Download SPP TPL-007-1 Standard Guidance Document

SPP TPL-007-1 Standard
Guidance Document
November, 2015
SPP Planning
Southwest Power Pool, Inc.
Revision History
Date or Version
Number
Author
Change Description
Comments
11/23/2015
TPL Task Force
First draft
First draft
SPP TPL-007-1 Standard Guidance Document
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Southwest Power Pool, Inc.
Table of Contents
Revision History ...........................................................................................................................................1
Executive Summary .....................................................................................................................................3
Requirements................................................................................................................................................4
R1 .....................................................................................................................................................4
R2 .....................................................................................................................................................4
R3 .....................................................................................................................................................4
R4 .....................................................................................................................................................5
R5 .....................................................................................................................................................6
R6 .....................................................................................................................................................6
R7 .....................................................................................................................................................6
R8 .....................................................................................................................................................7
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Executive Summary
This document outlines the requirements of the North American Electric Reliability Corporation
(NERC) TPL-007-1 standard and the breakdown of responsibilities between SPP, as the Planning
Coordinator, and its members, as Transmission Planners. A more detailed look into SPP’s
implementation of TPL-007-1 can be found in the three scope documents posted on spp.org: Steady
State, Stability, and Short Circuit.
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Requirements
R1
Requirement R1: Each Planning Coordinator, in conjunction with its Transmission Planner(s), shall
identify the individual and joint responsibilities of the Planning Coordinator and Transmission
Planner(s) in the Planning Coordinator’s planning area for maintaining models and performing the
study or studies needed to complete GMD Vulnerability Assessment(s).
SPP, as a Planning Coordinator, meets the requirements of R1 through the SPP MDWG model
building process. Transmission Planners under the SPP Planning Coordinator footprint meet the
requirements of R1 by participating in the SPP MDWG model building process.
The SPP MDWG model building process is performed in accordance with the applicable NERC
Modeling, Data, and Analysis (MOD) Standards.
R2
Requirement R2: Each responsible entity, as determined in Requirement R1, shall maintain System
models and GIC System models of the responsible entity’s planning area for performing the study or
studies needed to complete GMD Vulnerability Assessment(s).
SPP, as a Planning Coordinator (PC), and the Transmission Planners (TP) meet the requirements of
R2 by using current or qualified past studies1, documented assumptions, and documented
summarized results of the steady state, short circuit, and Stability analyses in the annual Planning
Assessment of the entity’s portion of the BES.
These analyses include:
1. Steady state analysis of the Near-Term Transmission Planning Horizon
2. Steady state analysis of the Long-Term Transmission Planning Horizon
3. Short circuit analysis of the Near-Term Transmission Planning Horizon
4. Stability analysis of the Near-Term Transmission Planning Horizon
5. Stability analysis of the Long-Term Transmission Planning Horizon
When the analysis indicates an inability of the System to meet the performance requirements in
Table 1, the Planning Assessment will include Corrective Action Plan(s) (CAP) addressing how the
performance requirements will be met. TPL-007-1 R2.7.1 provides examples of CAPs.
R3
Requirement R3 describes the requirements for steady state studies and Requirement R4
explains the requirements for stability studies. Requirement R3 and Requirement R4 also require
that simulations duplicate what will occur in an actual power system based on the expected
performance of the protection systems. Requirement R3 and Requirement R4 also include new
1
TPL-007-1 R2.6
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parts that require the planners to conduct an evaluation of possible actions designed to reduce
the likelihood or the consequences of extreme events that cause cascading.2
SPP, as a Planning Coordinator (PC), and the Transmission Planners (TP) meet the requirements of
R3 by performing steady state studies for the Near-Term and Long-Term Transmission Planning
Horizons.
Studies will be performed for planning events to determine whether the BES meets the performance
requirements in Table 1 based on the Contingency list created in Requirement R3.4 and R3.5. If the
study concludes there is Cascading caused by the occurrence of Table 1 extreme events, a CAP will
be formulated.
The studies will also simulate the removal of all elements that the Protection System and other
automatic controls are expected to disconnect for each Contingency without operator intervention.
The powerflow solution method will allow for automatic controls to be enabled (phase-shifting
transformers, load tap changing transformers, and switched capacitors and inductors).
