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ROLE
GBAO
ROLE
☑
SM
IRAC
RC
STSA
RE
☑
Rev History
Reason for Issue
Revised By Issue Date Effective Date
Steve Swan/ 01/03/2017 01/03/2017
0
Annual Review. Completed
Compliance Review. This
Durgesh
procedure replaces RTO-OPManjure/
Jessica
044 to meet new formatting
and writing standards as part
Collins/
of PREP. Operating Procedure
Brian
Owner approval on file.
Weaver/
David Beihl
RTO-OP- Revised procedure per
Steve Swan/ 07/01/2016 07/01/2016
044-r11 changes to NERC standard
Rodney
BAL-001-2 which is effective
Hamblen
7/1/2016. Operating
Procedure Owner approval on
file.
This document is prepared for informational purposes only to support the application of the provisions of the MISO Tariff and the
services provided thereunder. MISO may revise or terminate this document at any time at its discretion without notice. However,
every effort will be made by MISO to update this document and inform its users of changes as soon as practicable. Nevertheless, it is
the user’s responsibility to ensure you are using the most recent version of this document in conjunction with the MISO Tariff and
other applicable procedures, including, but not limited to, the applicable NERC Reliability Standards as they may be revised from time
to time.
In the event of a conflict between this document and the MISO Tariff, the MISO Tariff will control, and nothing in this document shall
be interpreted to contradict, amend or supersede the MISO Tariff. MISO is not responsible for any reliance on this document by
others, or for any errors or omissions or misleading information contained herein.
1.0
2.0
3.0
4.0
5.0
Purpose. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Roles and Responsibilities . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Precautions and Limitations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Prerequisites . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2
Instructions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2
5.1 Normal Operations Monitoring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2
6.0 References . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5
6.1 NERC References . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5
6.2 MISO References. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5
Attachment 1 — Automatic Generation Control (AGC) Operating Mode. . . . . . . . . . . . . 7
Attachment 2 — ACE Calculation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8
Attachment 3 — Real Power Balancing Control Performance. . . . . . . . . . . . . . . . . . . . 10
Attachment 4 — DCS Compliance. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12
Attachment 5 — Time Error Correction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13
Attachment 6 — HVDC External Asynchronous Resources . . . . . . . . . . . . . . . . . . . . . 14
Attachment 7 — Dynamic Schedules . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15
Attachment 8 — Pseudo-Tied Interchange Resources . . . . . . . . . . . . . . . . . . . . . . . . . 16
Attachment 9 — Interchange Meter Error (IME) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17
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1.0
Purpose
Provide detailed instructions for Generation and Balancing Authority
Operator (GBAO) Area Control Error (ACE) management.
2.0
Roles and Responsibilities
1. MISO GBAO
• Responsible for ACE management per Attachment 1 — Automatic
Generation Control (AGC) Operating Mode and Attachment 2 —
ACE Calculation.
• Monitors compliance with regard to Control Performance
Standard (CPS) per Attachment 3 — Real Power Balancing Control
Performance.
• Monitors and ensures that MISO does NOT exceed the
Balancing Authority ACE Limit (BAAL) limits for a continuous
period greater than 30 minutes per Attachment 3 — Real Power
Balancing Control Performance for more details.
• Monitors compliance with regard to Disturbance Control
Standard (DCS) requirements. Refer to Attachment 4 — DCS
Compliance for more details.
• Deploys Contingency Reserves (CR), when necessary, to
respond to real-time reserve sharing events.
• Ensures ACE returns to 0 MW or pre-disturbance value within
15 minutes of generation trip.
• Adjusts Frequency Scheduled (FS) value, and starts and ends Time
Error Corrections (TECs) per Shift Manager (SM) direction. Refer to
Attachment 5 — Time Error Correction for more details.
2. Local Balancing Authority (LBA)
• Provides MISO with Net Actual Interchange (NIA), Interchange
Meter Error (IME), Frequency Actual (FA) and FS via Inter-Control
Center Communications Protocol (ICCP).
• Provides MISO Operating Personnel with accurate and reliable
information when issues occur on the system.
