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NERC > NERC Prep > Flashcards

NERC Prep Flashcards

1
Q

Area control error

A

An instantaneous difference between a balancing authorities net actual and scheduled interchange , taking into account the effects of frequency bias and correction for meter error.

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2
Q

Contingency reserves

A

The provision of capacity deployed to meet the disturbance control standard and other nerc and regional reliability organization contingency requirements.

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3
Q

Disturbance control standard

A

The reliabity standard that sets the time limit following a disturbance within which a balancing authority must return its area control error to within a specified range

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4
Q

Operating reserve

A

That capability above firm system demand required to provide for regulation, load forecasting error, equipment forced and scheduled outages and local area protection. It consists of spinning and non spinning reserves

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5
Q

Reportable disturbance

A

Any event that causes an ace change greater than or equal to 80% of a balancing authorities or reserve sharing groups most severe contingency

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6
Q

Reserve sharing group

A

A group whose members consist of two or more balancing authorizes that collectively maintain allocate and supply operating reserves required for each balancing authority’s use in recovering from contingencies with the group

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7
Q

Disturbance

A

Nerc required time error to be fixed within 15 mins following a disturbance

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8
Q

Contingency reserves

A

Non spinning or supplemental and spinning reserves

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9
Q

Operating reserve

A

Non spinning , spinning reserves, and regulating reserves

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10
Q

Operating reserves contributors

A

Controllable load reserves, adjustments to interchange schedule, generation

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11
Q

Contingency reserve

A

Covers most servers single contingency , more that 80% - reportable. More than 100% of most severe contingency reportable event but no penalties apply for failure to meet DCS

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12
Q

Reportable contingency time

A

Within 15 mins recover from reportable disturbance, within 90 mins shall fully restore . 90 mins begins at end of 15 min period

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13
Q

Balancing authorities shall review contingencies how often to determine single worst contingency?

A

Annually

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14
Q

Contingencies occurring with in how long considered 1 event?

A

60 seconds

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15
Q

A sudden change in balancing authority’s demand supply balance following loss of generation results in sudden change in

A

ACE

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16
Q

What group can approve a change in the disturbance recovery period for an interconnection?

A

Nerc operating committee

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17
Q

Contingency reserve restoration period begins at?

A

The end of disturbance recovery period

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18
Q

Frequency bias setting

A

A value in mw/.1hz set into balancing authorities agc equipment to represent a balancing authorities response to a frequency deviation

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19
Q

Pseudo tie

A

A telemetered reading or value that is updated in real time and used as a tie line flow in the agc ace equation but for which no physical tie or energy metering actually exists

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20
Q

1% change in frequency =

A

2% load change in same direction - primarily of induction motors not heaters ( resistive ) this is used to determine BETA for ace equation

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21
Q

Generator response to governor droop

A

200mw/3hz x (60hz-59.95hz)=3.33mw

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22
Q

Frequency response charachteristic

A

Decrease load/decrease frequency+ generator output

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23
Q

Frequency bias = frequency response

A

x

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24
Q

Actual interchange + frequency bias =0 ACE

A

x

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25
Q

Bias setting

A

Reported to nerc yearly, must be at least 1% of the balancing authorities estimated yearly peak demand per .1hz change as described in the frequency response charachteristic survey training document for a native load serving balancing authority

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26
Q

Tie line frequency bias controls

A

Fixed frequency bias - based on a fixed straight line function of tie line deviation versus frequency deviation. Variable bias- based on a variable function of tie line deviation to frequency deviation

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27
Q

Balancing authorities- overlap regulation

A

ba that are performing overlap regulation service will increase its frequency bias setting to match the frequency response of the entire area being controlled

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28
Q

Balancing authorities- supplemental regulation

A

bA performing supplemental reg service shall not hangs its frequency bias setting

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29
Q

Jointly owned units

A

Frequnecy bias setting is included in the area in which the unit is located only

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30
Q

Frequency bias setting

A

Must be close to areas frequency response. If it is not and is set to low and an external loss of generation occurs, ace will become positive and agc will lower generation , screwing things up even more

