Family Field Descriptions

Amplification Code

Character

Identifies the cause of an outage and is used to populate the Amplification Code field in the Event record.

By default, this field is populated with the Amplification Codes included in the Amplification Codes family. You can use the GAA Data Loaders to import the latest Amplification Codes.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

Description

A baseline rule exists to populate this field with a list of the following values:

• Canadian Electricity Association (CEA)
• North American Electric Reliability Corporation (NERC)

This field is required.

This field is populated automatically using the value in the Event Start Date field in the Primary Event record that is linked to the APM Event record.

This field is required.

This field is populated automatically using the following template:

APM~<Unit Name>~<Event Start Date>

where:

• <Unit Name> is the value in the Unit ID field in the GAA Unit record that is linked to the Primary Event record for which the APM Event record exists.
• <Event Start Date> is the value in the Event Start Date field in the Primary Event record that is linked to the APM Event record.

The value in the Description field describes the APM event. You can enter a description into this field.

This field is populated automatically with the value in the Plant ID field in the GAA Plant that is linked to the GAA Unit that is linked to the Primary Event for which the APM Event exists.

The value in the Description field describes the name of Plant in which the event occurred. This field is populated automatically with the value in the Plant name field in the GAA Plant that is linked to the GAA Unit that is linked to the Primary Event for which the APM Event exists.

This field is populated automatically with the value in the Cause Code field in the Primary Event record that is linked to the APM Event record.

The value in the Description field describes the cause code for the event. This field is populated automatically with the value in the Cause Code Description field in the Primary Event that is linked to the APM Event.

This field is populated automatically with the value in the Unit ID field in the GAA Unit record that is linked to the Primary Event for which the APM Event exists.

This field is required.

The value in the Description field describes the name of Unit in which the event occurred. This field is populated automatically with the value in the Unit Name field in the GAA Unit that is linked to the Primary Event for which the APM Event exists.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

In an Event, when you set the value in the Cause Code field, if the value in this field is:

• True, the GE Digital APM system will automatically set the value in the OMC Event field to True.
• False, the GE Digital APM system will automatically set the value in the OMC Event field to False.

A baseline rule exists to populate this field with a list of the following values:

• Canadian Electricity Association (CEA)
• North American Electric Reliability Corporation (NERC)

This field is required.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

This field is disabled by default. This field is enabled and required when you enter an ambiguous date and time in one of the following fields:

• Event Start Date
• Event End Date
• Work Started
• Work Ended

You can select one of following values in this field:

• First Occurrence: Select this option if the date and time that you entered in the Event Start Date field occurred before the clock was reset.
• Second Occurrence: Select this option if the date and time that you entered in the Event Start Date field occurred after the clock was reset.

This field exists in the Primary Event family but not the Contributing Event family.

This field is enabled only when the Cause Code field is populated with a value. A baseline rule exists to populate this field with a list of values from the Amplification Code field in the Amplification Codes records.

This field is required when the Primary Event is in the Unit Approved state.

This field is included in NERC event reports.

Identifies the type of event.

For NERC,

• For a Primary Event, this field contains a list of values defined in the GAA Event Types records.
  • If the value of Unit State field in the GAA Unit record is set to Active, the Capacity Event Type field contains a list of types of events associated with the Active state.
  • If the value of Unit State field in the GAA Unit record is set to Inactive, the Capacity Event Type field contains a list of types of events associated with the Inactive state.
• For a Contributing Event, this field is disabled and populated automatically with the value in the Capacity Event Type field in the Primary Event to which it is linked.

For CEA, this field contains a list of values defined in the GAA Event Types records.

• If the value of Unit State field in the GAA Unit record is set to Commercial Service (CS), the Capacity Event Type field contains a list of types of events associated with the Available state for a GAA Unit that reports to CEA.
• If the value of Unit State field in the GAA Unit record is set to Not In Commercial Service (NICS), the Capacity Event Type field contains a list of types of events associated with the Not Available state for a GAA Unit that reports to CEA.

This field excludes the Event Types based on the Unit Types that you selected in the Excluded Unit Type field in the GAA Event Types record.

This field is included in NERC event reports.

This field is required.

A baseline rule exists to populate this field with a list of values in fields in Cause Codes records using the format Cause Code (Cause Code Description).

This field is required when the Primary Event is in the Unit Approved state.

A baseline rule exists to populate this field with a list of values in the Component field in Cause Codes records.

This field is required when the Primary Event is in the Unit Approved state.

A baseline rule exists to populate this field with a list of values in the Cause Code Description field in Cause Codes records.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

This field is required when the Primary Event is in the Unit Approved state.

A baseline rule exists to populate this field with a list of values in the System field in Cause Code records.

This field is required when the Primary Event is in the Unit Approved state.

This field is populated automatically with information regarding the status of the calculation performed in the Capacity Incident Cost field.

This field exists in the Primary Event family but not in the Contributing Event family.

Count of Contributing Events

This field is disabled and populated automatically with a value that indicates the number of Contributing Events that are linked to the Primary Event. The value in this field is updated each time you link a new Contributing Event to the Primary Event and each time you unlink a Contributing Event from the Primary Event.

This field exists in the Primary Event family but not the Contributing Event family.

Cumulative Engine Starts at Time of Event

Identifies the total number of engine starts the unit had experienced at the time the event occurred.

This field is available in the Additional Reporting section for a Primary Event.

Cumulative Fired Hours at Time of Event

Identifies the total cumulative number of hours the unit spent generating power at the time the event occurred.

This field is available in the Additional Reporting section for a Primary Event.

Indicates whether the Event represents a dominant derate event.

This field is enabled only when the Capacity Event Type field contains a value that identifies the event as a derate event. If the value in this field is:

• True, the Event represents the dominant derate event.
• False, the Event does not represent the dominant derate event.

This field exists in the Primary Event family but not in the Contributing Event family.

Indicates whether the value in the Event End Date field is an estimate.

Select this check box when the value in the Event End Date field represents an estimate of when the event ended or will end.

Clear this check box if the value in the Event End Date field represents the actual time that the event ended.

This field exists in the Primary Event family but not in the Contributing Event family.

Indicates how the incident contributed to the event.

A baseline rule exists to populate this field with a list of System Codes in the MI_GAA_EVENT_CONTR_CODE System Code Table.

You can change the value by selecting one of the following options:

• 2-Contributed to Primary Cause: Indicates that the event represents a secondary cause that contributed to the primary cause of the event.
• 3-Work done during the event: Indicates that the event represents work that was done during the event.
• 5-After startup, delayed unit from reaching load point: Indicates that the event delayed the unit from reaching its dependable capacity after startup and prevented the unit from filling its load requirement.

This value is included in the NERC event reports.

This field exists in the Contributing Event family but not in the Primary Event family.

Indicates how long the event lasted.

This field is disabled and calculated automatically using the following formula:

Event End Date - Event Start Date

The Event Duration takes into account any existing Daylight Saving Time Reference records for the time period between the Event Start date and Event End date.

Indicates the date and time that the event ended.

• For a Primary Event, if you enter an ambiguous date and time in this field:

  A message will appear indicating that the value is not valid.

  The Ambiguous Date and Time Preference field will be enabled and required.

  You cannot specify a value in the Event End Date field with a year that is different from the year in the value in the Event Start Date field.

• For a Contributing Event, this field is disabled and is populated automatically with the value in the Event End Date field from the Primary Event to which it is linked.

This value is included in NERC event reports.

• For a Primary Event, this value identifies the event with a value that is unique to all Primary Events associated with a given GAA Unit.
• For a Contributing Event, this value identifies the Primary Event for which the Contributing Event exists.

Indicates the order in which the event occurred with respect to other events that exist for the same unit.

• For a Primary Event, the value indicates the chronological order in which the event took place. When you create a Primary Event, this field is populated automatically. For example, when you create the third Primary Event for a given GAA Unit for a given reporting month and year, this field will be populated automatically with the value 3 (three).
• For a Contributing Event, this field is populated automatically with the value in the Event Number field in the Primary Event to which it is linked.

