Long-term Planning and TPL TP Workshop November 2, 2017

Long-term Planning and TPL-001-4 TP Workshop November 2, 2017
Jay Loock Senior Compliance WECC Auditor Western Electricity Coordinating Council

Western Electricity Coordinating Council
Agenda Review learning objectives Reliability and Compliance Overview of Transmission Planning Components of a Transmission Planning Assessment Key elements for a proper compliance approach Q&A Western Electricity Coordinating Council

Learning Objectives Provide a high level overview of the Transmission Planning process Identify specialized knowledge required in evaluating compliance with TPL (Transmission System Planning Performance Requirements) Based on available information, apply fact-based analysis to determine effectiveness of an entity’s Planning Assessment in supporting the purpose of the Standard Western Electricity Coordinating Council

Reliability and Compliance
Prevent future non-compliances that could result in harm to the BES. How do we help registered entities become high-performing, high-reliability companies? Understanding entity risk and how that risk is mitigated Understanding entity’s internal controls Compliance Monitoring tools allow backwards look to address violations that have occurred Focus should still be on reliability and preventing similar future non-compliances Western Electricity Coordinating Council

Operations Planning vs. Transmission Planning
Roles and Functions Operations Planning Model current state of the system Perform single element (N-1) contingency analysis (RTCA) Ensure operating criteria is respected Develop Operating Procedures as needed Keep the Lights ON! Transmission Planning Model future state of the system Perform single and multiple element contingency analysis Power flow, voltage stability, generator dynamics Respect planning criteria Propose System Upgrades! Western Electricity Coordinating Council

Operating vs. Planning Horizons
Western Electricity Coordinating Council

Who Does Transmission Planning?
Transmission Planner (TP): The entity that develops a long-term (generally one year and beyond) plan for the reliability (adequacy) of the interconnected bulk electric transmission systems within its portion of the Planning Authority area. Planning Coordinator (or Planning Authority (PA)): The responsible entity that coordinates and integrates transmission Facilities and service plans, resource plans, and Protection Systems. In WECC: 35 PAs and 51 TPs Western Electricity Coordinating Council

Transmission Planning Responsibilities
10 Year Plan Develop Long Term Plan (5 or 10 years) Planning Studies Generator Interconnection Requests End-Use Customers (new load, Municipals, Co-ops, etc.) Long Term Needs Assessments (scenarios) Expansion Plan Evaluations (prove concept, comparisons) Merchant Transmission Economic / Congestion mitigation TPL Compliance Modeling the Transmission System (develop, maintain) Western Electricity Coordinating Council

Project Development Transmission System Design (input) Transmission Line Sizing Substation Layouts Protections Systems Project Approvals Proposals to Company Management Regional Planning Committees External Stakeholders (public, local, state commissions) Support Permitting (environmental, federal, etc) Western Electricity Coordinating Council

Other Areas of Responsibility Facility Ratings (including methodology) Coordinate with Neighboring Transmission Planners Support Transmission Operations System Transfer Capability System Operating Limits (SOLs) Special Protection Systems (SPS or RAS) Resource Adequacy Western Electricity Coordinating Council

Key components of transmission planning: Modeling Selecting the cases Running the studies Developing the corrective action plans Western Electricity Coordinating Council

MODELING Modeling Scenarios Studies Western Electricity Coordinating Council

Modeling Modeling of power system components Synchronous generators Power transformers Transmission lines and cables Characteristics of the loads Capacitors, inductors, and SVCs Induction motors Wind generation Discuss modeling of components at a high level. Tie to R1 of TPL-001-4 Western Electricity Coordinating Council

Aspects of Model Validation
Component Model Validation Performed for a single power system element (e.g. generator, governor) Based on staged testing and data recording System Model Validation Conditions in power system model are adjusted to match actual power system conditions (e.g. tie flows, generation dispatch) Principally based on recorded events Western Electricity Coordinating Council

Modeling Load Transmission Line Transformer Generator Western Electricity Coordinating Council

