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Transmission System Modeling Data Requirements and Reporting Procedures

In Accordance with NERC’s MOD-032-1 Reliability Standard “Data for Power System Modeling and Analysis”

Prepared by: Vito De Luca, Eng. Effective date: July 1, 2015 Revision: 1

Hydro-Québec TransÉnergie

Table of Contents

1. Objective ............................................................................................................................. 5

2. Power System Modeling .................................................................................................... 6 2.1 Power flow and Dynamics Case Building ........................................................................................6 2.2 Functional Entities within the Québec Interconnection ....................................................................6 2.3 Power System Modeling Workflow and Processes ..........................................................................8

2.3.1 Power System Modeling Workflow ......................................................................................8 2.3.2 Description of Power System Modeling Activities .............................................................10 2.3.3 Case Building Timeline.......................................................................................................11

3. Modeling of Generating Facilities ....................................................................................12 3.1 Modeling Data Requirements .........................................................................................................12

3.1.1 Steady-State Data Requirements for Generator Modeling ..................................................13 3.1.2 Short-Circuit and Dynamics Data Requirements for Generator Modeling .........................14

3.2 Reporting Procedures .....................................................................................................................17 3.2.1 Data Format .........................................................................................................................17 3.2.2 Data Submission Procedure and Schedule ..........................................................................18

4. Transmission System Equipment ....................................................................................19 4.1 Modeling Data Requirements .........................................................................................................19

4.1.1 Transmission System Equipment Steady-State Data Requirements ...................................20 4.1.2 Transmission System Equipment Short-Circuit and Dynamics Data Requirements ..........23

4.2 Reporting Requirements .................................................................................................................25 4.2.1 Data Format .........................................................................................................................25 4.2.2 Data Submission Procedure and Schedule ..........................................................................26

5. Modeling of Aggregate Demand ......................................................................................27 5.1 Modeling Data Requirements .........................................................................................................27

5.1.1 Steady-State Data Requirements for Demand Modeling ....................................................27 5.1.2 Short-Circuit and Dynamics Data Requirements for Demand Modeling ...........................29

5.2 Reporting Procedures .....................................................................................................................29 5.2.1 Data Format .........................................................................................................................29 5.2.2 Data Submission Procedure and Schedule ..........................................................................29

6. Complementary Power System Information ...................................................................30 6.1 Resource Planning Data..................................................................................................................30

6.1.1 Resource Planning Data Requirements ...............................................................................30 6.1.2 Data Format .........................................................................................................................30 6.1.3 Data Submission Procedure and Schedule ..........................................................................30

6.2 Interchange Schedule ......................................................................................................................30 6.2.1 Interchange Data Requirements ..........................................................................................31

6.2.2 Data Format ........................................................................................................................ 31 6.2.3 Data Submission Procedure and Schedule ......................................................................... 31

7. Data Submission Procedure and Schedule .................................................................... 32 7.1 Data Submission Procedure ........................................................................................................... 32 7.2 Data Submission Schedule ............................................................................................................. 33 7.3 Compliance Violations................................................................................................................... 34

REFERENCES ............................................................................................................................. 35

APPENDIX 1 – Load Data Reporting Templates ....................................................................... 36

APPENDIX 2 – List of Approved Dynamics Models .................................................................. 37 A2.1 Standard Library Models .................................................................................................................. 37 A2.2 Approved User-Defined Models ....................................................................................................... 41

APPENDIX 3 – Examples of Siemens-PTI PSS/E Model Library Data sheets ......................... 43

APPENDIX 4 – Generator Modeling Data Reporting Template ................................................ 44

APPENDIX 5 – HQT Bus Numbering and Classification ........................................................... 45 A5.1 Bus Number Ranges ......................................................................................................................... 45 A5.2 NPCC Area Codes ............................................................................................................................ 46 A5.3 Québec Interconnection Zoning Codes ............................................................................................ 46

APPENDIX 6 – Interchange Data Template ............................................................................... 49


Transmission System Modeling Data Requirements and Reporting Procedures 5

1. Objective

Hydro-Québec TransÉnergie (HQT), in its role as Planning Coordinator and Transmission Planner, is charged with the task of maintaining transmission system models (steady-state, dynamics, and short-circuit) and developing power flow and dynamics cases necessary to support planning studies and reliability analysis of Québec’s interconnected transmission system. The accuracy of system models is heavily dependent on the reliability of modeling data collected from the various functional entities that interface with the transmission system.

The purpose of this document is to establish steady-state, dynamics, and short-circuit modeling data requirements and reporting procedures, in accordance with NERC’s MOD-032 reliability standard, “Data for Power System Modeling and Analysis”. The document shall serve as a reference guide to all functional entities that provide data necessary for system modeling, providing the basic requirements regarding the type of data required as well as applicable data submission procedures. It will also describe how entities shall reference and use existing HQT technical documents and procedures to meet modeling data requirements.

The most updated version of the present document shall be made available to all concerned functional entities by means of an online posting on HQT’s website, via the following link:

http://www.hydroquebec.com/transenergie/en/modeling.html.

http://www.hydroquebec.com/transenergie/en/modeling.html



2. Power System Modeling

Power flow and dynamics cases are developed by the Planning Coordinator (PC) in order to realistically simulate the steady-state and dynamic performance of the Québec interconnected transmission system. All electrical elements that comprise the transmission system, such as generating units, power lines, transformers, reactive power compensation equipment, and system loads, are modeled based on measured electrical parameters (modeling data) provided by various functional entities within or connected to the transmission system.

2.1 Power flow and Dynamics Case Building

Power flow and dynamics cases are developed using the Siemens Power Technologies Inc. (PTI) Power System Simulator for Engineers (PSS/E) simulation software. A power flow case is a collection of steady-state models of generation, transmission system equipment and topology, short-circuit data, load, dispatch, and interchanges that constitute a snapshot of the selected set of operating conditions. A dynamics case is a collection of dynamic models used in conjunction with a power flow case to perform stability analysis of system performance.

The PC develops a series of power flow and dynamics cases (also referred to as base cases) on an annual basis, reflecting various system conditions and planning scenarios. These cases are used by the PC and Transmission Planners (TPs) for system studies and reliability analysis. They are also used by the NPCC through its SS-37 Working Group on Base Case Development. Consequently, the accuracy of studies and reliability of base cases are heavily dependent on the quality of modeling data collected from functional entities.

The PC’s annual case building exercise is a structured and detailed process, which is explicitly outlined in HQT’s base case building manual document entitled “Mise à jour des réseaux planifiés” as well as in NPCC’s C-29 Document entitled “Procedures for System Modeling: Data Requirements & Facility Ratings”, available at https://www.npcc.org/Standards/Procedures/c-29.pdf.

2.2 Functional Entities within the Québec Interconnection

The functional entities, as per MOD-032-1 (part A, section 4.1 “Applicability”), that play key roles in obtaining, submitting, validating, and maintaining modeling data within the Québec Interconnection are defined in the following table.

https://www.npcc.org/Standards/Procedures/c-29.pdf

https://www.npcc.org/Standards/Procedures/c-29.pdf



Table 1 – Functional Entities within the Québec Interconnection

Functional Entities Names of Organization(s) Role in Power System Modeling

Generator Owners (GO) • Canadian Hydro Developers Inc. • Cartier Wind Energy Inc. • Domtar Inc. • Énergie éolienne Le Plateau s.e.c.

(Invenergy Wind LLC) • Énergie La Lièvre s.e.c. (Brookfield

Renewable Power) • Hydro-Québec Production (HQP) • Hydro-Saguenay • Manicouagan Power Limited Partnership

(SCHM) • NextEra Energy Resources (FPL Group) • Northland Power Inc. • Rio Tinto Alcan (RTA) • Rolls-Royce Canada Limited • TransCanada Québec Inc. • All other privately owned hydroelectric,

biomass and fossil fuel generating stations, and windfarms

Provides modeling data for generating units and generation outage information.

Load Serving Entity (LSE)

• Hydro-Québec Distribution (HQD) Provides aggregate demand modeling data.

Planning Authority/Coordinator (PC)

• HQT – Direction - Planification Responsible for Interconnection-wide base case building and modeling data maintenance (data storage).

Resource Planner (RP) • Hydro-Québec Distribution (HQD) Provides generator dispatching information based on load-side contractual obligations.

Transmission Owners (TO)

• Arcelor Mittal Montréal • Canexus Chemicals Canada Limited

Partnership • Cedars Rapids Transmission Co. (CRT) • Énergie éolienne Le Plateau s.e.c.

(Invenergy Wind LLC) • Énergie La Lièvre s.e.c. (Brookfield

Renewable Power) • HQT – Direction Principale – Exploitation des

installations • Kruger Inc. (Trois-Rivières) • Manicouagan Power Limited Partnership

(SCHM) • PPG Canada Inc. • Rio Tinto Alcan (RTA)

Provides modeling data and outage information of transmission system equipment.



Transmission Planners (TP)

• HQT – Direction - Planification Users of base cases for system studies.

Transmission Service Providers (TSP)

• HQT - Direction – Commercialisation et affaires règlementaires

• Cedars Rapids Transmission Co. (CRT)

Provides transmission service customer contract data (point-to-point transmission service details) as published on OASIS.

2.3 Power System Modeling Workflow and Processes

2.3.1 Power System Modeling Workflow

The PC’s annual exercise of developing reliable base cases is an intricate process requiring active inter-organizational collaboration from all function entities.

The following figure illustrates a general overview of how the functional entities listed above shall interact in regards to the submittal and processing of modeling data within the Québec Interconnection.



Figure 1 – Planning Coordinator Modeling Data Workflow



2.3.2 Description of Power System Modeling Activities

As illustrated above, power system modeling is comprised of a sequence of modeling data submission, validation and processing activities required to produce interconnection-wide base cases suitable for system studies. Modeling data is collected from various functional entities, validated to ensure functionality and compatibility with simulation tools, and then entered into specific data bases for referencing and base case building.

Essentially, case building is achieved based on the following inputs:

1. Steady-state and Short-circuit Modeling Data from PSS® Model on Demand (MOD) Database

The MOD database consolidates all generation and transmission system steady-state and short-circuit modelling data (including planned future projects) collected from various functional entities in a central data repository. MOD is synched with DSR, the PC’s main equipment data base containing updated modeling data of all existing generating and transmission system facilities, producing a MOD base case scenario in PSS/E format (.sav). Future projects, consisting of generation or transmission system additions, upgrades or modifications, are submitted to the PC by TPs and stored in MOD. They are then applied to the MOD base case scenario, allowing the PC and TPs to customize planning cases for any desired future point in time.

Corrections or modifications to modeling data for existing facilities are validated before data is updated in the DSR database. In the case of future projects, preliminary modeling data submitted by GOs, TOs and TPs are entered directly into MOD, after model validation by the PC. New generating units or transmission system equipment are only added to DSR after project commissioning and after the PC has received all updated modeling data. This updated data is obtained from GOs and TOs at the later stages of the project commissioning phase.

2. Dynamics Models and Modeling Parameters

Validated dynamics models and modeling parameters of existing facilities and future projects collected from GOs, TOs and TPs are stored in the PC’s dynamics library. The PC’s dynamics library consists of all dynamics model files required to run dynamics simulations in PSS/E (*.lib, *.obj, *.dll, etc.), source code files for certain user-defined models, dynamics parameters in the form of DYR files, and any IDEV or PYTHON programs necessary to set up dynamics simulation parameters.

3. Aggregate Demand Data

Once aggregate demand data for each load-serving bus is received from the LSE, the PC validates and processes the data, mapping load data to the appropriate load serving buses in the MOD base case. The validated data is then stored in the PC’s Load Forecast Database which is used to produce load profiles for a given forecast year in the form of PYTHON



automation files. These files are applied to the MOD base case scenario to produce customized planning cases for any desired future point in time.

4. Resource Data

The RP, in collaboration with GOs, provide the PC with data regarding all available resources needed to fulfill LSE demand requirements. This allows the PC to produce realistic generation dispatch scenarios, adequately balancing load and generation.

