics

• Relationship between reactive flow and voltage

– Voltage levels most affected by • VAR generation/absorption

• Reactive (MVAR) flow distribution

– Large reactive flows cause large voltage drops

– Large voltage differences cause large reactive flows

Reactive Power (MVAR) are required for Real Power (MW) to flow.



• Voltage profile

– On most lines voltage decreases from sending to receiving end of transmission line.



• a = angle of voltage

• b = angle of current

• P = real power = VIr = VI cos(a-b)

• Q = reactive power = VIx = VI sin(a-b)

• S = complex power = VI cos(a-b) +jVI sin(a-b)

• power factor = cos (a-b)

P=VIcos(a-b) W

Q=

VIs

in(a

-b) V

ar

(a-b)



• Factors affecting voltage

– VAR supply • Excess VARs on system, voltage will rise

• Shortage of VARs on system, voltage will decrease

– VAR Sources • System capacitance

• Capacitor banks

• Generators (lagging)



• Factors affecting voltage (continued)

– VAR loads • Motors

• VAR losses

• Generators (leading)

• Reactors

• Transformers

– Power (MW) Flow • Increasing load (MW) causes larger I2R loss and IR voltage drop



• Factors affecting voltage (continued) – Reactive (MVAR) Flow

• Increasing reactive (MVAR) flow causes larger I2X loss and IX voltage drop

• Voltage drop due to reactive flow is larger than for real power flow

• VARs don’t travel well.

– Solar Magnetic Disturbance • Can cause a large VAR requirement in transformers

• May cause tripping of capacitor banks

– MVAR Simulation on Powerworld H:\Corporate Services\Training\Powerworld Cases\Chapter 2\Problem 2_24.pwb



• Results

– Result is constantly changing voltage profile



• Results

– For light loads, voltage can rise due to low losses and line capacitance



• Results

– Voltage Varies with VAR supply and consumption


VARs From Transmission Lines

• Line open at one end

– VAR flow back toward closed end



Equation for Ferranti Effect



• VARs supplied by charging of line

MVARs Supplied by Lines and Cables

Voltage Transmission Line Transmission Cable

765 kV 4.6 MVAR/Mile

500 kV 1.7 MVAR/Mile

345 kV 0.8 MVAR/Mile 15–30 MVAR/Mile

230 kV 0.3 MVAR/Mile 5-15 MVAR/Mile

115 kV 0.1 MVAR/Mile 2-7 MVAR/Mile


Attachment B - Transmission Operation Manual



KEYSTONE-JUNIATA 5004 118 3.1 196.5 514.5 14.5 216.9 540.4 15.4 238.0 566.1 16.1

Keystone Juniata

550

525 kV V2 =

5004 Line



KEYSTONE-JUNIATA 5004 118 3.1 196.5 514.5 14.5 216.9 540.4 15.4 238.0 566.1 16.1

Keystone Juniata

550

528.1 kV

540.4 kV

216.9 MVAR 0 MVAR

5004 Line

V1 =




• Line connected to load

– Power (MW) losses increase with load

– Reactive (MVAR) losses increase with load

Load

Load

increases

MW Flow increases

MVAR Flow increases



• Surge Impedance Loading

– Loading point where VAR losses on a line equal VARs generated by line



• Surge Impedance Loading

– 765 kV = 2100 MW

– 500 kV = 850 MW

– 345 kV = 400 MW

– 230 kV = 135 MW


MW

0 400 600 850 1000 1400 1800

MVAR absorbed by

Transmission Line

MVAR supplied by

Transmission Line Long 500 kV line

Short 500 kV line Limited by charging

MVAR Surge Impedance Loading Example


1.0 pu 1.0 pu

MVAR

Required

MVAR

Required

Voltage Profile

Line loaded above SIL

As line loading increases:

Reactive losses increase proportional to I2

Reactive supply decreases proportional to V2

VARs from Transmission Lines

1.0 pu 1.0 pu

MVAR

Supplied

MVAR

Supplied

Voltage Profile

Line loaded below SIL

As line loading decreases:

Reactive losses decrease proportional to I2

Reactive supply increases proportional to V2

VARs from Transmission Lines



• Switching Operations

– Open one end • Provides VARs to closed end of line due to line capacitance

MVAR Flow



• Switching Operations (continued)

– Open both ends • Removes that line from service

• No longer supplies VARs (high voltage) or uses VARs (low voltage)

– Switching Over-voltages • Very high voltages which occur for a short duration

• Can be handled in insulation design or use of surge suppression devices



• Lightning Over-voltages

– Much more severe than switching surges

– >1000 kV

– Can cause insulation failure or flashover

– Controlled by surge arrestors or lightning rods


Summary

• Identify situations which may cause the system voltage to drop below accepted standards.

• Identify situations which may cause the system voltage to rise above accepted standards.