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31
Q

Tie line frequency bias

A

Each BA shall operate its AGC on tie line frequency bias

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32
Q

Minimum frequency bias setting for generation only balancing authority

A

1% of its estimated maximum generation level in the coming year per .1 hz change

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33
Q

Determining fixed frequency bias

A

By averaging the frequency response for several disturbances during on peak hours

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34
Q

Dynamic schedules

A

When jointly owned units - each BA shall account for the unit by including their respective share of units governor response charachteristics when calculating frequency bias . Used for the value for interchange accounting purposes

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35
Q

Time error correction

A

Adjust frequency by .02 hz so if it was fast it would be 59.980 or slow is 60.020 or adjust schedule frequency bias setting to + or - 20% of bias setting and take that off of NIs so for example if area had bias setting of 100mw it would add or subtract 20 me to NIs from ace equation

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36
Q

AGC

A

Automatically adjusts a balancing authorities generation from a central location to maintain its interchange schedule plus frequency bias.. Limits change in ACE to maintain a good cOS

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37
Q

CPS1

A

Measures a balancing authorities impact on interconnection frequency

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38
Q

CPS2

A

Measures the ability of a balancing authority to manage unscheduleed flows

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39
Q

Regulating reserve

A

The part of the operating reserve used to keep ace within a reasonable value to comply with CPS standards

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40
Q

Flat frequency control

A

Only used when area is islanded includes only 10b(Fa-Fs) part of ACE equation

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41
Q

Ace calculated every

A

6 seconds

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42
Q

Supplemental regulation service

A

Is a method of providing regulation service in which the balancing authority providing regulation service recieved a signal representing all or a portion of the other balancing authorities ACE

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43
Q

Overlap regulation service

A

A method of providing regulation service in which the balancing authority providing the regulation service incorporates all of the other balancing authorities tie lines, frequency response, and schedules into its own AGC/ ACE

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44
Q

Factors contributing to inadvertent interchange

A

Frequency support , load changes with in balancing authority, generator lag, metering errors, unilateral inadvertent interchange payback, human error

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45
Q

NIa

A

Algebraic sum of all the tie lines with adjoining balancing authorities

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46
Q

NIs

A

Scheduled flow of MW with all of the adjoining balancing authorities

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47
Q

Beta

A

Contribution to interconnection frequency control based on its frequency response charachtertics

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48
Q

Secondary/ good inadvertent interchange

A

Frequency support , regulation, governor support

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49
Q

Unilateral payback

A

Inadvertent interchange accumulations paid back unilaterally to a target of non zero ace, limited to balancing authorities L10 , cannot burden interconnection

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50
Q

Inadvertent interchange summaries

A

Must include at least the previous accumulation , net accumulation for the month, and final net accumulation for both the on peak and off peak periods

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51
Q

Frame relay

A

Data transmission technique used to send digitial info quickly to many destinations from one point of origin

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52
Q

Information assets

A

Proccessed or unproccessed data using nerc net

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53
Q

Nerc net

A

WAN used for exchanging power system info over frame relayit supports intergal security network, interchange distribution calculator, and reliability coordinator information system

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54
Q

Alternate pathways for communication

A

Looping a microwave system.. Redundant paths using different equipent such as protective relaying for transmission line carriers use microwave for one set or relays and power carrier for 2nd set of relays

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55
Q

Balancing authority

A

Integrates recourse plans ahead of time. Maintains load interchange generation with in a balancing authority area and supports frequency in real time

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56
Q

Reliability coordinator

A

The highest level of authority responsible for the reliable operation of the BES

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57
Q

Emergency load reduction plans

A

Must mitigate iROL violation within 30 mins

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58
Q

Balancing authority experiencing emergency

A

Shall only used assistance of interconnections frequency bias for the time needed to implement corrective actions

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59
Q

Balancing authority not experiencing trouble

A

Shall not unilaterally adjust generation to correct frequency problem while outside balancing authority is correcting its problem- it will strain the system plus add unshschuedulrd interchange

