“Importance of Reactive Power Management, Voltage Stability and FACTS

Applications in today’s Operating Environment”

Sharma KolluriManager of Transmission Planning

Entergy Services Inc

Engineering SeminarOrganized by IEEE Mississippi Section

Jackson State University

August 20, 2010

Outline

• Introduction• VAR Basics• Voltage Stability• FACTS • Applications at Entergy • Summary

.

• Voltages decay to almost 60% of normal voltage. This is probably the point that load started dropping off.

• However, the recovery is too slow and generators are not able to maintain frequency during this condition.

• Many generators trip, load shedding goes into effect, and then things just shut down due to a lack of generation.

Voltage Profile during Aug 14th Blackout

A “Near” Fast Voltage Collapse in Phoenix in 1995

North American Electric Reliability Council, System Disturbances, Review of Selected 1995 Electric System Disturbances in North America, March 1996.

Recommendation#23

• Strengthen Reactive Power and Control Practices in all NERC Regions

“Reactive power problem was a significant factor in the August 14 outage, and they were also important elements in the several of the earlier outages”

-Quote form the outage report

Reactive Power Reactive Power

Laws of Reactive Physics

• System load is comprised of resistive current (such as lights, space heaters) and reactive current (induction motor reactance, etc.).

• Total current IT has two components.

– IR resistive current

– IQ reactive current

– IT is the vector sum of IR & IQ

– IT = IR + jIQ

IT

IR

IQ

North American Electric Reliability Corporation

Laws of Reactive Physics

• Complex Power called Volt Amperes (“VA”) is comprised of resistive current IR and reactive current IQ times the voltage.

– “VA” = VIT* = V (IR – jIQ) = P + jQ

• Power Factor (“PF”) = Cosine of angle between P and “VA”

– P = “VA” times “PF”

• System Losses

– Ploss = IT2 R (Watts)

– Qloss = IT2 X (VARs)

VA

P

Q

North American Electric Reliability Corporation

Reactive Physics – VAR loss

• Every component with reactance, X: VAR loss = IT2 X

• Z is comprised of resistance R and reactance X– On 138kV lines, X = 2 to 5 times larger than R.

– One 230kV lines, X = 5 to 10 times larger than R.

– On 500kV lines, X = 25 times larger than R.

– R decreases when conductor diameter increases. X increases as the required geometry of phase to phase spacing increases.

• VAR loss– Increases in proportion to the square of the total current.

– Is approximately 2 to 25 times larger than Watt loss.

North American Electric Reliability Corporation

Reactive Power for Voltage Support

Reactive Loads

VARs flow from High voltage to Low voltage; import ofVARs indicate reactivepower deficit

Reactive Power Management/Compensation

What is Reactive Power Compensation?

• Effectively balancing of capacitive and inductive components of a power system to provide sufficient voltage support.

– Static and dynamic reactive power

• Essential for reliable operation of power system – prevention of voltage collapse/blackout

Benefits of Reactive Power Compensation:

• Improves efficiency of power delivery/reduction of losses.• Improves utilization of transmission assets/transmission capacity.• Reduces congestion and increases power transfer capability.• Enhances grid reliability/security.

Transmission Line Real and Reactive Power Losses vs. Line Loading

Source: B. Kirby and E. Hirst 1997, Ancillary-Service Details: Voltage Control,ORNL/CON-453, Oak Ridge National Laboratory, Oak Ridge, Tenn., December 1997.

Static and Dynamic VAR Support

• Static Reactive Power Devices– Cannot quickly change the reactive power level as long as the voltage

level remains constant.– Reactive power production level drops when the voltage level drops.– Examples include capacitors and inductors.

• Dynamic Reactive Power Devices– Can quickly change the MVAR level independent of the voltage level.– Reactive power production level increases when the voltage level drops.– Examples include static VAR compensators (SVC), synchronous

condensers, and generators.

Voltage Stability Voltage Stability

Common Definitions

• Voltage stability - ability of a power system to maintain steady voltages at all the buses in the system after disturbance.

• Voltage collapse - A condition of a blackout or abnormally low voltages in significant part of the power system.

• Short term voltage stability - involves the dynamics of fast acting load components such as induction motors, electronically controlled loads, and HVDC converters.

• Long term voltage stability - involves slower acting equipments such as tap-changing transformer, thermostatically controlled loads, and generator limiters.

What is Voltage Instability/Collapse?