3.0
Precautions and Limitations
1. MISO Reliability Coordinator (RC) and GBAO have the responsibility
and clear decision-making authority to take whatever action needed
to ensure the reliability of its area and shall exercise specific
authority to alleviate capacity and energy Emergencies per the
Letter of Authority.
[□]
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2. MISO will only use the assistance provided by the Interconnection’s
frequency bias for the time needed to implement corrective actions.
3. MISO shall NOT unilaterally adjust generation in an attempt to
return Interconnection frequency.
4. Attachment 6 — HVDC External Asynchronous Resources contains
general information on HVDC lines in MISO.
5. Attachment 7 — Dynamic Schedules contains general information
on Dynamic Schedules to ensure Schedules are accounted for in
the ACE equation.
6. Attachment 8 — Pseudo-Tied Interchange Resources contains
general information on Pseudo-Tie resources.
7. Attachment 9 — Interchange Meter Error (IME) contains general
information on IME.
GBAO
GBAO
GBAO
GBAO
GBAO
SM
GBAO
4.0
Prerequisites
None
5.0
Instructions
5.1
Normal Operations Monitoring
1. ENSURE the following data was sent from LBA via ICCP:
• NIA
[□]
[□]
[□]
[□]
[□]
[□]
[□]
[□]
•
IME
[□]
•
FA
[□]
•
FS
[□]
2. VERIFY MISO received data and data is of good quality.
3. IF data was received and State Estimator (SE) finds data to be
of good quality, THEN GO TO Section 5.1 Step 6.
4. IF data was received and SE does NOT find the data to
be of good quality, THEN PERFORM the following:
A. COORDINATE with data owner and Reliability Engineer (RE)
until issue is fixed.
B. GO TO Section 5.1 Step 6.
5. IF data was NOT received, THEN PERFORM the following:
A. NOTIFY on-duty MISO SM of missing ICCP data.
B. NOTIFY all control room personnel of missing data.
C. CONSULT with SM on whether a System Status Level (SSL) is
needed.
[□]
[□]
[□]
[□]
[□]
[□]
[□]
[□]
[□]
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SM
GBAO
GBAO
GBAO
GBAO
GBAO
GBAO
GBAO
GBAO
D. IF SSL is necessary, THEN PERFORM the following:
(1.) DETERMINE appropriate SSL per RTO-AOP-001 System
Status Level.
(2.) ALERT all control room personnel of SSL.
E. CONTACT appropriate data owner.
F. RECTIFY issue.
G. WHEN data issue is resolved, THEN VALIDATE data quality
via SE.
H. IF data is NOT of good quality, THEN PERFORM
Section 5.1 Step 4.A.
I. IF data is of good quality, THEN CONTINUE with procedure.
6. MONITOR system and applications to detect problems.
7. IF system problem occurs, THEN IDENTIFY problem.
8. SELECT appropriate mitigation procedure from Table 1: Common
System Issues and Mitigation Actions or
Table 2: Uncommon System Issues and Mitigation Actions below:
[□]
[□]
[□]
[□]
[□]
[□]
[□]
[□]
[□]
[□]
[□]
Table 1: Common System Issues and Mitigation Actions
Issue
Where to detect
issue?
How to detect issue?
Procedure
Internal Generation
or Importing Tie
Line Trips
ACE Chart (PI)/
Market Monitoring
Tool (RTD)/
Generation
Monitoring Tool
(RTD)/
Equipment Outages
Tool (RTD)/
Resource Control
(EMS)
ACE, Frequency, and Tie
Error will all move
negative together in
relation to the amount of
loss.
SO-P-NOP-00-464
Tie Line Error
Management
Island Conditions
RT Ops Dashboard
(RTD)/
Generation Area
Status (EMS)/
Island Control (EMS)/
Network Online
Sequence (EMS)
Island Present circle will
be red/
AGC will be suspended
SO-I-NOP-00-440
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Table 1: Common System Issues and Mitigation Actions
Where to detect
issue?
Issue
How to detect issue?