5. Interchange Data from TSPs

When preparing a base case scenario, the PC must consider scheduled MW transfer levels at each inter-area interconnection facility. Interchange data used in base case building is based on transmission service customer contract data (point-to-point transmission service details) as published on OASIS, as well as the NPCC Interchange Schedule prepared annually by NPCC’s SS37 work group.

6. Equipment Outage Information

Planned maintenance or commissioning of generating units and transmission system equipment resulting in outages must be considered in base case development. Short-term generator outages are reported to the PC by GOs and transmission system equipment outages are reported by the TOs.

2.3.3 Case Building Timeline

The modeling data produced by the power system modeling activities described above are assembled during case building according to the timeline illustrated in the following figure.

Figure 2 - Case Building Timeline

June 1st

Phase 1 of Load Data Collection

(Winter Peak)

October 1st Phase 2 of Load Data Collection

(All data)

January 15th

Start of Annual Case Building

Exercise

February 1st

Generation Modeling Data

Collection

March 1st

Reporting deadline for new future projects and

modifications to existing modeling data (DSR & MOD)

April 1st

Integration of complementary power

system information (Outage, resource

allocation and Interchange data)

May 1st

Delivery of finalized

Power flow and dynamics

base cases



3. Modeling of Generating Facilities

3.1 Modeling Data Requirements

All Generator Owners (GOs) connected to the Québec interconnected transmission system must provide valid modeling data of existing and future generating units to the PC on an annual basis.

The PC also requires GOs of existing facilities to recertify generator modeling data on an annual basis, either by resubmitting all required modeling data or by certifying that data has not changed from the previous year’s data submission. In the case of changes to modeling data, GOs must clearly identify all changes and submit all modified modeling data in accordance with the requirements herein.

For new or future planned generating units, generator modeling data shall be submitted 1) during the project’s planning phase, normally 3-5 years prior to commissioning, and 2) immediately after project commissioning.

1- Project Planning Phase Data

The PC and TPs initially collect approximated generator modeling data from new and prospective GOs in order to conduct interconnection or system impact studies prior to commissioning of generating facilities. This preliminary data is submitted to the PC and TPs in conjunction with GOs’ request for system impact studies, as described in section 3 of HQT’s technical requirements document and in HQT’s Procedure document for the connection of new generating units, available (in French) on HQT’s website at:

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/demarche-a-suivre-2012.pdf.

2- Post-commissioning Data

GOs shall update the preliminary data provided to the PC and TPs during the project planning phase by providing actual or measured modeling parameters. GOs must conduct data validation testing in order to validate modeling data as well as demonstrate that their facilities meet the requirements set out in the document “Transmission Provider Technical Requirements for the Connection of Power Plants to the Hydro-Québec Transmission System”, available on HQT’s website at:

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/exigence_raccordement_fev_09_en.pdf.

The validation procedures and testing for wind farms are outlined in HQT’s “General Validation Test Program for Wind Power Plants Connected to the Hydro-Québec Transmission System” document, available on HQT’s website at:

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/essais-eoliennes2011-en.pdf

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/demarche-a-suivre-2012.pdf

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/exigence_raccordement_fev_09_en.pdf





The validation of modeling data is a prerequisite for final TO acceptance of the generating facility project and must be completed within 6 months of initial commercial commissioning.

GOs of generating units with capacities less than 10 MW that are connected at the distribution network level are not required to provide detailed modeling data unless specifically requested by TPs or the PC for system studies purposes.

The following sections present the steady-state, dynamics and short-circuit data required to effectively model all generating units within the Québec interconnected transmission system, defining the type of data required and the units this data is to be reported in.

3.1.1 Steady-State Data Requirements for Generator Modeling

i. In general, generator owners shall provide steady-state modeling data of existing and prospective generating units according to the requirements set forth in Appendix A of HQT’s technical requirements document entitled “Transmission Provider Technical Requirements for the Connection of Power Plants to the Hydro-Québec Transmission System”. The most updated version of the document is readily available on HQT’s website at:


ii. The table below summarizes the main steady-state data requirements, as outlined in MOD-032-01, A1-3.

Table 2 – Steady-State Data Reporting Requirements for Generator Modeling

Generator Unit Component

Steady-State Modeling Data Requirements

Synchronous/Asynchronous Generators

• Generator type (hydroelectric, thermal, wind, etc.) • Real power capabilities (maximum and minimum values in

MW) • Reactive power capabilities (maximum and minimum

values in MVAR) • Machine MVA base • Generator unit regulated bus and set point voltage • Machine grounding impedances • In-service status

Generator Step-Up Transformers*

• Number of transformers • Nominal voltages of windings (kV) • Rated power (MVA) • Power ratings (MVA) with corresponding cooling method • Positive sequence impedances and winding resistance

(Ohms or p.u.)

* This data shall be provided by the owner of generator step-up transformers, which can be the GO or the TO.





• Coupling (winding connection) • Number of tap positions (kV or p.u.) • Tap ratios (voltage or phase angle) • Minimum and maximum tap position limits • Regulated bus (for voltage regulating transformers) • In-service status

Wind Farm Collector Network Equipment

• Transmission line impedance parameters (ohms or p.u.) • Transmission line admittance (siemens or p.u.) • Transmission line ratings (MVA or A) • Capacitor/Inductor number, in-service status, reactive

power ratings and voltage.

iii. For future planned generating units, GOs shall provide the expected commissioning date.

iv. GOs shall also provide generating station service auxiliary load information for existing units, detailing real (MW) and reactive power (MVAR) load values associated with a given generating unit.

v. In regards to “in-service status”, a 10-year forecast of scheduled outages of duration greater than 6 months shall be provided by GOs on a yearly basis. Outage information shall consist of:

• Start and end dates of planned outage

• Generating unit(s) and/or specific equipment within generation facility scheduled to be out of service.

• Impact of outage on generation (i.e. reduction in power plant generation in MW)

3.1.2 Short-Circuit and Dynamics Data Requirements for Generator Modeling

i. In general, GOs shall provide short-circuit and dynamics modeling data of existing and future planned generating units according to the requirements set forth in Appendices A and B of HQT’s technical requirements document entitled “Transmission Provider Technical Requirements for the Connection of Power Plants to the Hydro-Québec Transmission System”. The most updated version of the document is readily available on HQT’s website at:


ii. In order to accurately simulate dynamic performance of generating units, GOs must provide the PC with validated dynamics models and associated parameters of all power generating equipment and components of the power plant, including:

• Generators, including Wind Turbines, Photovoltaic Systems, Fuel Cells and any other resource that delivers MW to the electric power system.





• Excitation systems

• Turbine and speed governors

• Voltage regulators (if equipped)

• Power system stabilizers (if equipped)

iii. All dynamics models submitted to the PC must be based on standard IEEE models and must be compatible with the current version of Siemens-PTI’s PSS/E (Power System Simulator for Engineers) software, which is used by the PC and TPs for dynamics system studies.

The use of Siemens-PTI PSS/E standard dynamics models is preferred when they can accurately represent the dynamic performance of the device being modeled.

A list of Siemens-PTI PSS/E standard dynamics models as well as all user-defined models approved by the PC for use in dynamic simulations is listed in Appendix 2 of the present document.

iv. User-defined models

a) In the event that a compatible standard IEEE or PSS/E dynamics model is unavailable, user-defined or “black-box” models may be used. A user-defined model is any model that is not a standard Siemens-PTI PSS/E library model but has been accepted by the PC after being successfully tested for compatibility.

b) User-defined models submitted to the PC shall fulfill the following requirements:

• User-defined models must be able to work with a time-step exceeding 4 ms.

• User-defined models must be accompanied by a user manual providing all relevant technical documentation and characteristics of the model, including block diagrams, values and names for all model parameters and a list of all state variables.

• GOs must also provide compliance test results demonstrating that the model accurately represents the dynamic performance of the device being modeled. GOs must ensure that model compliance testing is performed every 10 years.

c) GOs are responsible for validating and maintaining all dynamics models, ensuring that models submitted to the PC are compatible and fully functional in the current version of PSS/E, allowing for error-free initialization. In the event of PSS/E version updates (PC migrates to a newer version of the PSS/E software), GOs shall provide all necessary model updates, ensuring all models are compatible with the new version of PSS/E.



d) In the case of user-defined models representing wind farms, the following requirements shall be observed:

• Validation of wind turbine models shall be conducted using HQT’s “Procedure for PSS/E model validation” document, available on HQT’s website at:

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/procedure-validation-modeles-psse-en.pdf

Test base cases are also available on HQT’s website at:

http://www.hydroquebec.com/transenergie/fr/commerce/zip/procedure-validation-eolien-v32.zip.

• The user-defined model must allow wind turbines to be represented as a single generator and must be functional across its entire range of real and reactive power.

• In the case where voltage regulation of a wind power plant is achieved by means of additional compensation equipment in the switchyard, the GO shall also provide the complete PSS/E model for the corresponding reactive power compensation equipment, including all associated technical documentation, modeling data and parameters.

e) In addition to providing all required data for user-defined models as stipulated in 3.1.2.iv above, GOs must also identify the Siemens-PTI PSS/E standard library model(s) that most closely represents the dynamic performance of the user-defined model, as well as provide the corresponding modeling parameters. GOs may refer to the list of accepted models presented in Appendix 2.

v. When submitting model parameters, GOs shall indicate the source of the data reported (manufacturer technical specifications, measured values, typical or estimated theoretical values, etc.).

vi. In the case of incomplete data or unknown parameters, GOs shall provide the PC with estimated values based on the GO’s assumptions and hypotheses. All estimated values shall be clearly indicated as such.

vii. In regards to under/over-frequency protection of generating units, all GOs shall provide under/over-frequency relay data, specifically generator unit protection relay trip settings and time delay, as described in NERC’s PRC-006-1 standard “Automatic Underfrequency Load Shedding”.



http://www.hydroquebec.com/transenergie/fr/commerce/zip/procedure-validation-eolien-v32.zip

http://www.hydroquebec.com/transenergie/fr/commerce/zip/procedure-validation-eolien-v32.zip

http://www.nerc.com/files/prc-006-1.pdf



3.2 Reporting Procedures

3.2.1 Data Format

i. Steady-state, dynamics and short-circuit data shall be submitted to the PC in one of the following formats:

• Table format: Siemens-PTI PSS/E dynamic library models are identified and all corresponding model parameters are provided in a table format. GOs with numerous generating units may use the sample modeling data reporting table provided in Appendix 4 of the present document.

• PSS/E Library Data Sheets: GOs using Siemens-PTI PSS/E dynamic library models may also elect to submit modeling parameters using the corresponding Siemens-PTI PSS/E library model data sheets. These data sheets may be provided to the GO upon request. An example of a PSS/E library model data sheet is included in Appendix 3.

• PSS/E RAW, DYR format: PSS/E dynamic library models are identified and all corresponding steady-state and dynamics parameters are provided in RAW and DYR files, respectively.

ii. In the case of user-defined models, GOs shall submit:

• All associated model files required to run simulations in PSS/E (*.lib, *.obj, *.dll, etc.). The PC may request the source code for certain user-defined models, which must be submitted in the FLECS language of the current PSS/E revision, in C, or in FORTRAN.

• All corresponding user-defined model steady-state and dynamics parameters, provided in RAW and DYR files, respectively.

• All relevant technical documentation and characteristics of the user-defined model, including compliance test results, block diagrams, values and names for all model parameters and a list of all state variables.

• Any IDEV or PYTHON programs necessary to set up dynamics simulation parameters.

• The Siemens-PTI PSS/E standard library model that most closely represents the generating unit’s dynamics performance, along with all corresponding model parameters.

iii. GOs shall provide generator outage information in an Excel table format.



3.2.2 Data Submission Procedure and Schedule

i. Data submission is to be performed annually according to the procedures and schedule described in section 7.