This field does not appear on the datasheet.

Indicates the date and time that the event began.

• If you enter an ambiguous date and time in this field:

  A message will appear indicating that the value is not valid.

  The Ambiguous Date and Time Preference field will be enabled and required.

  You cannot specify a value in the Event Start Date field with a year that is different from the year in the value in the Event End Datefield.

• For a Contributing Event, this field is disabled and is populated automatically with the value in Event Start Date field in the Primary Event to which it is linked.

This value is included in NERC event reports.

This field is required.

Indicates the manner in which the component failed.

A baseline rule exists to populate this field with a list of System Codes in the MI_GM_FAILURE_MECHANISM System Code Table.

This field exists in the Primary Event family but not the Contributing Event family.

This field is available in the Additional Reporting section for a Primary Event.

Identifies the gross available generation capacity of the unit during the event.

• This field is only enabled for a Reserve Shutdown event. This field contains a value that is calculated depending on the value in the Capacity Event Type field. If the value in the Capacity Event Type field contains a value that identifies the event as:

  • A derate event, this field will become required, and the value must be less than the value in the Gross Dependable Capacity field. This field is cleared and becomes required when the Gross Derate Amount field contains no value or the value 0 (zero). If the Gross Derate Amount field contains a value other than 0 (zero), this field will be populated automatically using the following formula:

    Gross Dependable Capacity - Gross Derate Amount

  • An outage event, this field will become disabled and populated with the value 0 (zero).
• For a Contributing Event, this field is disabled and populated automatically with the value in the Gross Available Capacity field in the Primary Event to which it is linked.

This field is populated automatically with the value in the Gross Dependable Capacity field in the Unit Capacity record for a GAA Unit based on the start date of the Primary Event.

This field exists in the Primary Event family but not the Contributing Event family.

Indicates the gross amount of generation capacity that was lost during the event.

• This field is only enabled for Derate events. This value is used to calculate the value in the Gross Available Capacity field. The default value is 0 (zero). If the value in the Capacity Event Type field contains a value that identifies the event as:

  • A derate event, this field will be optional. If this field contains a value other than 0 (zero), the value in the Gross Available Capacity field will be disabled and populated automatically using the following formula:

    Gross Dependable Capacity - Gross Derate Amount

    If this field contains no value or the value 0 (zero), the Gross Available Capacity field becomes required.

  • An outage event, this field will become disabled and populated with the value 0 (zero).
• For a Contributing Event, this field is disabled and populated automatically with the value in the Gross Derate Amount field in the GAA Unit for which the Contributing Event exists.

This field is populated automatically with the value in the Gross Maximum Capacity field in the Unit Capacity record for a GAA Unit based on the start date of the Primary Event.

This field does not appear on the datasheet.

You can enter a value manually.

Identifies the net available capacity of the unit during the event.

• This field is only enabled for Reserve Shutdown events. This field contains a value that is calculated depending on the value contained in the Capacity Event Type field. If the value in the Capacity Event Type field contains a value that identifies the event as:

  • A derate event, this field will become required, and the value must be less than the value in the Net Dependable Capacity field. This field is cleared and becomes required when the Net Derate Amount field contains no value or the value 0 (zero). If the Net Derate Amount field contains a value, this field will be populated automatically using the following formula:

    Net Dependable Capacity - Net Derate Amount

  • An outage event, this field will become disabled and populated with the value 0 (zero).
• For a Contributing Event, this field is disabled and populated automatically with the value in the Net Available Capacity field in the GAA Unit that contains a value in the Unit ID field that matches the value in the Unit ID field in the Event.

Identifies the net dependable generation capacity of the unit at which the event occurred.

This field is populated automatically with the value in the Net Dependable Capacity field in the Unit Capacity record for a GAA Unit based on the start date of the Primary Event.

This field exists in the Primary Event family but not the Contributing Event family.

Indicates the net amount of generation capacity that was lost during the event.

• This field is only enabled for Derate events. This value is used to calculate the value in the Net Available Capacity field. The default value is 0 (zero). If the value in the Capacity Event Type field contains a value that identifies the event as:

  • A derate event, this field is an optional field. If this field contains a value other than 0 (zero), the value in the Net Available Capacity field will be disabled and populated automatically using the following formula:

    Net Dependable Capacity - Net Derate Amount

    If this field contains no value or the value 0 (zero), the Net Available Capacity field is cleared and becomes required.

  • An outage event, this field will become disabled and populated with the value 0 (zero).
• For a Contributing Event, this field is disabled and populated automatically with the value in the Net Derate Amount field in the GAA Unit that contains a value in the Unit ID field that matches the value in the Unit ID field in the Event.

This field is populated automatically with the value in the Net Maximum Capacity field in the Unit Capacity record for a GAA Unit based on the start date of the Primary Event.

This value is defined by NERC in the GADS DRI.

This field does not appear on the datasheet.

Indicates whether the event occurred for reasons that are outside of management control, such as a flood or lightning.

If the value in this field is:

• True, the event is considered outside of management control.
• False, the event is considered to be within management control.

Identifies the potential cost of the event.

This field is disabled and populated automatically with the calculated event cost, if a cost has been calculated.

This field exists in the Primary Event family but not in the Contributing Event family.

This field is disabled and populated automatically with the value in the Event ID field in the Primary Event to which the Contributing Event is linked.

This field exists in the Contributing Event family but not the Primary Event family.

Indicates whether the problem that caused the event is the result of a design flaw or standard operating practices.

If the value in this field is:

• True, the problem was the result of a design flaw or standard operating practices.
• False, the problem was the result of another cause.

Indicates whether the GE Digital APM system should refresh the cost calculation for the Primary Event.

When you save the Primary Event, if the value in this field is:

• True, the GE Digital APM system will update the value in the Capacity Incident Cost field and then save the new value, along with any other changes that you made the Primary Event.
• False, the GE Digital APM system will save any changes that you made to the Primary Event but will not update the value in the Capacity Incident Cost field.

This field exists in the Primary Event family but not the Contributing Event family.

Identifies the month for which the data in the Primary Event should be reported.

This field is disabled and populated automatically with the month indicated by the value in the Event Start Date field.

This field exists in the Primary Event family but not the Contributing Event family.

Identifies the year for which the data in the Primary Event should be reported.

This field is disabled and populated automatically with the year indicated by the value in the Event Start Date field.

This field exists in the Primary Event family but not the Contributing Event family.

Identifies the revision number of the Event and should be incremented each time you re-submit a report which includes information in the Event to a Regulatory Organization.

By default, for an Event submitted to the regulatory organization for the first time, the value in this field is set to 0.

You must increase the value in this field each time you submit a report to the Regulatory Organization.

Indicates whether the value in the Event Start Date field is an estimate.

Select this check box when the value in the Event Start Date field represents an estimate of when the event ended or will end.

Clear this check box if the value in the Event Start Date field represents the actual time that the event ended.

This field exists in the Primary Event family but not the Contributing Event family.

Indicates how the unit was shut down during the event.

This field contains no value by default, and a baseline rule exists to populate this field with a list of the following values:

• A - Automatic: The unit shut down automatically.
• M - Manual: The unit was shut down manual by an operator.

After you select a value in this field and save the Event record, you will not be able to clear the field.

This field is available in the Additional Reporting section for a Primary Event.

Identifies the Unit ID of the GAA Unit record with which the Event is associated.

• For a Primary Event, a baseline rule exists to populate this field with a list of values from the Unit ID and Unit Name fields in all GAA Unit records that you have permission to modify using the formula Unit ID (Unit Name).

  This field is required when the Primary Event is in the Unit Approved state.

• For a Contributing Event, this field is disabled and populated automatically with the value in the Unit ID field in the Primary Event for which the Contributing Event exists.

Identifies the name of the unit to which the event occurred.

Indicates whether the GE Digital APM system will validate the record against all other existing Primary Events.