Procedure
Tie Line Errors
Tie Line Error (RTD)/ Reversed Polarity/
Tier 1 BA Details (PI)/ Erratic RTU results/
ACE Chart (PI)
Frozen State RTU
SO-P-NOP-00-464
Tie Line Error
Management
Ancillary Services
Market Product
Clearing Issues
UDS MOI
CLRD REG, SPIN, and
SUPP columns will be
shaded red
Approved TLR
Curtailments
RC will notify STSA
and GBAO
MISO RC or adjacent
RC/Transmission Owner
(TO) notification
Dynamic Schedule
Issues
Tier 1 BA Details (PI)/ Discrepancies between
Scheduled Dynamic
webTrans value and
Interchange
UDS value
(webTrans)
SO-P-NOP-00-460
Dynamic Schedule
Net Scheduled
Interchange Issues
NSI Comparison
Tool/
OATI webTrans NSI
Data
Discrepancies between
OATI and webTrans NIS
SO-P-AOP-00-207 ETag System
Unavailability
Frequency Trigger
Limit (FTL) Issues
Frequency Monitor
Display (RTD)
Discrepancies appear in
yellow.
SO-P-EOP-00-004
Transmission System
Emergency
Table 2: Uncommon System Issues and Mitigation Actions
Issue
Where to detect
issue?
How to detect issue?
Procedure
Automatic Reserve
Sharing (ARS)
Activation
ACE Chart (PI)
Loss of Generation or
importing NSI Schedules
SO-P-NOP-00-459
Automatic Reserve
Sharing
ARS Failure
Refer to SO-P-AOP00-210 Automatic
Reserve Sharing
Failure
Refer to SO-P-AOP-00210 Automatic Reserve
Sharing Failure
SO-P-AOP-00-210
Automatic Reserve
Sharing Failure
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6.0
References
6.1
NERC References
1. BAL-002-1 Disturbance Control Performance
•
R1 [Attachment 4 — DCS Compliance]
2. BAL-004-0 Time Error Correction
•
•
R3 [Attachment 5 — Time Error Correction]
R4 [Attachment 5 — Time Error Correction]
3. BAL-005-0.2b Automatic Generation Control
•
•
•
•
•
•
•
•
R6 [Attachment 2 — ACE Calculation]
R7 [Attachment 1 — Automatic Generation Control (AGC)
Operating Mode]
R8 [Attachment 2 — ACE Calculation]
R9 [Attachment 2 — ACE Calculation, Attachment 6 — HVDC
External Asynchronous Resources]
R10 [Attachment 7 — Dynamic Schedules]
R12 [Attachment 4 — DCS Compliance, Attachment 8 — PseudoTied Interchange Resources]
R13 [Attachment 3 — Real Power Balancing Control Performance]
R16 [Attachment 3 — Real Power Balancing Control Performance]
4. EOP-002-3.1 Capacity and Energy Emergencies
•
R6 [Attachment 3 — Real Power Balancing Control Performance,
Attachment 4 — DCS Compliance]
5. IRO-005-3.1a Reliability Coordination - Current Day Operations
•
6.2
R5 [Attachment 3 — Real Power Balancing Control Performance,
Attachment 4 — DCS Compliance]
MISO References
1. SO-I-NOP-00-440
2. SO-P-NOP-00-459 Automatic Reserve Sharing
3. SO-P-AOP-00-210 Automatic Reserve Sharing Failure
4. SO-P-NOP-00-464 Tie Line Error Management
5. SO-P-NOP-00-460 Dynamic Schedule
6. RTO-AOP-001 System Status Levels Procedure
7. SO-P-AOP-00-211 AGC Failure
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8. SO-P-AOP-00-207 E-Tag System Unavailability
9. SO-P-EOP-00-004 Transmission System Emergency
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Attachment 1 — Automatic Generation Control (AGC) Operating Mode
1.0
General Information
1. The MISO GBAO operates continuously with AGC on Tie-Line Bias
Control, unless such operation adversely impacts the reliability of the
Interconnection.
