LONG-TERM DEVELOPMENT PLAN-2016 - for Manitoba Hydro's Electrical Transmission System - OATi Oasis
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LONG-TERM DEVELOPMENT PLAN—2016
for Manitoba Hydro's Electrical Transmission System
Manitoba
Manitoba Hydro’s
Hydro’s Existing
Existing Generating
Generating Stations
Stations
and
and Transmission
Transmission System
System
ii LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System
2 LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System
Executive Summary
Manitoba Hydro’s electrical transmission system, consists of a network of alternating current (ac)
transmission lines and terminal stations plus high voltage direct current (HVDC) transmission lines and
converter stations that collectively deliver the power from Manitoba Hydro’s generating stations to
customers across the province and beyond provincial boundaries. This report describes the current
long term development Plan for Manitoba Hydro’s electrical transmission system covering the period
from 2016 to 2035.
The Plan describes the proposed additions, enhancements, replacements, and refurbishments that
are needed to ensure the transmission system continues to meet Manitoba Hydro’s mandate of
serving the province with a reliable supply of electricity as well as meeting the regulated performance
requirements of Manitoba Hydro and its interconnected utilities in Canada and the United States.
A basic performance requirement is that the transmission system be able to continue to serve firm
load during an outage of a system element such as a transmission line, transformer, circuit breaker,
or other auxiliary device (also known as N-1 contingency planning). The transmission system must
also be designed and operated such that an outage to one part of the network will not cascade
or cause stress to other parts of the transmission system or interconnected utilities outside the
province. Achieving these goals requires the timely implementation of additions, enhancements and
replacements in order to avoid load shed, rotating blackouts or loss of export capacity.
The bulk of Manitoba’s power is transmitted from remote generating stations in the north to
customers in southern Manitoba over the Nelson River HVDC transmission system. The HVDC
system is a critical component for meeting the electricity needs of the province. The two Nelson
River HVDC transmission lines are located in the same corridor, and both HVDC southern
converters are located at Dorsey which makes the current HVDC system vulnerable to a common
outage. This plan includes overview of Bipole III project which increases the robustness of the
HVDC system by providing an alternate transmission corridor and terminus.
This Plan describes projects that span two main investment types and eight drivers of need for
transmission capital investments. The two investment types are growth and sustainment, while the
eight drivers are safety, load growth, reliability, transmission service, new generation, new customer
connections, efficiency and aging infrastructure. The Plan also identifies which region of the province
is being addressed by each capital investment. The map on the following page provides a visual for
the more significant growth and sustainment projects to be implemented during the first ten years
(fiscal years 2016/17 to 2025/26) of the current Capital Expenditure Forecast CEF16. A summary
table follows, listing the approved and proposed capital investments covered by the Plan, grouped by
region and investment type, with a mapping to the drivers that apply to each. A total of $6.15 billion of
transmission-related project expenditures has been identified in the 20-year CEF16. The large majority
of these expenditures are associated with growth, at $4.65 billion or 76%, while $1.50 billion or 24% are
investments for sustainment.
The long-term development plan is reviewed and adjusted annually to reflect revised load forecasts,
updated system performance and asset condition assessments, and new requests for transmission
service, bulk load connections and generation connections. Not all of the projects identified in this
Plan will necessarily be built; while some are approved and either underway or ready for execution,
others represent proposed investments that are in the early planning stage and hence are subject
to change.