When you save the Primary Event, if the value in this field is:

• True, the GE Digital APM system will check all other Primary Events to validate any sequential event pairs of which the Primary Event is a part, update the value in the Incident Validation Status field if necessary, and then save the Primary Event to the database.
• False, the GE Digital APM system will save any changes that you made to the record, but will not validate the Primary Event against any other Primary Events.

This field exists in the Primary Event family but not the Contributing Event family.

Describes the event.

This field can be used to store any information about the event that is not captured in the other fields in the Event record.

When you create a Primary Event, you can enter a verbal description of up to 255 characters. When you generate a NERC Event Report, the verbal description in the generated report will display only the first 84 characters of the description that you entered in the Verbal Description field.

This field is required when the Primary Event is in Unit Approved state.

Indicates the duration of the work that was completed as a result of the event.

This field is disabled and populated automatically using the following formula:

Work Started + Work Ended

Indicates the date and time when work on the unit ended as a result of the event.

If you enter an ambiguous date and time in this field, a message will appear and the Ambiguous Date and Time Preference field will be enabled and required.

This value is included in NERC event reports.

Indicates the date and time when work on the unit started as a result of the event.

If you enter an ambiguous date and time in this field, a message will appear and the Ambiguous Date and Time Preference field will be enabled and required.

This value is included in NERC event reports.

Indicates the CEA Amplification Code for the selected Unit type.

This field is populated using the following format:

<AmplificationCode>(<Description>)

Where,

• <Description> is the value in the Description field in the Amplification Code record, which has Regulatory Organization field set to Canadian Electricity Association (CEA).
• <AmplificationCode> is the value in the Amplification Code field in the Amplification Code record, which has Regulatory Organization field set to Canadian Electricity Association (CEA).

You can select a value from the available CEA Amplification Codes for the selected Unit Type.

The available values appear in this field only after you select a value in the CEA Unit Type field.

Indicates the CEA Outage Code for the selected Unit type.

This field is populated using the following format:

<Code> ~ <Code Description>

Where,

• <Code> is the value in the Code field in the Cause Code record.
• <Code description> is the value in the Code Description field in the Cause Code record.

You can select value (s) from the available CEA Outage Codes for the selected Unit Type.

The available values appear in this field only after you select a value in the CEA Unit Type field.

This field is required.

Indicates the type of Unit available for CEA.

You can select a type of Unit from the list of available options.

This field is required.

This field is populated using the following format:

<AmplificationCode>(<Description>)

Where,

• <Description> is the value in the Description field in the Amplification Code record, which has Regulatory Organization field set to North American Electric Reliability Corporation (NERC).
• <AmplificationCode> is the value in the Amplification Code field in the Amplification Code record, which has Regulatory Organization field set to North American Electric Reliability Corporation (NERC).

You can select a value from the available NERC Amplification Codes for the selected Unit Type.

Indicates the NERC Cause Code for the selected Unit type.

This field is populated using the following format:

<Code> ~ <Code Description>

Where,

• <Code> is the value in the Code field in the Cause Code record, which has Regulatory Organization field set to North American Electric Reliability Corporation (NERC).
• <Code description> is the value in the Code Description field in the Cause Code record, which has Regulatory Organization field set to North American Electric Reliability Corporation (NERC).

You can a select value from the available NERC Cause Code for the selected Unit Type.

This field is required.

This field appears in the Identification section.

You can enter a value in this field.

This field appears in the Identification section.

You can enter a value in this field.

This field appears in the Identification section. It is required.

You can select a Functional Location to associate with the Company.

This field appears in the Identification section.

You can enter a value in this field.

This field appears in the Identification section.

You can enter a value in this field.

This field appears in the References section.

You can enter a value in this field.

This field appears in the References section.

You can enter a value in this field.

This field appears in the Identification section. It is required.

You can enter a value in this field.

This field appears in the Identification section. It is required.

You can enter a value in this field.

This field appears in the References section.

You can enter a value in this field.

This field appears in the Identification section.

You can enter a value in this field.

This field appears in the Identification section. It is populated by the MI_GM_POWER_REGION System Code Table.

This field appears in the Identification section.

You can enter a value in this field.

This field is populated by the MI_GAA_MODULE_TYPE System Code Table and it is automatically populated with the value Power.

This field does not appear in the datasheet.

This field appears in the Identification section.

You can enter a value in this field.

This field appears in the Identification section.

You can enter a value in this field.

This field appears in the Identification section.

You can enter a value in this field.

This field appears in the Identification section. It is populated by a baseline rule with the following values:

• Canadian Electricity Association (CEA)
• North American Electric Reliability Corporation (NERC)

This field is required and automatically populated with the value North American Electric Reliability Corporation (NERC).

This field appears in the Identification section.

You can enter a value in this field.

The Primary Utility Code for NERC must be three characters whereas that for CEA must be two characters.

This field appears in the Identification section. It is populated by a baseline rule with the following values:

• Canadian Electricity Association (CEA)
• North American Electric Reliability Corporation (NERC)

If the value in the Primary Regulatory Organization field is North American Electric Reliability Corporation (NERC), this field is disabled.

If the value in the Primary Regulatory Organization field is Canadian Electricity Association (CEA), the value in this field is North American Electric Reliability Corporation (NERC) and the field is disabled.

This field appears in the Identification section.

You can enter a value in this field.

The Secondary Utility Code for NERC must be three characters whereas that for CEA must be two characters.

This field appears in the Identification section. It is populated by the MI_GM_STATE System Code Table.

This field appears in the Identification section.

You can enter a value in this field.

A baseline rule exists to populate this field with a list of values based on your selection of Regulatory Organization.

A baseline rule exists to assign a hexadecimal color code for each of the Event Categories.

When you add a new Event Category, by default, the hexadecimal color code (#000000) corresponding to black color is specified in this field.

• You can enter the hexadecimal color code corresponding to a desired color manually.

  -Or-

• You can save the record with the default value, and then in the Color Code column, select the desired color from the grid.

The value in this field will be used to identify color code to be used for the Event Category in the graphs in GAA Overview page and in GAA Unit Summary page.

A baseline rule exists to populate this field based on your selection of Event Category Code and Regulatory Organization.

<Event Category Code>~<Regulatory Organization>

Where, each of the variable represents the value in the corresponding field in this record.

This field does not appear on the datasheet.

You can enter a value manually.

This field is required.

A baseline rule exists to populate this field based on your selection in the Regulatory Organization.

If you selected North American Electric Reliability Corporation (NERC) in the Regulatory Organization field, this field is disabled.

If you selected Canadian Electricity Association (CEA) in the Regulatory Organization field:

• Value corresponding to NERC is populated.
• This field is required.

A baseline rule exists to populate this field with a list of the following values:

• Canadian Electricity Association (CEA)
• North American Electric Reliability Corporation (NERC)

This field is required.

A value is required. This field appears as a list that is populated by values in the Event Type Code field in each GAA Event Type record.

The value in this field is used to populate the Capacity Event Type field in the related event based on the value in the Capacity Event Type, Cause Code, and Net Derate Amount fields in the parent event.

Color Code

Character

Identifies the color code for the Event Type.

A baseline rule exists to assign a hexadecimal color code for each of the Event Type.

When you add a new Event Type, by default, the hexadecimal color code (#000000) corresponding to black color is specified in this field.

• You can enter the hexadecimal color code corresponding to a desired color manually.

  -Or-

• You can save the record with the default value, and then in the Color Code column, select the desired color from the grid.

The value in this field will be used to identify color code to be used for the Event Type in the graphs in GAA Overview page and in GAA Unit Summary page.

Event Type Code

Character

Identifies the event type.

You can enter a value manually.

This field, along with the Event Type Description field, populates the Capacity Event Type field in the Primary Event records.

This field is required.

Event Type Description

Character

Describes the type of event.

You can enter a value manually.

This field, along with the Event Type Code field, populates the Capacity Event Type field in Event records.

This field is required.

This list of available values in this field are populated only if you select a value in the Regulatory Organization field.

For an existing Primary Event, you must not exclude Unit Type for the associated GAA Unit. If you do so, the Capacity Event Type field in the Event record will be cleared.