• A power system undergoes voltage collapse if post-disturbance voltages are below “acceptable limits”

– voltage collapse may be due to voltage or angular instability

• Main factor causing voltage instability is the inability of the power systems to “maintain a proper balance of reactive power and voltage control”

Voltage Instability/Collapse

• The driving force for voltage instability is usually the load

• The possible outcome of voltage instability:– loss of loads – loss of integrity of the power system

• Voltage stability timeframe:– transient voltage instability: 0 to 10 secs– long-term voltage stability: 1 – 10 mins

Voltage stability causes and analysis

• Causes of voltage instability – Increase in loading

– Generators, synchronous condensers, or SVCs reaching reactive power limits

– Tap-changing transformer action

– Load recovery dynamics

– Tripping of heavily loaded lines, generators

• Methods of voltage stability analysis – Static analysis methods

– Algebraic equations, bulk system studies, power flow or continuation power flow methods

– Dynamic analysis methods– Differential as well as algebraic equations, dynamic modeling of power system

components required

MW

Stator Winding Heating Limit

Turbine Limit

- P

er u

nit

MV

AR

(Q

) +

0.8 pf line

Under-excitation Limit

Lag

gin

g

(Ove

r-ex

cite

d)

Lea

din

g

(Un

der

-exc

ited

)

Normal Excitation (Q = 0, pF = 1)

Over-excitation Limit

Stability Limit

Generator Capability Curve

P-V Curve

Q-V Curve

200

Q-V Curve with Detailed Load Model

Peak Load with Fixed Taps

-80

-60

-40

-20

0

20

40

60

80

100

120

0.5 0.6 0.7 0.8 0.9 1 1.1 1.2 1.3 1.4 1.5

Voltage (p.u.)

Mv

ars

Base Case

Contingency

Key Concerns

Minimize motor tripping

Limit UVLS activation

Voltage (pu)

Possible Solutions for Voltage Instability

• Install/Operate Shunt Capacitor Banks

• Add dynamic Shunt Compensation in the form of SVC/STATCOM to mitigate transient voltage dips

• Add Series Compensation on transmission lines in the problem area

• Implement UVLS Scheme

• Construct transmission facilities

Voltage Collapse

Fault Induced Delayed Voltage Recovery (FIDVR)

• FIDVR Definition

• Load Models

Fault Induced Delayed Voltage Recovery (FIDVR)

• What is it?

– After a fault has cleared, the voltage stays at low levels (below 80%) for several seconds

• Results in dropping load / generation or fast voltage collapse

• 4 key factors drive FIDVR:

– Fault Duration

– Fault Location

– High load level with high Induction motor load penetration

– Unfavorable Generation Pattern

Villa Rica 500 Pos Seq Volts at Bowen

0.0 4.0 8.0 12.0 16.0 20.0 24.0 28.0 32.0 215000.0 220000.0 225000.0 230000.0 235000.0 240000.0 245000.0 250000.0 255000.0 260000.0 265000.0 270000.0 275000.0 280000.0 285000.0 290000.0 295000.0 300000.0 305000.0 310000.0 315000.0 320000.0 325000.0

7/ 30/ 99 @ 19:25:40.458 hrs CDT

Flt #1

Flt #2

Flt #3

Seconds

Phase- Gnd Voltage Voltage profile at

Plant Bowen 500kV

Load characteristics

• The accuracy of analytical results depends on modeling of power system components, devices, and controls.

• Power system components - Generators, excitation systems, over/under excitation limiters, static VAr systems, mechanically switched capacitors, under load tap changing transformers, and loads among others.

• Loads are most difficult to model.– Complex in behavior varying with time and location

– Consist of a large number of continuous and discrete controls and protection systems

• Dynamics of loads, especially, induction motors at low voltage levels should be properly modeled.

Induction motor characteristics• Impact of fault on transmission grid

– Depressed voltages at distribution feeders and motor terminals

– Reduction of electrical torque by the square of the voltage resulting in slow down of motors

– The slow down depends on the mechanical torque characteristics and motor inertias

• With fault clearing

– Partial voltage recovery– Slowed motors draw high reactive currents, depressing voltage magnitudes– Motor will reaccelerate to normal speed if, electrical torque>mechanical torque

else, the motors will rundown, stall, and trip– The problem is severe in the summer time with large proportion of air conditioner

motors

Fig. 1 Induction motor characteristics

Speed – per unit

Electric torque

1.0

Constant load torque

Square-law load torque

Air conditioner motor characteristics

• Characteristics– Main portion (80-87%) consumed by compressor motor

– Electromagnetic contactor drop out between (43-56%) of the nominal voltage and reclose above drop out voltage

– Stalling at (50-73%) of the nominal voltage

– Thermal overload protection act if motors stall for 5-20 seconds

– The operation time of thermal over load (TOL) protection relay is inversely proportional to the applied voltage at the terminal