Modeling Predicting unit/system performance & identifying operational problems Is there oscillations between units or between areas under certain contingencies? Is there a risk of instability and/or unit trip? System Design Design of load-shedding scheme – inertias/governors are critical Assessment of stability limits & identification of need for new facilities Post-mortem studies Western Electricity Coordinating Council

Modeling Data Standard
Component Model Validation Standards MOD — Verification and Data Reporting of Generator Real and Reactive Power Capability and Synchronous Condenser Reactive Power Capability MOD — Verification of Models and Data for Generator Excitation Control System or Plant Volt/Var Control Functions MOD — Verification of Models and Data for Turbine/Governor and Load Control or Active Power/Frequency Control Functions System Model Validation MOD — Steady-State and Dynamic System Model Validation Western Electricity Coordinating Council

WECC Modeling Work Groups/Task Force
Modeling and Validation Work Group (MVWG) Reviews, recommends, develops, and validates system models for use in the WECC system studies. Renewable Energy Modeling Task Force (REMTF) Leads the effort to develop generic, non-proprietary models for planning studies. GE PSLF/PTI/PW Users Work Groups Ensures the WECC power flow and stability computer programs meet the needs of the users Western Electricity Coordinating Council

Modeling FERC Order 890 Directive: Paragraph 290: incorporate periodic review and modification of models, with certain criteria FERC Order 693 Directives: Paragraph 1210: require models be validated against actual system responses Paragraph 1211: require actual system events be simulated and if model output is not within the accuracy required, the model shall be modified to achieve the necessary accuracy Paragraph 1220: require actual system events be simulated and dynamics system model output be validated against actual system responses Western Electricity Coordinating Council

Modeling Why is model validation and verification important in context of TPL-001-4: Accurate power system element models Use of the model that best represents the machine / equipment Use of accurate and validated parameters in each model Accurate power system area models Use of accurate and validated interconnection wide, or PC area model Scenario and system state Assessments include various loading conditions (e.g. light-load, winter, summer) Generator availability (e.g. maintenance outages of generators or transmission lines) Accurate modeling of wind/solar or any other inverter based technologies Western Electricity Coordinating Council

Modeling Existing and planned generation and transmission facility availability and representation. Generation retirements are incorporated into the cases. Did the entity use interconnection-wide cases or did they build the PC area? Verification of consistency and coordination with neighboring areas. Cross checks between short-circuit and steady-state cases. Availability of dynamic models for generating facilities; such as governor models and limiters. Which load model is utilized to represent the dynamic behavior of loads, and why did the entity select this load model? Western Electricity Coordinating Council

Questions and Answers Western Electricity Coordinating Council

SCENARIOS Modeling Scenarios Studies Western Electricity Coordinating Council

Scenarios Peak Load Cases Studies required for Year One or year two, and year five What is the entity’s rationale for selecting Year One or year two? It may be appropriate to evaluate both years if there are known issues. Summer or winter Peak Load cases may be used depending on location Did the entity evaluate summer and winter peak? Generator capacity and thermal Equipment Ratings are usually lower in summer due to higher ambient temperature. Load distribution may vary from summer to winter. Off-Peak Load Cases Studies required for one of Year One through year five What is the entity’s rationale for selecting the year and conditions? There may be known off-peak operating issues that warrant analysis. Generation dispatch can vary widely in off-peak cases. Western Electricity Coordinating Council

Scenarios Long-Term Transmission Planning Horizon Peak Load Cases Studies required for one of year six through year ten with rationale for why the year was selected. How does the entity deal with uncertainty in these cases? Load growth is unpredictable for this horizon. Most projects are not planned this far out. New technologies may be introduced to the System. If past studies are utilized, is this done for convenience or reliability? Use of year ten may allow the analysis to be a qualified past study for up to four more years. No requirements for rationale for why the year was selected, but a rationale inferring convenience should be challenged. Western Electricity Coordinating Council