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60
Q

5% reduction in voltage

A

Equals overall 3% reduction in inductive and resistive loads

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61
Q

2nd steps for balancing authority

A

Manually shed firm load then request reliability coordinator to declare energy emergency

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62
Q

Enery emergency type

A

1- all available recourses are in use , foresees problems, all sources curtailed2- load management procedures are in effect , designated energy difficient, public appeals, dropping load, 3- firm load is being shed , must complete report and send within 2 business days to reliability coordinator

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63
Q

DOE loss of load reporting

A

Customer load lost,efforts to reduce load, deliberate acts of sabotag, vandalism, cyber attacks initial report due within 60 mins, final done within 48hours with all Events and remedies

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64
Q

NERC loss of load report

A

Same as DoE report but includes , unusual event that occurred to bulk system

Subject to regional reliability organization apprival,Preliminary due within 24 hours, final within 60 days

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65
Q

Role of regional reliability organization following a report/ disturbance

A

Shall make a representative available for preparation and investigation of final report, track and review status of final report recommendations, this should happen twice per year to make sure reccomendations are being acted upon, if any recommendation has not been acted on within 2 years, RRI shall notify Nercplanning committee. -SOS-notes/#sthash.11jXj9fk.dpuf

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66
Q

Transmission operators responsible for

A

Reliability of local transmission system, operates or directs operations of the transmission facilities, provides maintainence schedules, maintains voltage profiles , defines operating limits, develops contingency plans, coordinates load shedding

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67
Q

87 relay

A

Differential relay

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68
Q

21 relay

A

Distance relay

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69
Q

67 relay

A

Directional over current relay

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70
Q

Transfer trip signal

A

Form of pilot relaying, can be sent over fiber optics, microwave etc

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71
Q

Distance relays

A

3 zones of protection

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72
Q

System operating limits based on

A

Facility ratings, transient stability ratings, voltage stability ratings , system voltage limits

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73
Q

Voltage collapse

A

Lack of reactive power, voltage down by 10-20%, not enough mvars to serve power system and loads

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74
Q

Getting ahead of voltage

A

Putting capacitor banks in service before planned outage

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75
Q

Other actions to get ahead of voltage

A

Take shunt reactors out of service, raise generator voltage,raise tap positions on transformers, return lines and generators to service, curtail interchange transactions, curtail or shed load

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76
Q

Prevent voltage collapse by

A

Carrying dynamic reactive reserves close to the load, if mvars are not available shed load, ideally heavy inductive loads

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77
Q

Instability

A

Trans system does not have reserve transmission capacity mw or mvar reserves to handle the loss of a major electrical component such as line or generator

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78
Q

Uncontrolled separation

A

Instability when the power angle between two sections grows to large and the magnetic bond between the two sections is not sufficient to keep generators from losing sychronism

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79
Q

N-1

A

Operating the system to satisfy the most severe single contingency is also referred to as operating to satisfy the most severe N-1

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80
Q

TOs operate to protect against

A

Instability, uncontrolled separation, cascading outages from multiple outages

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81
Q

SOL

A

Must return system to within normal operating limits within 30 mins, transmission operator must take immediate action such as curtailing loads, energy service etc

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82
Q

Operational reliability info that balancing authorities provide reliability coordinators with

A

To be updated every 10 mins.. Example tie lines flows, operating reserves, mw reserve available within 10 minutes

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83
Q

Power angle

A

Difference in voltage angles between two locations in the power system

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84
Q

More capacitive circuit

A

Current will lead voltage which will tend to raise voltage

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85
Q

As power angle increases power transfer increases

A

x

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86
Q

Torque angle

A

Difference in voltage angles between generator internal or excitation voltage and the system voltage

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87
Q

Real power flows from

A

Higher voltage angle to lower voltage angle

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88
Q

Real power transfer

A

The higher the voltage the lower the power angle required for a given power transfer

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89
Q

When iROL or sol exceeded for more than 30 mins

A

Notify nerc and rro

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90
Q

Transformers rated in?