The new station sites and transmission lines associated with the projects described in this Plan are
shown for illustrative purposes only. Manitoba Hydro follows a Site Selection and Environmental
Assessment Process, which includes public consultation on the preferred location of new stations
and routing of new transmission lines, and obtaining the regulatory licenses necessary for
construction of facilities.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System iii
Transmission Business Unit - Heat Map for Major + Base Capital Under CEF16 (Fiscal years 2017-2026) iv LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System
Major Transmission System Projects and Drivers
Maintain or Improve Reliability
Provide Transmission Service
Address Aging Infrastructure
Connect New Generation
Serve Local Load Growth
Drivers of Need
Customer Connections
Increase Efficiency
Improve Safety
ISD
INTERCONNECTION PROJECTS
Manitoba-Minnesota Transmission Project 2020 05
Manitoba-Saskatchewan Transmission Interface Project 2021 06
Keeyask Generation Outlet Transmission Facilities 2021 08
INTER-REGIONAL
Sustainment
Bipole II Thyristor Valve Replacement 2027 03(**)
Bipole I & II Major Refurbishment (*) 2036 03
HVDC Transformer Sustainment Program 2037 03(**)
Dorsey Synchronous Condenser Refurbishment (extended) 2031 03 (**)
Bipole I & II DC Disconnects 2029 03
HVDC Transformer Sustainment (extended) 2030 03 (**)
Transmission Line Upgrades for Improved Clearance (NERC) 2023 03 (**)
Dorsey Synchronous Condenser Refurbishment 2026 03(**)
Transmission Transformers Sustainment Capital Program 2032 09 (**)
Transmission Line Footing Sustainment Program 2030 03 (**)
HVDC Smoothing Reactor Replacements 2023 10 (**)
Station Battery Bank Replacement Program 2022 03
Transmission Line Protection & Teleprotection Replacement 2018 05 (**)
Bipole I & II Space Dampers Project (Phase 2) 2017 12 (**)
Transmission Line Wood Pole Sustainment Capital Program 2026 03 (**)
Mobile Radio System Modernization 2017 06
Bipole I & II Communications Upgrade 2024 03
115 kV Protection Upgrades 2023 03 (**)
Telecommunications 48VDC Upgrades 2036 (**)
HVDC BP2 Valve Hall Wall Bushing Replace 2024 10 (**)
PCB Bushing Elimination Program 2024 03 (**)
HVDC Gapped Arrester Replacement 2021 11 (**)
Transmission Breaker Sustainment Capital Program 2033 03 (**)
HVDC Circuit Breaker Opp. Mechanical Replacement 2019 03 (**)
13.2 kV Shunt Reactor Replacement Program 2018 11 (**)
HVDC BP2 Refrigerant Condenser Replacement 2025 11 (**)
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System v
Maintain or Improve Reliability
Provide Transmission Service
Address Aging Infrastructure
Connect New Generation
Serve Local Load Growth
Drivers of Need
Customer Connections
Increase Efficiency
Improve Safety
ISD
HVDC BP1 DCCT Transductor Replacement 2028 10 (**)
HVDC System Transformer & Reactor Fire Protection 2017 06
Bipole I & II DC Filter Protection 2025 03
Growth
Bipole III Reliability Project 2018 07
Southern AC System Breaker Replacements 2017 06 (**)
Winnipeg Area Capacitor Bank Additions (Phase 1) 2019 11
Winnipeg Area Capacitor Bank Additions (Phase 2) 2026 10
REGIONAL
Northern Region
Sustainment
Diesel Generating Station Upgrades 2020 03
Mile 13 Station Salvage 2028 03
Western Region
Sustainment
Brandon Area Transmission Improvements 2016 07
Growth
Southwestern Manitoba Capacity Enhancement 2030 10
Winnipeg to Brandon System Improvements 2025 04
Brandon-Victoria 115-66 kV Capacity Addition 2022 10
Souris East Transformer Capacity Enhancement 2019 10
Dauphin/Vermillion 230 kV Station Capacity Increase 2022 10
Interlake Region
Growth
Ashern Bank Addition 2023 09
Rosser Station 115-66 kV Transformer Addition 2019 10
Eastern Region
Sustainment
Pointe du Bois Transmission Refurbishment/Redevelopment (Phase 1) 2016 12
Growth
Steinbach Area 230-66 kV Capacity Enhancement 2020 10 (**)
Lake Winnipeg East System Improvements 2017 09
Letellier - St. Vital 230 kV Transmission Line 2020 07
Pointe du Bois Transmission Refurbishment/Redevelopment (Phase 2) 2024 04
vi LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System
Maintain or Improve Reliability
Provide Transmission Service
Address Aging Infrastructure
Connect New Generation
Serve Local Load Growth
Drivers of Need
Customer Connections
Increase Efficiency
Improve Safety
ISD
Whiteshell Area 115-33/66 kV Station 2028 10
Stanley Station 230-66 kV Transformer Additions 2018 10
Portage Area 230-66 kV Capacity Upgrade 2029 10
Winnipeg Region
Growth
Rockwood East 230-115 kV Station & Line Sectionalization 2016 02 (**)
SW Winnipeg 115 kV Transmission System Improvements 2021 10 (**)
La Verendrye to St. Vital 230 kV Transmission Line and Breakers 2020 10 (**)
Northeast Winnipeg Capacity Enhancement 2031 10
La Verendrye Station 230-66 kV Bank Addition 2023 10
(*) Projects indicated in red are currently in the Early Planning Stage and subject to change.