4. Transmission System Equipment


All Transmission Owners within the Québec Interconnection shall provide the PC with valid modeling data of all existing and future transmission system equipment, including:

• AC transmission lines

• DC transmission systems

• Voltage and phase shifting transformers

• Breakers

• Shunt reactive compensation equipment (capacitors and reactors)

• Series reactive compensation equipment

• Static Var systems and synchronous condensers

• Special protection systems (SPS)

The PC, in accordance with NERC’s MOD-032 standard, requires all TOs of existing facilities to recertify system modeling data on an annual basis, either by resubmitting all required modeling data or by certifying that data has not changed from the previous year’s data submission. In the case of changes to modeling data, TOs must clearly identify all changes and submit all modified modeling data in accordance with the requirements herein.

For future planned modifications, additions or upgrades of transmission system equipment, TOs must submit preliminary modeling data to the PC and TPs during the planning phase of the project, during which system impact studies are conducted. This data is generally submitted to the PC and TPs approximately 3-5 years prior to project commissioning. At this stage, estimated or typical modeling parameters are acceptable.

TOs shall update the preliminary data provided to the PC during the project planning phase by providing actual or measured modeling parameters based on equipment compliance testing results conducted during the commissioning phase. The validation of modeling data is a prerequisite for final TO acceptance of the transmission system facility project and must be completed within 6 months of initial commercial commissioning.

The following sections present the steady-state, dynamics and short-circuit data required to effectively model transmission system equipment within the Québec Interconnection, defining the type of data required and the units this data is to be reported in.



4.1.1 Transmission System Equipment Steady-State Data Requirements

i. Each TO shall provide steady-state modeling data of existing and future transmission equipment according to the requirements set forth in the present document.

ii. The table below summarizes the main steady-state data requirements, as outlined in MOD-032-01, A1- 1, 4-8.

Table 3 – Transmission System Equipment Steady-State Data Reporting Requirements

Transmission System Component

Steady-State Modeling Data Requirements

Buses • Bus numbers and alphanumeric names • Nominal voltage • Type of bus (substation bus bar, load or generator) • Area, zone and owner • Associated substation or line

AC Transmission Lines • To and from buses or substations • Line length (km) • Impedance parameters, R and X (ohms or p.u.) • Susceptance, B (siemens or p.u.) • Thermal ratings at -20⁰C, 0⁰C and 30⁰C (MVA or A) • In-service status

DC Transmission Systems (DC lines and converter stations)

• To and from buses or substations • DC Line length (km) • DC Line impedances and data (Voltage, Rcmp-Ohms,

Vcmode, CCC Itmax, Rdc-Ohms, Delti, Dcvmin, CCC Accel)

• Rectifier and Inverter data (Primary base voltage, Bridges in Series, Trans Ratio, CCC X, AC Tx From Bus, AC Tx To Bus, Max Firing Angle, Commutating R and X, Max & Min Tap Settings, Tap Step)

• In-service status

Transformers (Voltage and Phase Shifting)

• Location of transformer (substation name) • Transformer name (ID number) and assigned position

number • Nominal voltages of primary, secondary and tertiary

windings (kV) • Impedance parameters, R and X (p.u.) • Magnetizing admittance G and susceptance B (p.u.) • Nominal MVA base • Tap ratios (voltage or phase angle) • Minimum and maximum tap position limits • Number of tap positions • Regulated bus (for voltage regulated transformers) • Capacity ratings at -20⁰C, 0⁰C and 30⁰C (MVA)



• In-service status

Breakers • Location of breaker (substation name) • Breaker name (ID number) and assigned position number • Nominal voltage (kV) • Manufacturing data (manufacturer, year, design standard) • Breaker interrupting symmetrical and asymmetrical

current capacities (kA) • Breaker X/R ratio

Shunt Reactive Compensation Devices (Capacitors and Reactors)

• Location of shunt unit (substation name) • Shunt unit name (ID number) and assigned position

number • Number of capacitors and reactors in unit • Reactive power capacity of each capacitor and reactor

(MVAR) • Rated voltage (kV) • Regulated voltage band limits (kV) • Mode of operation (fixed, discrete, continuous, etc.) • Regulated bus • In-service status

Series Reactive Compensation Devices

• Location of series capacitor (substation name and transmission line compensated)

• Series capacitor unit name • Unit type • Rated voltage (kV) • Unit impedance (p.u. or ohms) • Unit admittance (p.u. or siemens) • Reactive compensation % • Reactive power capacity (MVA) • Overload factor • In-service status

Static Var Systems and Synchronous Condensers

• Location of Static VAR or Synchronous Condenser (substation name)

• Rated voltage (kV) • Machine MVA base • Reactive power limits (MVAR) • Regulated bus • Voltage set point (p.u. or kV) • In-service status

iii. Attribution of bus numbers and associated bus data must be consistent with the PC’s bus

numbering and naming practices presented in the table below:

Table 4 – HQT Bus Numbering and Naming Practices

Bus Data Bus Numbering and Naming Practices

Bus Number • Bus numbers must be unique for all buses in the Québec



Interconnection. • Bus numbers must be attributed in accordance to the assigned

bus number ranges presented in Appendix 5.

Bus Name • Bus names are descriptive names given to buses in PSS/E • Bus names must be unique for all buses in the Québec

Interconnection and must not exceed 8 alphanumeric characters.

• By convention, bus names must be in the following format: ABC123-1 or ABC123-A In general, the first 3 characters are letters relating to the name of the substation where the bus is located, and the next 3 characters are numbers denoting the nominal voltage level of the bus. A dash and a number or letter may be added at the end of the name in order to help differentiate between multiple buses with the same first 6 characters. For example, according to the naming practice, the PSS/E names of two 315 kV bus bars at the Duvernay substation would be DUV315-1 and DUV315-2.

Bus Location • For each bus in the transmission system, an Area number, Zone number and Owner name/number must be specified.

• Area refers to the NPCC Area where a given bus is located. For example, buses of the HQT transmission system are located in the HQTÉ Area denoted by number 104.

• Zone refers to the specific geographic region within the Québec Interconnection.

• Owner refers to the specific transmission owner responsible for a given bus.

• A complete listing of all available Area and Zone number codes are presented in Appendix 5.

iv. Transmission owners shall also provide substation service auxiliary load information for existing substations, detailing real (MW) and reactive power (MVAR) load values associated with a given substation.

v. For all future additions or upgrades where HQT is TO, steady-state modeling data shall reflect technical data specified in the Design Specifications Document (cahier des charges).

vi. In regards to “in-service status”, transmission system equipment outages for the upcoming year of duration greater than 6 months shall be provided by the TO on a yearly basis. Outage information shall consist of:

• Start and end dates of planned outage

• Transmission equipment scheduled to be out of service

• Voltage level

• Location (substation name, zone, etc.)



• Description of project or maintenance causing outage

4.1.2 Transmission System Equipment Short-Circuit and Dynamics Data Requirements

i. Each TO shall provide short-circuit and dynamics modeling data of existing and future transmission equipment according to the requirements set forth in the present document.

ii. The table below summarizes the main short-circuit and dynamics modeling data requirements, as outlined in MOD-032-01, A1.

Table 5 – Transmission System Equipment Short-circuit and Dynamic Data Reporting Requirements

Transmission System Component

Dynamics and Short-Circuit Modeling Data Requirements

AC Transmission Lines • Zero sequence impedance parameters, R and X (ohms or p.u.)

• Zero sequence susceptance, B (siemens or p.u.)

DC Transmission Systems (DC lines and converter stations)

• DC line dynamics model and associated parameters • DC converter dynamics model and associated

parameters

Transformers (Voltage and Phase Shifting)

• Winding connection • Zero sequence impedance parameters, R and X

(ohms or p.u.) • Zero sequence grounding impedances, RG and XG

(ohms or p.u.)

Shunt Reactive Compensation Devices (Capacitors and Reactors)

• Zero sequence shunt admittances, G and B (p.u.)

Series Reactive Compensation Devices

• Zero sequence impedances, R and X (p.u. or ohms) • Zero sequence admittance, B (p.u. or siemens) • Unit admittance (p.u. or siemens)

Static Var Systems and Synchronous Condensers

• Positive sequence machine impedances, R1 and X1 (p.u.)

• Negative sequence machine impedances, R2 and X2 (p.u.)

• Zero sequence machine impedances, R0 and X0 (p.u.)

• Static Var System equipment dynamics model and associated parameters

• Synchronous Condenser dynamics model and associated parameters

Special protection systems (SPS) • SPS dynamics model and associated parameters



iii. All dynamics models submitted to the PC must be based on standard IEEE models and must be compatible with the current version of Siemens-PTI’s PSS/E (Power System Simulator for Engineers) software, which is used by the PC and TPs for dynamics system studies.

The use of Siemens-PTI PSS/E standard dynamics models is preferred when they can accurately represent the dynamic performance of the device being modeled.

A list of Siemens-PTI PSS/E standard dynamics models as well as all user-defined models approved by the PC for use in dynamic simulations is listed in Appendix 2 of the present document.

iv. In the event that a compatible standard IEEE or PSS/E dynamics model is unavailable, user-defined or “black-box” models may be used. A user-defined model is any model that is not a standard Siemens-PTI PSS/E library model but has been accepted by the PC after being successfully tested for compatibility.

v. User-defined models submitted to the PC shall fulfill the following requirements:

• User-defined models must be able to work with a time-step exceeding 4 ms.

• User-defined models must be accompanied by a user manual providing all relevant technical documentation and characteristics of the model, including block diagrams, values and names for all model parameters and a list of all state variables.

• TOs must also provide compliance test results demonstrating that the model accurately represents the dynamic performance of the device being modeled. TOs must ensure that model compliance testing is performed every 10 years.

vi. TOs are responsible for validating and maintaining all dynamics models, ensuring that models submitted to the PC are compatible and fully functional in the current version of PSS/E, allowing for error-free initialization. In the event of PSS/E version updates (PC migrates to a newer version of the PSS/E software), TOs shall provide all necessary model updates, ensuring all models are compatible with the new version of PSS/E.

vii. In addition to providing all required data for user-defined models as stipulated in 4.1.2.iv-vi, TOs must also identify the Siemens-PTI PSS/E standard library model(s) that most closely represents the dynamic performance of the user-defined model, as well as provide the corresponding modeling parameters. TOs may refer to the list of accepted models presented in Appendix 2.

viii. When submitting model parameters, TOs shall indicate the source of the data reported (manufacturer technical specifications, measured values, typical or estimated theoretical values, etc.).



ix. In the case of incomplete data or unknown parameters, TOs shall provide the PC with estimated values based on the TO’s assumptions and hypotheses. All estimated values shall be clearly indicated as such.

x. For all future additions or upgrades where HQT is TO, short-circuit modeling data shall reflect technical data specified in the Design Specifications Document (cahier des charges).

4.2 Reporting Requirements

4.2.1 Data Format

iv. Steady-state, dynamics and short-circuit data shall be submitted to the PC in one of the following formats:

• Table format: Siemens-PTI PSS/E dynamic library models are identified and all corresponding model parameters are provided in a table format.

• Manufacturer Testing Reports: Modeling parameters may be submitted in the form of a report, presenting results from the manufacturer’s technical compliance testing.

• PSS/E Library Data Sheets: TOs using Siemens-PTI PSS/E dynamic library models may also elect to submit modeling parameters using the corresponding Siemens-PTI PSS/E library model data sheets. These data sheets may be provided to the TO upon request. An example of a PSS/E library model data sheet is included in Appendix 3.

• PSS/E RAW, DYR format: PSS/E dynamic library models are identified and all corresponding steady-state and dynamics parameters are provided in RAW and DYR files, respectively.

• Siemens PSS®MOD format: This form of data reporting is only applicable to HQT. Future projects or modifications shall be submitted to the PC in the form of MOD *.prj files or entered directly into HQT’s MOD database, available online at:

http://131.195.100.81/MODWeb/login.aspx?ReturnUrl=%2fmodweb%2fDefault.aspx.

v. TOs shall also submit a one-line diagram, illustrating the planned or commissioned transmission system additions and/or modifications.

vi. In the case of user-defined models, TOs shall submit:

• All associated model files required to run simulations in PSS/E (*.lib, *.obj, *.dll, etc.). The PC may request the source code for certain user-defined models, which must be submitted in the FLECS language of the current PSS/E revision, in C, or in FORTRAN.

http://131.195.100.81/MODWeb/login.aspx?ReturnUrl=%2fmodweb%2fDefault.aspx




• All corresponding user-defined model steady-state and dynamics parameters, provided in RAW and DYR files, respectively.