2. IF AGC becomes inoperative, THEN MISO GBAO re-dispatches
generation set-points or relies on Extensible Markup Language (XML)
dispatch target instructions specified in SO-P-AOP-00-211 AGC Failure
to adjust generation and maintain NIS.
3. There are three modes of AGC available in the EMS for controlling the
NSI in the MISO Balancing Authority Area (BAA).
A. Tie-Line Bias Control
•
Tie-line bias control is the most widely used mode of control
for multi-LBA power systems.
•
This mode of control responds to both frequency and net tieline flow deviations.
B. Flat Frequency Control
•
Flat frequency control only considers power system frequency
as the controlling parameter.
•
This mode of control only responds to frequency deviations
and does not adjust operations for any Interconnection tie-line
schedule deviations.
•
This mode is applicable only when the MISO BAA becomes
isolated from the Eastern Interconnection.
C. Flat Tie-Line Control
•
Flat tie-line control only considers interconnection tie-line flow
as the controlling parameter.
•
This mode of control only responds to net tie flow deviations
and does not adjust operation for any frequency deviations.
•
This mode is limited to special circumstances when the MISO
GBAO desires to maintain a given net interchange flow and
the power system frequency is stable and being controlled by
other control areas.
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Attachment 2 — ACE Calculation
1.0
General Information
1. The MISO BA includes all interchange tie-line flows, including NIA and
NIS with LBAs and Adjacent BAs to calculate the MISO BA ACE. The
MISO BA ACE calculation also includes Frequency Bias and
Interchange Meter Error (IME).
2. All AGC inputs are sampled every 2 seconds.
3. Once the MISO BA ACE is calculated, dispatch set-points are sent to
Regulating Reserve Resources every four seconds.
4. The MISO BA has an independent frequency source for each of the
four EMS systems (two at Carmel Control Center (CCC) and two at
Sheridan Control Center (SCC)).
5. The primary and alternate frequency sources are telemetered via ICCP
links at primary and alternate facilities and are associated with each of
the four EMS’s.
6. Automatic Fail-Over – The EMS automatically fails-over to alternate
frequency sources when a frequency source is suspect in the EMS.
EMS has an automatic fail-back feature that defaults to the primary
frequency source when it returns to a valid state.
7. Manual Fail-Over – The MISO GBAO has the ability to skip a frequency
source if the Remote Terminal Unit (RTU) is determined to be an
unreliable data source.
8. The MISO BA ensures data acquisitions and ACE calculations occur at
least every 6 seconds. If EMS is unable to calculate ACE for more than
five minutes, the MISO GBAO notifies the RC and SM.
2.0 ACE Calculation
1. The MISO BA equation for ACE is:
ACE =  NI A – NI S  – 10Bs  F A – F S  – I ME
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2. Where:
• NIA is the algebraic sum of actual flows on all tie-lines.
• NIS is the algebraic sum of scheduled flows on all tie-lines.
• Bs is the Frequency Bias Setting (MW/0.1 Hz) for the BA. The
constant factor 10 converts the frequency setting to MW/Hz.
• FS is the scheduled frequency. FS is normally 60 Hz but may be
offset to effect manual time error corrections.
• FA is the actual frequency.
• IME is the meter error correction factor typically estimated from the
difference between the integrated hourly average of the net tie-line
flows (NIA) and the hourly net interchange demand measurement
(MWh). This term should normally be very small or zero.
3. The EMS performs hourly error checks using tie-line megawatt-hour
meters with common time synchronization to determine the accuracy of
its control equipment. The MISO BA adjusts the component (e.g., Tieline meter) of ACE that is in error (if known) or uses the IME term of the
ACE equation to compensate for any error until repairs can be made.
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Attachment 3 — Real Power Balancing Control Performance
1.0
General Information
1. When and if the MISO BA can NOT comply with the NERC CPS and
DCS, the MISO GBAO in conjunction with the SM, RC, and RGD will
immediately implement remedies. These remedies include, but are
NOT limited to, the following:
• Loading all available generating capacity.
• Deploying all available operating reserve.