(**) Multiple years
Table does not include projects under $10 million.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System vii
Contents
Manitoba Hydro’s Existing Generating Stations and Transmission System.................................... ii
Executive Summary......................................................................................................................................... iii
Major Transmission System Projects and Drivers.................................................................................. v
1. Introduction.................................................................................................................................................. 1
2. Drivers and Process for Transmission Capital Investments............................................................. 3
2.1 Drivers.................................................................................................................................................................................................3
2.1.1 Improve Safety............................................................................................................................................................3
2.1.2 Serve Local Load Growth...................................................................................................................................3
2.1.3 Maintain and Improve Reliability....................................................................................................................4
2.1.4 Provide Transmission Service...........................................................................................................................4
2.1.5 Connect New Generation..................................................................................................................................4
2.1.6 Customer Connections........................................................................................................................................5
2.1.7 Increase Efficiency....................................................................................................................................................5
2.1.8 Address Aging Infrastructure............................................................................................................................5
2.2 Planning Process..........................................................................................................................................................................6
3. Transmission System Projects................................................................................................................. 9
3.1 Interconnections Projects.....................................................................................................................................................9
3.1.1 Manitoba - Minnesota Transmission Project (MMTP)....................................................................9
3.1.2 Manitoba-Saskatchewan Transmission Interface Project (MH-SPC)..................................11
3.1.3 Keeyask Generation Outlet Transmission Facilities.........................................................................13
3.2 Inter-Regional Projects..........................................................................................................................................................15
3.2.1 Growth..............................................................................................................................................................................17
3.2.1.1 Bipole III Reliability Project............................................................................................................................17
3.2.1.2 Winnipeg Area Capacitor Bank Additions..........................................................................................19
3.2.2 Sustainment..................................................................................................................................................................19
3.2.2.1 Transmission Line Upgrades for Improved Clearance................................................................19
3.2.2.2 Bipole I & II Spacer Damper Replacement..........................................................................................20
3.2.2.3 Bipole II Thyristor Valve Replacement...................................................................................................20
3.2.2.4 HVDC Transformer Replacement Program.......................................................................................20
3.2.2.5 Dorsey Synchronous Condenser Refurbishment.........................................................................21
3.2.2.6 Circuit Breaker Replacements.....................................................................................................................21
viii LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System
3.3 Regional Issues/Solutions......................................................................................................................................................22
3.3.1 Regional Load Growth...........................................................................................................................................22
Summer Load Growth Projections............................................................................................................................24
Winter Load Growth Projections...............................................................................................................................25
3.3.2 Northern Region.....................................................................................................................................................................26
3.3.2.1 Diesel Plant Upgrades.......................................................................................................................................27
3.3.2.2 Mile 13 Station Salvage...................................................................................................................................27
3.3.3 Western Region.......................................................................................................................................................................28
3.3.3.2 Souris East Capacity Enhancement........................................................................................................31
3.3.3.3 Brandon-Victoria 115 kV Breaker Replacement..........................................................................31
3.3.3.4 Reston Station New 230 kV Ring Breaker........................................................................................31
3.3.3.5 Virden West Capacitor Bank Installation.............................................................................................31
3.3.3.6 Dauphin/Vermilion 230 kV Capacity Increase................................................................................31
3.3.3.7 Brandon-Victoria Station Capacity Increase....................................................................................32