• All relevant technical documentation and characteristics of the user-defined model, including compliance test results, block diagrams, values and names for all model parameters and a list of all state variables.

• Any IDEV or PYTHON programs necessary to set up dynamics simulation parameters.

• The Siemens-PTI PSS/E standard library model that most closely represents the generating unit’s dynamics performance, along with all corresponding model parameters.

vii. The TO shall provide transmission system equipment outage information in the form of a report or a simplified Excel table.





5. Modeling of Aggregate Demand


The main Load Serving Entity (LSE), in this case Hydro-Québec Distribution (HQD), is responsible for preparing and submitting demand data to the Planning Coordinator (PC) for the entire Québec Interconnection. This data is based on demand forecasts prepared and/or assembled on an annual basis by all LSEs.

The following sections present the steady-state, dynamics and short-circuit data required to effectively model demand within the interconnected transmission system, defining the type of data required and the units this data is to be reported in.

5.1.1 Steady-State Data Requirements for Demand Modeling

i. Steady-state load data shall be submitted to the PC, listing forecasted aggregated load data at each load-serving bus bar for each year of a given demand forecast.

ii. The LSE shall also provide Interconnection-wide total demand forecasts, summing substation, customer facility and substation auxiliary load data.

iii. Demand forecasts shall be prepared and submitted to the PC in accordance with HQD-HQT agreements (“Ententes sectorielles”) 1, 3 and 6, available at http://transenergie.hydro.qc.ca/ planification_expertise_aff_reglementaires/528.htm, and in compliance with NERC standards MOD-016, MOD-017, MOD-018, MOD-019, MOD-020, MOD-021.

The table below summarizes the steady-state data requirements outlined in the HQD-HQT agreements for loads modeled at satellite substation feeder buses (< 44 kV) and loads representing customer facilities (large industrial plants, pulp and paper mills, aluminum smelters, refineries, mining facilities, etc.), directly connected to the high voltage transmission system (44 kV to 324 kV).

Table 6 – Steady-State Data Reporting Requirements for Demand Modeling

Loads at satellite substation feeder buses < 44 KV

(15 year forecast)

Customer facility loads at buses > 44 kV (10 year forecast)

Bus number Substation name Real power (MW) Reactive power (MVAR) Load apparent power (MVA) Rated power (MVA) and voltage (kV) of

low-voltage side reactive compensation

Bus number Customer facility name Expected real power (MW) Total load apparent power (MVA) Load in-service status Number of shunt capacitors and reactors Rated power (MVA) and voltage (kV) of each

http://transenergie.hydro.qc.ca/%20planification_expertise_aff_reglementaires/528.htm




equipment reactive compensation equipment Reactive compensation equipment in-service

status Quantity of interruptible load

iv. In general, load data submitted to the PC shall reflect the following annually prepared demand forecasts:

• A 15-year aggregate demand forecast for all load-serving satellite substations within the Hydro-Québec Distribution system with secondary bus voltages less than 44 kV.

• A 15-year aggregate demand forecast for all load-serving substations belonging to independent municipal distribution systems with secondary bus voltages less than 44 kV.

• A 10-year estimated demand forecast for industrial customer facilities (large industrial plants, pulp and paper mills, aluminum smelters, refineries, mining facilities, etc.), directly connected to the high voltage transmission system (44 kV to 324 kV).

• A 10-year Interconnection-wide aggregated demand forecast for all three categories listed above.

v. Each demand forecast shall provide load data for the following types of load levels:

• Winter Peak Load

• Summer Peak Load

• Summer Light Load

vi. According to HQD-HQT Agreement #1, Part 2, Article 1, HQD must also provide historical load data based on meter readings at each load-serving satellite substation.

vii. In the case of new customer facilities connected directly to the high voltage transmission system, the submission of more detailed modeling information is required prior to the commissioning of new customer facilities, as stipulated in the PC’s “Technical Requirements for Customer Facilities Connected to the Hydro-Québec Transmission System” document. The most updated version of the document is readily available on HQT’s website at:

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/ ex_inst_client_en.pdf.

viii. Existing customer facilities must also provide load modeling data according to these same technical requirements upon request from the PC or in the event of any modifications to customer facilities.

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/%20%20ex_inst_client_en.pdf



5.1.2 Short-Circuit and Dynamics Data Requirements for Demand Modeling

i. Short-circuit and dynamics data is normally required for customer facilities equipped with large motors that can impact the transmission system’s transient and dynamic performance. This information is normally provided by customer facilities prior to commissioning and connection to the transmission system or in the event of modifications to existing customer facilities.

ii. Customer facilities, with the collaboration of HQD, shall provide short-circuit and dynamics data according to the requirements set forth in Appendix 1 of HQT’s “Technical Requirements for Customer Facilities Connected to the Hydro-Québec Transmission System” document. The most updated version of the document is readily available on HQT’s website at:

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/ ex_inst_client_en.pdf.

iii. Customer facilities must also indicate the source of the data submitted (manufacturer technical specifications, measured values, typical or estimated theoretical values, etc.).

iv. In the case of incomplete data or unknown parameters, HQD/Customer facilities are responsible for providing theoretical or estimated values.

5.2 Reporting Procedures

5.2.1 Data Format

i. Steady-state load data submitted to the PC shall be presented in an Excel table format similar to the sample tables provided in Appendix 1, as stipulated in HQD-HQT Agreement #1, Part 2, Articles 2 and 4.

ii. Short-circuit and dynamic load data shall be submitted to the PC using the modeling data template provided in Appendix A of the “Technical Requirements for Customer Facilities Connected to the Hydro-Québec Transmission System” document. All fields of the said document must be completed in order to be considered as a valid data submission. Other accepted data submission formats for short-circuit and dynamic load data are the following:

• Excel Table listing model parameters

• PSS/E RAW and DYR files, with all corresponding PSS/E dynamic model files.



http://www.hydroquebec.com/transenergie/fr/commerce/pdf/%20%20ex_inst_client_en.pdf



6. Complementary Power System Information

In addition to steady-state and dynamics models, power flow and dynamics cases require quantitative power system information in order to set generation dispatch and inter-area transfer levels. This additional information consists of resource planning data and interchange transfer quantities to neighbouring Areas.

The following sections present the data required to effectively integrate resource planning and interchange data into power flow and dynamics cases, defining the type of data required and the units this data is to be reported in.

6.1 Resource Planning Data

6.1.1 Resource Planning Data Requirements

i. The Resource Planner (RP), in this case Hydro-Québec Distribution (HQD), shall provide the PC with data regarding all long term generation purchasing agreements between GOs and LSEs, determining the generating resources available to fulfill demand requirements.

ii. This data shall be prepared and submitted to the PC in accordance with HQD-HQT agreements (“Ententes sectorielles”) 1, 3 and 6, available at http://transenergie.hydro.qc.ca/ planification_expertise_aff_reglementaires/528.htm

6.1.2 Data Format

i. Resource data shall be reported in an Excel table format, as specified in the above mentioned HQD-HQT agreements.



6.2 Interchange Schedule

An Interchange schedule is a list of scheduled power transfer quantities exchanged between the Québec Interconnection and its neighbouring Area systems (i.e. New England, New York, Ontario, and New Brunswick). These transactions and transmission reservations reflect firm export/import or point-to-point transmission agreements, as per HQT’s Open Access Transmission Tariff (OATT). This information is published on the OATI webOASIS application and provided to the PC by the Transmission Service Provider (TSP).





6.2.1 Interchange Data Requirements

i. The TSP shall collect and provide the required interchange data regarding all point-to-point transmission agreements, transmission reservations and spot trades between TOs within the Québec Interconnection as well as TOs of neighbouring NPCC Areas. This information must be reflective of the most updated transaction information available on OASIS.

ii. Interchange data shall include:

• Transmission service customer name

• OASIS reference number

• Source and destination substations

• Name of interconnection path

• Transaction quantity (MW)

• Transaction frequency (yearly, monthly, etc.)

• Transmission service type

• Start and end date of transmission service contract

6.2.2 Data Format

i. Interchange data shall be reported in an Excel table format, similar to the sample table in Appendix 6.





7. Data Submission Procedure and Schedule

7.1 Data Submission Procedure

i. All communication regarding modeling data submission shall be sent to the following email address: [email protected].

ii. Data submission is to be performed electronically by email, preferably using a secure file transfer server such as Hydro-Québec’s secure FTP server, available to HQ entities at https://ftps.hydro.qc.ca/ and external clients at https://ftps.hydroquebec.com/.

iii. TOs owned by HQT may also submit modeling data using Hydro-Québec’s file storage software, Hydro-Doc (Enterprise Connect) or enter future project data directly into MOD using the MOD online application, available at: http://131.195.100.81/MODWeb/login.aspx?ReturnUrl=%2fmodweb%2fDefault.aspx

iv. Recertification Process

As stipulated in sections 3.1 and 4.1 of the present document, in addition to reporting additions or modifications to modeling data, GOs and TOs of existing facilities must recertify that existing unchanged modeling data is valid. This recertification of modeling data shall be performed on an annual basis, either by resubmitting all required modeling data or by submitting a written confirmation that data has not changed from the previous year’s data submission. The recertification process is presented as follows:

• Request for recertification: Every year, the PC shall send an email to GOs and TOs requesting the recertification of modeling data for existing generators and transmission system equipment 90 calendar days prior to scheduled data submission deadlines. The PC’s request for recertification will include the modeling information currently maintained by the PC in DSR and MOD.

• Recertification response: Recertification of modeling data or information indicating changes to modeling data shall be provided to the PC prior to the data reporting deadline. GOs and TOs must identify all changes or updates to modeling data (including model compatibility updates for PSS/E version upgrades) and submit the changes in accordance to the requirements specified in sections 3 and 4 of the present document. In the case there are no changes to modeling data, GOs and TOs must submit a written confirmation indicating that there are no changes to report and that current modeling data is valid.

v. Technical Concerns and Questions Regarding Submitted Modeling Data

mailto:[email protected]

https://ftps.hydro.qc.ca/

https://ftps.hydroquebec.com/




a) In the case there are technical concerns with regards to the data submitted, the concerned entity (GO, TO, LSE, RP, etc.) will receive a written notification from the PC or a TP describing the technical basis or reason for the technical concerns.

b) Each notified entity shall respond to the notifying PC or TP as follows:

• Provide either updated data or an explanation with a technical basis for maintaining the current data;

• Provide the response within 90 calendar days of receipt of the notification, unless a longer time period is agreed upon with the PC or TP.

7.2 Data Submission Schedule

All concerned entities responsible for providing modeling data shall submit data annually according to the following schedule:

Table 7 – Modeling Data Submission Schedule

Modeling Data Description of Deliverables Functional Entity Responsible

Submission Date

Aggregate Demand Data

Steady-state winter peak load forecast Load Serving Entity June 1st

Steady-state summer peak and light load forecasts

Load Serving Entity October 1st

Steady-state demand forecast for industrial customer facilities

Load Serving Entity October 1st

Total system load forecast Resource Planner October 1st

Generation Data Recertification of steady-state, dynamics and short-circuit modeling data for existing generating units

Generator Owners February 1st

Steady-state, dynamics and short-circuit modeling data for new future planned projects

Generator Owners February 1st

Generator facilities outage schedule Generator Owners April 1st

Transmission System Equipment Data

Recertification of steady-state, dynamics and short-circuit modeling data for existing equipment

Transmission Owners March 1st

Steady-state, dynamics and short-circuit modeling data for new future planned projects

Transmission Owners Transmission Planners

March 1st

Transmission system equipment outage schedule

Reliability Coordinator April 1st

Complementary Power System Information

Resource Planning Data Resource Planner April 1st

Interchange Data Transmission Service Provider

April 1st



7.3 Compliance Violations

For entities registered with NERC, failure to submit required modeling data by the prescribed submission schedule and in the requested format may be in violation of the requirements established in NERC’s MOD-032 standard.