• Interrupting interruptible load and exports.
• Requesting emergency assistance from other BAs.
• Declaring an Energy Emergency through the MISO RC.
• Reducing load, through procedures such as public appeals, voltage
reductions, curtailing interruptible loads, and firm loads.
2.0 CPS 1
1. The MISO BA verifies the rolling 12 month CPS1 performance criteria
meets associated NERC compliance requirements. The GBAO
monitors and coordinates actions to ensure LBA resources are
following set point instructions, as well as monitoring the deployment of
cleared Regulating Reserves.
2. In order to ensure that the average ACE and Frequency Deviation
calculated for any 1 minute interval is representative of that 1 minute
interval, it is necessary that at least 50% of both ACE and Frequency
Deviation samples during 1 minute intervals are present.
3. Should a sustained interruption in the recording of ACE or Frequency
Deviation occur due to the loss of telemetering abilities or computer
unavailability results in a 1 minute interval NOT containing at least 50%
of ACE and Frequency Deviation samples, the 1 minute interval is
excluded from the MISO BA CPS1 calculation.
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4. The MISO BA identifies and excludes associated 1 minute interval(s)
that do NOT contain at least 50% of ACE and Frequency Deviation
samples, by flagging on the 1 minute interval. All the 1 minute intervals
that are excluded are logged in the MISO Communication System
(MCS) Log with the reason for the exclusion of the 1 minute interval. If
AGC is paused due to bad telemetry for more than seven consecutive 4
second ACE and Frequency Deviation samples during any one-minute
interval, the flag should be set to exclude the 1 minute interval.
Figure 1: CPS Formula
5. The MISO BA specific limit ε1 is a constant derived from a targeted
frequency bound (separately calculated for each Interconnection) that is
reviewed and set as necessary by the NERC Operating Committee.
3.0 BAAL
1. The MISO GBAO monitors real-time ACE and interconnection
frequency against associated limits, and balances Resources and
Demands in real-time so that the MISO BA ACE does NOT exceed the
BAAL limits (BAAL LOW or BAAL HIGH) for a continuous time period
greater than 30 minutes. For any BAAL exceedance greater than 30
minutes the GBAO will make a MCS Log entry (“Event Type” BAAL)
providing the details of the event.
2. The MISO GBAO monitors BAAL control performance intervals for the
MISO BA, to communicate and coordinate information with MISO to
ensure Resources are following set point instructions and monitoring of
the deployment of cleared Regulating Reserves.
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Attachment 4 — DCS Compliance
1.0
DCS General Information
1. The MISO GBAO monitors the MISO BAA to measure its ability to
recover from DCS reportable disturbances.
2. The MISO BA elects to fulfill its Contingency Reserve obligations by
participating in the MISO-Manitoba Hydro Electric Board (MHEB)
Contingency Reserve Sharing Group (CRSG). MISO and MHEB
assume the same responsibilities and obligations with respect to
monitoring and meeting the requirements of NERC Standard
BAL-002-1.
3. MISO and MHEB activate sufficient contingency reserves to ensure
100% compliance with DCS reportable disturbances.
4. The MISO BA does NOT filter the power flow and ACE signals utilized
for calculating BA performance criteria or that are transmitted for
Regulation Service, except for the anti-aliasing filters of tie-lines.
5. MISO acts as a CRSG member when responding to ARS events in
conjunction with MHEB.
6. MISO acts as an individual BA when responding to ARS events without
enlisting MHEB resources.
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Attachment 5 — Time Error Correction
1.0
General Information
1. The MISO SM is responsible for documenting instances of Time Error
Correction in the MCS.
2. The MISO GBAO enters the start time and the desired scheduled
frequency into the EMS using +/- 0.02 Hz offset (59.98 Hz to correct for
fast time error or 60.02 Hz to correct for slow time error) as directed by
the MISO SM.
3. IF the Time Error Monitor (TEM) requests the MISO SM to terminate an
instance of Time Error Correction for reasons related to reliability, THEN
the MISO SM coordinates with the GBAO to terminate the Time Error
Correction.
