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NERC- RC > RC Prep > Flashcards

RC Prep Flashcards

1
Q

ACE

A

ACE=(NIa-NIs)-10B(Fa-Fs)-Ime

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2
Q

How often is ACE calculated

A

Every 6 seconds

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3
Q

Time error correction

A

+/-0.02 Hz for time error correction, offsets ACE by .20 or 20% (NIAs)

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4
Q

CPS1- Control Performance Standard

A

Calculated and evaluated monthly, CPS1 >/=100%

Rolling 12 month average <100% is non compliant

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5
Q

BAAL- BA Ace Limit

A

Cannot exceed for 30 minutes
BAAL High >scheduled frequency
BAAL Low < scheduled frequency

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6
Q

MSSC

A

Most severe single contingency, reviewed annually

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7
Q

Reportable DCS

A

Disturbance control standard
Less than MSSC or > 80% of MSSC
Within one minute of sudden decline of ACE–>More than 1 event occurring within that one minute equates to 1 event

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8
Q

Contingency event recovery period

A

Time frame from resource output to decline within the first one minute interval of a reportable BA contingency event and extending for 15 minutes thereafter

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9
Q

Exemptions to reporting DCS

A

RC declared EEA
Multiple contingency events and magnitude exceeds MSSC
Multiple balancing contingency events within the sum of the time periods defined by the cont. event recovery period and the contingency event restoration period whose combined magnitude exceeds the MSSC

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10
Q

Contingency reserve restoration period

A

Restore contingency reserve within 90 minutes of the end of the contingency event recovery period

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11
Q

DCS Requirement

A

Must achieve 100% ACE Recovery- NERC CR Form 1

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12
Q

Frequency and load relationship (thumbrule)

A

1% decrease in frequency results in 2% decrease in load (3% for inductive motors)

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13
Q

Governor dead band

A

+/- 0.036 Hz–>Will not see change in NIa in ACE equation if no governor response occurs from a change in frequency

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14
Q

Frequency Response Measure (FRM)

A

Median of all frequency response observed for frequency deviation events identified by NERC for previous year
FRM must be = or more (-) than its FRO

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15
Q

Frequency Response Obligation (FRO)

A

FRM must be = or more (-) than its FRO
Calculated each year
BA’s percentage of the interchange and load

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16
Q

FRSG- Frequency Response Sharing Group

A

Jointly meet FROs- must modify frequency bias to represent frequency bias setting for the combined area–>Either sum area or single FB setting for the combined area

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17
Q

BAAL-005 action if ACE cannot be calculated

ACE Requirements

A

> 30 minutes, BA inform RC within 45 minutes starting at the initial time ACE was not able to be calculated

Manually calculate at this time
Must be available 99.5% of year (45 hours)

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18
Q

Frequency metering equipment requirements

A

Accurate to 0.001 Hz and available 99.95% of year (4.5 hours)

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19
Q

Dynamic transfers

A

Dynamic schedules- reflected in NIs
Pseudo tie- used as virtual AGC in ACE equation- reflected in NIa

Developed as way to account for the generation and load in the appropriate BA’s ACE equation

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20
Q

AGC (Automatic Generator Control)

A

Partially replaces lost generation–>Contingency reserves return ACE to 0
Hydro can respond quick (2-5 minutes on AGC)

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21
Q

AGC Modes

A

Tie line bias- uses entire ACE equation
Flat frequency- Considers only frequency control- islanded or isolated BA
Flat tie line- Only interchange component- if frequency signal is unavailable or unreliable

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22
Q

Assessment period for interchange request

A

Time from ramp:
1 hour or less- 10 minutes
1-4 hours- 20 minutes
>4 hours- 2 hours

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23
Q

Assessment evaluation for interchange

A

Energy profile
Ramp
Scheduling path

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24
Q

ATC- Available Transfer Capability

A

ATC=TTC-CBM-TRM

CBM- Capacity benefit margin
TRM- Transmission reliability margin

ATC**- accounts for unscheduled flow

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25
Q

Reliability Adjustment Arranged Interchange

A

Modify schedule for reliability between only the source and sink BA
Must communicate to RC within 10 minutes if denied and reason for denial

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26
Q

Who confirms and and who is informed once interchange is confirmed?

A

Sink BA

  • Source BA
  • Intermediate BA
  • Each RC
  • TSP
  • Purchasing and selling entity
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27
Q

TLR- Transmission Loading Relief (TLR)

A

Interchange transactions >5% may be curtailed to provide relief

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28
Q

How often are real time assessments performed by the RC and purpose?

A

Every 30 minutes- identify IROL exceedances

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29
Q

How long can a IROL exceed its limit?

A

30 minutes or Tv (Tv must be 30 minutes or less)

30
Q

Who implements plan to prevent exceeding IROL/SOL?

