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WECC Criterion – TPL-001-WECC-CRT-3Transmission System Planning Performance

Posting 34July 24-August 24, 2015TBA

Criterion Development

This section is maintained by the drafting team during the development of the document and will be removed when on final disposition of the document is approved by the WECC Board of Directors (Board)..

Updates

Changes made to the document is response to Posting 3 were substantial. All changes can be seen on the redline version of the document posted at the WECC-0100 project page on the Posted for Comment accordion. An explanation of changes made can be found in the Posting 3 Response to Comments form located at the WECC-0100 project page on the Submit and Review Comments accordion.

Document Scope

This document is designed to address the substance of TPL-001-WECC-CRT-2.1 (TPL), Requirement WR3 and the requirements imposed by NERC TPL-001-4, Requirements R5 and R6. Standard Authorization Request (SAR) WECC-0100 also provides for review and disposition of Table W-1 associated with the WECC TPL. Once the Requirements of this document are more fully developed the drafting team will revisit the need to edit, modify, or delete the table.Table W-1 will not migrate to this document; rather, combined interactive language of WR1, WR2, and WR3 is designed to meet that intent.

Procedural Background

On September 5, 2012, the WECC Board of Directors (Board) adopted a recommendation by the Regional Criteria Work Group (RCWG) changing the designation of this document from a WECC Criterion (CRT) to a WECC Regional Business Practice (RBP). On June 24, 2014, the Board reversed that decision and designated this document as a CRT.

In further keeping with the September 5, 2012 recommendation, on November 28, 2012, a Standard Authorization Request (SAR) was submitted to evaluate whether this document should be drafted as a WECC Regional Reliability Standard (RRS).

On December 19, 2012, the WECC Standards Committee (WSC) accepted the SAR as drafted with specific approval to assign an evaluation team to review the subject matter and return a recommendation to the WSC as to whether the document should be redrafted as an RRS.

Developed as WECC-0100 1

WECC Criterion – TPL-001-WECC-CRT-3 of 22

On June 26, 2013, the WSC approved the evaluation team’s recommendation to ballot the retirement of TPL-001-WECC-RBP-2.1, WR1, WR2, WR4 and WR5. If approved the retirement would become effective coincident with the Effective Date of NERC’s TPL-001-4, because the content of the WECC Requirements will be resident in the NERC TPL-001-4.

On August 8, 2013, the WSC assigned the original drafting team, augmenting the team during later weeks.

On October 8, 2013, a WECC Ballot Pool voted to retire TPL-(012 through 014)-WECC-RBP-2.1, WR1, WR2, WR4 and WR5 of the Effective Date of NERC TPL-001-4. (The Effective Date is projected for approximately January 1, 2016. It should be noted that the TPL has a staggered Effective Date.)

On November 1, 2013, the WECC-0100 Drafting Team (DT):

1. Reported completion of the tasks assigned in the WECC-0100 Standard Authorization Request (SAR);

2. Requested the WECC Standards Committee (WSC) deem the WECC-0100 SAR complete; and,

3. Requested the WSC accept the DT’s recommendation to proceed with informal drafting in support of an iterative SAR tailored to the remedial needs of TPL-001-WECC-RBP-2.1, System Performance, WR3 as well as a more granular implementation plan of TPL-001-4, Transmission System Planning Performance Requirements Requirement R5 and R6.

The WSC agreed to expand the WECC-0100 drafting team to include the entire Reliability Subcommittee, and accept the drafting team’s recommendation that further drafting continue on remedial language for:

1. TPL-001-WECC-RBP-2.1. WR3;

2. Table W-1; and,

3. TPL-001-4, Requirements R5 and R6.

On December 5, 2013, the Board approved the decision to retire portions of the WECC TPL upon the Effective Date of the NERC TPL.

During June 2014, the Planning Coordinating Committee (PCC) conducted a straw poll concluding the most appropriate document categorization for this document should be that of a WECC Regional Criterion.

On June 24, 2014, the Board changed the designation of this document from that of a RBP to that of CRT.