For more information regarding compliance violations, functional entities may refer to pages 5-11 of the MOD-032-1 standard document, available on NERC’s website at:

http://www.nerc.com/pa/Stand/Reliability%20Standards/MOD-032-1.pdf

http://www.nerc.com/pa/Stand/Reliability%20Standards/MOD-032-1.pdf



REFERENCES

[1] Data for Power System Modeling and Analysis, NERC Reliability Standard MOD-032-1, 2015.

[2] Automatic Underfrequency Load Shedding, NERC Standard PRC-006-1, 2015.

[3] Demand and Energy Data, NERC Reliability Standard MOD-031-1, 2015.

[4] Procedures for System Modeling: Data Requirements & Facility Ratings, NPCC Document C-29, March 2007.

[5] F. Bélanger, ing, “Mise à jour des réseaux planifiés,” Hydro-Québec TransÉnergie, Montréal, Québec, September 2015.

[6] Hydro-Québec TransÉnergie (July 2012), Démarche à suivre pour un raccordement de centrale au réseau d’Hydro-Québec [Online]. Available : http://www.hydroquebec.com/ transenergie/fr/commerce/pdf/demarche-a-suivre-2012.pdf

[7] Hydro-Québec TransÉnergie (February 2009), Transmission Provider Technical Requirements for the Connection of Power Plants to the Hydro-Québec Transmission System [Online]. Available : http://www.hydroquebec.com/transenergie/fr/commerce/pdf/exigence_raccordement_fev_09_en.pdf

[8] Hydro-Québec TransÉnergie (February 2011), General Validation Test Program for Wind Power Plants Connected to the Hydro-Québec Transmission System [Online]. Available : http://www.hydroquebec.com/transenergie/fr/commerce/pdf/essais-eoliennes2011-en.pdf.

[9] Hydro-Québec TransÉnergie (April 2014), Procedure for PSS/E Model Validation [Online]. Available : http://www.hydroquebec.com/transenergie/fr/commerce/pdf/procedure- validation-modeles-psse-en.pdf.

[10] Hydro-Québec TransÉnergie (December 2008), Technical Requirements for Customer Facilities Connected to the Hydro-Québec Transmission System [Online]. Available : http://www.hydroquebec.com/transenergie/fr/commerce/pdf/ex_inst_client_en.pdf.

[11] Ententes sectorielles HQ Distribution / HQ TransÉnergie [Online]. Available FTP : transport.hydro.qc.ca Directory : commerce/commerce/ File : FBack_ententes_sect.htm

[12] Siemens Energy Inc. (October 2010), PSSE 32.05 Model Library [Online]. Available FTP : transport.hydro.qc.ca Directory : PTI/PSSE32/DOCS/ModelLibrary File : MODELS.pdf

[13] Siemens Energy Inc. (October 2010), PSSE 32.05 Program Operation Manual [Online]. Available FTP : transport.hydro.qc.ca Directory : PTI/PSSE32/DOCS/POM File : POM.pdf

http://www.hydroquebec.com/%20transenergie/fr/commerce/pdf/demarche-a-suivre-2012.pdf

http://www.hydroquebec.com/%20transenergie/fr/commerce/pdf/demarche-a-suivre-2012.pdf




http://www.hydroquebec.com/transenergie/fr/commerce/pdf/procedure-%20validation-modeles-psse-en.pdf

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/procedure-%20validation-modeles-psse-en.pdf

http://www.hydroquebec.com/transenergie/fr/commerce/pdf/ex_inst_client_en.pdf



APPENDIX 1 – Load Data Reporting Templates

Total Demand Forecast Template (Winter)

2014-15 2015-16 2016-17 2017-18 2018-19 2019-20 2020-21 2021-22 2022-23 2023-24

Besoins réguliers du Distributeur1 37 892- Consommation des centrales HQP dans BRD 74

= Charge locale du Transporteur 37 818Croissance annuelle 375

en % 1.0%

dont Alcan 92

1

PRÉVISION DE LA CHARGE LOCALE DU TRANSPORTEUR - POINTE D'HIVER (MW)

Version du JJ/MM/AAAA

La définition des besoins réguliers du Distributeur (BRD) se limite aux besoins des clients desservis par le réseau de TransÉnergie (exclusion des besoins des réseaux autonomes). Les BRD incluent la consommation des centrales d'HQP associée à l'électricité patrimoniale. Ils sont après effacement de la bi-énergie résidentielle (tarif DT) et avant interruptions chez les clients de la Grande entreprise.

2015-12-16H:\deluca\2015\Autres\MOD-032\APPENDIX 1 - Load Data Reporting Templates.xlsx

Total Demand Tarification, prévision et caractérisationVice-présidence - Clientèle

Aggregate (per bus/substation) Demand Forecast Template (Winter)

Nom_Poste Bus No. Unité Saison Année V01 Charge V01 Charge V02 Charge V03 Charge V04 Charge V05 Charge P01 Charge P02 Charge P03 Charge P04 Charge P05 Charge P06 Charge P07 Charge P08 Charge P09 Charge P10 Charge P11 Charge P12 Charge P13 Charge P14 Charge P15Abitibi MW Hiver 2009Abitibi MVAR Hiver 2009Abitibi MVA Hiver 2009Achigan MW Hiver 2009Achigan MVAR Hiver 2009Achigan MVA Hiver 2009Acton MW Hiver 2009Acton MVAR Hiver 2009Acton MVA Hiver 2009Adamsville MW Hiver 2009Adamsville MVAR Hiver 2009Adamsville MVA Hiver 2009Alain-Grandbois MW Hiver 2009Alain-Grandbois MVAR Hiver 2009Alain-Grandbois MVA Hiver 2009Albanel MW Hiver 2009Albanel MVAR Hiver 2009Albanel MVA Hiver 2009Alma MW Hiver 2009Alma MVAR Hiver 2009Alma MVA Hiver 2009Almaville MW Hiver 2009Almaville MVAR Hiver 2009Almaville MVA Hiver 2009Amos MW Hiver 2009Amos MVAR Hiver 2009Amos MVA Hiver 2009Amqui MW Hiver 2009Amqui MVAR Hiver 2009Amqui MVA Hiver 2009Anne-Hébert MW Hiver 2009Anne-Hébert MVAR Hiver 2009Anne-Hébert MVA Hiver 2009Anse Pleureuse 25 kV MW Hiver 2009Anse Pleureuse 25 kV MVAR Hiver 2009Anse Pleureuse 25 kV MVA Hiver 2009Antoine Lemieux MW Hiver 2009Antoine Lemieux MVAR Hiver 2009Antoine Lemieux MVA Hiver 2009Aqueduc 25 MW Hiver 2009Aqueduc 25 MVAR Hiver 2009Aqueduc 25 MVA Hiver 2009Armagh MW Hiver 2009Armagh MVAR Hiver 2009Armagh MVA Hiver 2009Arthabaska MW Hiver 2009Arthabaska MVAR Hiver 2009Arthabaska MVA Hiver 2009Arthur-Buies MW Hiver 2009Arthur-Buies MVAR Hiver 2009Arthur-Buies MVA Hiver 2009Asbestos MW Hiver 2009Asbestos MVAR Hiver 2009Asbestos MVA Hiver 2009Atwater 12 MW Hiver 2009Atwater 12 MVAR Hiver 2009Atwater 12 MVA Hiver 2009Atwater 25 MW Hiver 2009Atwater 25 MVAR Hiver 2009Atwater 25 MVA Hiver 2009Aubertois MW Hiver 2009Aubertois MVAR Hiver 2009Aubertois MVA Hiver 2009Austin MW Hiver 2009Austin MVAR Hiver 2009Austin MVA Hiver 2009Baie D'urfée 12 MW Hiver 2009Baie D'urfée 12 MVAR Hiver 2009Baie D'urfée 12 MVA Hiver 2009Baie D'urfée 25 MW Hiver 2009Baie D'urfée 25 MVAR Hiver 2009Baie D'urfée 25 MVA Hiver 2009Baie Saint-Paul MW Hiver 2009Baie Saint-Paul MVAR Hiver 2009Baie Saint-Paul MVA Hiver 2009Baie Saint-Paul 315 MW Hiver 2009Baie Saint-Paul 315 MVAR Hiver 2009Baie Saint-Paul 315 MVA Hiver 2009Baie-Trinité MW Hiver 2009Baie-Trinité MVAR Hiver 2009Baie-Trinité MVA Hiver 2009Beauceville Est MW Hiver 2009Beauceville Est MVAR Hiver 2009Beauceville Est MVA Hiver 2009Beaulieu MW Hiver 2009Beaulieu MVAR Hiver 2009Beaulieu MVA Hiver 2009Beaumont 12 MW Hiver 2009Beaumont 12 MVAR Hiver 2009



APPENDIX 2 – List of Approved Dynamics Models

A2.1 Standard Library Models

Model Name Model Description Developer

Generator Models

CBEST EPRI battery energy storage FACTS model PTI-Siemens

CDSMS1 American Superconductor DSMES device model PTI-Siemens

CGEN1 Third order generator model PTI-Siemens

CIMTR1 Induction generator model with rotor flux transients PTI-Siemens

CIMTR2 Induction motor model with rotor flux transients PTI-Siemens

CIMTR3 Induction generator model with rotor flux transients PTI-Siemens

CIMTR4 Induction motor model with rotor flux transients PTI-Siemens

CSMEST EPRI superconducting electromagnetic energy storage FACTS model PTI-Siemens

CSTATT Static condenser FACTS model PTI-Siemens

CSVGN1 SCR controlled static var source model PTI-Siemens



CSVGN5 WECC controlled static var source model PTI-Siemens

CSVGN6 WECC controlled static var source model PTI-Siemens

FRECHG Salient pole frequency changer model PTI-Siemens

GENCLS Classical generator model PTI-Siemens

GENDCO Round rotor generator model with dc offset torque component PTI-Siemens

GENROE Round rotor generator model PTI-Siemens

GENROU Round rotor generator model PTI-Siemens

GENSAE Salient pole generator model PTI-Siemens

GENSAL Salient pole generator model PTI-Siemens

GENTRA Transient level generator model PTI-Siemens

Compensator Models

COMP Voltage regulator compensating model PTI-Siemens

COMPCC Cross compound compensating model PTI-Siemens

IEEEVC 1981 IEEE voltage compensating model PTI-Siemens

REMCMP Remote bus voltage signal model PTI-Siemens

Stabilizer Models

BEPSST Transient excitation boosting stabilizer model PTI-Siemens

IEE2ST Dual-input signal power system stabilizer model PTI-Siemens

IEEEST 1981 IEEE power system stabilizer model PTI-Siemens

IVOST IVO stabilizer model PTI-Siemens

OSTB2T Ontario Hydro delta-omega power system stabilizer PTI-Siemens

OSTB5T Ontario Hydro delta-omega power system stabilizer PTI-Siemens

PSS1A IEEE Std. 421.5-2005 PSS1A Single-Input Stabilizer model PTI-Siemens

PSS2A 1992 IEEE type PSS2A dual-input signal stabilizer model PTI-Siemens



PSS2B IEEE 421.5 2005 PSS2B IEEE dual-input stabilizer model PTI-Siemens

PSS3B IEEE Std. 421.5 2005 PSS3B IEEE dual-input stabilizer model PTI-Siemens

PSS4B IEEE 421.5(2005) dual-input stabilizer model PTI-Siemens

PTIST1 PTI microprocessor-based stabilizer model PTI-Siemens

PTIST3 PTI microprocessor-based stabilizer model PTI-Siemens

ST2CUT Dual-input signal power system stabilizer model PTI-Siemens

STAB1 Speed sensitive stabilizer model PTI-Siemens

STAB2A ASEA power sensitive stabilizer model PTI-Siemens

STAB3 Power sensitive stabilizer model PTI-Siemens

STAB4 Power sensitive stabilizer model PTI-Siemens

STABNI Power sensitive stabilizer model type NI (NVE) PTI-Siemens

STBSVC WECC supplementary signal for static var system PTI-Siemens

Excitation System Models

AC7B IEEE 421.5 2005 AC7B excitation system PTI-Siemens

AC8B IEEE 421.5 2005 AC8B excitation system PTI-Siemens

BBSEX1 Brown-Boveri static excitation system model PTI-Siemens

BUDCZT Czech proportional/integral excitation system model PTI-Siemens

CELIN ELIN brushless excitation system model PTI-Siemens

DC3A IEEE 421.5 2005 DC3A excitation system PTI-Siemens

DC4B IEEE 421.5 2005 DC4B excitation system PTI-Siemens

EMAC1T AEP Rockport excitation system model PTI-Siemens

ESAC1A 1992 IEEE type AC1A excitation system model PTI-Siemens






ESAC8B Basler DECS model PTI-Siemens

ESDC1A 1992 IEEE type DC1A excitation system model PTI-Siemens

ESDC2A 1992 IEEE type DC2A excitation system model PTI-Siemens

ESST1A 1992 IEEE type ST1A excitation system model PTI-Siemens



ESST4B IEEE type ST4B potential or compounded source-controlled rectifierexciter PTI-Siemens