A

MVA

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91
Q

Shunt capacitor banks

A

Supply reactive power to the inductive load, reduce current between generator and load, reduce mvar losses

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92
Q

Shunt reactors

A

Absorb excessive reactive power locally

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93
Q

Capacitor

A

Element that stores energy in the form of electrical charge and introduces capacitance into a circuit . The stored energy creates an electrical field

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94
Q

Capacitive reactance

A

Measure of how a capacitor affects the flow of ac current . It describes the reaction of a circuit to the fluctuating electric fields of ac voltage. A capacitor that is places into an ac circuit builds up a charge that opposes change in voltage

95
Q

Inductance

A

The property of an electrical circuit that produxes an electromotive force by induction when the current is changing. Inductance opposes current changes

96
Q

Reactive power

A

The product of voltage and out of phase current , measured in volt ampheres reactive or var.

97
Q

MVA

A

Consists of 2 different types of power, megawatts and mvar, mw does the actual work or real power… Mvar produces the magnetic field that enables the power to do the work

98
Q

Angular separation or phase angle

A

Angular seperatipn between current and voltage cycles..in capacitive circuit. Current leads voltage . Inductive circuit is opposite

99
Q

How to raise voltage on a system

A

Capacitive reactance must me increased or inductive reactance lowered

100
Q

Placing capacitor near inductive load

A

Reduces current flow and line losses

101
Q

Dynamic sources of reactive power

A

Transmission lines and generators w auto voltage regulators

102
Q

Knee of pv curve

A

Once this point is reached . Any increase in mw will cause voltage collapse , to avoid this , redid patch generation or place capacitors inservce closer to the load

103
Q

Ace DCS violation restore time

A

15 minutes

104
Q

If a transmission operator is in unknown state

A

He has 30 minutes to restore

105
Q

AGC control types

A

Pulse control or set point contro

106
Q

Agc pulse contro

A

Units recieve raise or lower controls every few seconds this pulse acts on a speed changer motor to change its load reference settings in small increments

107
Q

Set point control for agc

A

Set desired mega watts fed directly to turbine controls- once through fossil units use this

108
Q

Communications

A

Must be redundant such as looping a microwave system or using redundant paths with different equipment

109
Q

Facilities management

A

All operators who may need to use backup system should practice with it monthly ,

110
Q

Communications

A

Coordinated communications include nerc hotline, weccnet, and reliability coordinator information system .. Must have procedures for backup communications

111
Q

Nerc net

A

A WAN that supports interregional security network, interchange distribution calculator and the reliability coordinator information system

112
Q

Communications and coordination

A

Each TO and BA shall notify its RC and all other potentially affected TO and BA through pre determined communication paths of any condition that could impact reliability or which could require firm load shedding

113
Q

Voltage reduction customer demand

A

A 5% reduction in voltage will drop load by 3%

114
Q

Emergency operating agreements between adjacent BAs

A
  1. Provisions for emergency assistance 2. Provisions to obtain emergency assistance from remote BAs
115
Q

If a BA loses its largest generating source

A

A neighboring BA can change the NIs part of its ace equation to make up for the generation

116
Q

Reserve sharing group

A

Agreements for emergency assistance minimize the amount of time a bA has to rely on the interconnection for bias support - should only be used to evaluate options and resolve emergencyreturning ACE to normal values as soon as possible is primary objective

117
Q

Transmission operators emergency load reduction plan

A

Shall have load reduction plan for all IROL that includes facilities in its area. Shall include details of amount of load shedding to be done to mitigate iROL violation before system separation or collapse occurs. Must be done within 30 minutes .