D E V E L O P E D A S W E C C - 0 1 0 0

W E S T E R N E L E C T R I C I T Y C O O R D I N A T I N G C O U N C I L


Completed Actions Date

1. SAR Filed. November 28, 2012

2. Review Team files Preliminary Recommendation.

June 20, 2013

3. WSC approves ballot to retire WR1, WR2, WR4 and WR5.

June 26, 2013

4. Notice of Joint Session to discuss retirement.

August 2, 2013

[5.] Ballot Pool openopens asking for retirement of WR1, WR2, WR4 and WR5.

August 5, 2013

5.[6.] WSC approves Drafting Team. August 8, 2013

6.[7.] Ballot Pool closed asking for re-tirement of WR1, WR2, WR4 and WR5.

September 3, 2013

7.[8.] Joint Session to discuss retire-ment.

September 5, 2013

[9.] Ballot openopens asking for re-tirement of WR1, WR2, WR4 and WR5.

September 16, 2013

8.[10.] Drafting Team – First Meeting – Orientation.

September 26, 2013

9.[11.] Ballot closed asking for retire-ment of WR1, WR2, WR4 and WR5. Retirement approved.

October 8, 2013

10.[12.] Posting 1 - Open 45-day October 15, 2014

11.[13.] Posting 1 – Closed December 1, 2014

12.[14.] Posting 1 – Response to Com-ments Posted

February 4, 2015




15. Posting 2 – Open 30-day February 4, 2015

16. Posting 2 – Closed March 6, 2015

17. Posting 2 – Response to Com-ments Posted

March 17, 2015

18. Posting 3 – Open 30-day July 24, 2015

19. Posting 3 - Closed August 24, 2015

20. Posting 3 – Response to Com-ments Posted

October 16, 2015

Anticipated Actions Date

1. Version 4 Posted – Open 30-Day Comment Period

October 27, 2015

2. Version 4 Posted – Closed November 30, 2015

3. DT meets for final Comments / For-ward to WSC

December 3, 2015

4. WSC Meets

5. Open Ballot Pool

6. Joint Session – Notice

7. Close Ballot Pool

8. Joint Session

9. Open Ballot

10. Ballot Closed

11. WSC Meets

12. Notice to WECC Board of Directors

13. Board




Implementation Plan

Approvals Required

TPL-001-WECC-CRT-3, Transmission System Planning Performance

A WECC Criterion

Prerequisite Approvals

WECC Ballot Pool WECC Standards Committee WECC Board of Directors

Applicable Entities

Planning Coordinator

Transmission Planner

Conforming Changes to Other Standards

None required.

Effective Date

The Effective Date is the later of January 1, 2016 or the Effective Date of TPL-001-4, Transmission System Planning Performance, Requirements R2-R6 and R8, subject to required approvals.

Justification

The effective date is targeted to coincide with the effective date of TPL-001-4, Transmission System Planning Performance.

Consideration of Early Compliance

The DT foresees no reliability-related issues if an entity chooses to implement the document early; however, entities should continue to adhere to approved WECC Criteria until they are retired.

Retirements

This document will replace TPL-001-WECC-CRT-“2” that is to be retired as of the Effective Date of this project.




New or Modified Term(s) Used in the WECC Glossary for WECC Criteria and Naming Conventions (WECC Glossary).

This section includes all new or modified terms used in the proposed criterion that will be included in the WECC Glossary upon applicable approval. The new or revised terms listed below will be presented for approval with the proposed document. Upon WECC Board of Director (Board) adoption, this section will be removed and the approved terms will be moved to the WECC Glossary.

Term(s): None proposed




A. Introduction

1. Title: Transmission System Planning Performance

2. Number: TPL-001-WECC-CRT-3

Purpose: To facilitate coordinated near-term and long-term trans-mission planning forwithin the Western Interconnection, of the West-ern Electricity Coordinating Council (WECC), and to facilitate the ex-change of the associated planning information for normal and abnor-mal conditions.

This document applies to all transmission planning studies conducted within the Interconnection of the Western Electricity Coordinating Council (WECC).

