1. Workshop Session 2: Forms
Transmission Availability Data System (TADS) TADS Workshops: January 16, 2008 and February 6, UPDATED
Workshop Session 2: Forms

2. TADS Forms Overview
Administrative Forms with Transmission Owner Information
1.1  Non-Reporting Transmission Owner Statement
1.2  Reporting Transmission Owner Information
Forms for Ties & Jointly-Owned Facilities
2.1  Tie Lines and Jointly-Owned AC and DC Circuits
2.2  Jointly-Owned AC/DC Back-to-Back Converters
Forms for Element Inventory and Summary Outage Data
3.1  AC and DC Circuit Inventory Data
3.2  Transformer Inventory Data
3.3  AC/DC Back-to-Back Converter Inventory Data
3.4  Summary Automatic Outage Data
Forms for Detailed Element Automatic Outage Data
4.1  AC Circuit Detailed Automatic Outage Data
4.2  DC Circuit Detailed Automatic Outage Data
4.3  Transformer Detailed Automatic Outage Data
4.4  AC/DC Back-to-Back Converter Detailed Automatic Outage Data
Form for Event ID Code Data
5 Event ID Code and Event Type No. Data

3. Form 1.1 Non-Reporting TO Information

4. Form 1.1 Non-Reporting TO Information (cont’d)
If a non-reporting TO adds TADS facilities during the reporting year, it is required to report on those facilities in that year.

5. Form 1.2 Reporting TO Information

6. Form 1.2 Problems Encountered
We added pseudo NERC IDs for three TOs for TADS only
PSD00001: Southern Company Transmission (in SERC) to be used instead of their five registered NERC IDs
NERC ID Company Name
NCR01166 Alabama Power Company
NCR01247 Georgia Power Company
NCR01252 Gulf Power Company
NCR01273 Mississippi Power Company
NCR01322 Southern Power Company
PSD00002: AltaLink Management Ltd. – An unregistered Canadian TO in WECC who will voluntarily report
PSD00003: ATCO Electric – An unregistered Canadian TO in WECC who will voluntarily report
PSD00004: ITC Midwest LLC – purchased the transmission of Alliant West. They have applied for NERC registration.
ITC Midwest LLC is registered with NERC ID NCR10192

7. Form 1.2 Reporting TO Information (continued)
The forms status table accounts for all forms for reporting TOs

8. Form 2.1 Tie Lines and Jointly-Owned Circuits
Form 2.1 is reported at the start of each reporting year and at the end of each reporting year.
2008 will have three submissions of Form 2.1 because of the first quarter reporting requirement
The TO that reports outages for joint-owned circuits also reports the entire circuit length in its inventory
Each DC pole (plus or minus polarity) is a separate DC Circuit
In an AC Circuit,
Transformers are not part of the circuit
In-line switches located inside an AC Substation are part of the AC Circuit
Will expand to allow for 3-terminal circuits

9. AC Circuit Transformer Exclusion
Dashed lines are substation boundaries
AC Circuit boundaries are defined by the red “arcs” (A, B, & C)
Transformer boundaries are defined by the breaker or disconnect switch

10. Sectionalizing Switches
They are considered “in-line switches,” regardless of location
50 mi.
20 mi.
In-line switches are now inside AC Substation C.
50 mi.
Zero mi.
AC Circuit boundaries (A, B, & C) are the same, but Circuit Miles are different (120 vs. 100).

11. Form 2.1 Problems Encountered
Some TOs that jointly-own a circuit are not on the NERC Compliance Registry
Example: A customer owns a 345 kV tap off of a registered TOs circuit, but the customer is not a registered TO. If the customer was registered, this would be a jointly-owned 3-terminal circuit.
The registered TO then has reporting responsibility
TO registration of customers and IPPs is before the FERC
Why report tie lines if they are not jointly owned?
Originally thought to be useful for RE review
See the Manual, Section 2.1: “Tie lines for TADS purposes are those AC Circuits (or DC Circuits) that are Elements which connect the AC Substations (or AC/DC Terminals) of two Transmission Owners on the NERC Compliance Registry.”
We will probably drop tie line reporting in the future and just require jointly-owned circuits to be reported