118
Q

Each TO and BA shall develop 4 plans

A

1.’mitigateoperating emergencies for insufficient generating capacity. 2) mitigate operating emergencies on the transmission system 3) implementation of load shedding when nessasary 4) system restoration

119
Q

TO and BA emergency plans to mitigate operating emergencies

A

1)communications protocols to be used during emergencies , including assignments to communicate within and external to the organization 2)a list of controlling actions such as starting offline generators etc 3) tasks to be coordinated with other entities such as providing reActive power, voltage control at interconnection 4) staffing levels for emergency. It is important to note that one of the controlling actions shall be load reduction in sufficient quantities to resolve emergency within established nerc guidelines

120
Q

TO and BA emergency plan review

A

To be done once a year

121
Q

BA anticipating operating emergency

A

Bring on all avail generation, postpone equipment maintainence , schedule interchange purchases in advance, be prepared to she’d firm load

122
Q

BA not experiencing emergency

A

Shall not unilaterally adjust frequency during emergency. Will cause overloading of transmission lines and will develop excessive inadvertent interchange accumulation

123
Q

If a BA needs to declare energy emergency

A

This is done through its RC

124
Q

BA not complying with DCS or CPS

A

Shall remedy by , loading all available generation , deploying all available operating reserve, interrupting interrupt able loads and exports, requesting emergency assistance through other BAs , declaring an energy emergency though its RC , reducing load through such procedures as voltage reduction, publicappealsand curtailment of interrupt able and firm loads

125
Q

Energy emergency alert levels

A

Eea1) when a BA or lse foresees a problem sustaining its load eea2) when a BA is no longer able to provide its customers energy requirements , eea3 when firm load shedding is imminent or in progress
CMD

126
Q

Load shedding plans

A

Shall be coordinated with interconnected BAs and TOs to shed load for under frequency and under voltage . Load shed should be done before generation is shed. Under voltage load shedding occurs in pre selected blocks

127
Q

A BA or TO or LSE experiencing a disturbance

A

Shall submit a preliminary written report within 24 hours to RRO and NERC and DOE of the disturbance .. If weather does not permit the writing of the report then they should verbally notify the rro and nerc

128
Q

DOE reporting

A

Initial reporting done within60 mins ,final report done within 48 hours

129
Q

DOE disturbances

A

Uncontrolled loss of 300mw for more than 15 mins from single incident, load shedding of 100mw during emergency plan, voltage reductions of 3% or more,public appeals to reduce use of electricity, actual or suspected attacks , fuel supply emergencies, loss of electric service to 50k customers for more than am hour, complete operational shutdown of transmission or electrical system

130
Q

Nerc disturbance reporting

A

Loss of component that affects integrity of the interconnection, interconnection islanding, loss of generation (200mw or more in eastern and 1k I’m ercot), equipment failures that result In firm load loss for 15 mins or more, firm load shedding of 100mw or more to maintain continuity of BES,a violation of IROL , any disturbance that the operating committee wants to submit to the dawg

131
Q

Final report due to nerc

A

Within 60 days

132
Q

RRO responsibilities during emergency

A

Make representatives of the nerc operating committee and the dawg available to assist in final report. Track and review status pf reccomendations of report. This should occur at least twice that year

133
Q

TO restoration plan requirements

A

Personel identified, reliable black start units, contingency plans, synchronizing areas, load restoration including critical loads , procedures for simulating and where practical testing every 3 years, training records showing restoration excersizes, functions to be coordinated with and among RC and neighbors , notifications to operating entities as steps are completed

134
Q

TOP system restoration plans must be

A

Updated as nessasary to reflect changes and correct deficiencies , reviewed annually, developed w intent to restore interconnection , coordinated w neighboring systems , periodically testing of telecommunications equipent

135
Q

TOP emergency plans as it relates to generation

A

Emergency power should be available to shutdown safely, operate turning gears, minimize damage to units, maintain communications , expedite restart

136
Q

TO and BA must coordinate restoration actions with

A

RC

137
Q

How to proceed after islanding or collapse

A

Determine extent and condition of area, contact other BAs and TOs to determine circumstances in their areas, start taking nessasary actions to restore system frequency by matching generation to load, begin reviewing interchange schedules , reschyronoze the isolated area to surrounding areas only after RC gives their approval, use strongest transmission lines and restore offsite power to nuclear station ASAP

138
Q

Open circuit breakers

A

On distribution side of blacked out area to control power levels, also disable automatic reclosing relays.