3.3.3.8 Southwestern Manitoba Capacity Enhancement.........................................................................32
3.3.4 Interlake Region.......................................................................................................................................................................33
3.3.4.1 Ashern Bank Addition........................................................................................................................................34
3.3.4.2 Rosser Station 115–66 kV Transformer Addition .....................................................................34
3.3.5 Eastern Region.........................................................................................................................................................................35
3.3.5.1 Steinbach Area Capacity Enhancement...............................................................................................36
3.3.5.2 Stanley Station 230-66 kV Station Expansion..............................................................................37
3.3.5.3 Pointe du Bois Transmission Refurbishment/Redevelopment.............................................38
3.3.5.4 Lake Winnipeg East System Improvements.....................................................................................39
3.3.5.6 Letellier - St. Vital 230 kV Transmission Line..................................................................................41
3.3.5.7 Whiteshell Station Bank 1 Replacement.............................................................................................42
3.3.5.8 Whiteshell Area 115–33/66 kV Station............................................................................................42
3.3.6 Winnipeg Region.....................................................................................................................................................................43
3.3.6.1 Improvements of 115 kV Southwest Winnipeg Transmission System.........................45
3.3.6.2 La Verendrye to St. Vital 230 kV Transmission Line...................................................................47
3.3.6.3 La Verendrye 3rd Bank Addition...............................................................................................................48
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System ix
4. Future Capital Requirements for Transmission.................................................................................. 49
4.1 Future Transmission Interconnections.........................................................................................................................49
4.2 Access to Electricity Markets - Transmission Service.......................................................................................49
4.3 Future Generation Interconnection..............................................................................................................................50
4.4 Wind Generation Interconnection.................................................................................................................................51
4.5 Northern Exploratory Study...............................................................................................................................................53
4.6 Major Customer Interconnection and Load Addition.......................................................................................53
4.7 Addressing Aging Infrastructure.......................................................................................................................................53
4.8 Northern Damping (Low Frequency Oscillations)..............................................................................................54
4.9 Future Transmission Corridors..........................................................................................................................................55
4.10 Resource Adequacy................................................................................................................................................................56
Appendix 1......................................................................................................................................................... 57
Appendix 2 — Glossary................................................................................................................................. 63
x LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System1. Introduction
The Long Term Development Plan - for Manitoba Hydro’s Electrical Transmission System - 2016
addresses future transmission system developments.
This 2016 plan reflects planned projects that have been approved in the 2016 Manitoba Hydro
Capital Expenditure Forecast (CEF16).
Manitoba Hydro is a provincial Crown Corporation providing electricity to 567,634 customers
throughout Manitoba and natural gas service to 276,858 customers in various communities
throughout southern Manitoba (Manitoba Hydro-Electric Board 65th Annual Report). Manitoba
Hydro also has formal electricity export sale agreements with a number of electric utilities and
marketers in the Midwestern U.S., Ontario, and Saskatchewan.
Nearly all electricity generated is from clean renewable water power. On average, about 33.1
billion kilowatt-hours of electricity are generated annually. Seventy-five percent is produced by five
hydroelectric generating stations on the Nelson River; the remainder is generated at ten hydroelectric
stations on the Winnipeg, Saskatchewan, Burntwood and Laurie rivers; two thermal stations; two
independently owned wind farms and four diesel sites. The electricity is transmitted over nearly
100,000 kilometres of transmission and distribution lines.
Manitoba Hydro has 5,690 MW of generation connected to its network. In addition, 116 MW of wind
generation at St. Leon and 138 MW of wind generation at St. Joseph are available to Manitoba Hydro
under power purchase agreements. Roughly 3.7% of Manitoba’s annual energy generation is supplied
by wind turbines.
In 2015/16, the corporation supplied a provincial gross total peak of 4,479 MW (weather adjusted
4,634 MW). The provincial peak load is growing at an average rate of about 1.4% per year (energy
1.4% per year) over the next 10 years.
The length of transmission lines connected to Manitoba Hydro’s transmission network include the
following:
• 1840 km of 500 kV transmission (HVDC)
• 210 km of 500 kV transmission (AC)
• 5000 km of 230 kV transmission (AC)
• 1400 km of 138 kV transmission (AC)
• 2900 km of 115 kV transmission (AC)
Manitoba Hydro plans additions and enhancements to its transmission and distribution systems to
ensure that the systems will continue to operate acceptably in the future, as the requirements change.
Manitoba Hydro expects its transmission system to meet performance requirements set out in the
following:
• North American Electric Reliability Corporation (NERC) Reliability Standards
• Manitoba Hydro’s own Transmission System Interconnection Requirements (TSIR), which
defines standards for system adequacy, reliability, and security.