12. Form 2.2 Jointly-Owned AC/DC BTB Converters
Its similar to Form 2.1, but only requires the reporting of jointly-owned AC/DC BTB Converters

13. Form 3.1 AC & DC Circuit Inventory Data
In Rows 1-18, the no. of circuits and associated Circuit Miles are adjusted for time in-service of added or retired circuits to properly account for exposure
If circuits are added or retired, this data cannot be filed out until the end of the reporting period
Appendix 7 has examples that calculate the “equivalent” data for no. of circuits and Circuit Miles

14. Form 3.1 AC & DC Circuit Inventory Data (cont’d)
In Rows request AC Multi-Circuit Structure Miles data only
We did not define a “circuit” for common structures, so the no. of circuits is not required
Reminders
Multi-circuit structures that are occupied by only one circuit do not contribute to the tabulation of Multi-Circuit Structure Miles. Examples:
A structure designed to have two 345 kV circuits that has only one circuit on the structure does not contribute
A structure contains a 230 kV circuit and a 138 kV circuit does not contribute since the 138 kV circuit is < 200 kV

15. Form 3.1 AC & DC Circuit Inventory Data (cont’d)
For common structures that carry circuits owned by different TOs, we expect the TOs to coordinate with each other on their reporting of Multi-Circuit Structure Miles so that no double counting takes place.
As an example, suppose two circuits owned by different TOs occupy common structures for 10 miles. For this section, the combined number of Multi-Circuit Structure Miles reported by the TOs should not exceed 10. We do not want each TO to report 10 miles since that would double count the miles for the region.

16. Forms 3.2 and 3.3
Form 3.2 (Transformer Inventory Data) and Form 3.3 (AC/DC Back-to Back Converter Inventory Data) are similar to Form 3.1 for the number of circuits
For Transformers
The Voltage Class is the high-side voltage
Do not include spares… only include transformers that are “in-service” energized and fully connected and that have been declared commercially in service by the TO.

17. Form 3.4 Contains Automatic Outage summary data
Columns B and C are self-checks based upon data reported in Forms 4.1, 4.2, 4.3, and 4.4
They may be eliminated in a future TADS update.
Column D is a number that the TO must derive. Its based upon the number of Elements (AC Circuits, Transformers, etc.) that are “in-service” at the end of the reporting period and which are included in column B on Form 3.1 (AC & DC Circuits), Form 3.2 (Transformers) and 3.2 (AC/DC BTB Converters)

18. Forms 4.1 - 4.4: Individual Element Outage Data
Data that will be recorded for each outage includes…
Several Element descriptors.
The type of Element. A different Form is used for each Element.
Its location: (e.g., Substation Names that define an AC Circuit or Substation Name where Transformer is located)
The Element’s Voltage Class
The TO’s Element Identifier (optional)
For AC or DC Circuits, was it an Overhead or Underground Circuit?
An Outage ID Code
Unique ID assigned by the TO to each specific Element outage being reported
An Event ID Code.
Data for each Event ID Code is described on slides 31-36

19. Fault Type Several selections are available (Updated):
No fault
Phase-to-phase fault (P-P)
Single phase-to-ground fault (P-G)
Phase-to-phase-to ground (P-P-G), 3P, or 3P-G fault
Unknown fault type
Fault Types may be determined from recorded relay targets or by other analysis. TOs should use the best available data to determine (1) whether a fault occurred and, if so, (2) what type of fault occurred
Relay targets should be examined as soon as possible after a fault and re-set to prepare for the next fault

20. Fault Type (cont’d)
If a single fault results in several Element outages, the Element’s protective relays that indicated the Fault Type should be indicated on that Element’s outage.
Element’s whose relays did not indicate a fault should be reported as “no fault occurred”
Example: A 500 kV AC Circuit has a single line-to-ground fault that results in the outage of a 500/230 kV Transformer. The AC Circuit outage would have “ground target” selected as the Fault Type, while the Transformer would have “no fault” selected.