This is a planning criterion. This document does not designate the entity responsible for system remediation.1

3. Applicability:

4.1. Functional Entities:

4.1.1. Planning Coordinator

4.1.2. Transmission Planner

4.2. Facilities:

[4.2.1.] This document applies to studies conducted in both the near-term and the long-term planning horizons.

[4.2.2.] This document applies only to Bulk- Electric System (BES) substations buses.Facilities.

[4.2.3.] This document applies to all transmission planning studies conducted at the Western Interconnection level.

[4.2.4.] Each of the following elementsbuses is specifically excluded from this Criterion:

4.2.1.1.[4.2.4.1.] Non-BES buses.

4.2.1.2. Line side series capacitor buses

4.2.1.3.[4.2.4.2.] Line side series reactor buses

1 TPL-001-WECC-2.1, System Performance, WECC’s Disturbance Performance Table (Table W-1) of Allowable Effects Other System (Table) was retired by the WECC Ballot Body on October 8, 2015 with WECC Board of Director approval on Decem-ber 5, 2013.




[4.2.4.3.] ShuntDedicated shunt capacitor buses

[4.2.4.4.] ShuntDedicated shunt reactor buses

[4.2.4.5.] Metering buses, fictitious buses, or other pointsbuses that model point of interconnection modeled solely for measur-ing electrical quantities; and,

4.2.1.4.[4.2.4.6.] Other buses specifically excluded by each Planning Coordinator or Transmission Planner internal to their sys-tem.

4. Effective Date: The Effective Date is the later of January 1, 2016 or the Effective Date of TPL-001-4, Transmission System Planning Performance, Require-ments R2-R6 and R8, subject to approvals.

[B.] Requirements and Measures

Rationale Blocks will be relocated to the Guidance section when the project is complete.

Rationale for Requirement WR1:

This is a planning criterion.

WR 1 addresses NERC TPL R5 and R6.

WR1 is designed to state the base planning criteria the system must meet – unless an in-dividual entity or group of entities has different criteria. WECC Requirements WR2 and WR3 allow for entities to have different criteria.Neither WR2 nor WR3 changes the WR1 default; rather, WR2 and WR3 allow for devia-tion from the WR1 default. WR2 allows for a more stringent approach without changing the WR1 default. A more stringent approach may be used in accordance with WR2 so long as all the affected parties agree. Similarly, WR3 allows deviation from the default with the additional protection that when used, other Transmission Planners and Planning Coordinators are allowed to use the same criteria on that part of the system for the same category of planning events (e.g., P1 and P2).

In the context of Requirement WR1, the word “nominal” carries its common definition and could be, for example, either the base voltage or the operating voltage as established in the entity’s Planning Assessment. This voltage will vary




from entity to entityThis means that nominal may have a varying definition or use from one entity to the next. If an entity does not specify what is nominal, the default use of the term nominal defaults to the kilo-volt class that is specified in the WECC Base Case, with the exception of the 500 kilo-vote class, in which case the default nominal would be specified as 525 kilo-volt.

Requirement WR1.1.2, refers to the post automatic equipment adjustment effect prior to manual adjustment.

WR1. Each Transmission Planner and Planning Coordinator shall use the following default base planning criteria in its Planning Assessment, unless otherwise specified in ac-cordance with Requirements WR2 and WR3: [Addresses NERC TPL R5 and R6]

1.1. Steady-state voltages at all applicable Bulk-Electric System (BES) buses shall stay within each of the following limits:

1.1.1 95 percent to 105 percent of nominal for P02 event (system normal), pre-contingency powerflow);

1.1.2 90 percent to 105110 percent of nominal for P1-P73 events (post-contin-gency powerflow).

Rationale for Requirement WR1.2:

Requirement WR1.2 establishes a target that could be met by each entity without incurring costs that would outweigh the benefits. Many legacy systems were not designed to meet a more stringent threshold. The eight percent target of Requirement WR1.2 is established not by a technical study; rather, it is established based on sound engineering judgment. Further, cer-tain entities are bound by state tariffs that establish the percentage rate specifically at eight percent.