Is Extension

Logical

Indicates whether the Event Type is an extension event.

If this field is selected, it indicates that the Event Type is an extension of another event.

If the field is cleared, it indicates that the Event Type is not an extension event.

Indicates the Cause Codes mapped to Regulatory Organization.

A baseline rule exists to populate this field based on your selection in the Regulatory Organization.

If you selected North American Electric Reliability Corporation (NERC) in the Regulatory Organization field, this field is disabled.

If you selected Canadian Electricity Association (CEA) in the Regulatory Organization field:

• Value corresponding to NERC is populated.
• This field is required.

Regulatory Organization

Character

Identifies the council to which the data will be reported.

A baseline rule exists to populate this field with a list of the following values:

• Canadian Electricity Association (CEA)
• North American Electric Reliability Corporation (NERC)

This field is required.

State Code

Character

Indicates the state of the GAA Unit during the Event.

This field is used by a GAA Unit that reports to CEA.

You can enter a value manually.

Unit State

Character

Indicates the state of the GAA Unit.

A baseline rule exists to populate this field based on your selection in the Regulatory Organization.

This field is required.

You can enter a value manually.

This value is defined by the Regulatory Organization.

This field is required.

You can enter a value manually.

This value is defined by the Regulatory Organization.

This field is required.

You can enter a value manually.

This value is defined by the Regulatory Organization.

You can enter a value manually.

This value is defined by the Regulatory Organization.

Indicates the mapped Fuel Code and Fuel Description based on the Regulatory Organization.

A baseline rule exists to populate this field with a list of the values using the following format:

<RegulatoryOrganization> ~ <FuelCode> ~ <FuelDescription>

Where,

• <RegulatoryOrganization> is the value in the Regulatory Organization field.
• <FuelCode> is the value in the Fuel Code field.
• <FuelDescription> is the value in the Fuel Description field.

If you selected North American Electric Reliability Corporation (NERC) in the Regulatory Organization field, this field is disabled.

If you selected Canadian Electricity Association (CEA) in the Regulatory Organization field:

• Value corresponding to NERC is populated.
• This field is required.

A baseline rule exists to populate this field with a list of the following values:

• Canadian Electricity Association (CEA)
• North American Electric Reliability Corporation (NERC)

This field is required.

This field is enabled when the value in Record Type field is Performance, and the Is Report field is cleared.

This field is required.

This field is populated using the following format:

<Record Name> ~ <Record Type> ~ <Report Format> ~ <Performance Type>

Where, each of the variable represents the value in the corresponding field in this record.

This field does not appear on the datasheet.

This field is selected if the report is associated with the GAA Unit.

This field does not appear on the datasheet.

This field is selected by default.

If you clear this check box, and the value in the Record Type field is Performance then the Report Format and Report Query fields are disabled and the following fields are enabled:

• Policy ID
• Associated Events Catalog Path
• Performance Type
• Weightage Type

Indicates whether the Performance record will contain all Primary Events including OMC Events or not.

This field is enabled when the value in Record Type field is Performance, and the Is Report field is cleared.

You can select one of the following options:

• AllEvents: Select this option if you want to configure the Performance record to contain all Primary Events including OMC
• Excluding OMC: Select this option if you want to configure the Performance record to contain all Primary Events excluding OMC

This field is enabled when the value in Record Type field is Performance, and the Is Report field is cleared.

This field is required.

This field is enabled only when the Is Report field is selected.

A baseline rule exists to populate this field with a list of the following values based on the type of report that you selected in the Report Type field:

• If Report Type is Event, you can select 07 in this field.
• If Report Type is Performance, you can select 05 in this field.

This field is required.

You can enter a value manually.

This field is required.

A baseline rule exists to populate this field with a list of the following values:

• Event
• Performance

This field is required.

This field is enabled only when the Is Report field is selected.

A baseline rule exists to populate this field with a list of queries that exist in the Catalog folder \\Public\Meridium\Modules\Generation Management\Queries\NERC Queries. You must select the query that corresponds to the value you selected in the Report Format field.

This field is required.

This field is enabled when the value in Record Type field is Performance, and the Is Report field is cleared.

You can select multiple capacity types simultaneously from the following options:

• NMC
• GMC

This field is required.

You can enter a value manually.

You can enter a value manually.

This field is populated automatically with the value in the Primary Fuel Code or Secondary Fuel Code field in the GAA Unit record. Based on the Regulatory Organization to which the data will be reported, the GAA Unit record is linked to the Performance record.

This field is required.

You can select a value from the drop-down list.

For NERC, this field is enabled only if the value in the Fuel Code field indicates coal, peat, or lignite as the fuel.

This field is enabled only if the value in the Fuel Code field indicates coal, peat, or lignite as the fuel.

This field is enabled only if the value in the Fuel Code field indicates coal, peat, or lignite as the fuel.

This field is enabled only if the value in the Fuel Code field indicates coal, peat, or lignite as the fuel.

This field is enabled only if the value in the Fuel Code field indicates coal, peat, or lignite as the fuel.

The value in this field is used to calculate the value in the Energy Source Consumption field in GAA Fuel Report records that are linked to the Performance record.

Indicates the energy that was produced by a Generating Unit in a given period as a fraction of the Maximum Generation.

Maximum Generation is the period hours (PH) times the Maximum Capacity.

This field is disabled and populated automatically using the following formula:

[Actual Generation / (Period Hours X Maximum Capacity)] X 100%

Indicates the amount of capacity lost (in Mega Watt hours) when the unit cannot reach its full capacity due to Unplanned Derating (D1).

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Equivalent Unplanned Derated hours (D1)

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Equivalent Unplanned Derated hours (D2)

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Equivalent Unplanned Derated hours (D3)

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Equivalent Unplanned Derated hours (D4)

This field is disabled and populated automatically using the following formula:

[(Available Hours - Equivalent Planned Derated Hours – Equivalent Unplanned Derated Hours - Equivalent Seasonal Derated Hours) / Period Hours] X 100%

This field is disabled and populated automatically using the following formula:

(Derating Hours x Size of Reduction) / NMC

Where,

Derating Hours are the sum of individual Forced Derating hours (D1, D2, D3) or the portion of any Forced derating hours which occurred during a Reserve Shutdown (RS).

Size of Reduction is calculated by subtracting the Net Available Capacity (NAC) from the Net Dependable Capacity (NDC). For multiple deratings, the Size of Reduction of each derating will be calculated by the difference in the Net Available Capacity of the unit before the derating and the reported Net Available Capacity after the derating.

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

[(Forced Outage Hours + Equivalent Forced Derated Hours) / Period Hours] X 100 %

This field is disabled and populated automatically using the following formula:

[(Forced Outage Hours + Equivalent Forced Derated Hours) / (Forced Outage Hours + Service Hours + Synchronous Hours + Pumping Hours + Equivalent Forced Derated Hours During Reserve Shutdown)] X 100 %

This field is disabled and populated automatically using the following formula:

[(Forced Outage Hours Demand + Equivalent Forced Derated Hours Demand) / (Service Hours + Forced Outage Hours Demand)] X 100 %

This field is disabled and populated automatically using the following formula:

(Derating Hours x Size of Reduction) / NMC

Where,

Derating Hours are the sum of individual Maintenance Derating hours (D4, DM).

Size of Reduction is calculated by subtracting the Net Available Capacity (NAC) from the Net Dependable Capacity (NDC). For multiple deratings, the Size of Reduction of each derating will be calculated by the difference in the Net Available Capacity of the unit before the derating and the reported Net Available Capacity after the derating.

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

(Derating Hours x Size of Reduction) / NMC

Where,

Derating Hours are the sum of individual Maintenance Derating hours (D4) or the portion of any Maintenance derating hours which occurred during a Reserve Shutdown (RS).

Size of Reduction is calculated by subtracting the Net Available Capacity (NAC) from the Net Dependable Capacity (NDC). For multiple deratings, the Size of Reduction of each derating will be calculated by the difference in the Net Available Capacity of the unit before the derating and the reported Net Available Capacity after the derating.