4. When notified by the MISO SM to terminate the Time Error Correction,
the GBAO enters the stop time into the EMS.
5. The MISO RC has the authority to request the TEM to terminate a time
error correction in progress, or a scheduled time error correction that
has NOT begun, for reliability reasons. The MISO RC coordinates
internally with the SM and the GBAO to terminate time error
corrections.
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Attachment 6 — HVDC External Asynchronous Resources
1.0
General Information
1. High Voltage Direct Current (HVDC) interchange ties link MISOManitoba Hydro-Electric Board (MHEB) Asynchronous Resources to
Synchronous Resources located in the Eastern Interconnection. The
energy exchanged over the MISO-MHEB HVDC tie-line is accounted
for on a Dynamic External Asynchronous Resource (EAR) schedule.
2. The MISO BA requires HVDC interchange ties to be modeled to
equivalent generators/load located externally to the MISO BAA, similar
to pseudo-tied, External Resources.
3. The MISO BA requires an EAR Schedule to be submitted to coincide
with equivalent energy being transferred on HVDC interchange ties.
4. Only one Dynamic EAR schedule submitted by MHEB is allowed to
participate in the MISO Energy and Operating Reserve Markets.
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Attachment 7 — Dynamic Schedules
1.0
General Information
1. The MISO GBAO and EMS Shift Engineers monitor the MISO BA
dynamic interchange to ensure valid generation and load data is being
provided by LBAs, to ensure that all Dynamic Schedules are included in
the MISO BA ACE equation.
2. The MISO RC and the MISO BA work with the LBA to request Dynamic
Schedule modification if the associated interchange differs substantially
from the scheduled Dynamic Schedules.
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Attachment 8 — Pseudo-Tied Interchange Resources
1.0
General Information
1. Pseudo-tied generation resources physically located in an Adjacent
BAA are electronically telemetered to the transmission system and may
require transmission service to be provided by MISO. The associated
telemetry signals relate the pseudo-tied generation or load to an asset
owner and redundant frequency sources provide ICCP data to MISO in
real-time.
2. Pseudo-tied metering devices send telemetered data to redundant
MISO control centers over agreed-upon interchange sources. MISO
requires common metering points and adequate communication
infrastructure between pseudo-tied interchange tie-lines, but does NOT
imply specific ownership of the telemetry devices.
3. The EMS calculates and reports megawatt-hour data at the end of each
operating hour. The MISO GBAO and EMS Shift Engineers monitor
pseudo-tied generation and load values and verify pseudo-tied
interchange ties are modeled correctly in the MISO BA ACE equation.
A. External Pseudo-Tied Load Zone
(1.) If the Load is physically inside the MISO BA footprint, but
pseudo-tied to an external BA, then the Load is considered
external.
(2.) The Load will be represented in the Network Model of the
external BA and be registered as a Pseudo-Tie Load Zone for
congestion and loss charges from the MISO BA.
B. Internal Pseudo-Tied Load Zone
(1.) If the Load is physically outside of the MISO BA footprint, but
pseudo-tied to an internal LBA, then the Load is considered
internal.
(2.) The Load will be represented in the MISO Network Model and
assigned to a Load Zone within the MISO BAA.
(3.) However, appropriate Transmission Service arrangements
must be in place with the Transmission Provider of the
Adjacent BA.
C. LBA Responsibilities
(1.) LBAs are required to install common metering equipment
where Dynamic Schedules or Pseudo-Ties are implemented
between the MISO BAA and its adjacent BAAs.
(2.) This is done to deliver the output of Jointly Owned Units
(JOUs) or to serve remote load
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Attachment 9 — Interchange Meter Error (IME)
1.0
General Information
1. The MISO GBAO monitors the MISO IME Overview display to verify IME
values sent via ICCP from LBAs is accurate. If the value of the IME is
higher than the pre-determined reasonability limit, the MISO GBAO has
the ability to override a LBAs IME value for use in the MISO BA ACE
equation. The MISO GBAO coordinates with LBAs in real-time to verify
LBAs are providing valid IME data via ICCP.