R4
Requirement R3 describes the requirements for steady state studies and Requirement R4
explains the requirements for stability studies. Requirement R3 and Requirement R4 also require
that simulations duplicate what will occur in an actual power system based on the expected
performance of the protection systems. Requirement R3 and Requirement R4 also include new
parts that require the planners to conduct an evaluation of possible actions designed to reduce
the likelihood or the consequences of extreme events that cause cascading.3
SPP, as a Planning Coordinator (PC), and the Transmission Planners (TP) meet the requirements of
R4 by performing Stability studies for the Near-Term and Long-Term Transmission Planning
Horizons.
Studies will be performed for planning events to determine whether the BES meets the performance
requirements in Table 1 based on the Contingency list created in Requirement R4.4 and R4.5. If the
study concludes there is Cascading caused by the occurrence of Table 1 extreme events, a CAP will
be formulated.
The dynamic solution method will simulate the expected automatic operation of existing and
planned devices designed to provide dynamic control of electrical system quantities when such
devices impact the study area. (Generation exciter control and power system stabilizers, static var
compensators, power flow controllers, and DC Transmission controllers).
2
3
FERC Order 786, page 10
FERC Order 786, page 10
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R5
Requirement R5: Requirement R5 deals with voltage criteria and voltage performance. NERC
proposes in Requirement R5 that each transmission planner and planning coordinator must
have criteria for acceptable system steady state voltage limits, post-contingency voltage
deviations, and the transient voltage response for its system. For transient voltage response the
criteria must specify a low-voltage level and a maximum length of time that transient voltages
may remain below that level. This requirement will establish more robust transmission planning
for organizations and greater consistency as these voltage criteria are shared.4
SPP, as a Planning Coordinator (PC), and the Transmission Planners (TP) meet the requirement R5
by adhering to the SPP Criteria5 and the documented SPP Disturbance Performance Requirements.6
R6
Requirement R6: Specifies that an entity must define and document the criteria or methodology
used to identify system instability for conditions such as cascading, voltage instability, or
uncontrolled islanding within its planning assessment.7
SPP, as a Planning Coordinator (PC), and the Transmission Planners (TP) meet the requirement R6
by using the established SPP Disturbance Performance Requirements document which includes rotor
angle damping and transient voltage recovery requirements.
R7
Requirement R7: Mandates coordination of individual and joint responsibilities for the planning
coordinator and the transmission planner which is intended to eliminate confusion regarding the
responsibilities of the applicable entities and assures that all elements needed for regional and wide
area studies are defined with a specific entity responsible for each element and that no gaps will
exist in planning for the Bulk-Power System.8
For each of the studies (Steady State, Stability, and Short Circuit) required for compliance with TPL007-1, the following responsibilities are identified between the TP and PC:
1. Development and Approval of Study Scope
a. The SPP PC will develop and submit a study scope to the Transmission Working
Group (TWG).
b. The TWG, on behalf of the TP, will review, provide feedback, and approve the study
scope.
2. Request Data
4
FERC Order 786, page 10-11
SPP Criteria 3.3 and 12.3.2 page 20, 159
6
SPP Disturbance Performance Requirements
7
FERC Order 786, page 11
8
FERC Order 786, page 11
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a. The SPP PC will send to TP any necessary data requests required to perform the work
defined in the approved scope.
b. The TP will provide the requested data.
3. Perform Analyses
a. The SPP PC will perform the analysis.
b. The TP may elect to perform additional analysis in support of the TP’s individual
Planning Assessment.
4. Review Results and Provide Feedback
a. The SPP PC will send preliminary study results to the TP for review and feedback.
b. The TP will review the preliminary study results and provide feedback to the SPP PC.
c. The SPP PC will review TP provided feedback and perform any additional analysis
required.
5. Document Results and Develop Report
a. The SPP PC will document the final study results and prepare an annual Planning
Assessment of its portion of the BES for submittal to the TWG for review and
approval.
b. The TWG, on behalf of the TP, will review and approve the SPP PC’s Planning
Assessment.
c. Each TP will prepare an annual Planning Assessment of its portion of the BES
utilizing the results of its own studies, SPP PC studies, or a combination of the two.
R8
Requirement R8: Addresses the sharing of planning assessments with neighboring systems. The
requirement ensures that information is shared with and input received from adjacent entities
and other entities with a reliability related need that may be affected by an entity’s system
planning.9
SPP, as a Planning Coordinator (PC), and the Transmission Planners (TP) meet the requirement R8
by sharing its Planning Assessment results with adjacent PCs and TPs.
9
FERC Order 786, page 11
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