• Air conditioner should be modeled to analyze the short term voltage stability problem

• Quite important for utilities in the Western interconnection

Load modeling

• Old models – Loads are represented as lumped load at distribution feeder

• Does not consider the electrical distance between the transmission bus and the end load components

• The diversity in composition and dynamic behavior of various electrical loads is not modeled

• Modeling– WECC interim model

– 20% of the load as generic induction motor load

– 80% constant current P and constant impedance Q

Fig. 2 Traditional load model

Distribution Capacitor

Distribution Bus

OLTC

Transmission Bus

Lumped Load (ZIP load)

Composite load modeling

• Representation of distribution equivalent– Feeder reactance

– Substation transformer reactance

• Parameters of various load components– Discharge lighting

– Electronic Loads

– Constant Impedance loads

– Motor loads

– Distribution Capacitor

Fig. 3 Composite load model structure

Bus 3

Distribution Capacitor

Transmission Bus

Bus 1

Bus 2

Distribution Bus

Substation Capacitor

OLTC

Distribution Feeder

Feeder Equivalent

Static Loads(Constant impedance,

constant current, constant impedance loads)

Dynamic Loads(Small motor, Large

motor, trip motor loads)

FACTS FACTS

What is FACTS?

Alternating Current Transmission Systems

Incorporating Power Electronic Based and

Other Static Controllers to Enhance

Controllability and Increase Power Transfer

Capability.

•power semi-conductor based inverters

•information and control technologies

Major FACTS Controllers

• Static VAR Compensator (SVC)

• Static Reactive Compensator (STATCOM)• Static Series Synchr. Compensator (SSSC) • Unified Power Flow Controller (UPFC)• Back-To-Back DC Link (BTB)

FACTS Applications

Voltage ControlPower System Stability

SSSC

S/S

UPFCPower Generation

Load

IncreasedTransmission Capacity

Inter-area ControlInter-tie Reliability

Power Flow ControlSystem Reliability

ImprovedPower Quality

EnhancedImport Capability

Inter-connectedRTO System

Inter-connectedPower System

BTB

BTB

STATCOM

S/S

S/S

STATCOMLoad

Load

Static VAr compensator (SVC)

• Variable reactive power source

• Can generate as well as absorb reactive power

• Maximum and minimum limits on reactive power output depends on limiting values of capacitive and inductive susceptances.

• Droop characteristic Fig. 4 Schematic diagram of an SVC

XC

TCR

XL

I

V

Firing angle control

Static compensator (STATCOM)

• Voltage source converter device

• Alternating voltage source behind a coupling reactance

• Can be operated at its full output current even at very low voltages

• Depending upon manufacturer's design, STATCOMs may have increased transient rating both in inductive as well as capacitive mode of operation

Transformer

DC-AC switching converter

IX

System bus

Cs

Vdc

V

E

Fig. 5 Schematic diagram of STATCOM

Technology Applications at Technology Applications at

EntergyEntergy

Technology Applications at Entergy to Address Reactive Power Issues

• Large Shunt Capacitor Banks • UVLS• Series Compensation • SVC • Coordinated Capacitor Bank Control • DVAR• AVR

Determining Reactive Power Requirements in the Southern Part of the Entergy System for Improving

Voltage Security – A Case Study

Sharma Kolluri

Sujit Mandal

Entergy Services Inc

New Orleans, LA

Panel on Optimal Allocation of Static and Dynamic VARS for Secure Voltage Control

2006 Power Systems Conference and Exposition

Atlanta, Georgia

October 31, 2006

Areas of Voltage Stability Concern

West of the Atchafalaya Basin(WOTAB)

North Arkansas

Southeast Louisiana

Western Region

Amite South/DSG

Mississippi

Study Objective

• Identify Voltage Stability Problems in the DSG area

• Determine the proper mix of reactive power support to address voltage stability problem

• Determine size and location of static and dynamic devices.

Downstream of Gypsy Area - Critical Facilities

Waterford-Ninemile 230kV line

Ninemile Units1 - 50 MW2 - 60 MW3 - 128 MW4 - 740 MW5 - 750 MW

115 kV

230 kV

Michoud Units1 - 65 MW2 - 240 MW3 - 515 MW

115 kV

- 230 kV

Little Gypsy-South Norco 230kV line

DSG Issues

• Area load growth• 1.6% projected for 2003 - 2013• Weather normalized to 100º F• Projected peak load – 3800 MW

• Area power factor - Low• 94% at peak load

• Worst double contingency• Loss of the Waterford to

Ninemile 230 kV transmission line and one of the 230 kV generating units at Ninemile or Michoud