These standards and criteria are used to develop system addition and enhancement plans. Numerous
transmission system developments comprise this plan.
Each of the developments discussed has one or more drivers of need, which are described in detail in
Chapter 2. This chapter also includes the planning process followed to develop and prioritize projects.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 1Transmission regional issues and solutions are introduced in Chapter 3. Project developments are
also highlighted in this chapter with brief descriptions, expected in-service dates, and estimated cost
estimates.
Currently, there are no independent generator developments in the queue. For the sake of
completeness, the major proposed utility transmission and generation developments, although not
finalized, are also briefly reviewed in Chapter 4. Section 4.7 of this plan provides insight into a long-
term (10 years) strategy to replace aging transformers, circuit breakers and wood pole transmission
structures.
Manitoba Hydro’s existing transmission facilities are outlined in Appendix 1. Abbreviations and some
utility terms are listed in Appendix 2.
This document is the current Long Term Development Plan for Manitoba Hydro’s electrical
transmission system. Subsequent development plans will be issued annually to reflect changing
circumstances such as changes in customer demand, the need for reliability enhancements, request
for transmission service, or the addition of new generator connections, addressing aging infrastructure
or regulatory requirements.
The Long Term Development Plan will be posted on Manitoba Hydro Open Access Same Time
Information System (OASIS) website, which can be found on the Manitoba Hydro web page (http://
www.hydro.mb.ca), then by clicking on Transmission Tariffs for Energy Supplies and Power Producers,
under Your Business tab, and then selecting either the Transmission Tariff Link or Interconnection
Tariff Link to get to the Manitoba Hydro OASIS page (http://www.oasis.oati.com/MHEB/index.html).
The Long Term Transmission Plan is located under the System Information tab.
From Generating Stations to
Customers
The major transmission system is a network Voltage Ranges:
of high voltage transmission lines used to
move electrical power over long distances, • Generating Stations: 4 kV to 15 kV
from generating stations to terminal stations.
• HVDC ± 463.5 kV, ± 500 kV
At terminal stations, electrical power is
• Northern Transmission: 138 kV,
transformed down to mid-range voltages and
230 kV
sent over a network of distribution system
lines to groups of distribution stations. • Southern Transmission: 115 kV,
230 kV, 500 kV
At each distribution station power is
transformed to lower voltages and distributed • Distribution: 4 kV to 66 kV
over the distribution system feeder lines
(either overhead pole lines or underground Note: 1 kV is 1,000 volts
cables) to distribution transformers. Each
distribution transformer transforms the
voltage to lower user voltages, to directly
feed a customer or a cluster of customers.
2 LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System2. Drivers and Process for Transmission Capital
Investments
Manitoba Hydro’s transmission planning process identifies plans to connect new generating resources
and new customers and assesses the adequacy of the existing and planned transmission network to
provide a reliable and economic supply of electricity to Manitoba customers and external customers.
Conceptual plans are developed, based on generation and load forecasts over a 10-20 year period, to
ensure that the Manitoba load and contractual firm exports can be served.
Manitoba Hydro plans transmission facilities in compliance with all applicable local, regional and
international reliability standards and requirements. Planning studies and assessments follow
established methodologies and must meet standards and criteria established by Manitoba Hydro and
other regulating entities such as the Midwest Reliability Organization (MRO) and NERC.
2.1 Drivers
There are eight drivers of need in determining additions, enhancements, repairs and replacements
required to the transmission and HVDC systems.
1. Improve safety
2. Serve local load growth
3. Maintain or improve reliability
4. Provide transmission service
5. Connect new generation
6. Customer connections
7. Increase efficiency
8. Address aging infrastructure
Each of the projects highlighted in this plan reflects one or more of these drivers, but not necessarily
all eight of the drivers.
2.1.1 Improve Safety
Safety is Manitoba Hydro’s first priority and most important goal. One of the important components of
Manitoba Hydro’s vision is to be recognized as a leading utility in North America with respect to safety.
Manitoba Hydro is committed to protecting the public and its employees from personal injury by
maintaining and operating the transmission system in a safe manner. This commitment involves
modifying existing circuit protection schemes, implementing new protection schemes, and periodically
replacing or upgrading aging infrastructure to meet changing conditions. Circuit protection schemes
are installed to minimize the probability of equipment failure and personal injury. Transmission lines are
upgraded to ensure adequate clearance between the energized conductors and ground level.