For purposes of this document, a BES bus that is serving load is the bus with direct transformation from BES-level voltage to distribution-level voltage that serves load.

In developing Subsection 1.2, the drafting team was aware that eight percent is not the only practical percentage for use. Historically, stakeholders reported successfully using percentages between five and ten whereas others reported being under a regulatory mandate to use eight

2 P0 through P7 refers to the categories of contingencies identified in Table 1 of NERC Standard TPL-001-4, Transmission System Planning Performance Requirements. 3 Previously cited.




percent. To accommodate both positions the team selected the eight percent.

By default, only automatic post-contingency actions including capacity or reactor switchingoc-curring in the studied timeframe are considered when calculating voltage deviation. This would include, among other things, capacitor or reactor switching. For purposes of WR1.2, automatic generally means a programmed response not manually initiated. The intent of the language is that the action be performed within 30 seconds, regardless of how the action is performed.

If the action is completed in more than 30 seconds, regardless of how the action is performed (manual completion versus computerized completion) these should NOT be included in the cal-culations, even if driven by automatic controls as in the example presented.

For P1 there is no high voltage deviation requirement. For P2-P7, there is no low or high volt-age deviation requirement. It is implied that P2 through P7 events don’t require a voltage devi-ation beyond meeting the requirements in WR1.1.2.

For purposes of this document, a BES bus that is serving load is the bus with direct transforma-tion from BES-level voltage to distribution-level voltage that serves load.

The following illustrations apply to WR1.3 and WR1.4, and not WR1.2.

The following diagrams are offered for illustrative purposes. They are not designed to depict all possible variables.




[1.2.] Post-Contingency steady-state low voltage deviation at each applicable BES bus serving load (having no intermediate connection) shall not exceed eight percent8% for P1 events. [Addressing TPL R5]

[1.3.] Transient stability Following fault clearing, the voltage response at applicable BES buses serving load (having no intermediate connection) shall recover to at least 80 percent% of the pre-contingency voltage within 1020 seconds of the initiating event for all P1- through P7 category events., for each applicable BES bus serving load.

1.4 For voltage swings subsequent toFollowing fault clearing and the first voltage recovery above 80%, voltage dips at each applicable BES bus serving load (having no intermediate buses) shall not dip below 70% of pre-contingency voltage for more than 30 cycles or re-main below 80% of pre-contingency voltage for more than two seconds for all P1-P7 cate-gory events.




1.5 For Contingencies without a fault (P2.1 category event), voltage dips voltage at each appli-cable BES bus serving load (having no intermediate buses) shall not dip below 70% of pre-contingency voltage for more than 30 cycles or remain below 80% of pre-contingency voltage for more than two seconds, for all P1 through P7 events.

1.5 For Contingencies without a fault (P2.1 category event), voltage dips at each applicable BES bus serving load shall not dip below 70% of pre-contingency voltage for more than 30 cycles or remain below 80% of pre-contingency voltage for more than two seconds.

Rationale for Requirement WR1.5

Requirement and 1.56

For purposes of this document, a BES bus that is serving load is the bus with direct transformation from BES-level voltage to distribution-level voltage that serves load.

The intent is not intended to require that transient stability simulations be run out to 30-seconds in all the timecases in order to ensure the system is stable and positively damped. Shorter runs are permissible. if it can be shown that applicable criteria can be met within a shorter time frame.

Rationale for Requirement WR1.6:

For purposes of Requirement WR1.6, positive damping in stability analysis is demonstrated by showing that the amplitude of power angle or voltage magnitude oscillations after a minimum of 10 seconds is less than the initial post-contingency amplitude. In any case, results that do not show positive damping within a 30-second time frame are considered to be undamped.

The 30-second window is a general reference and does not refer to any specific time window.

1.6 OscillationsAll oscillations that do not show positive damping within a 30-second time frame30-seconds after the start of the studied event shall be deemed unac-ceptableunstable.

WM1. Each Transmission Planner and Planning Coordinator will have evidence that it used the base criteria in its Planning Assessment specified in Requirement WR1, unless otherwise allowed in accordance with Requirements WR2 and WR3.