139
Q

Reschyronize with interconnection

A

Only done at power plant w scope, the phase angle should be less than 10 degrees, frequency should be the same and voltage magnitude close too. If differences are to large, operator can re dispatch generation to reduce differences

140
Q

Self certification

A

Every year each TO shall self certify to the RRO compliance standard . Shall include : operating instructions for restoring loads , set of procedures for annual review and of possible simulation , documentation of personnel training records to verify training , reporting of any significant changes to restoration plan to the RRO

141
Q

RC has highest level of authority

A

It is responsible for the coordination of system restoration

142
Q

During restoration RC shall

A

Establish communications with other RCs the RRO and Nerc via the nerc hotline and the RC’S

143
Q

Each RC is required to sign nerc standards of conduct

A

Nerc standards of conduct address …independence , emergency actions, reporting deviations, rules governing employee conduct, books and records,rules governing maintainence of written procedures

144
Q

During restoration

A

Nominal voltages shall be maintained between 90-110%

145
Q

Shunt capacitor banks during restoration

A

Should be taken out of service while restoring the system

146
Q

Static var compensators and synchronous condensers during restoration

A

Should be placed in service as soon as practical

147
Q

Synchronizing of islands

A

Shall be approved, coordinated, communicated by the RC as to not burden surrounding areas.

148
Q

Back up control centers

A

Reliability entities are not required to have back up control centers but procedures must be in place if primary control center goes down. Must not burden interconnection

149
Q

Loss of control center contingency plans

A

Must address .. Ability for instantaneous tie line mw and mvar telemetry.. Ability for instantaneous generating unit telemetry.. Ability to read mw hour accumulators for all tie lines and generating units.. Ability to collect system frequency and time error measurements.. Data links to send generation control signals to generator control centers.. Lost of critical facilities of applicable entities

150
Q

Loss of control center cont.

A

Must contain procedures for maintaining basic voice communications .. Conduction of annual testing of plan.. Annual training. Review of plan annually.. And updating plan annually

151
Q

Indications of lightening fault

A

Ground relay operation ( relay 64) or directional current relay (67)

152
Q

Phase to phase fault

A

Protected by distance relay (21)

153
Q

2 different types of zones for relaying

A

Open and closed .. Differential protection is example of closed zone.. Distance relay example of open zone

154
Q

Differential relaying

A

Closed protective zone.. Measures current entering and leaving zone

155
Q

Distance relaying

A

Open zone… Looks at impudence of line for a specific distance..have quality known as Reach. This tells how far down the line it will detect a fault. If it is set to high it will detect faults to far down line which will cause excess tripping

156
Q

Over current relaying

A

Used as a backup to distance relaying and differential relaying . Can be directional or non directional ( will only trip of current is flowing 1 way) -

157
Q

Pilot relaying

A

Protective relaying where relays communicate with each other to allow for faster and more accurate clearing of faults within line segment

158
Q

Transfer trip relaying

A

Form of pilot relaying.. Initiated at one location and sent via communications channel to trip another breaker or trip auxiliary relay which will trip multiple circuits

159
Q

Misoperation procedures

A

Each GO TO or anyone that owns a transmission protection system shall provide its RROwith it’s misoperation analysis and corrective action according to RRo procedures

160
Q

Operating emergencies

A

Line overloading .. Loss of transmission line..loss of generation..shortage of reactive power

161
Q

Actions TO takes during energy emergency

A

Curtailing transmission service.. Curtailing energy schedules. Operating equipment such as reactive sources.. Shedding firm load

162
Q

A system with a generating deficiency

A

Must reduce its load to restore ace to an acceptable value if they cannot balance generation and load in a timely manner

163
Q

Being prepared for a large system disturbance or pending voltage collapse

A

Areas must have a program in place to arrest these conditions..should address levels of voltage and frequency at which manual action should be taken.. Also to prevent abnormalities such as over voltage or generation instability caused by automatic load shedding