A

RC

31
Q

How often are plans, processes and procedures reviewed?

A

Every 15 months

32
Q

GMD are more likely to occur in what terrain?

A

Igneous rock

33
Q

Impacted equipment by GMD event?

A

Transformer with high side wye grounded windings >200kv

34
Q

Who disseminates GMD info?

A

Designated RC

35
Q

EEA Levels

A

EEA 1- All available generation resources in use, concerned about sustaining contingency reserves, non firm energy sails are curtailed
EEA 2- Load management procedures in effect, no longer able to provide energy requirements- BA has implemented Operating Plan to mitigate emergencies and still able to maintain minimum contingency
EEA 3- Firm load interruption imminent or in progress- unable to meet minimum contingency reserves

36
Q

Who issues EEA?

A

RC

37
Q

Time requirement for reviewing Operating Plans

A

30 days

Submitted by BA and TO to RC

38
Q

Operating plan should include what?

A

Communication Pro
Controlling Actions
Coordination
Staffing levels

39
Q

Requirement for review of changes to restoration plan with blackstart resources

A

Planned- prior to change

Unplanned- within 90 days of change

40
Q

Requirement to verify blackstart plans?

A

Every 5 years through:

  • Actual events
  • Blackstart resource testing every 3 years
41
Q

Training requirements for blackstart resources

A

TO- Annually
Switching Personnel- 2 hours every 2 years
GO- 2 hours every 2 years- starting unit and energizing bus

42
Q

Blackstart resource testing requirements

A

Every 3 years

  • No assistance from BES
  • Energize a bus
43
Q

TO and GO agreement for changes in blackstart resource ability

A

Within 24 hours if offline

Within 30 minutes if online

44
Q

RC review of restoration plan frequency

A

Every 13 months

- Neighboring plan within 30 days and notification within 60 days if there is a conflict, resolved within 30 days

45
Q

Island load shed thumbrule

A

6-10% will increase frequency 1 Hz

46
Q

Load restoration thrumbrule

A

5% of online generation

47
Q

Restoration drill training

A

2 drills/year
Annual training for RC
Each TO/GO every 2 years participate in drill

48
Q

BCC (Back up control center) requirements

A

Implemented in 2 hours or less and maintained 2 hours or more
Performed annually

49
Q

Differential relay (87)

A

Power in=Power out, closed zone of protection

50
Q

Distance relay (21)

A

Open zone, uses PT and CT–>Z=V/I

51
Q

Relay zones of protection

A

1- 90%
2- 120-150%
3- 150-300%

52
Q

Overcurrent Relay

A

Back up to distance and differential
50- instantaneous
51- timed
Directional- 67

53
Q

SIL- Surge impedance loading

A

@ SIL- Produced reactive power=consumed reactive power

>SIL- Inductive, voltage lowers

54
Q

Capacitor equation

A

Rated*[(Bus voltage/Rated voltage)^2]

55
Q

AVR Requirements

A

Must run in AVR unless:
S/u, S/d, testing
Notify SO within 30 minutes for a change in VR status, not required if within 30 minutes

56
Q

Generator Transformer requirements

A

W/ in 30 days of request if the primary transformer windings are > generator terminal voltage, Gen. owner shall provide TO and TP w/:

  • Tap settings
  • Available fixed tap ranges
  • Impedance data
57
Q

DCS Compliance

A

100% to 15 minute recovery

58
Q

CPS Compliance

A

> 100% (monthly)

59
Q

Reportable manual load shed

A

> /= 100 MW

60
Q

Reportable loss of firm load

A

> /=300 MW

61
Q

BAAL

A

<30 minutes to get within bound

62
Q

COM requirements for RC (primary/backup)

A

TO, BA, adjacent RC

63
Q

COM requirement for BA (primary/backup)

A

RC, adjacent BA, TO, GO, DSP

Back up: RC, TO, adjacent BA

64
Q

COM requirement for TO (primary/back up)

A

RC, adjacent TO, BA, GO, DSP

Back up: RC, BA, adjacent TO

65
Q

Failure of comms

A

Notify affected entities within 60 minutes if >30 minutes

66
Q

Testing of alt. comms

A

Once very month (TO, BA, RC)- must initiate corrective action within 2 hours to repair or replace

67
Q

Requirement to report EOP-004 event

A

IAW Operating plan within 24 hours or 4PM the following business day

68
Q

TOP-001 data validation

A

BA must validate data once every 90 days–>must be restored within 2 hours if lost

69
Q

EOP-005, System restoration plan requirements

A

Reviewed annually and submitted to RC- within 90 days of unplanned changes, prior to any planned changes, verified every 5 years

70
Q

Restoration drill plan review requirement

A

Every 13 months
RC review neighboring RC and TO plan within 30 days
If an issue arises, not. of conflict within 60 days and resolved in 30 days

NERC- RC (2 decks)

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