Planning Assessment is a NERC defined term. For purposes of Requirement R2,As stated in the requirementPurpose statement, this document applies to all




transmission planning studies applied atconducted within the Western Interconnection level. of the Western Electricity Coordinating Council (WECC).

The rationale for Requirement R2WR2 is to ensure that the each planning entities doentity does not impose more stringent requirements on systems other than their own. It may use more stringent criteria on its own system but may not impose more stringent criteria on others.

Transmission Planners and Planning Coordinators may mutually agree to use study criteria that is more stringent than that described in this document.

WR2. Each TPTransmission Planner and PCPlanning Coordinator that uses more stringent criteria in its Planning Assessmentcriterion than that stated in Requirement WR1 shall apply that criteriacriterion only to its own system, except where otherwise agreed upon by all planning entities included in the Planning Assessmentimpacted planning area.

WM2. Each TPTransmission Planner and PCPlanning Coordinator that uses a more stringent criteria in its Planning Assessmentcriterion than that stated in Requirement WR1 will have evidence that it applied those criteriathat criterion only to its own system, except where otherwise agreed upon by all planning entities included in the Planning Assess-ment.impacted planning area.


The rationale is to ensure equity between planning entities. (Availability of differing criteria is addressed in Requirement WR6.)

WR3. Each Transmission Planner and Planning Coordinator that uses less stringent criteria in its Planning Assessmentcriterion than that stated in Requirement WR1 shall allow other Transmission Planners and Planner Coordinators to have the same impact on that part of the system for the same category of planning events (e.g., P1, P2).

WM3. Each Transmission Planner and Planning Coordinator that uses less stringent criteria in its Planning Assessmentcriterion than that stated in Requirement WR1 will have evi-denced that it allowed other Transmission Planners and Planner Coordinators to have




the same impact on that part of the system for the same category of planning events (e.g., P1, P2).


[4.] Requirement WR4 is designed to establish precautionary markers that when discovered warrant investigation. The Requirement is not intended to imply that the presence of any one ofor more of the bulleted conditions creates a de facto negative impact on reliability.

[5.] The term “cascading”Cascading in Requirement WR4 is not used as the NERC defined term “Cascading.”.

In WR4, Bullet 1, the 125% threshold is imported from the Peak RC System Operating Limits Methodology. The 125% threshold should only be used for facilities where the trip setting is not known. If the trip setting is known that known setting should be used. For example, if the known trip setting is 150% of the continuous rating, this should take precedence over the 125% of the highest rating.

The specific amounts of unrestrained load loss addressed in WR4, bulletBullet three, haveare not been specified. The drafting team suggests that due to in this document. Because of the breadth of the possible permutations, the amount should be left to the sound engineering judgment of the planning entity.

WR4. Each Transmission Planner and Planning Coordinator shall use the following indicatorsminimum threshold criteria to identify the potential for cascadingCascading or uncontrolled islanding:

When a post contingency analysis results in steady-state facility loading that is either in excess of a known BES facility trip setting, or exceeds 125% of the highest applicableseasonal facility rating for the BES facility studied. If the trip setting is known to be higher than the 125% threshold, the known setting should be used.

TransientWhen transient stability voltage response occurs at any applicable BES bus outside of the criteria that is definedstated in Requirement WR1.3 of this document.

IfWhen either unrestrained successive load loss occurs or unrestrained successive generation loss occurs.

WM4. Each Transmission Planner and Planning Coordinator will have evidence that it used the indicators of Requirement WR4 to identify the potential for cascadingCascading or uncontrolled islanding.




Rationale for Requirement WR5:Requirement WR5 addresses “what” must be achieved and does not address “how” to do it.

For a review of “how” to achieve the goals, please refer to:

The WECC Voltage Stability Assessment Methodology WECC Guide to WECC/NERC Planning Standards I.D: Voltage Support and

Reactive Power, Prepared by: Reactive Reserve Working Group (RRWG), Under the auspices of Technical Studies Subcommittee (TSS); Approved by TSS, March 30, 2006

Additional guidance is contained in Section 2.2 Voltage Stability of the Guide to WECC/NERC Planning Standards 1.D, Voltage Support and reac-tive Power, March 30, 2006.