21. Outage Initiation Code
An Outage Initiation Code that describe where an Automatic Outage was initiated on the power system. Five Outage Initiation Codes are available:
Element-Initiated
Other Element-Initiated
AC Substation-Initiated
AC/DC Terminal-Initiated
Other-Facility Initiated - any facilities not includable in any other Outage Initiation Code
Note: The Protection System is not part of an AC Substation or an AC/DC Terminal. While almost all outages involve the operation of the Protection System, the Protection System is only considered in these codes if the Protection System misoperates and therefore initiates an outage. In this case, it will be classified as Other-Facility Initiated.

22. Cause Codes Sustained Outages require two Cause Codes*:
An Initiating Cause Code that describes the initiating cause of the outage.
A Sustained Cause Code that describes the cause that contributed to the longest duration of the outage. (Momentary Outages omit this second code)
Example: A lightning strike on an AC Circuit (the Initiating Cause Code is Lightning) that should have cleared normally became a Sustained Outage because of a relay misoperation (the Sustained Cause Code could be Failed Protection System Equipment or Human Error)
Seventeen (17) Cause Codes are defined
For 2008 an additional code is also allowed (“Unavailable”)
*See 2008 exceptions in the Manual, p.13, column N, and discussed next.

23. Cause Codes – 2008 Exceptions
All Momentary Outages must supply this code, and the “Unavailable” Cause Code cannot be used for Momentary Outages. Sustained Outages may use the “Unavailable” code in 2008 only for either the Initiating Cause Code or the Sustained Cause Code, but not both. If the TO has the ability to capture Initiating and Sustained Cause Codes, the “Unavailable” code is not to be used.

24. Listing of Cause Codes Weather (excl. lightning) Lightning
Environmental
Contamination
Foreign interference
Fire
Vandalism, terrorism, malicious acts
Failed AC Substation equipment
Failed AC/DC Terminal equipment
Failed Protection System equipment
Failed AC Circuit equipment
Failed DC Circuit equipment
Vegetation
Power system condition
Human error
Unknown
Other
Unavailable
Definitions of each cause code are included in the Manual, Appendix 6

25. Vegetation Cause Code and FAC-003-1
It is possible for more Vegetation Cause Codes to be recorded for outages than are reported as vegetation outages under FAC (Vegetation Management Program Standard)
TADS records Momentary Outages due to vegetation while FAC does not
The TADS definition of a Sustained Outage is different that the Sustained Outage definition in FAC Under FAC-003-1, a Sustained Outage is “The deenergized condition of a transmission line resulting from a fault or disturbance following an unsuccessful automatic reclosing sequence and/or unsuccessful manual reclosing procedure.”
For a circuit with no automatic reclosing, a vegetation outage would not be “counted” under FAC if the TO has a successful manual reclosing

26. Outage Mode Code
The Outage Mode Code describes whether an Automatic Outage is related to other Automatic Outages. Several Outage Mode Codes are provided:
A Single Mode Outage is an Automatic Outage which occurred independent of any other outages (if any).
A Dependent Mode Initiating Outage is a Single Mode Outage that initiates one or more subsequent Automatic Outages.
A Dependent Mode Outage is one that occurred as a result of an initiating outage, whether the initiating outage was an Element outage or a non-Element outage.
A Common Mode Outage is one of two or more Automatic Outages with the same Initiating Cause Code and where the outages are not consequences of each other and occur nearly simultaneously (i.e., within cycles or seconds of one another).
A Common Mode Outage Initiating Outage is a Common Mode Outage that initiates one or more subsequent Automatic Outages.