• Area Problems• Thermal overloads of underlying 115 kV and 230 kV

transmission system• Depressed voltages throughout New Orleans metro area

potentially leading to voltage collapse and load shedding

New Orleans area voltage profile on June 2, 2003

(with 2 major generators offline)

Michoud

Ninemile

Various Steps Used for Determining Reactive Power Requirements

• Step 1 – Problem identification • Step 2 – Determining total reactive power

requirements• Step 3 – Sizing and locating dynamic devices • Step 4 – Sizing and locating static shunt

devices• Step 5 – Verification of reactive power

requirements

Tools & Techniques Used

• Various tools and techniques used for analysis purposes – PV analysis using PowerWorld– Transient stability using PSS/E Dynamics– Mid-term stability using PSS/E Dynamics – PSS/E Optimal Power Flow

• Detailed Models used– Motor models and appropriate ZIP model for dynamic analysis – Tap-changing distribution transformers, overexcitation limiters,

self-restoring loads modeled in mid-term stability study

Criteria/Requirements

Minimize motor tripping

Improve post-fault voltage

Voltage (pu)

Steady State AnalysisResults

PV CurveNinemile Unit 4 out-of-service

Trip Ninemile Unit 5 and Waterford – Ninemile 230 kV line

Without Waterford - 9Mile 230kV line 3of5 & Michoud unit 3 PV curves

0.8

0.85

0.9

0.95

1

1.05

3300 3350 3400 3450 3500 3550 3600 3650 3700 3750 3800

Load in DSG (MW)

Vo

ltag

e (p

.u.)

Berman 230kV

Market 230kV

Tricou 230kV

Almonaster 230kV

PARIS 230kV

Gretna 115kV

Delta 115kV

9mile 230kV

cc

Dynamic Analysis

Stability Simulation Ninemile Unit 4 out-of-service

Trip Ninemile Unit 5 and Waterford – Ninemile 230 kV line

Process for Determining Reactive Power Requirements

• Approx 700 MVAr of reactive power shortage identified in the DSG

– How much static and how much dynamic?

• Criteria for determining static and dynamic requirements– Voltage at critical buses should recover to 1 pu in several seconds– Voltage at critical buses should recover to 0.9 pu within 1.5 - 2 seconds– Voltage should not dip below 0.7 pu for more than 20 cycles– Generator reactive power output should be below Qmax

• Factors considered in sizing static/dynamic devices– Short circuit levels, size & location of the stations, number and existing size

of cap banks, back-to-back switching, etc

SVC Size and Location

• Sites considered– Ninemile 230 kV– Gretna 115 kV– Paterson 115 kV

• Size– 300 MVAR– 500 MVAR

Optimal size and

location

Steps to locate Static Shunt Devices

• Static shunt requirements – 400 MVAR approximately

• Options available to locate the static shunt devices on the transmission or distribution systems

• OPF Program used to come up with size and location of shunt devices

OPF Application

• PSS/E OPF Program used

• Objective Function – Minimize adjustable shunts

• OPF simulated for critical contingencies

List of Shunt Capacitor Banks Banks Recommended

Simulation Results with the Capacitors and SVC Ninemile Unit 4 out-of-service

Trip Ninemile Unit 5 and Waterford – Ninemile 230 kV line

SVC Performance Ninemile Unit 4 out-of-service

Trip Ninemile Unit 5 and Waterford – Ninemile 230 kV line

Summary

• Process for determining static and dynamic reactive power requirements discussed

• OPF program utilized for sizing/locating static shunt capacitor banks

• Results verified using mid-term stability simulations

• Study recommendation – 400 MVAR of static shunt devices and 300 MVAR of dynamic shunt compensation

Ninemile SVC Configuration

SN = 300 MVA, uk = 9.5 %

3AC 60Hz 230kV

3AC 60Hz 15.5kV

CTSC2

LTSC2

TSC 2

V2

VR2

TSC 1

CTSC3

LTSC3

TSC 3

V3 VR3

CTSC1

LTSC1

V1

VR1

= 75 MVAr = 75 MVAr = 150 MVAr

External Device ControlSingle line diagram of SVC and MSC

TSC 1-3

MSC 1

Ninemile 230kV

MSC 10

.................

Different voltage levels

(115 kV)

SVC system

SVC Ninemile

SVC Ninemile

Porter 0/+300Mvar SVC

SVC Topology: 2 x 75MVAr TSC & 1 x 150MVAr TSC

Porter Static Var Compensator (SVC)

Maintains system voltage by continuously varying VAR output to meet system demands Controls capacitor banks on the transmission system to match reactive output to the load requirements.