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

[(Maintenance Outage Hours + Equivalent Maintenance Derated Hours) / Period Hours] X 100 %

This field is disabled and populated automatically using the following formula:

[(Maintenance Outage Hours + Equivalent Maintenance Derated Hours) / ∑ (Maintenance Outage Hours + Service Hours + Synchronous Hours + Pumping Hours + Equivalent Maintenance Derated Hours During Reserve Shutdowns)] X 100%

Indicates the amount of capacity lost (in Mega Watt hours) when the unit cannot reach its full capacity due to Planned Deratings (PD, DP). Each individual Planned Derating is transformed into equivalent full outage hour(s).

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Equipment Planned Derate hours

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

(Derating Hours x Size of Reduction) / NMC

Where,

Derating Hours are the sum of individual Planned Derating (PD) or the portion of any Planned derating which occurred during a Reserve Shutdown (RS).

Size of Reduction is calculated by subtracting the Net Available Capacity (NAC) from the Net Dependable Capacity (NDC). For multiple deratings, the Size of Reduction of each derating will be calculated by the difference in the Net Available Capacity of the unit before the derating and the reported Net Available Capacity after the derating.

This value is defined by NERC in the GADS DRI.

Indicates the amount of capacity lost (in Mega Watt hours) when the unit cannot reach its full capacity due to Planned Deratings (PD, DP). Each individual Planned Derating is transformed into equivalent full outage hour(s).

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Equipment Planned Derate hours

This field is disabled and populated automatically using the following formula:

[(Planned Outage Hours + Equivalent Planned Derated Hours) / Period Hours] X 100 %

This field is disabled and populated automatically using the following formula:

[(Planned Outage Hours + Equivalent Planned Derated Hours) / (Planned Outage Hours + Service Hours + Synchronous Hours + Pumping Hours + Equivalent Planned Derated Hours During Reserve Shutdowns)] X 100%

This field is disabled and populated automatically using the following formula:

(Derating Hours x Size of Reduction) / NMC

Where,

Derating Hours are the sum of individual Planned Derating hours (PD, DP) and Maintenance Derating hours (D4, DM).

Size of Reduction is calculated by subtracting the Net Available Capacity (NAC) from the Net Dependable Capacity (NDC). For multiple deratings, the Size of Reduction of each derating will be calculated by the difference in the Net Available Capacity of the unit before the derating and the reported Net Available Capacity after the derating.

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using one of the following formula:

[(Scheduled Outage Hours + Equivalent Scheduled Derated Hours) / Period Hours] X 100 %

This field is disabled and populated automatically using the following formula:

(Net Maximum Capacity (NMC) - Net Dependable Capacity (NDC) x Available Hours (AH)) / Net Maximum Capacity (NMC).

((NMC - NDC) x AH) / NMC

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

(Derating Hours x Size of Reduction) / NMC

Where,

Derating Hours are the sum of individual Unplanned Derating hours (D1, D2, D3, D4, DM) and Unplanned Deratings (D1, D2, D3, D4, DM) during Reserve Shutdowns (RS).

Size of Reduction is calculated by subtracting the Net Available Capacity (NAC) from the Net Dependable Capacity (NDC). For multiple deratings, the Size of Reduction of each derating will be calculated by the difference in the Net Available Capacity of the unit before the derating and the reported Net Available Capacity after the derating.

This field is disabled and populated automatically using the following formula:

[(Unplanned Outage Hours + Planned Outage Hours + Equivalent Unplanned Derated Hours + Equivalent Planned Derated Hours) / Period Hours] X 100%

This field is disabled and populated automatically using one of the following formula:

[(Unplanned Outage Hours + Equivalent Unplanned Derated Hours) / Period Hours] X 100%

This field is disabled and populated automatically using the following formula:

[(Unplanned Outage Hours + Equivalent Unplanned Derated Hours) / Unplanned Outage Hours + Service Hours + Synchronous Hours + Pumping Hours + Equivalent Unplanned Derated Hours During Reserve Shutdowns)] X 100%

Indicates the amount of capacity lost (in Mega Watt hours) when the unit cannot reach its full capacity due to extension of a Maintenance Derating beyond its estimated completion date.

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Extended Maintenance Equivalent hours

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Extended Planned Derate Equivalent hours

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Forced Outage hours

Indicates the amount of capacity lost (in Mega Watt hours) when the unit was inactive due to Maintenance Outages (MO) and Maintenance Outage Extensions (ME) of any Maintenance Outages (MO). This also includes the extension of a Maintenance Outage beyond its estimated completion date.

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Maintenance and Extended Outage hours

Indicates the amount of capacity lost (in Mega Watt hours) when the unit was inactive due to maintenance outages. This includes all the hours experienced during Maintenance Outages (MO).

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Maintenance Outage hours

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Maintenance Outage Scheduled Extension hours

Indicates the amount of capacity lost (in Mega Watt hours) when the unit was inactive due to removal of an equipment or a major component from service for maintenance, testing, or other purposes that did not result in a unit outage or derating.

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Number of Non Curtailing Events

This field is disabled and populated automatically using the following formula:

[Actual Generation / (Service Hours X Maximum Capacity)] X 100 %

If you selected Net Maximum Capacity (NMC) in the weightage type in the GAA Unit record, the value in this field will based on the net values.

If you selected Gross Maximum Capacity (GMC) in the weightage type in the GAA Unit record, the value in this field will based on the gross values.

Planned and Extension Outage MWH

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Planned and Extension Outage hours

Indicates the amount of capacity lost (in Mega Watt hours) when the unit was inactive due to planned outages. This includes all the hours experienced during Planned Outages (PO).

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Planned Outage hours

Planned Outage Scheduled Extension MWH

Indicates the amount of capacity lost (in Mega Watt hours) when the unit was inactive due to extension of a Planned Outage beyond its estimated completion date.

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Planned Outage Scheduled Extension hours

Indicates the amount of capacity lost (in Mega Watt hours) when the unit was available, but was not in service.

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Reserve Shutdown hours

This field is disabled and populated automatically using the following formula:

(Equivalent Seasonal Derated Hours / Period Hours) X 100%

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Startup Failure hours

Indicates the amount of capacity lost (in Mega Watt hours) when the unit will be inactive when the unit cannot reach its full capacity due to any of the derates.

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x Total Equivalent Derate hours

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x U1 Unplanned Outage hours

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x U2 Unplanned Outage hours

This field is disabled and populated automatically using the following formula:

Net Maximum Capacity x U3 Unplanned Outage hours

This field is disabled and populated automatically using the following formula:

[(Equivalent Planned Derated Hours + Equivalent Unplanned Derated Hours) / Period Hours] X 100%

This field is disabled and is populated automatically when the value in the Reporting Status field is set to Unit Level Approval, validation is performed on this field to ensure that the value is equal to the number of Attempted Unit Starts minus the number of Startup Failures.

This field is required.

This field is disabled and is populated automatically when the value in the Reporting Status field is set to Unit Level Approval, validation is performed on this field to ensure that the value is equal to the number of outage events that occurred within the month that the Performance record represents.

This field is required.

Indicates the total number of hours in which the unit was available.

This field is disabled and populated automatically as the sum of Pumping Hours, Reserve Shutdown Hours (RSH), Service Hours (SH), and Synchronous Condensing Hours.

This field is required.

This value is defined by NERC in the GADS DRI and included in NERC performance reports.

This field is disabled and populated automatically using the following formula:

(Available Hours / Period Hours) × 100%

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

(Service Hours / Actual Unit Starts ) × 100%

This value is defined by NERC in the GADS DRI.

Extension of Scheduled Outage Hours

Indicates the number of hours that the unit was scheduled to be inactive.

This field is disabled and populated automatically as the sum of Planned Extension Outage Hours and Maintenance Extension Outage Hours.

This field is required.

This field is disabled and populated automatically as the sum of all hours experienced during Forced Outages (U1, U2, U3) and Startup Failures (SF).