27. Outage Example #1
A tornado takes down a tower that is a common structure for two 230 kV circuits
How many outages are reported?
The Fault Type was for one circuit was determined to be “ground target,” while the Fault Type for the second circuit was “phase target.”
What was the Outage Initiation Code?
What was the Initiating Cause Code and the Sustained Cause Code?
What was the Outage Mode Code?
How many outages are reported? Two
What was the Outage Initiation Code? Element-Initiated for both outages
What was the Initiating Cause Code and the Sustained Cause Code? For both circuits, the Initiating Cause Code is Weather (excl. lightning) and the Sustained Cause Code is Failed AC Circuit Equipment.
What was the Outage Mode Code? Common Mode for both outages

28. Outage Example #2
A circuit breaker opens due to low gas pressure, resulting in the outage of a 500 kV circuit
How many outages are reported?
What is the Fault Type?
What was the Outage Initiation Code?
What was the Initiating Cause Code and the Sustained Cause Code?
What was the Outage Mode Code?
How many outages are reported? One
What is the Fault Type? No fault occurred
What was the Outage Initiation Code? AC Substation-Initiated
What was the Initiating Cause Code and the Sustained Cause Code? Initiating and Sustained Cause Codes are both Failed AC Substation Equipment
What was the Outage Mode Code? Single Mode

29. Outage Example #3
Insulator contamination causes a fault on a 230 kV AC Circuit, but a breaker on one end fails to open due to a failure of a relay to operate properly. A second 230 kV AC Circuit, which is connected to the same bus as unopened breaker, is outaged as a result of the first circuit’s breaker failing to open. The failed relay was manually isolated, and both lines were returned to service with no other repairs.
How many outages are reported?
The Fault Type was determined to be “ground target” for the first circuit, and second circuit did not experience a fault, it’s Fault Type was “no fault.”
What was the Outage Initiation Code?
What was the Initiating Cause Code and the Sustained Cause Code?
What was the Outage Mode Code?
How many outages are reported? Two
What was the Outage Initiation Code? First circuit – Element-Initiated. Second circuit – Other Facility-Initiated (Protection System is “Other Facility.”)
What was the Initiating Cause Code and the Sustained Cause Code?
Initiating Cause Codes: First circuit – Contamination. Second circuit – either Failed Protection System or Human Error, depending on why the relay misoperated.
Sustained Cause Codes: First circuit – either Failed Protection System or Human Error, depending on why the relay misoperated. Second circuit – either Failed Protection System or Human Error, depending on why the relay misoperated.
What was the Outage Mode Code? First circuit – Dependent Mode Initiating. Second Circuit – Dependent Mode

30. Outage Example #4
A 345/138 kV Transformer in one leg of a three-terminal 345 kV AC Circuit is outaged due to a 138 kV bus fault caused by contact with a snake. The Transformer and its terminal are isolated, but the other terminals remain in service.
How many outages are reported?
What is the Fault Type?
What was the Outage Initiation Code?
What was the Initiating Cause Code and the Sustained Cause Code?
What was the Outage Mode Code?
How many outages are reported? No outages are reported. The Transformer is not a TADS Element, and the 3-terminal circuit is considered to remain in service even with one terminal out because that terminal contains a Transformer.
What is the Fault Type? Not reported
What was the Outage Initiation Code? Not reported
What was the Outage Mode Code? Not reported
What was the Initiating Cause Code and the Sustained Cause Code?
Not reported

31. Outage Times
The Outage Start Time - The date (mm/dd/yyyy) and time (hhhh:mm), rounded to the minute, that the Automatic Outage of an Element started
Outage Start Time is expressed in Coordinated Universal Time (UTC), not local time
Common time reference will allow REs and NERC to assign common Event ID Codes to Events that cross TO and RE boundaries
The Outage Duration (for Sustained Outages only), rounded to the nearest minute.
Momentary Outages are recorded as a zero minute outage duration time to avoid confusion in rounding to the nearest minute
For outages that continue beyond the reporting period, see Section 4.1 of the Manual

32. Partial Outages
With one exception, TADS does not recognize partial power flow outages.
The exception is a three-terminal circuit with a Transformer on one leg.
If terminal A or B open, an AC Circuit outage is recorded.
The AC Circuit is considered to be restored when partial power flow is restored on both A & B and the Transformer (TADS or non-TADS) is out-of-service.

33. Form 5: Event ID Code Data
An Event ID Code.
An Event is a transmission network incident that results in the Sustained or Momentary outage of one or more Elements.
Each TO will assign its own Event ID Code, with the reporting year appended to it. Regional Entities and NERC will assign common Event ID Codes if outages affect two or more TOs.