Scenarios Sensitivity Cases Used to demonstrate impact of changes to assumptions in the model. Entities are required to vary at least one of the conditions listed in TPL Part How did the entity select which conditions to vary? Should be valid and realistic scenarios. Could be related to credible past or prospective future thermal loading, steady state voltage, voltage/angular stability or other operating conditions. Did the entity vary more than one condition? Best practice is to vary any condition where there is uncertainty in the assumption. Were conditions varied by a sufficient amount to stress the System? Goal is to identify issues on the System. Western Electricity Coordinating Council

Questions to Consider Are you winter or summer peaking? Do you have renewables on or around your system and what unique issues does that create? Are there light load conditions that create unique results or overloads? How do you determine system transfers in your cases? Have you experienced transfer scenarios that create operational challenges and are those included in the model(s)? Are all improvements certain? Have negative impacts been identified if they are delayed? Western Electricity Coordinating Council

STUDIES Modeling Scenarios Studies Western Electricity Coordinating Council

Planning Events Table 1- Steady State & Stability Performance
Category P0 through P7 (no contingency, single contingency and multiple contingency) Event Loss of generator, transmission circuit, transformer, shunt device, DC line, bus, breaker Fault Type 3 phase, SLG BES Level Extra high voltage (EHV) [>300 kV], high voltage (HV) [< 300 kV] Interruption of Firm Transmission Service Non-consequential Load Loss Allowance Western Electricity Coordinating Council

Transmission Planning Performance Requirements
Western Electricity Coordinating Council

Transmission Planning Performance Requirements Western Electricity Coordinating Council

Extreme Events Table 1 – Steady State & Stability Performance
Loss of two elements (no system adjustments) Local area events affecting Transmission System Loss of tower line with 3 or more circuits; Loss of all lines on a common ROW; Loss of a switching station of substation; Loss of all units at a generating station; Loss of a large load or load center Wide area effects resulting in loss of two generating stations due to: Gas pipeline; Cooling water source; Wildfires; Severe weather; Cyber attack; Nuclear plants similar design problem Stability Single element forced out, then 3 phase fault on another element prior to system adjustments Three phase fault on an element with a stuck breaker or relay failure resulting in delayed fault clearing Western Electricity Coordinating Council

Point out section 3 and 12

Questions to Consider Does your assessment cover all scenarios required in the Standard? Does your assessment contain studies performed in regional planning groups? Does your assessment include and study facilities outside of your planning area? How did you determine how far out to monitor? How do you ensure all the required contingencies where simulated in your studies? What determines the N-1 scenarios in your studies? What determines the N-2 and greater scenarios in your studies? Western Electricity Coordinating Council

Results from Studies Studies Scenarios Modeling System Deficiencies CAP Western Electricity Coordinating Council

Solutions/Corrective Actions Plans
Corrective Action Plan (CAP) During then planning process, when the analysis indicates an inability of the system to meet the required performance, Corrective Action Plans need to address how the required performance will be met. Examples of CAPs include but are not limited to: Building a new transmission line Replacing circuit component(s) (conductor, CT, breakers, jumpers, etc.) Adding reactive resources (capacitor banks, Static Var Compensators) Reconfiguring the system Use of operating procedures Western Electricity Coordinating Council

Solutions/Corrective Actions Plans
When reviewing Corrective Action Plans it’s important to understand the following: Does the solution / CAP address the issue that was initially identified? Does the in-service date meets the need date? Does the solution / CAP introduce new issues? Do prior CAP need to be changed or modified? While the auditors are not going to be performing independent verification its about understanding the entity’s process Example Western Electricity Coordinating Council

Questions to Consider Questions to the entity: How do you ensure your CAP addresses the issues? How do you track changes that may arise between in-service dates and the need dates? How do track CAPs in process? How do ensure no issues are identified without a CAP? Questions the auditors can ask themselves: Do the entity’s processes robust enough to capture a CAP for all system deficiencies? Does the entity’s processes lead to adequate CAPs that address the need by when it is required? How does the entity address a difference between the need date and in-service date for a CAP that was identified in a prior assessment? Western Electricity Coordinating Council