This field is required.

This field is disabled and populated automatically using the following formula:

(Forced Outage Hours / Period Hours) × 100%

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

[Forced Outage Hours / ∑ (Service Hours + Synchronous Hours + Pumping Hours)] × 100%

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

[Forced Outage Hours Demand / (Σ Forced Outage Hours Demand + Service Hours)] × 100%

This value is defined by NERC in the GADS DRI.

Indicates the actual gross generation of the unit during the month for which the Performance record stores generation data.

This field is disabled and populated automatically using the following formula:

Gross Actual Generation = Max Generation (G) - Unavailable Generation

Where,

• Max Generation (G) = Period Hours × Gross Max Capacity
• Unavailable Generation = ∑(All Outage hours + All Equivalent Derate hours + All Reserve Shutdown hours) × Gross Max Capacity

This field is used to calculate the value in the Gross Generation of Electricity field in the GAA Fuel Report records that are linked to the Performance record.

This field accepts both positive and negative numbers. In some cases, if a unit does not produce power during the month, the equipment in the plant still consumes power, causing a negative Gross Actual Generation value.

This field becomes required when the value in the Reporting Status field is set to Unit Level Approval.

This value is defined by NERC in the GADS DRI and included in NERC performance reports.

This field is populated automatically with the value in the Gross Dependable Capacity field in the Unit Capacity record for a GAA Unit based on the start date of the Performance record.

This value is defined by NERC in the GADS DRI and included in NERC performance reports.

If you modify the value in this field, a validation message appears indicating that the pumping hours or capacity values have changed and that the performance calculation is being run.

This field is populated automatically with the value in the Gross Maximum Capacity field in the Unit Capacity record for a GAA Unit based on the start date of the Performance record.

This value is defined by NERC in the GADS DRI and included in NERC performance reports.

If you modify the value in this field, a validation message appears indicating that the pumping hours or capacity values have changed and that the performance calculation is being run.

Indicates the number of hours the unit was inactive during the month for which the Performance record stores generation data.

This field is disabled and populated automatically with the value from the Event Duration field in the Primary Event record that is linked to the Performance record.

This field is populated automatically as the sum of durations of Inactive events (IR, MB, RU).

This field is required.

This value is defined by NERC in the GADS DR.

Indicates the number of hours the unit was inactive due to maintenance outages.

This field is disabled and populated automatically as the sum of all hours that occurred during Maintenance Outages (MO) and Maintenance Outage Extensions (ME) of any Maintenance Outages (MO).

This field is required.

This field is disabled and populated automatically using the following formula:

(Maintenance Outage Hours / Period Hours) × 100%

This value is defined by NERC in the GADS DRI.

Indicates the maximum gross generation that the unit is capable of producing during the month for which the Performance record stores generation data.

This field is disabled and populated automatically using the following formula:

Max Generation (G) = Period Hours × Gross Max Capacity

Indicates the maximum net generation that the unit is capable of producing during the month for which the Performance record stores generation data.

This field is disabled and populated automatically using the following formula:

Max Generation (N) = Period Hours × Net Max Capacity

This field is disabled and populated automatically using the following formula:

Forced Outage Hours which occur from in-service state only / Number of Forced Outages which occur from in-service state only

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

Forced Outage Hours which occur from in-service state only / Number of Maintenance Outages which occur from in-service state only

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

Planned Outage Hours which occur from in-service state only / Number of Planned Outages which occur from in-service state only

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

Service Hours / Number of (Unplanned) Forced Outages which occur from in-service state only

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

Service Hours / Number of Maintenance Outages which occur from in-service state only

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

Service Hours / Number of Planned Outages which occur from in-service state only

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

Service Hours / Number of Unplanned Outages which occur from in-service state only

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

Unplanned Outage Hours which occur from in-service state only / Number of Unplanned Outages which occur from in-service state only

This value is defined by NERC in the GADS DRI.

Indicates the actual net generation of the unit during the month for which the Performance record stores generation data.

This field is disabled and populated automatically using the following formula:

Net Actual Generation = Max Generation (N) - Unavailable Generation

Where,

• Max Generation (N) = Period Hours × Net Max Capacity
• Unavailable Generation = ∑(All Outage hours + All Equivalent Derate hours + All Reserve Shutdown hours) × Net Max Capacity

This field is used to calculate the value in the Net Generation of Electricity field in the Generation Fuel Report records that are linked to the Performance record.

This field accepts both positive and negative numbers. In some cases, if a unit does not produce power during the month, the equipment in the plant still consumes power, causing a negative Net Actual Generation value.

This field becomes required when the value in the Reporting Status field is set to Unit Level Approval.

This value is defined by NERC in the GADS DRI and included in NERC performance reports.

Indicates the net dependable capacity of the unit.

This field is populated automatically with the value in the Net Dependable Capacity field in the Unit Capacity record for a GAA Unit based on the start date of the Performance record.

This field is required.

This value is defined by NERC in the GADS DRI and included in NERC performance reports.

If you modify the value in this field, a validation message appears indicating that the pumping hours or capacity values have changed and that the performance calculation is being run.

This field is populated automatically with the value in the Net Maximum Capacity field in the Unit Capacity record for a GAA Unit based on the start date of the Performance record.

This field is required.

This value is defined by NERC in the GADS DRI and included in NERC performance reports.

If you modify the value in this field, a validation message appears indicating that the pumping hours or capacity values have changed and that the performance calculation is being run.

Number of Non Curtailing Events

Indicates the number of Non Curtailing events that occur in a Unit during the specified month.

This field is disabled and populated automatically when each time an Event occurs with value in the Capacity Event Type field specified as NC (Noncurtailing Event), this field is incremented by 1.

This field is disabled and populated automatically. The value in this field is equal to the sum of the values in the Available Hours field and Unavailable Hrs field.

This field is required.

Indicates the number of hours the unit was inactive due to planned outages.

This field is disabled and populated automatically as the sum of all hours experienced during Planned Outages (PO) and Planned Outage Extensions (PE) of any Planned Outages (PO).

This field is required.

This field is disabled and populated automatically using the following formula:

(Planned Outage Hours / Period Hours ) × 100%

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically with the value in the Primary Unit Code field in the GAA Unit record that is linked to a Performance record.

This field is required.

This value is defined by NERC in the GADS DRI and included in NERC performance reports.

This field is disabled and populated automatically with the value in the Primary Utility Code field in the GAA Unit record.

This field is required.

This value is defined by NERC in the GADS DRI and included in NERC performance reports.

This field is enabled in Performance records that contain the value Pumped Storage/Hydro in the Unit Type field. You can enter a value in this field manually.

This field is required.

This value is defined by NERC in the GADS DRI.

If you modify the value in this field, a validation message appears indicating that the pumping hours or capacity values have changed and that the performance calculation is being run.

This field is populated automatically with the date when the record was created.

This field is disabled when the Performance record is in the Approved state.

This field is required.

The combination of the value in this field and the Reporting Year field represents a unique year and month combination. You can create only one record with this combination for a particular type of Performance.

This field is disabled and populated automatically with the month when the record was created.

This value is included in NERC performance reports.

Indicates the year that the Performance record represents.

The combination of the value in this field and the Reporting Month field represents a unique year and month combination. You can create only one record with this combination for a particular type of Performance.

This field is disabled and populated automatically with the year of the created record.

This value is included in NERC performance reports.

This field is disabled and populated automatically as the sum of all hours the unit was not in service.

This field is required.

You must increment this number each time you resubmit a report which includes information in the Performance record to NERC or CEA.

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically with the sum of all hours experienced during Planned Outages (PO), Maintenance Outages (MO), and Scheduled Outage Extensions (PE and ME) of any Maintenance Outages (MO) and Planned Outages (PO).

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

(Scheduled Outage Hours / Period Hours) × 100%

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

(Service Hours / Period Hours) × 100%

This value is defined by NERC in the GADS DRI.

Indicates the starting reliability of the unit.