34. Form 5: Event ID Code Data (cont’d)
An Event associated with a Single Mode Automatic Outage will have just one Event ID Code. 
Each outage in a related set of two or more outages (e.g., Dependent Mode, Dependent Mode Initiating, Common Mode, or Common Mode Initiating) shall be given the same Event ID Code.

35. Form 5: Event ID Code Data (cont’d)
The Event Type Number
Event Type Number Possibilities

36. Event Type No. 30 or 40
To qualify for an Event Type No. 30 or 40, the outages must be a direct result of the circuits occupying common structures. These characteristics will generally apply.
The Outage Initiation Codes are either Element-Initiated or Other-Element Initiated.
The Outage Mode Codes are one of the following: (a) Dependent Mode Initiating (one outage) and Dependent Mode (second outage); (b) Common Mode Initiating and Common Mode (two outages); or (c) both Common Mode (two outages)

37. Assign an Event Type No.
On one circuit, a conductor breaks (outaging the circuit), and the conductor swings into a second circuit on common structures and outages the second circuit. Both circuits have Normal Clearing. Event Type No. = ?
Two AC Circuits on common structures are outaged due to a bus fault in the AC Substation were the circuits terminate. Both circuits have Normal Clearing. Event Type No. = ?
First bullet: Event Type No. = 30
Second bullet: Event Type No. = 50

38. Form 5: Event ID Code Data (cont’d)
Was the Event was associated with the filing of a disturbance report (an EOP disturbance report filing)?
TO may select “yes, “no,” or “unknown”
NERC staff will examine reports to fill in “unknown” responses
Year-to-date public (i.e., non-confidential) data of all disturbance report filings are located at
Info on disturbance reports is an “impact measure”
Since TADS tracks a part of the transmission system, other potential measures (load lost, transmission service interrupted) would be a subset of the impacts

39. AC Multi-Owner Common Structure Flag
For AC Circuits only: AC Multi-Owner Common Structure Flag
= 0 Not applicable. The circuit is not on common structures with another circuit, or the circuit is on common structures, but all circuits are owned reported by the same Transmission Owner. No analysis of the Event ID Code or the Event Type Number is required by the Regional Entity.
= 1 Circuit is on common structures with another circuit that is being reported and owned by a different TOs Transmission Owner. The Regional Entity will need to examine Outage Start Times with this same flag to determine whether a second circuit had an outage with nearly the same Outage Start Time, and if so, whether the TOs properly coordinated their Event ID Codes and Event Type Numbers.

40. Examples: Inventory & Outage Mode
Examples in the Manual were developed to assist TOs in responding properly to TADS data request
Both inventory and outage mode examples are included in the data instruction manual
Inventory examples are designed to demonstrate proper calculation of entries in Form 3.1 (AC/DC Circuit Inventory Data)
But they are applicable to all Elements
Outage mode examples are provided to illustrate several AC Circuit & Transformer outage scenarios

41. TADS Metrics
Intent of the proposed metrics is to assist in measuring performance
Given richness of the data collected, metrics can be computed for many data combinations
Comprehensive set of metrics not established yet – waiting until sufficient amount of data collected
Basic metrics presented here will be reported to describe the performance of each Element for the reporting year.

42. Metrics and Data Analysis - Basic Metrics
Outage frequency (Sustained, Momentary, and total)
For AC and DC Circuits:
Outage frequency/100 Circuit Miles (Sustained, Momentary, and total). Additional calculations for Events 30 and 40 per 100 Multi-Circuit Structure Miles
Additional calculations will exclude outages not related to mileage
For Sustained Outages:
Outage Duration
Mean Time Between Failure -MTBF
Mean Time to Repair – MTTR
Median Time to Repair - MdTTR
Percent Availability
Percent of Elements w. zero outages.
Percent of Element outages that were associated with a disturbance report.

43. Metrics and Data Analysis- Additional Items
MTBF and Percent Unavailability will not follow standard industry terms since no planned outage data will be collected in Phase I
Lots of ways to “slice” metrics (Cause Code, Outage Mode, Event Type#, etc.)
Additional metrics will be determined – we will work with the data looking for meaningful information