TPL-001-4 Studies Scenarios Modeling System Deficiencies CAP Western Electricity Coordinating Council

TPL-001-4 (Transmission System Planning Performance Requirements) Purpose: Establish Transmission system planning performance requirements within the planning horizon to develop a Bulk Electric System (BES) that will operate reliably over a broad spectrum of System conditions and following a wide range of probable Contingencies. Applicability: Planning Coordinator, Transmission Planner Western Electricity Coordinating Council

TPL introduces significant revisions and improvements: ‘Raises the bar’ in several performance areas Loss of Non-Consequential Load or interruption of firm transfers not allowed for certain events Distinct Requirements for Steady State (Power Flow) and Stability Analysis New Requirements for Modeling and Short Circuit testing New Requirements to develop specific planning criteria or methodology Western Electricity Coordinating Council

Understanding the entity’s overall planning program The auditor(s) should have a basic understanding of the entity’s “Overall Planning Program.” This can be accomplished by reviewing past audits that included the TPL standards in the scope of the audit(s) or by reviewing the most current TPL Planning Assessment(s). If the assessment(s) do not clearly address the requirements a data request or interviews may be required with the TPL SMEs. Western Electricity Coordinating Council

Questions to Consider Entities are involved (neighboring TPs / regional planning groups / meetings with internal departments) in helping create your entity’s planning assessments? (R7 and R4.4.1) What are the timelines to meet the annual requirements of the assessment(s)? Who internally and externally reviews the assessments prior to a finished product? After a completed Planning Assessment is established, with whom do you share the document(s)? (R2 and R8) How are base cases developed and modified to create applicable planning cases to meet the light and heavy load requirements of the standard for both the near-term and the long-term transmission planning horizon? (R2) Western Electricity Coordinating Council

Questions to Consider How are sensitivity cases determined and developed in the Near-Term Planning Horizon? (2.14) How do you incorporate reoccurring constrained scenarios experienced from operations under market dispatches (firm and non-firm transfers) in developing your sensitivity cases? Describe your spare equipment strategy. What studies were performed when your entity is expected to experience the possible unavailability of the long lead time equipment? (2.1.5) Describe the short circuit analysis portion of your Planning Assessment. (R2.3) What were the results and corrective action plan(s)? (R2.8) Were these studies and corrective action plans shared with other departments in the company? Western Electricity Coordinating Council

Questions to Consider In the Long-Term Transmission Planning Horizon portion of the Stability analysis of your Planning Assessment how do you address the impact of proposed material generation / transmission additions or changes in that timeframe and are supported by current or past studies? What is your rationale for determining material changes? (R2.5) What is your study criteria for acceptable system steady state voltage limits, post-contingency voltage deviations, and the transient voltage response for your System? How do you determine from planning studies the inability of your system to meet performance criteria? (R5) Western Electricity Coordinating Council

Questions to Consider Where is your definition and documentation within your Planning Assessment, the criteria or methodology used in the analysis to identify your system’s instability for conditions such as Cascading, voltage instability, or uncontrolled islanding? (R6) What is your approach to Corrective Action Plan(s) when system performance is not achieved? (R2.7) How do you determine extreme events for your studies? (R3.2) How do you simulate protection systems and other automatic controls in your studies? (R3.3) Western Electricity Coordinating Council

Corrective Action Plan(s)
Be reviewed in subsequent annual Planning Assessments for continued validity and implementation status of identified System Facilities and Operating Procedures. Western Electricity Coordinating Council

Questions to Consider How do you simulate the expected automatic operation of existing and planned devices that are designed to provide steady state control of electrical systems such as phase-shifting transformers, load tap changing transformers, switched capacitors and inductors and other devices that could impact your study area? (R3.3.2) Western Electricity Coordinating Council

Long-term Planning and TPL TP Workshop November 2, 2017

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Long-term Planning and TPL TP Workshop November 2, 2017

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