ESURRY Modified IEEE Type AC1A excitation model PTI-Siemens

EX2000 EX2000 Excitation System PTI-Siemens

EXAC1 1981 IEEE type AC1 excitation system model PTI-Siemens

EXAC1A Modified type AC1 excitation system model PTI-Siemens




EXBAS Basler static voltage regulator feeding dc or ac rotating exciter model PTI-Siemens

EXDC2 1981 IEEE type DC2 excitation system model PTI-Siemens

EXELI Static PI transformer fed excitation system model PTI-Siemens



EXNEBB Bus or solid fed SCR bridge excitation system model type NEBB (NVE) PTI-Siemens

EXNI Bus or solid fed SCR bridge excitation system model type NI (NVE) PTI-Siemens

EXPIC1 Proportional/integral excitation system model PTI-Siemens

EXST1 1981 IEEE type ST1 excitation system model PTI-Siemens


EXST2A Modified 1981 IEEE type ST2 excitation system model PTI-Siemens


IEEET1 1968 IEEE type 1 excitation system model PTI-Siemens




IEEET5 Modified 1968 IEEE type 4 excitation system model PTI-Siemens

IEEEX1 1979 IEEE type 1 excitation system model and 1981 IEEE type DC1 model PTI-Siemens

IEEEX2 1979 IEEE type 2 excitation system model PTI-Siemens

IEEEX3 1979 IEEE type 3 excitation system model PTI-Siemens

IEEEX4 1979 IEEE type 4 excitation system, 1981 IEEE type DC3 and 1992 IEEE type DC3A models PTI-Siemens

IEET1A Modified 1968 IEEE type 1 excitation system model PTI-Siemens

IEET1B Modified 1968 IEEE type 1 excitation system model PTI-Siemens

IEET5A Modified 1968 IEEE type 4 excitation system model PTI-Siemens

IEEX2A 1979 IEEE type 2A excitation system model PTI-Siemens

IVOEX IVO excitation system model PTI-Siemens

OEX12T Ontario Hydro IEEE Type ST1 excitation system with continuous and bang bang terminal voltage limiter PTI-Siemens

OEX3T Ontario Hydro IEEE Type ST1 excitation system with semicontinuousand acting terminal voltage limiter PTI-Siemens

REXSYS General purpose rotating excitation system model PTI-Siemens

Excitation Limiter Models

MAXEX1 Maximum excitation limiter model PTI-Siemens

MAXEX2 Maximum excitation limiter model PTI-Siemens

MNLEX1 Minimum excitation limiter model PTI-Siemens



UEL1 IEEE 421.5 2005 UEL1 under-excitation limiter PTI-Siemens

UEL2 IEEE 421.5 2005 UEL2 minimum excitation limiter PTI-Siemens

Turbine-Governor Model

BBGOV1 Brown-Boveri turbine-governor model PTI-Siemens

CRCMGV Cross compound turbine-governor model PTI-Siemens

DEGOV Woodward diesel governor model PTI-Siemens

DEGOV1 Woodward diesel governor model PTI-Siemens

GAST Gas turbine-governor model PTI-Siemens

GAST2A Gas turbine-governor model PTI-Siemens

GASTWD Gas turbine-governor model PTI-Siemens

GGOV1 GE general purpose turbine-governor model PTI-Siemens

HYGOV Hydro turbine-governor model PTI-Siemens



HYGOV2 Hydro turbine-governor model PTI-Siemens

HYGOVM Hydro turbine-governor lumped parameter model PTI-Siemens

HYGOVT Hydro turbine-governor traveling wave model PTI-Siemens

IEEEG1 1981 IEEE type 1 turbine-governor model PTI-Siemens



IEESGO 1973 IEEE standard turbine-governor model PTI-Siemens

IVOGO IVO turbine-governor model PTI-Siemens

PIDGOV Hydro turbine and governor model PTI-Siemens

SHAF25 Torsional-elastic shaft model for 25 masses PTI-Siemens

TGOV1 Steam turbine-governor model PTI-Siemens

TGOV2 Steam turbine-governor model with fast valving PTI-Siemens

TGOV3 Modified IEEE type 1 turbine-governor model with fast valving PTI-Siemens

TGOV4 Modified IEEE type 1 speed governing model with PLU and EVA PTI-Siemens

TGOV5 Modified IEEE type 1 turbine-governor model with boiler controls PTI-Siemens

Two-Terminal DC Line Models

CDC1T Two-terminal dc line model PTI-Siemens



CDC6TA Two-terminal dc line model PTI-Siemens

CDC7T dc line model PTI-Siemens

CDCABT ABB dc line model for Kontek line PTI-Siemens

CEELT New Eel River dc line and auxiliaries model. This model internally uses the following models: CHAAUT (auxiliary-signal model), CEEL2T (two-terminal dc

line model), and RUNBK (dc line runback model). PTI-Siemens

CEEL2T New Eel River dc line model PTI-Siemens

Multi-Terminal DC Line Models

MTDC1T Multiterminal (five converter) dc line model PTI-Siemens

MTDC2T Multiterminal (five converter) dc line model PTI-Siemens

MTDC3T Multiterminal (eight converter) dc line model PTI-Siemens

VSC dc Line Model

VSCDCT Two-terminal VSC dc line model PTI-Siemens

Generic Wind Generator Models

WT1G1 Direct connected (Type 1) generator PTI-Siemens

WT2G1 Induction generator with controlled external rotor resistor (Type 2) PTI-Siemens

WT3G1 Doubly-fed induction generator (Type 3) PTI-Siemens

WT3G2U Doubly-fed induction generator (Type 3), version 2 PTI-Siemens

WT4G1 Wind generator model with power converter (Type 4) PTI-Siemens

W4G2U Wind generator model with power converter (Type 4), version 2 PTI-Siemens

Generic Wind Electrical Model

WT2E1 Rotor resistance control model for Type 2 wind generator PTI-Siemens

WT3E1 Electrical control for Type 3 wind generator PTI-Siemens

WT4E1 Electrical control models for Type 4 wind generator PTI-Siemens

W4E2U Electrical control for Type 4 wind generator, version 2 PTI-Siemens

Generic Wind Mechanical Model



WT12T1 Two mass turbine model for Type 1 and Type 2 wind generators PTI-Siemens

WT3T1 Mechanical system model for Type 3 wind generator PTI-Siemens

Generic Wind Pitch Control

WT3P1 Pitch control model for Type 3 wind generator PTI-Siemens

Generic Wind Aerodynamic Model

WT12A1

Pseudo-governor model for Type 1 and Type 2 wind generators PTI-Siemens

Switched Shunt Model

CHSVCT SVC for switched shunt PTI-Siemens

CSSCST SVG for switched shunt PTI-Siemens

SWSHNT Switched shunt model PTI-Siemens

A2.2 Approved User-Defined Models

Model Name Model Description Developer

Stabilizer Models

MBPS4S User-defined PSS model Hydro-Québec TransÉnergie

Excitation System Models

EXHQSC User-defined Excitation System model for synchronous condensers Hydro-Québec TransÉnergie

Excitation Limiter Models

OELHQ User-defined Excitation Limiter Model (TCE) Hydro-Québec TransÉnergie

Turbine-Governor Model

HQRVW User-defined Hydro turbine-governor model Hydro-Québec TransÉnergie

HQRVM User-defined Hydro turbine-governor model Hydro-Québec TransÉnergie

HQRVN User-defined Hydro turbine-governor model Hydro-Québec TransÉnergie

HQRVC User-defined Hydro turbine-governor model Hydro-Québec TransÉnergie

Two-Terminal DC Line Models

CHTFWX User-defined Hydro-Québec DC Model Hydro-Québec TransÉnergie

CHTRVX User-defined Hydro-Québec DC Model Hydro-Québec TransÉnergie

CHTFWD User-defined Hydro-Québec DC Model Hydro-Québec TransÉnergie

CHARVS User-defined Hydro-Québec DC Model Hydro-Québec TransÉnergie

RSPDC3 User-defined Hydro-Québec DC Model Hydro-Québec TransÉnergie

HIGTDC User-defined Hydro-Québec DC Model (High Gate) Hydro-Québec TransÉnergie

CMDS User-defined Hydro-Québec DC Model Hydro-Québec TransÉnergie

Multi-Terminal DC Line Models

NEDCV3 User-defined Multi-Terminal DC Line Model (HQ-NE)

VSC dc Line Model

VSCDCT Two-terminal VSC dc line model PTI-Siemens

CABB02 HVDC Light® Open model version Ov1.1.10 ABB

CEmpty HVDC Light® Open model version Ov1.1.10 (Dummy call) ABB

Generic Wind Generator Models

EXF2 User-defined Wind Generator Model for Enercon E82 Enercon

EXS3 User-defined Wind Generator Model for Enercon E82 Enercon

E822S3 User-defined Wind Generator Model for Enercon Enercon



R21201 User-defined Wind Generator Model for Senvion MM92 Senvion

R21301 User-defined Wind Generator Model for Senvion MM82 Senvion

Generic Wind Electrical Model

EFCU02 User-defined Wind Farm Control Unit Model (Enercon) Enercon

RPMU01 Senvion User-defined Power Management Unit Model Senvion

Switched Shunt Model

CHASVC User-defined SVC Model for synchronous condensers Hydro-Québec TransÉnergie

IM_AM1 User-defined SVC Model for shunt reactors Hydro-Québec TransÉnergie

IM_CMP User-defined SVC Model (Master) Hydro-Québec TransÉnergie

IM_EXC User-defined SVC Model (Slave) Hydro-Québec TransÉnergie

SVSMO1U1 User written model for continuously controled SVC PTI-Siemens

SVSMO2U1 User written model for discretely controled SVC PTI-Siemens

Other Models

VFTU1 User-defined Phase Shifting Transformer Model Hydro-Québec TransÉnergie

PVGU1 User written generator model to represent photo-voltaic (PV) systems PTI-Siemens

PVEU1 User written electrical control model for photo-voltaic (PV) systems PTI-Siemens

PANELU1 User written model to represent the linearized model of PV panel’soutput curve PTI-Siemens

IRRADU1 User written model to represent the linearized model of PV panel’ssolar irradiance profile. PTI-Siemens



APPENDIX 3 – Examples of Siemens-PTI PSS/E Model Library Data sheets

Siemens Energy, Inc., Power Technologies International 1-47

PSS®E32.0.5 Generator Model Data SheetsPSS®E Model Library GENSAL

1.21 GENSALSalient Pole Generator Model (Quadratic Saturation on d-Axis)

Note: Xd, Xq, X´d, Xd, Xq, Xl, H, and D are in pu, machine MVA base.

Xq must be equal to Xd.