This field is disabled and populated automatically using the following formula:

(Actual Unit Starts / Attempted Unit Starts)*100

Indicates the number of hours the unit operated in synchronous condensing mode.

This field is disabled and populated as the sum of durations of Non-Curtailing events when cause code of the event is 9340 Synchronous Condenser Operation.

This value is defined by NERC in the GADS DRI.

Typical Unit Loading Characteristics

This field is populated automatically with the value in the Default Unit Loading field in the GAA Unit record to which the Performance record is linked.

This value is defined by NERC in the GADS DRI.

Indicates the number of hours that the unit was unavailable.

This field is disabled and populated automatically as the sum of the Forced Outage Hours (FOH), Maintenance Outage Hours (MOH), and Planned Outage Hours (POH).

This value is included in NERC performance reports.

This field is disabled and populated automatically using the following formula:

(Unavailable Hours / Period Hours) × 100%

This value is defined by NERC in the GADS DRI.

This field is disabled and populated automatically using the following formula:

(Unplanned Outage Hours / Period Hours ) × 100%

This value is defined by NERC in the GADS DRI.

You can manually enter the description in this field.

When you create a Performance record, you can enter a verbal description of up to 255 characters. When you generate a NERC Performance Report, the verbal description in the generated report will display only the first 50 characters of the description that you entered in the Verbal Description field.

You can enter a value manually. We recommend that you use the address that is on file with the Regulatory Organization.

This field is available in the Plant section.

You can enter a value manually. We recommend that you use the address that is on file with the Regulatory Organization.

This field is available in the Plant section.

A baseline rule exists to populate this field with a list of each unique value that exists in the Area field in all other GAA Plants.

You can enter a value manually.

When you enter a value in the Area field for one GAA Plant, the value will be available in the Area drop-down for next plant.

This field is available in the Plant section.

You can select a Functional Location to associate with the GAA Plant.

This field is required.

You can enter a value manually. We recommend that you use the city associated with the address that is on file with the Regulatory Organization.

This field is available in the Plant section.

When a GAA Plant is created, this field is populated automatically with the value in the Company ID field in the GAA Company to which the GAA Plant is linked.

This field is available in the Plant section.

When a GAA Plant is created, this field is populated automatically with the value in the Company Name field in the GAA Company to which the GAA Plant is linked.

This field is available in the Plant section.

You can enter a value manually. We recommend that you use the country associated with the address that is on file with the Regulatory Organization.

This field is available in the Plant section.

You can enter a value manually. After you enter a value in the Organization field for one GAA Plant, the Organization value will be available in the drop-down list for the next plant. Therefore, when you create a new plant, you can either enter a new value or select the Organization value for an existing plant in the list.

This field is available in the Plant section.

This field is required for all GAA Plants.

This field is available in the Plant section.

This is a character field that is required for all GAA Plants. This value is defined by the Regulatory Organization.

This field is available in the Plant section.

You can enter a value manually.

This field is required.

A baseline rule exists to populate this field based on your selection in the Primary Regulatory Body field in the GAA Company recorda dn is disabled.

This field is available in the Plant section.

This field is required only if the Primary Regulatory Organization is CEA and is disabled.

The Plant family inherits Secondary Regulatory Body field from the Company.

This field is available in the Plant section.

A baseline rule exists to populate this field with a list of System Codes in the MI_GM_STATE System Code Table. We recommend that you use the state associated with the address that is on file with the Regulatory Organization.

This field is available in the Plant section.

By default, this field is set to Eastern Standard Time. You can select a time zone from the available list of time zones.

This field is available in the Plant section.

This field is required.

Indicates whether Daylight Saving Time should be used in records that are associated with the GAA Plant.

If the value in this field is:

• True, Daylight Saving Time will be adjusted automatically.
• False, Daylight Saving Time will not be adjusted automatically.

This field is available in the Plant section.

You can enter a value manually. We recommend that you use the zip code associated with the address that is on file with the Regulatory Organization.

This field is available in the Plant section.

You can enter a value manually.

This field is required.

This field is selected by default if the Regulatory Organization is North American Electric Reliability Corporation (NERC).

This field is selected by default if the Regulatory Organization is North American Electric Reliability Corporation (NERC).

Determines under what conditions APM Events will be created.

A baseline rule exists to populate this field with a list of the following values:

• All Primary Events
• MWH Loss Exceeds Reference
• Production Loss Exceeds Reference

This field is available on the Calculation Settings tab.

This field is enabled and required if the value in the APM Event Creation is MWH Loss Exceeds Reference or Production Loss Exceeds Reference.

This field is available on the Calculation Settings tab.

You can select a Functional Location to associate with the GAA Unit.

This field is required.

Identifies the generation block for the unit.

This field contains a list of all values in the Block Number field in all other GAA Units. Block number typically applies to combined-cycle or co-generation unit types.

In Primary Events and Contributing Events that are linked to a GAA Unit that has a value in the Block Number field, the following fields will contain the cause code values that are associated with the value in the Unit Type field of all GAA Units which contain the same value in the Block Number field.

• Cause Code System
• Cause Code Component
• Cause Code fields

This field is available on the References tab.

You can enter a value manually.

When you enter a value in the Block Number field for one GAA Unit, the value will be available in the Block Number drop-down for next unit.

If the value in this field is:

• True, it indicates that the GAA Unit is able to produce the required heating output.
• False, it indicates that the GAA Unit is not able to produce the required heating output.

This field is available on the Startup Summary tab.

If the value in this field is:

• True, it indicates that the GAA Unit can start immediately.
• False, it indicates that the GAA Unit cannot start immediately.

This field is available on the Startup Summary tab.

You can enter a value manually.

This field is available on the Startup Summary tab.

When a GAA Unit is first created, this field is disabled and populated automatically with the value in the Company ID field for the GAA Plant to which the GAA Unit is linked.

This field is available on the Unit tab.

When a GAA Unit is first created, this field is disabled and populated automatically with the value in the Company Name field in the GAA Plant to which the GAA Unit is linked.

This field is available on the Unit tab.

Indicates whether a Performance record will be created to exclude Primary Events and Contributing Events in which the value in the OMC Event field is True.

If the value in this field is:

• True, a Performance record will be created to exclude data for OMC events.
• False, a Performance record will NOT be created to exclude data for OMC events.

This field is available on the Calculation Settings tab.

A baseline rule exists to populate this field with a list of System Codes in the MI_GM_UNIT_LOADING System Code Table based on the value in the Primary Regulatory Body field in GAA Unit record.

This field is available on the Fuel Data tab.

This field is required. You should accept the default value, Event Order Number. You should not select Ranked Masking and All Additives.

This field is available on the Calculation Settings tab.

You can enter a value manually.

This field is available on the References tab.

Determines how the Potential Event Cost will be calculated in Primary Events that are linked to the GAA Unit.

A baseline rule exists to populate this field with a list of the following values:

• No Cost Calculation
• Reference Value
• Price Curve

This field is set to No Cost Calculation by default.

This field is available on the Calculation Settings tab and is disabled.

This field is enabled and required when the value in the Generation Cost Model field is set to Reference Value.

This field is available on the Calculation Settings tab.

You can enter a value manually.

This field is available on the Startup Summary tab.

Determines whether Primary Event or Performance records that are linked to the GAA Unit can be modified.

If the value in this field is:

• True, only a member of the MI GAA Administrator Security Group will be allowed to create Primary Event or Performance records to link to the GAA Unit or modify Primary Events or Performance records that are already linked to the GAA Unit.
• False, the ability to create and modify Primary Events and Performance records will be controlled by GAA role-based security.

This field is available on the Unit tab.

Indicates the minimum time for which the GAA Unit is shut down and is not producing power.

You can enter a value manually.

This field is available on the Startup Summary tab.

You can enter a value manually.

This field is available on the Startup Summary tab.

This field is available on the Unit tab.

Either this field or the Nameplate Net Maximum Capacity field must be populated in order to save a GAA Unit.

This field is available on the Unit tab.

This field is required.

This field is available on the Unit tab.