• List the MVAR sources and sinks on the power system.


Summary

• Explain how system capacitance supplies MVARS to the system.

• Define Surge Impedance Loading and state its significance to system operation.


Distribution Factors and Generation Shift Factors

TO1-3


Lesson Objectives

• Define a transmission line distribution factor.

• Briefly describe the application of distribution factors for system operation.

• Given appropriate distribution factors, analyze the impact of taking a line out of service.

• Define a generation shift factor and describe its application for system operation.


Lesson Objectives

• Given appropriate generation shift factors, analyze the impact of a shift in generation.

• Define the concept of $/MW effect and its application in the new operating environment.


Introduction to Distribution Factors

• Definition

– The percentage of flow currently on a line that will transfer to another line as a result of the loss of the first line

• Characteristics of Distribution Factors

– Determined by line impedances

– Computer generated

– Expressed as a decimal number of 1.0 or less

– Distribution factor for a line for the loss of itself is -1.0 if line flow is positive.


Introduction to Distribution Factors

• Characteristics of Distribution Factors (continued)

– Can be a positive or negative factor

– Sum of all distribution factors in a closed system is zero

• Formula: • New flow on line = Previous flow + [(Dfax) (Flow on outaged

facility)]


Example Simple Calculations

For the loss of line C:

Dfaxb= 0.5 Dfaxc = -1.0

Dfaxd = 0.3 Dfaxe = 0.2


Example Simple Calculations

Let’s do Exercise TO1_3.1!


Applications of Distribution Factors

• Line Outages

– Use distribution factors to estimate how power will flow and predict any flow problems which may result from a line outage. • Generally performed by computer tool

• Flow Analysis

– Used to predict the results of losing a specific piece of equipment (Contingency analysis)


PJM Distribution Factor Table

• Try Exercise TO1_3.2.


Generation Shift Factors

• Similar to Distribution Factors

– Decimal Fraction

– Used to analyze the effect of generation shifts on MW flow

– Does NOT add up to 0

• Definition

– Fraction of change in generation MW output that will appear on a line or facility

– Used to predict the effect of generation changes on transmission line flow



• Formula

New flow on line = Previous flow + [(Gen Shift Factor)(Amount of MW

Shift)]



Line 3 = 500 MW

Increase Gen A by

100 MW.

What is resultant

flow on Line 3? LINE 5

New Flow = 500 MW + (.12)(+100MW) = 512 MW



Line 3 = 512 MW

Now, Generator C is

decreased by 100 MW.

What is resultant flow

on Line 3? LINE 5

New Flow = 512 MW + (-0.6)(-100MW) = 572 MW



Try Exercise

TO1_3.3!

LINE 5


$/MW Effect

• Adjustment of Shift Factors due to Economics.

• Definition

– $/MW Effect = (Current Dispatch Rate - Unit Bid) / Unit Generator Shift Factor

– Unit with lowest $/MW effect is redispatched when system is constrained.

– Other unit operating constraints taken into account (I.e. min run time, time from bus, etc)

– In an emergency, economics takes the “back seat” to reliability.


$/MW Effect

Line #1 is overloaded!

Dispatch rate = $20

Unit D = $21

Unit B = $40

Which unit would you

raise to alleviate the

overload?


$/MW Effect

Unit D = ($20-$21)/(-.12)

= $8.33/MW

Unit B = ($20-$40)/(-.2)

= $100/MW

Select Unit D even

though effect is less!


$/MW Effect

• Let’s do Exercise TO1_3.4 on $/MW Effect.

• 2 PowerWorld Simulations on Loop Flows and Power Transfer Distribution Factors (PDTF)


Summary

• Define a transmission line distribution factor.

• Briefly describe the application of distribution factors for system operation.

• Given appropriate distribution factors, analyze the impact of taking a line out of service.

• Define a generation shift factor and describe its application for system operation.


Summary

• Given appropriate generation shift factors, analyze the impact of a shift in generation.

• Define the concept of $/MW effect and its application in the new operating environment.


Module Summary

• Review the purpose and function of the transmission system.

• Review basic system voltage and VAR characteristics

• Demonstrate basic distribution factor theory.

• Determine power flows utilizing system distribution factors and generation shift factors

• Introduce the concept of $/MW effect.


Questions?


Disclaimer: PJM has made all efforts possible to accurately document all information in this presentation. The information seen here does not supersede the PJM Operating Agreement or the PJM Tariff both of which can be found by accessing: http://www.pjm.com/documents/agreements/pjm-agreements.aspx For additional detailed information on any of the topics discussed, please refer to the appropriate PJM manual which can be found by accessing: http://www.pjm.com/documents/manuals.aspx

http://www.pjm.com/documents/agreements/pjm-agreements.aspx



http://www.pjm.com/documents/manuals.aspx

tso series transmission system operation glen boyle, sr

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