IBUS, ’GENSAL’, ID, CON(J) to CON(J+11) /

This model is located at system bus

#_____ IBUS,

Machine identifier #_____ ID,

This model uses CONs starting with

#_____ J,

and STATEs starting with #_____ K.

The machine MVA is _________ for each of units = _________ MBASE.

ZSORCE for this machine is _________ + j ________ on the above MBASE.

CONs # Value Description

J T´do (>0) (sec)

J+1 Tdo (>0) (sec)

J+2 Tqo (>0) (sec)

J+3 H, Inertia

J+4 D, Speed damping

J+5 Xd

J+6 Xq

J+7 X´d

J+8 Xd = Xq

J+9 Xl

J+10 S(1.0)

J+11 S(1.2)

STATEs # Description

K E´q

K+1 kd

K+2 q

K+3 speed (pu)

K+4 Angle (radians)

EFD

VOLT at ETERMGENSALTerminal

Bus

Efd

VT

ISORCE

SPEED Speed

Source Current

Terminal Voltage

PMECHPm

ANGLE Angle

Excitation System Model Data Sheets PSS®E 32.0.5IEEEX1 PSS®E Model Library

6-98 Siemens Energy, Inc., Power Technologies International

6.44 IEEEX1IEEE Type 1 Excitation System

This model is located at system bus #_______ IBUS,

Machine identifier #_______ ID,

This model uses CONs starting with #_______ J,

and STATEs starting with #_______ K,

and VAR #_______ L.


J TR (sec)

J+1 KA

J+2 TA (sec)

J+3 TB (sec)

J+4 TC (sec)

J+5 VRMAX or zero

J+6 VRMIN

J+7 KE or zero

J+8 TE (>0) (sec)

J+9 KF

J+10 TF1 (>0) (sec)

J+11 Switch

J+12 E1

J+13 SE(E1)

J+14 E2

J+15 SE(E2)


K Sensed VT

K+1 Lead lag

K+2 Regulator output, VR

K+3 Exciter output, EFD

K+4 Rate feedback integrator

ECOMP

VOEL

VOTHSGEFD

IEEEX1VUEL


PSS®E 32.0.5 Excitation System Model Data SheetsPSS®E Model Library IEEEX1

IBUS, ’IEEEX1’, ID, CON(J) to CON(J+15) /

VAR # Description

L KE

– + +VERR

11 + sTR

VREF

+

VS

+

–

1 + sTC1 + sTB

KA1 + sTA

RegulatorVRMAX

VRMIN

VR

1sTE

SE + KEsKF

1 + sTF1

–

VFB

DampingVS = VOTHSG + VUEL + VOEL

(pu)EC (pu)

EFD


PSS®E 32.0.5 Turbine-Governor Model Data SheetsPSS®E Model Library GAST2A

7.6 GAST2AGas Turbine Model





and VARs starting with #_______ L.


J W, governor gain (1/droop) (on turbine rating)

J+1 X (sec) governor lead time constant

J+2 Y (sec) (> 0) governor lag time constant

J+3Z, governor mode:

1 Droop 0 ISO

J+4 ETD (sec)

J+5 TCD (sec)

J+6 TRATE turbine rating (MW)

J+7 T (sec)

J+8 MAX (pu) limit (on turbine rating)

J+9 MIN (pu) limit (on turbine rating)

J+10 ECR (sec)

J+11 K3

J+12 a (> 0) valve positioner

J+13 b (sec) (> 0) valve positioner

J+14 c valve positioner

J+15 f (sec) (> 0)

J+16 Kf

J+17 K5

J+18 K4

J+19 T3 (sec) (> 0)

J+20 T4 (sec) (> 0)

J+21 t (> 0)

J+22 T5 (sec) (> 0)

J+23 af1

SPEED PMECHGAST2A

Turbine-Governor Model Data Sheets PSS®E 32.0.5GAST2A PSS®E Model Library


IBUS, ’GAST2A’, ID, CON(J) to CON(J+30) /

J+24 bf1

J+25 af2

J+26 bf2

J+27 cf2

J+28 TR (degree), Rated temperature1

J+29 K6 (pu), Minimum fuel flow

J+30 TC (degree), Temperature control1

1 Units can be F or C depending on constants af1 and bf1.


K Speed governor

K+1 Valve positioner

K+2 Fuel system

K+3 Radiation shield

K+4 Thermocouple

K+5 Temperature control

K+6 Gas turbine dynamics

K+7 Combustor

K+8 Combustor

K+9 Turbine/exhaust

K+10 Turbine/exhaust

K+11 Fuel controller delay

K+12 Fuel controller delay

VARs # Description

L Governor reference

L+1 Temperature reference flag

L+2 Low value select output

L+3 Output of temperature control



PSS®E 32.0.5 Turbine-Governor Model Data SheetsPSS®E Model Library GAST2A

+

1.0

Wf1Reference

+

–

W(Xs+1)

Ys + Z

VAR(L)

Speed

Low

Speed

X K3a

bs + c1

fs + 1

Kf

Fuel

Combustor

T5s + 1

tsTemperature

Control* 1T4s + 1

f1

K6

TCThermocouple

Radiation

Turbine

1TCDS + 1

f2

Turbine

XPMECH Wf2

Gas Turbine

+

+

N

SPEED

f1 = TR - af1(1 - wf1) - bf1(SPEED) f2 = af2 +bf2(wf2) - cf2 (SPEED)

+

–

+

–

MAX

MIN

e-sT

e-sETD

MAX

Fuel

Turbine Exhaust

TRATEMBASE

e-sECR

*Temperature control output is set to output of speed governor when temperature control input changes from positive to negative.

Valve

(pu deviation)

T3s + 1K4 +

K5

Governor Control

ValueSelect

Positioner SystemFuelFlow

WfControl

Dynamics

Shield

Generic Wind Generator Model Data Sheets PSS®E 32.0.5WT3G2U PSS®E Model Library


17.5 WT3G2UDoubly-Fed Induction Generator (Type 3)





and VAR #_______ L,

and ICON #_______ M.


J Tiqcmd, Converter time constant for IQcmd

J+1 Tipcmd, Converter time constant for IPcmd

J+2 KPLL, PLL gain

J+3 KIPLL, PLL integrator gain

J+4 PLLMAX, PLL max. limit

J+5 Prated

J+6 VLVPL1, LVPL voltage 1 Low voltage power logic

J+7 VLVPL2, LVPL voltage 2

J+8 GLVPL, LVPL gain

J+9 VHVRCR, High Voltage Reactive Current (HVRC) logic, pu voltage

J+10 CURHVRCR, HVRC logic, current (pu)

J+11 RIp_LVPL, Rate of active current change

J+12 T_LVPL, Voltage sensor for LVPL, second


K Converter lag for Ipcmd

K+1 Converter lag for Iqcmd

K+2 PLL first integrator

K+3 PLL second integrator

K+4 Voltage sensor for LVPL

VAR # Description

L deltaQ, overvoltage correction factor


PSS®E 32.0.5 Generic Wind Generator Model Data SheetsPSS®E Model Library WT3G2U

IBUS, ’USRMDL’, ID, ’WT3G2U’, 1, 1, 1, 13, 5,1, ICON(M), CON(J) TO COM(J+12)

ICON # Description

M Number of lumped wind turbines



APPENDIX 4 – Generator Modeling Data Reporting Template

Generator Modeling Data Reporting TemplateGenerator Characteristics and Steady-state Data

i Machine Type MES Sb (MVA)* Eb (kV) Sété (MVA) Shiv (MVA) S2h Pnom (MW) En (kV) Snom (MVAR) PF (%) HBus No. Round rotor or salient

pole Initial Commissioning

DateRated apparent

powerRated phase

voltageCoolant Coolant temp.

⁰CRated power @

high temp.Rated power @ design ambient

temp.

Nominal Real Power

Nominal Voltage

Nominal Apparent

Power

Power Factor Inertia Constant (for each

generating unit)

9000 99990 Plant 1 19001 99991 Plant 1 29002 99992 Plant 1 39003 99993 Plant 2 19004 99994 Plant 2 29005 99995 Plant 3 1

* Machine reactances (in p.u.) and inertia values must all be based on the base apparent power Sb (MVA) of the machine.

Generator Dynamics Data - Syncrhonous Machines

i Model Type Ra @ 25 C R1 Xl X2 Xdu X'du X''du Xqu X'qu X''qu X'ds X''ds X'qs X''qs Sgl Sgu T'do T''do T'qo T''qoBus No. Installation

No.Power Plant Name Standard Library Model

or User-written Model Armature

resistance per phase

Stator forward resistance

Positive-sequence leakage

reactance

Negative-sequence reactance

Unsaturated direct-axis

synchronous reactance

Unsaturated direct-axis transient

reactance

Unsaturated direct-axis

subtransient reactance

Unsaturated quadrature-axis

synchronous reactance


transient reactance



Saturated direct-axis transient

reactance

Saturated direct-axis subtransient

reactance

Saturated quadrature-axis

transient reactance

Saturated quadrature-axis


Saturation factor at 1.2 p.u. of

nominal voltage

Saturation factor at 1 p.u. of

nominal voltage

Direct-axis transient open-

circuit time constant

Direct-axis subtransient

open-circuit time constant

Quadrature-axis transient open-


Quadrature-axis subtransient

open-circuit time constant

9000 99990 Plant 1 1 GENSAL Standard9001 99991 Plant 1 29002 99992 Plant 1 39003 99993 Plant 2 19004 99994 Plant 2 29005 99995 Plant 3 1

Generator Dynamics Data - Asyncrhonous Machines

i Model Type Rs Xs Rr Xr Xm Xlr Xo T'do sBus No. Installation

No.Power Plant Name Standard Library Model

or User-written Model Stator resistance Stator leakage

reactanceRotor

resistanceRotor leakage

reactanceMagnetizing reactance

Locked rotor reactance

Open-circuit reactance

Direct-axis transient open-


Generator slip factor


Voltage Regulator Dynamics Data

i Model Type CON1 CON2 CON3 CON4 CON5 CON6 CON7 CON8 CON9 CON10 ICON1 ICON2 ICON3 ICON4Bus No. Installation

No.Power Plant Name Standard Library

Model or User-written Model


Excitation System Dynamics Data

i Model Type VR Type RR TRH KA TA1 TA2 VRMAX VRMIN KE TE SE.75 max SE max EFD max EFD min AEX BEX KF TF1 TF2Bus No. Installation



Excitation Type Exciter response ratio

Regulator Input filter

time constant (s)

Regulator gain

Regulator time constant 1 (s)

Regulator time constant 2 (s)

Maximum regulator output

Minimum regulator output

Exciter self-excitation

Exciter time constant (s)

Rotating exciter saturation at 0.75 max field voltage

Rotating exciter saturation at max

field voltage

Maximum field voltage (p.u.)

Minimum field voltage (p.u.)

Derived saturation constant

Derived saturation constant

Regulator stabilizing circuit

gain

Regulator stabilizing circuit time constant (s)

Regulator stabilizing circuit time constant (s)

9000 99990 Plant 1 1 IEEET5 Standard9001 99991 Plant 1 29002 99992 Plant 1 39003 99993 Plant 2 19004 99994 Plant 2 29005 99995 Plant 3 1

Turbine & Speed Governor Dynamics Data

i Model Type GOV R PMAX T1 T2 T3 T4 F CON1 CON2 CON3 CON4 CON5 CON6 CON7 CON8 CON9 CON10Bus No. Installation



Governor Type Turbine steady-state regulation setting (droop)

Maximum turbine output

(MW)

Control time constant (governor

delay)

Hydro reset time constant or pilot

valve time

Servo time constant or

dashpot time constant

Steam valve bowl time constant

Shaft output (p.u.) or

maximum gate velocity (MW/s)

9000 99990 Plant 1 1 HQRVN User-Written9001 99991 Plant 1 29002 99992 Plant 1 39003 99993 Plant 2 19004 99994 Plant 2 29005 99995 Plant 3 1

Power System Stabilizer Governor Dynamics Data

Base Values Generator Capacties Nominal Values

Saturated reactances

Other Constants

Other Constants

Steam reheat time, hydro water starting time constant (s) or

minimum gate velocity (MW/s)

T5

Typical Governor Parameters, Constants and Coefficients (may vary depending on type of governor model)

Typical Stabilizer Parameters, Constants and Coefficients (may vary depending on type of stabilizer model)

Unit No. Dynamic Model


Dynamic ModelUnit No.