Either this field or the Nameplate Gross Maximum Capacity field must be populated in order to save a GAA Unit.

This field is available on the Unit tab.

This field is required.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

This field is available on the References tab.

This field is available on the Unit tab and is populated with the value 100(PCT) by default.

This field is available on the Unit tab and is populated with the value 100(PCT) by default.

This field is available on the Unit tab and is populated with the value 100(PCT) by default.

When a GAA Unit is created, this field is disabled and populated automatically with the value in the Plant ID field in the GAA Plant to which the GAA Unit is linked.

This field is available on the Unit tab.

When a GAA Unit is created, this field is disabled and populated automatically with the value in the Plant Name field in the GAA Plant to which the GAA Unit is linked.

This field is available on the Unit tab.

A baseline rule exists to populate this field with values in GAA Fuel Types records.

This field is required.

This field is available on the Fuel Data tab.

A baseline rule exists to populate this field based on your selection in the Primary Regulatory Organization field in the GAA Company record. You can, however, modify the value in this field.

If the value in this field is set to North American Electric Reliability Corporation (NERC), the Secondary Regulatory Organization field is disabled.

If the value in this field is set to Canadian Electricity Association (CEA) , the value in Secondary Regulatory Organization field is set to North American Electric Reliability Corporation (NERC) and the field is disabled.

This field is required.

This field is available on the Unit tab.

You can enter a value manually.

The Primary Unit Code for NERC must be three characters. The Primary Unit Code for CEA must be two characters.

This field is available on the References tab.

This is a required field.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

This field is required.

This field is available on the References tab.

A baseline rule exists to populate this field with values in GAA Fuel Types records.

This field is available on the Fuel Data tab.

You can enter a value manually.

This field is available on the Startup Summary tab.

A baseline rule exists to populate this field with a list of System Codes in the MI_GM_POWER_REGION System Code Table. This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

This field is required only if the Primary Regulatory Organization is NERC.

This field is available on the References tab.

A baseline rule exists to populate this field with a list of the following values: NERC, Internal, NERC and Internal, and Do Not Report.

This field is available on the References tab.

A baseline rule exists to populate this field with values in GAA Fuel Types records.

This field is available on the Fuel Data tab.

A baseline rule exists to populate this field based on your selection in the Secondary Regulatory Organization field in the GAA Company record. You can, however, modify the value in this field.

If the value in the Primary Regulatory Organization field is set to North American Electric Reliability Corporation (NERC), this field is disabled.

If the value in the Primary Regulatory Organization field is set to Canadian Electricity Association (CEA) , the value in this field is set to North American Electric Reliability Corporation (NERC) and the field is disabled.

This field is available on the Unit tab.

You can enter a value manually.

You must enter a value in this field if you have selected a value in the Secondary Regulatory Organization field.

The Secondary Unit Code for NERC must be three characters. The Primary Unit Code for CEA must be two characters.

This field is available in the References tab.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

If the value in the Primary Regulatory organization field is Canadian Electricity Association (CEA), then the Secondary Utility Code field is enabled and will be required.

This field is available on the References tab.

A baseline rule exists to populate this field with a list of the System Codes in the MI_GM_POWER_SUBREGION System Code Table that contain a System Code Reference to the System Code identified by the value in the Region field.

This value is defined by NERC in the GADS DRI and CEA in the Generation Equipment Status ERIS.

This field is required only if the Primary Regulatory Organization is NERC.

This field is available on the References tab.

A baseline rule exists to populate this field with values in GAA Fuel Types records.

This field is available on the Fuel Data tab.

Indicates the minimum time for which the unit is shut down to be classified for cold start.

You can enter a value manually.

This field is available on the Startup Summary tab.

You can enter a value manually.

This field is available on the Startup Summary tab.

You can enter a value manually.

This field is available on the Startup Summary tab.

Indicates the time in hours for a unit to start from hot.

You can enter a value manually.

This field is available on the Startup Summary tab.

The value in this field should not exceed 50 characters in length. While you can save a GAA Unit that contains more than 50 characters in this field, when you attempt to create a Primary Event for that unit, an error message will be displayed.

This field is required.

This field is available on the Unit tab.

This field is required.

This field is available on the Unit tab.

This field is available on the Operating Notes tab.

Indicates whether the unit represented by the GAA Unit is active.

A baseline rule exists to populate this field with a list of the values based on your selection in the Primary Regulatory Organization field.

If you selected North American Electric Reliability Corporation (NERC) in the Primary Regulatory Organization field, the following options appear in drop-down list box:

• Active (Active)

• Inactive (Inactive)

  If you select this value, make sure that the GAA Unit has at least one event which meets the following criteria:

  • Capacity Event Type field in the Event record is set to:
    • Reserve Shutdown when the Event Type is IR (Inactive Reserve)
    • Outage when the Event Type is MB (Mothballed)
    • Mothball
  • Duration of the Event is more than 60 days

If you selected Canadian Electricity Association (CEA) in the Primary Regulatory Organization field, the following options appear in drop-down list box:

• Not In Commercial Service (NICS)
• Commercial Service (CS)

This field is required.

This field is available on the Unit tab.

A baseline rule exists to populate this field based on your selection in the Primary Regulatory Organization field. The value in this field will be used in conjunction with the Nameplate Gross Maximum Capacity or Nameplate Net Maximum Capacity to calculate missing capacity values.

This field is required.

This field is available on the References tab.

This field is available on the Fuel Data tab.

If the value in the Generation Cost Model field is Price Curve, this field becomes required and the value will be used to associate Power Price Curves with the same Zone with events linked to the GAA Unit.

A baseline rule exists to populate this field with a list of System Codes in the MI_GM_POWER_PRICE_ZONE System Code Table.

This field is available on the Calculation Settings tab.

A baseline rule exists to populate this field with a list of the following values:

• Canadian Electricity Association (CEA)
• North American Electric Reliability Corporation (NERC)

This field is required.

Indicates the state of the GAA Unit.

Indicates the identification for the state represented by the GAA Unit.

Regulatory Organization

Character

Identifies the council to which data will be reported.

A baseline rule exists to populate this field with a list of the following values:

• Canadian Electricity Association (CEA)
• North American Electric Reliability Corporation (NERC)

This field is required.

Indicates the identification of the Unit Type associated with the GAA Unit.

Identifies the GAA Unit Capacity record.

This field is populated using the following format:

<UnitID> ~ <StartDate> ~ <EndDate>

Where,

• <UnitID> is the value in the Unit Id field in the GAA Unit record
• <StartDate> is the value in the Start Date field in the GAA Unit Capacity record
• <EndDate> is the value in the End Date field in the GAA Unit Capacity record

The value in Gross Dependable Capacity field must be less than the value in Gross Maximum Capacity field.

You must provide a value in this field or the Net Maximum Capacity field. This field is required if you do not provide a value in the Net Maximum Capacity field.

The value in Gross Maximum Capacity field must be greater than the value in Net Maximum Capacity field.

The value in Net Dependable Capacity field must be less than the value in Net Maximum Capacity field.

You must provide a value in this field or the Gross Maximum Capacity field. This field is required if you do not provide a value in the Gross Maximum Capacity field.

The value in Net Maximum Capacity field must be less than the value in Gross Maximum Capacity field.

The Start Date of any GAA Unit Capacity record must be a date after the End Date of the previous GAA Unit Capacity record.

When you add a GAA Unit record, a GAA Unit Capacity record is automatically created with the values defined in the capacity related fields in the GAA Unit record. In the default GAA Unit Capacity record, the Start Date is set to 01/01/1900 00:00:00 and the End Date is blank. If you want to add an additional GAA Unit Capacity record, you must modify the End Date of the default record and set it to a date before the Start Date of the new record.

This field is required.

Action on Primary Event

Character

Indicates the type of action taken on the Primary Event.

This field is populated automatically.

Depending on the action taken on the Primary Event, the field is populated with either Update or Delete.

This field is populated automatically with one of the following states:

• Approved
• In Progress
• New
• Pending Review
• Reviewed
• Unit Approved