164
Q

All BAs are required by nerc

A

To maintain operating reserves

165
Q

Exceptions for burdening neighboring systems

A

Generator outages- must coordinate with TP…transmission facilities- must coordinate with RC

166
Q

Elevating transmission service priority of an interchange transaction

A

You can change the priorities of interchange transactions and interrupt power if it will help the energy deficient area the LSE must have RC declare an EEA which must be posted on NERC website and include the expected level of the transmission service priority declaration

167
Q

Daily load forecast is determined by tools such as

A

Load forecast..unit commitment.. Power flow simulation programs

168
Q

SOLs are based on

A

Facility ratings ..transient stability ratings.. Voltage stability ratings.. System voltage limits

169
Q

Economic dispatch

A

Point where all generation is operating at the same incremental cost while serving the demand

170
Q

Transfer capability studies

A

Should be done between operating entities annually or whenever a change in facilities warrants a new study. All entities should use uniform line identifiers to not get confused

171
Q

Transfer capability issues include

A

Voltage limits.. Reactive limits.. Thermal limits .. Stability limits

172
Q

GO must provide info on outages for the following day

A

To TO for any generator greater than 50mw.. TO must provide info daily to RC if generator over 50mw or line over 100kv.. Outage info posted by 1200 cst

173
Q

N-1 contingency

A

single worst contingency on the system

174
Q

Voltage control equipment outages

A

Shall be coordinated between entities for AVRs..shunt capacitors etc

175
Q

Voltage collapse

A

When there is lack of reactive power .. Voltage levels down 10-20%

176
Q

Getting ahead of voltage

A

When you Know you are going to have a voltage decline. Place capacitors in service, take reactors out.. Raise gen voltage.. Raise transformer tap positions .. Curtail transactions.. Curtail or shed load.

177
Q

When reactive recourses are limited

A

Limit mw transfers - this prevents power angle increases.. Keep voltage high- this reduces current and angle.. Redid patch generation .. Shift generation patterns to unload heavy loaded lines .. Request neighbor reactive support . Shed load

178
Q

RC is responsible for

A

Scheduling of potential reliability conflicts

179
Q

Uncontrolled separation can occur as the result of

A

When power angle gets too large between two sections and the magnetic bond breaks and they loose synchronisim

180
Q

TOs must operate in anticipation of worst contingency

A

This night be loss of largest unit or large interchange purchase

181
Q

Following a contingency or other event which results in SOL violation

A

TO must return limits within 30 mins.they must make every effort to stay connected to interconnection but of they deem they are in danger of sol or iROL they can disconnect

182
Q

If TO enters unknown operating status

A

Must restore system to proven reliable operating status within 30 mins

183
Q

TOs must coordinate with other TOs

A

Maintain develop and implement procedures to provide for transmission reliability

184
Q

Transmission line capacity is determined by

A

Thermal limits

185
Q

Transmission line inductive reactance

A

Dependent upon spacing between strands within each conductor and distance between each conductor

186
Q

Transmission line capacitive reactance

A

Dependent upon size and spacing of conductors

187
Q

All transmission equipment rated by

A

Transmission owner..these ratings are used to establish SOLs for system

188
Q

TOs and BAs provide monitoring data to RC

A

This helps RC to perform reliability assessments .. Coordinate reliable operations within RCa and with other RCs

189
Q

Electric system reliability data is updated

A

Every 10 mins.. Includes tie line flows generator mw output.. Etc

190
Q

Torque angle

A

Angular difference between the rotor magnetic field and the magnetic field of the stator of the generator

191
Q

Power angle

A

The voltage angle difference between 2 locations in the power system

192
Q

Phase angle

A

The angular separation or difference in phase between the current and the voltage waves

193
Q

RCs publish BA data and system operating assesnements

A

On the nerc isn or rcis.. BAs provide electric systems reliability data to the RCs via the rcis

194
Q

RC,BA,TO

A

Shall have access to all info nessasary to balance generation and load including .. Status of generators and transmission recourses.. Protective relay status.. Weather forecast and past loads.. System frequency

195
Q

Sufficient metering and monitoring equipment

A

Shall be provided to all RC TO and RC

196
Q

3 types of stability

A

Steady state- no significant changes … Transient- a sudden large change….. Oscillating - constantly changing voltage frequency and angles

197
Q

Avoid excessive transmission line loading

A

This results in large power angles.