Porter SVC

Series Capacitor – Dayton Bulk 230kV Station

The Capacitor offsets reactance in the line, making it appear to the system to be half of its actual length. Power flows are redirected over this larger line, unloading parallel lines and increasing transfer capability.

DSMES Unit

Stores Energy in a superconducting coil

Automatically releases energy to the system when needed to ride through voltage dips caused by faults. This unit improves power quality and reduces customer loss of production.

Industry Issues

• Coordination of reactive power between regions

• No clearly defined requirements for reactive power reserves

• Proper tools for optimizing reactive power requirements

• Incentive to reduce losses

Summary

• The increasing need to operate the transmission system at its maximum safe transfer limit has become a primary concern at most utilities

• Reactive power supply or VAR management is an important ingredient in maintaining healthy power system voltages and facilitating power transfers

• Inadequate reactive power supply was a major factor in most of the recent blackouts

Questions?

Under Voltage Load Shed Logic - Western Region

T&D Planning

April 2010

Western Region – Overview

≤ 230 kV Tie Lines

Generation

Load Center

Load Projection

• 2010 peak: 1770 MW

• 2012 peak: 1852 MW

Sample PV Curve ResultLewis Creek Unit 1 & China-Porter 230kV Out - 2010

0.8

0.85

0.9

0.95

1

1.05

1.1

1350 1450 1550 1650 1750 1850 1950 2050 2150

-100

-50

0

50

100

150

200

Dayton

Rivtrin

Conroe

Poco

Jacinto

Cleveland

Huntsville

Goslin

Lewis Creek

Pelican Road

Cypress

Frontier

2010 Summer PV Curve Analysis

Approved Construction Plan Projects included:*Relocate Caney Creek 138kV

ScenariosP Limit (MW)

With 3% Margin (MW)

Voltage (4/8 Buses) (pu)

Lewis Creek U1 out 2385 2313 0.84 – 0.89

Lewis Creek U1 + China-Jacinto out 2260 2192 0.83 – 0.89

Lewis Creek U1 + Grimes-Crockett out 2230 2163 0.86 – 0.91

Lewis Creek U1 + China-Porter out 2065 2003 0.85 – 0.93

Dynamic Analysis Results

Results: 2010 case without load shed

Case 3 Voltages (pu): Goslin: 0.810; Conroe: 0.855; Cleveland: 0.909; Jacinto: 0.924; Dayton: 0.944; Huntsville: 0.944

Case 4 Voltages (pu): Goslin: 0.757; Conroe: 0.800; Dayton: 0.913; Huntsville: 0.928; Cleveland: 0.928; Rivtrin: 0.941

2010 Summer Conditions - Dynamics Analysis

• Lewis Creek Unit 1 outaged in the base case

• 50% induction motor load is modeled• Result: Shed Load Block 1 (183 MW)

Observations for 2010 Summer Peak Conditions

• Existing load shed logic in Western Region OK for 2010 Summer conditions

• Voltage at some critical buses drop below 0.7 pu for more than 20 cycles – Potential of motor load tripping

Conclusions for 2010 Summer

• Reducing load shed blocks to 180 + 70 MW in Western Region has no negative impact

Results: 2010 case with load shed (Block 1)

Case 3 Voltages (pu): Goslin: 0.872; Conroe: 0.902; Cleveland: 0.934; Jacinto: 0.948; Dayton: 0.966; Huntsville: 0.968

Case 4 Voltages (pu): Goslin: 0.827; Conroe: 0.855; Dayton: 0.939; Cleveland: 0.951; Huntsville: 0.954; Jacinto: 0.964

Conclusions and Recommendations

• Retain the exiting UVLS logic

• Change the load blocks– Block one: 180 MW– Block two: 70 MW (existing size 111 MW)

Proposed Load Shed Logic

Voltage @ 4/8 buses <0.90 pu

Voltage @ 4/8 buses < 0.92 pu

Armed all time

Drop load

Time Delay 3 seconds

Reset the Process for next

LVSH block

OEL at Lewis Creek

units

Load Blocks:Block 1: 175 MWBlock 2: 75 MW

One or more Lewis Creek

units in-service?

The above conditions need to be met for 3 scans to trigger load shedding

Monitored Buses:Metro 138kVGoslin 138kVAlden 138kVOakridge 138kVHuntsville 138kVRivtrin 138 kVPoco 138 kVConroe 138 kV

Load Blocks:Block 1: 175 MWAlden: 50 MWMetro: 35 MWOakridge:30 MWGoslin: 60 MW

Block 2: 75 MWIn the vicinity of Block 1