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Why TADS Is Needed No systematic transmission outage data collection effort exists for all of North America Energy Information Administration data (Schedule.

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Presentation on theme: "Why TADS Is Needed No systematic transmission outage data collection effort exists for all of North America Energy Information Administration data (Schedule."— Presentation transcript:

0 Workshop Session 1: Overview
Transmission Availability Data System (TADS) TADS Workshops: January 16, 2008 and February 6, 2008 Workshop Session 1: Overview

1 Why TADS Is Needed No systematic transmission outage data collection effort exists for all of North America Energy Information Administration data (Schedule 7 on Form 411) is voluntary and of no use to NERC EIA proposed to make Schedule 7 mandatory in 2008 TADS data is intended to provide data for improving planning and operating standards It will help define credible contingencies TADS will provide a partial measure of bulk power system performance

2 How TADS Was Developed NERC Planning Committee Chairman Scott Helyer formed the TADS Task Force on October 24, 2006 Task Force’s report was approved by the Planning Committee on June 7, 2007 The report and a data reporting instruction manual were posted for public comment The Task Force also conducted a Beta test with four transmission owners using data from 2006 Original report was revised on September 26, 2007 to incorporate changes Data Reporting Instruction Manual was released on October 17, 2007 and updated on November 20, 2007

3 TADS References and Forms
TADS references available at Link. Transmission Availability Data System Revised Final Report (Sept 26, 2007) 2008 TADS Data Forms (Nov 2, 2007), an Excel workbook TADS Data Reporting Instruction Manual (Nov 20, 2007) DRAFT Data Reporting Instruction Manual (Jan 10, 2008)* DRAFT Data Reporting Instruction Manual redline (Jan 10, 2008)* * The DRAFT Manual will be used when discussing the Forms section regarding Fault Type and Event ID Code. It describes expected TADS changes which will be discussed by NERC’s TADS Task Force this month.

4 NERC Authority to Require TADS
NERC’s authority to issue a mandatory data request in the U.S. is contained in FERC’s rules. Volume 18, C.F.R., Section 39.2(d) states: NERC Board has approved TADS as mandatory for U.S. Transmission Owners on the NERC Compliance Registry beginning with calendar year 2008 data1 Each user, owner or operator of the Bulk-Power System within the United States (other than Alaska and Hawaii) shall provide the Commission, the Electric Reliability Organization and the applicable Regional Entity such information as is necessary to implement section 215 of the Federal Power Act as determined by the Commission and set out in the Rules of the Electric Reliability Organization and each applicable Regional Entity. 1TADS data is being requested from non-U.S. TOs, but it is not mandatory.

5 Can TOs Have Another Entity Report Its Data?
Yes. From Section 5.1 of the September 26, 2007 report: “A TO may designate another entity, such as an RTO, to assume the TO's reporting obligation, provided that the designated entity and the TO jointly register with NERC per the requirements of the NERC Rules of Procedures sections and Otherwise, TO with the reporting obligation is ultimately responsible for ensuring the timely and accurate reporting of data.” What if a TO wants to have another entity (like a Transmission Operator) report its data without joint registration? A TO may “subcontract” its reporting obligation to another entity, but the TO is still responsible A written agreement between the TO and the other entity would be prudent

6 Fundamental TADS Structure Decisions
Whatever data and metrics are recommended, they should be: Comparable (consistent framework) Attainable Verifiable Simple Relevant to various “users” Transmission Owners (TOs), Transmission Operators, and Planning Coordinators, ERO, Governmental bodies (FERC, EIA, etc.) Chosen to balance several factors: the level of data detail the level of effort required to collect the data and the usefulness of the resulting metrics Initial TADS structure may be enhanced and improved over time.

7 Phase I and Phase II Phase I will collect Automatic Outage data on four Elements beginning with 2008 data AC Circuits ≥ 200 kV (Overhead & Underground) Transformers with ≥ 200 kV low-side AC/DC Back-to-Back Converters with ≥ 200 kV AC on both sides DC Circuits with ≥ ±200 kV DC Voltage Phase II TADS will be designed to expand the collection of Phase I outage data to: Include historic planned outage data Include manual unscheduled outage data. Consider 100 kV DC Circuits data (a Schedule 7 requirement) Phase II details will be brought to the PC at its March 2008 meeting for review. Data collection will commence in 2009

8 Overview of Data & Metrics
Element Inventory Data Automatic Outage Data (each outage) Outage ID Event ID Code Fault Type Outage Initiation Code Outage Start Time Outage Duration Outage Cause Codes Initiating Sustained Outage Mode Basic metrics Outage frequency Outage duration Mean time between failure Mean time to repair Median time to repair Percent availability Percent of Elements with no outages Disturbance report events Other metrics developed as needed RE can add additional metrics

9 Confidentiality of TADS information
Under NERC’s confidentiality policy (Section 1500 of NERC’s Rules of Procedures), the entity claiming that information is confidential must state the category under which such information qualifies as confidential. For practicality, TADSTF made judgments that data on certain forms will likely be confidential information because it contains critical energy infrastructure information (CEII), while other information is not confidential. A TO may make its CEII information (per NERC’s classification) non-confidential by requesting, in writing, that NERC treat it as such.

10 Confidentiality Designations

11 Information Disclosure
No TO’s data would be released in public reports if the TO could be identified by the data reported For example, if the TO in a region is the only owner of assets in a particular Voltage Class, the metrics on that data would not be released if the TO’s name and its confidential information could be identified. The exception is if the TO voluntarily provides NERC permission to do so, which NERC will seek. However, if the identity of the TO in the previous example could not be identified in a NERC-wide report that combines the data from all reporting TOs, that report would not violate the confidentiality of that TO’s data, and the NERC-wide report containing information on the Voltage Class would be released.

12 Role of Regional Entities
The process involves a coordinated effort between NERC and the Regional Entities. This coordination is critical to the success of TADS. Regional Entities are responsible for the following tasks: Request data from TOs. Review tie lines and jointly-owned facilities to ensure that a single TO is responsible for TADS reporting. Review inventory and outage data for consistency and completeness (but do not review a TO’s source data). Assign common Event ID Codes for Events affecting more than one TO in their region. Evaluate AC Circuit outages on common structures when the circuits are owned by different TOs.

13 TADS Regional Coordinators

14 Data Collection, Analysis & Reporting Process
Software will be developed (funded by NERC) to facilitate data entry, verification/validation, data management, analysis and reporting. We expect the software to be ready by mid-March 2008 that will permit Web-based data entry. It will contain the data on the TADS forms Overall process consists of 3 major steps Data request issued by RE Data submittal by TOs and review by RE Data analysis & reporting by NERC

15 Data Request Process

16 Data Submittal & Review

17 Analysis & Reporting

18 Schedule for TADS For 2008 data, two reporting cycles are planned
Q1 data will be submitted by May 30, 2008 so that the procedures can be validated & reporting processes tested Full year data submittal in March 2009 Beginning with year 2009 data, schedule will be “normal” reporting procedure

19 Phase I TADS Implementation Timetable: 2008

20 Phase I TADS Implementation Timetable: 2009
This schedule represents a normal reporting year.

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