198
Q

The more transmission lines that are in service

A

The more power can be transferred at a given torque angle

199
Q

Verify generator voltage regulators are in service

A

If they are in automatic the higher the voltage the lower the power angle that is required for given power transfer

200
Q

Records must be kept to show

A

Evidence that TOinformed RC when iROL or sol was exceeded.. There were actions to return system to within limits .. The TO returned system to within an IROL -

201
Q

Each iROL or sol exceeding 30 min

A

Shall be reported to the RRO and nerc within 72 hours.. Using nerc iROL report

202
Q

Transformers are rated in

A

MVA..usually have several ratings associated with the stages of cooling

203
Q

Shunt reactor banks

A

Absorb excess reactive power , usually lightly loaded lines

204
Q

Priority to alleviate violations

A

Redispatch generation.. Curtain interchange transactions.. Disconnect overloaded equipment.. Shed load

205
Q

Circuit breakers

A

Usually not limiting component in power transfers due to high continuous rating.. If a CB fault clearing time is too great it can limit power transfers by need for creating stability limit

206
Q

Disconnect switches

A

Not used to interrupt fault current

207
Q

Air break switches

A

Limited ability to interrupt load . Limited to small current ineruption such as transformer charging current

208
Q

Shunt capacitor banks

A

When energized. Produce reactive power.

209
Q

Interchange transactions and schedules may contribute to sol and iROL

A

Because of parallel flows

210
Q

Increased current cause

A

Increased loading and larger power angles

211
Q

When TO takes action to alleviate sol or iROL

A

Must notify RC and effected TOs.. If possible notify before you take action

212
Q

Priority to alleviate violations

A

Redispatch .. Curtail interchange .. Disconnect overloaded equip.. Shed load

213
Q

Benefits of being connected to interconnection

A

System inertia from stored energy in rotating generators.. Ability of affected system to resist changes in frequency .. Access to reserves, not only mw but also dynamic reactive reserves.. Instant assistance from tie line bias

214
Q

Synchronizing relays

A

Need 20 percent power angle or less to tie busses together

215
Q

Collapse

A

Low frequency .. Low voltage.. High currents

216
Q

Apparent power MVA

A

Consists of both active and reactive power

217
Q

Increased loading causes

A

Circuits to be more inductive

218
Q

Voltage control is

A

Control or reactive power flow

219
Q

When generator AVR is in service

A

It is considered a dynamic source of reactive power

220
Q

Nerc standard for maintaining reactive reserves

A

Each TO shall have adequate reactive resources within its area to protect voltage levels under normal and contingency conditions

221
Q

A strong bus

A

One that has 1 or more generators attached at the closed end of a line that has the ability to absord mvar
/Nerc-SOS-notes/#sthash.fx7ecXpD.dpuf

222
Q

Responsibility of development of emergency load reduction plan to respond to iROL

A

Transmission operator.. Plan must be able to be implemented within 30 mins

223
Q

An emegency Alert is a

A

Emergency procedure

224
Q

Nerc has how many emergency alert levels

A

3

225
Q

Rro final reports are due within

A

60 days

226
Q

A reportable incident shall be reported to

A

Nerc and rro

227
Q

Doe reports are aimed at

A

Customer load loss, sabotage, and efforts to reduce load

228
Q

Rescynchronising of major system islands should only be attempted after approval by the

A

Reliability coordinator

229
Q

Audit of loss of primary control center plan is conducted

A

Every 3 years

230
Q

Loss of primary control center plan must be implemented within

A

1 hour

231
Q

Distribution providers and load serving entities take reliability directives from

A

Transmission operator

232
Q

Balancing authority is required to maintain

A

Operating reserves

233
Q

Angle instability

A

Is the inability for system to maintain magnetic bonds

NERC (8 decks)

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