The intent of Requirement WR5 is to ensure the voltage stability of transfer paths as well as the system as a whole during peak load or peak transfer conditions. A margin on real power flow is used as a test for voltage stability. A positive reac-tive power margin can be demonstrated by a valid steady state power flow solu-tion.

Power flow solutions refer to post contingency conditions where the actions of re-active devices should be modeled for the appropriate time frame being studied.

There is a higher likelihood of occurrence of a P0 to P1 category event; therefore, a higher margin (105%) is used. For P2-P7, there is a lower likelihood of occur-rence; therefore, the lower margin (102.5%) is used.

WR5. Each Transmission Planner and Planning Coordinator shall identify voltage stability by maintaining positive reactive power margin at the real power flow defined throughuse the following minimum criteria: when identifying voltage stability:

5WR5.1 All For transfer paths, all P0-P1 events shall demonstrate a positive reactive power margin at a minimum of 105 percent of transfer path flow.

5.2 All P0-P1 events WR5.2 For transfer paths, all P2-P7 events shall demon-strate a positive reactive power margin at a minimum of 102.5 percent of transfer path flow.

WR5.3 For load areas, all P0-P1 events shall demonstrate a positive reactive power margin at a minimum of 105 percent of forecasted peak load.

5.3 All P2-P7 events shall demonstrate a positive reactive power margin at a mini-mum of 102.5 percent of transfer path flow.




5.4 All P2-P7 events WR5.4 For load areas, all P2-P7 events shall demonstrate a positive reactive power margin at a minimum of 102.5 percent of fore-casted peak load.

WM5. Each Transmission Planner and Planning Coordinator will have evidenced that it used the minimum criteria identified in Requirement WR5 to identify voltage stabil-ity.


Requirement WR6 ensures the free flow of information between entities.

WR6. Each Transmission Planner and Planning Coordinator that uses study criteria differ-ent from the base criteria in Requirement WR1 shall make its criteria available upon request.

WM6. Each Transmission Planner and Planning Coordinator that uses study criteria different from the base criteria in Requirement WR1 will have evidence that it made its crite-ria available upon request, as required in Requirement WR6.




Version History

Version Date Action Change Tracking

1 March 6, 2008

WECC Planning Coordi-nation Committee (PCC) approved TPL-(001 thru 004)-WECC-1-CR.

Reliability Subcommittee trans-lates existing WECC compo-nents of NERC/WECC Planning Standards into a CRT.

1 April 16, 2008

WECC Board of Direc-tors (Board) approved

No substantive changes

2 October 13, 2011

PCC approves Clarifies “corridor”

2 December 1, 2011

Board approves No substantive change

2 September 5, 2012

Board approves Approved a nomenclature change from “CRT” to “RBP”

2.1 August 6, 2013

Errata WM2 Measure moved to WM3. WM3 Measure moved to WM4. WM4 Measure moved to WM2.

2.1 December 5, 2013

Board approves On October 8, 2013, the Ballot Pool voted to retire WR1, WR2, WR4 and WR5 of TPL-(012 through 014)-WECC-RBP-2 as of the Effective Date of NERC TPL-001-4. On December 5, 2013, the Board ratified that decision.

2.1 June 24, 2014

Board changed the RBP designation to that of CRT

No substantive change, only designation.

3 Pending




Disclaimer

WECC receives data used in its analyses from a wide variety of sources. WECC strives to source its data from reliable entities and undertakes reasonable efforts to validate the accuracy of the data used. WECC believes the data contained herein and used in its analyses is accurate and reliable. However, WECC disclaims any and all representations, guarantees, warranties, and liability for the information contained herein and any use thereof. Persons who use and rely on the information contained herein do so at their own risk.




Attachments

TBD




Rationale

During development of this document, text boxes were embedded within the body to explain the rationale for various parts of the standard. In the final document the rationale boxes will be relocated to this section and edited into a narrative.



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