Installation No.

Damper winding

(connection method)

Unit No.Power Plant Name

Typical Exciter Parameters, Constants and Coefficients (may vary depending on type of exciter model)



Model CONS Model ICONS

Saturation coefficients Time constantsUnsaturated reactances

Design ambient temperature ⁰C

Temp. rise at rated power ⁰C

i Model Type PSS KQV KQS TQ T'Q1 TQ1 T'Q2 TQ2 T'Q3 TQ3 VS lim CON1 CON2 CON3 CON4 CON5 CON6 CON7 CON8Bus No. Installation



PSS feedback (frequency, speed,

accelerating power)

PSS voltage gain (p.u.)

PSS speed gain (p.u.)

PSS reset time constant

(s)

First lead time constant (s)

First lag time constant (s)

Second lead time constant (s)

Second lag time constant (s)

Third lead time constant (s)

Third lag time constant (s)

PSS output limit setting (p.u.)

9000 99990 Plant 1 1 IEEEST Standard9001 99991 Plant 1 29002 99992 Plant 1 39003 99993 Plant 2 19004 99994 Plant 2 29005 99995 Plant 3 1


Wind Farm Modeling Data Reporting TemplateWind Generator Characteristics and Steady-state Data

i MES PMAX (MW) EPOI (kV) PRated (MW) QMAX (MVAR) QMIN (MVAR) En (kV) Snom (MVAR) XSource (p.u.) ECollector (kV) RCollector (p.u.) XCollector (p.u.)Bus No. Initial Commissioning

DateInstalled Capacity Voltage level at

point of interconnection

WEC Manufacturer

Model Name Rated power of one WT

Number of WTs

Max Reactive Power Export

Min Reactive Power Import

Nominal Voltage

Nominal Apparent

Power

Source Reactance Voltage level of

collector network

Equivalent Resistance of

collector network

Equivalent Reactance of

collector network

9500 Wind Farm 1 19501 Wind Farm 2 1

Wind Generator Dynamics Data

i Model Type CON1 CON2 CON3 CON4 CON5 CON6 CON7 CON8 CON9 CON10 ICON1 ICON2 ICON3 ICON4Bus No. Wind Farm Name Standard Library Model

or User-written Model


Wind Electrical Model Data

i Model Type CON1 CON2 CON3 CON4 CON5 CON6 CON7 CON8 CON9 CON10 ICON1 ICON2 ICON3 ICON4Bus No. Wind Farm Name Standard Library



Wind Mechanical Model Data




Wind Pitch Control Model Data

i Model Type CON1 CON2 CON3 CON4 CON5 CON6 CON7 CON8 CON9 CON10 ICON1 ICON2 ICON3 ICON4



Model CONS

U it

Model ICONS


Single Wind Turbine (WT) Data Collector Network Data


Model ICONS

Wind Farm Name Unit No.


Model CONS

Bus No. Wind Farm Name Standard Library Model or User-written

Model


Wind Aerodynamic Model Data






Model ICONSModel CONS



APPENDIX 5 – HQT Bus Numbering and Classification

A5.1 Bus Number Ranges

Bus Number Ranges Bus Types Nominal Voltage Regional Area

1-299 Generator Buses All All

300-699 Substation and Line Buses 315 kV All


800-999 Reactive Compensator Buses 735 kV All

1000-1099 Miscellaneous Buses All All






2500-2799 Load Buses < 120 kV La Grande

2800-3149 Load Buses < 120 kV Mauricie Nord

3150-3499 Load Buses < 120 kV Manicouagan

3500-3829 Load Buses < 120 kV Montmorency Nord

3860-4149 Load Buses < 120 kV Saguenay

4150-4499 Load Buses < 120 kV Laurentides (Outaouais)

4500-5509 Load Buses < 120 kV Richelieu

5510-5699 Load Buses < 120 kV Mauricie Sud

5700-6349 Load Buses < 120 kV Montmorency Sud

6350-6999 Load Buses < 120 kV Matapédia

7000-7599 Load Buses < 120 kV St-Laurent

7600-8899 Load Buses < 120 kV Laurentides (inc. Laval)

8900-8999 Reserved Buses All All

9000-9999 Miscellaneous Load Buses < 120 kV All

10000-12999 Miscellaneous All All

13000-13999 Generator Buses (Wind Farm) < 6 kV Montmorency

14000-14999 Generator Buses (Wind Farm) < 6 kV Richelieu

15000-15999 Generator Buses (Wind Farm) < 6 kV Mauricie

16000-16999 Generator Buses (Wind Farm) < 6 kV Matapédia


20000-98999 Transformer tertiary winding bus < 69 kV All




A5.2 NPCC Area Codes

Area Number Area ID Area Name

101 ISO-NE ISO New England

102 NYISO New York ISO

103 IESO Independant Electric System Operator (Ontario)

104 HQT Hydro-Québec TransÉnergie

105 NB New Brunswick Power

106 NS Nova Scotia Power

107 CRT Cedars Rapids Transmission

A5.3 Québec Interconnection Zoning Codes

Zone Number Classification Voltage Level Regional Zone

1 HQT Transmission System 315 kV St-Laurent

2 HQT Transmission System 315 kV Laval

3 HQT Transmission System 161 to 49 kV St-Laurent

4 HQT Transmission System 161 to 49 kV Laval

5 HQT Transmission System 230 kV Richelieu

7 HQT Transmission System 315 kV Rive-Nord

8 HQT Transmission System 315 kV Mauricie Nord, Mauricie Sud

9 HQT Transmission System 315 kV Montmorency Nord, Montmorency Sud

10 HQT Transmission System 230 kV Mauricie Nord

11 HQT Transmission System 230 kV Montmorency Nord

12 HQT Transmission System 161 to 49 kV Rive-Nord

13 HQT Transmission System 161 to 49 kV Mauricie Nord

14 HQT Transmission System 161 to 49 kV Montmorency Nord

15 HQP Generating Facilities N/A Mauricie Nord

16 HQP Generating Facilities N/A Laval, Rive-Nord


18 HQT Transmission System 230 kV Mauricie Sud

19 HQT Transmission System 230 kV Montmorency Sud


21 HQT Transmission System 161 to 49 kV Richelieu

22 HQT Transmission System 161 to 49 kV Mauricie Sud

23 HQT Transmission System 161 to 49 kV Montmorency Sud

24 HQP Generating Facilities N/A Richelieu

25 HQP Generating Facilities N/A Mauricie Sud

26 HQT Transmission System 161 to 49 kV Mauricie Nord

27 HQT Transmission System 315 kV Matapédia

28 HQT Transmission System 230 kV Matapédia

29 HQT Transmission System 161 to 49 kV Matapédia

30 HQP Generating Facilities N/A Matapédia

32 HQT Transmission System 315 kV Manicouagan

33 HQT Transmission System 161 to 49 kV Manicouagan

34 HQP Generating Facilities N/A Manicouagan



36 SCHM Transmission System N/A Manicouagan

37 RTA Transmission System N/A Saguenay


39 RTA Generating Facilities N/A Saguenay

41 HQT Transmission System 230 kV Saguenay

42 RTA Transmission System 161 to 49 kV Saguenay

43 HQT Transmission System 230 kV Outaouais

44 HQT Transmission System 315 kV Outaouais

45 HQT Transmission System 161 to 49 kV Outaouais

46 HQP Generating Facilities N/A Outaouais

47 ÉLL Transmission System N/A Outaouais

48 HQT Transmission System 315 kV Abitibi

49 HQT Transmission System 161 to 49 kV Abitibi

50 HQP Generating Facilities N/A Abitibi

51 HQT Transmission System 161 to 49 kV Baie James

53 HQT Transmission System 735 kV Manicouagan

54 HQT Transmission System 735 kV Montmorency Nord, Rive-Nord, Saguenay

55 HQT Transmission System 735 kV Mauricie Sud, Montmorency Sud, Richelieu

56 HQT Transmission System 735 kV Laval

57 HQT Transmission System 735 kV Baie James, Rive-Nord, Sageunay

58 HQT Transmission System 315 kV Baie James

59 HQP Generating Facilities N/A Baie James

60 Privately Owned Generating Facilities N/A Abitibi, Baie James

61 Privately Owned Generating Facilities N/A Laval, Rive-Nord

62 Privately Owned Generating Facilities N/A Matapédia

63 Privately Owned Generating Facilities N/A Mauricie Nord, Mauricie Sud

64 Privately Owned Generating Facilities N/A Manicouagan

65 Privately Owned Generating Facilities N/A Montmorency Nord, Montmorency Sud

66 Privately Owned Generating Facilities N/A Richelieu

67 Privately Owned Generating Facilities N/A St-Laurent

68 Privately Owned Generating Facilities N/A Saguenau

69 High Voltage Client Facilites N/A Manicouagan

70 High Voltage Client Facilites N/A Matapédia

71 High Voltage Client Facilites N/A Saguenay

72 High Voltage Client Facilites N/A Outaouais

73 High Voltage Client Facilites N/A Abitibi

74 High Voltage Client Facilites N/A Mauricie Sud

75 High Voltage Client Facilites N/A Richelieu

76 High Voltage Client Facilites N/A Montmorency Nord

77 High Voltage Client Facilites N/A Montmorency Sud

78 High Voltage Client Facilites N/A St-Laurent

79 High Voltage Client Facilites N/A Rive-Nord

80 High Voltage Client Facilites N/A Mauricie Nord

81 Interconnections N/A Outaouais

82 Interconnections N/A Richelieu

83 RTA Transmission System N/A Mauricie Nord

84 RTA Transmission System N/A Richelieu




86 Interconnections N/A Abitibi

87 Interconnections N/A Richelieu

88 Interconnections N/A Matapédia

90 Load Zone < 49 kV Saguenay

91 Load Zone < 49 kV Manicouagan

92 Load Zone < 49 kV St-Laurent

93 Load Zone < 49 kV Richelieu

94 Load Zone < 49 kV Montmorency Nord, Montmorency Sud

95 Load Zone < 49 kV Laval, Outaouais, Rive-Nord

96 Load Zone < 49 kV Mauricie Nord, Mauricie Sud

97 Load Zone < 49 kV Abitibi, Baie James

98 Load Zone < 49 kV Matapédia

99 Reserved for internal usage N/A N/A



APPENDIX 6 – Interchange Data Template

LISTE DES CLIENTS 20XXPOUR LE SERVICE DE TRANSPORT

POINT-À-POINT

No. Clients Code No Code Nom Mode Date signat. POR/POD Lcrédit /garantie Actifs Dernier achat Déléguédossier OASIS ref PSE original pré- Convention MW LT LT CT Révoquée achats en 2015 Année responsable

Résev. OASIS Tag paiement AA/MM/JJ (sortie) Début Fin AA/MM/JJ12345678910

Convention

Mise à jour: 23 février 2015 1

Référ

ence

OASI

S

clien

t

POR

/ POD

MW so

rtie

REDI

RECT

RECA

LL

À L'É

TUDE

Débu

t

Fin HQT

-CHN

O

HQT-

DYMO

HQT-

LAW

HQT-

ON

HQT-

P33C

HQT-

CORN

HQT-

NB

HQT-

DEN

HQT-

MASS

HQT-

DER

HQT-

HIGH

HQT-

NE

EMI-M

AHO

LAW

-HQT

ON-H

QT

OTTO

-HQT

Q4C-

HQT

NB-H

QT

LAB-

HQT

DEN-

HQT

MASS

-HQT

HIGH

-HQT

NE-H

QT

MAT

I-HQT

MAF

A-HQ

T

MAH

O-MA

TI

65 85 800 1250 345 160 1029 199 1800 50 225 2000 250 470 1250 85 140 785 5150 100 1000 170 2000 250 99 110

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