2.1.2 Serve Local Load Growth
Forecasted provincial load growth is used to determine the need for transmission system additions
and enhancements. Expected provincial load growth is detailed in a corporate “2016 Electric Load
Forecast”. Developed annually, the Electric Load Forecast predicts provincial electric load growth
for the next 20 years in various load sectors, including residential, general service, area and roadway
lighting, construction power, and station service. Electric load forecast predictions are based on
historical billing data and the current economic and energy price outlook and planned corporate
demand side management targets.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 32.1.3 Maintain and Improve Reliability
To fulfill its vision to be recognized as a leading utility in North America with respect to reliability,
Manitoba Hydro endeavors to continue to serve firm load for an outage of a transmission system
element such as transmission line, transformer, circuit breaker, or any other auxiliary device. If
a system element fails to function to its design specification for any reason, the network can be
re-configured so that affected area can be served from an alternate supply in most of cases. The
transmission system is designed such that outages in one part of the network should not cascade or
spread to neighboring areas of the transmission system causing stress on other system elements.
Achieving these goals often requires transmission system additions, replacements and enhancements.
If these improvements are not completed in a timely manner, service to firm load customers would be
greatly compromised.
Manitoba Hydro regularly conducts system simulation studies to assess the performance of the
existing and future projected systems against reliability standards and to determine what transmission
system improvements are required to maintain system reliability.
Manitoba Hydro expects its transmission system to meet the provincially legislated performance
requirements of the North American Electric Reliability Corporation (NERC) standards, and its own
Transmission System Interconnection Requirements.
2.1.4 Provide Transmission Service
Transmission system improvements may be required to provide or maintain transmission service
under Manitoba Hydro’s Open Access Transmission Tariff (OATT). In addition Manitoba Hydro receives
numerous requests for seasonal firm service and short term non-firm service, all of which are posted
on the Manitoba Hydro website. (see section 4.2)
Export Sales: Manitoba Hydro currently has long term firm export sales agreements with utilities in
Minnesota, Wisconsin and Saskatchewan.
Import Purchases: Manitoba Hydro plans its generation resources based on hydraulic generation
availability during the lowest river flows on record. The hydraulic generation is augmented by Manitoba
Hydro thermal generation and imports.
Manitoba Hydro secures imported power during the winter season. The Corporation’s predominantly
hydraulic generation system usually produces surplus energy during the summer season, when river
flows are generally normal or above normal. Peak Manitoba loads occur in winter.
Import purchase agreements are also used to provide energy during periods of sustained drought.
2.1.5 Connect New Generation
Generation within the province may be connected to the Manitoba Hydro transmission or
distribution system, in accordance with the terms and conditions of the Manitoba Hydro’s Open
Access Interconnection Tariff (OAIT), posted on the Manitoba Hydro website (see section 4.2).
Manitoba Hydro conducts system studies to determine what enhancements or additions to the
network will be required to connect new generation. Major generation can be connected to the
transmission system with minor transmission additions only if the generation is close to major load
centres or if the generation results in reversed or reduced flow on the existing transmission network.
4 LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System2.1.6 Customer Connections
New major customer loads requiring up to 5000 kW of power can generally be supplied by the
distribution system, whereas new major loads requiring more than 5000 kW of power will likely
need to be supplied by the high voltage distribution system or network transmission system.
Technical requirements for connecting generators and loads to the high voltage distribution
or network transmission systems are defined in Manitoba Hydro’s “Transmission System
Interconnection Requirements”, also available on Manitoba Hydro’s website which can be found on
the Manitoba Hydro web page (http://www.hydro.mb.ca), then by clicking on Transmission Tariffs
for Energy Supplies and Power Producers, under Your Business tab, then selecting either the
Transmission Tariff link or Interconnection Tariff link to get to the Manitoba Hydro OASIS page
(http://oasis.midwestiso.org/oasis/mheb).
2.1.7 Increase Efficiency
The responsibility of the Transmission is to provide a reliable and safe transmission system for the
delivery of electricity to domestic and out-of-province customers at the lowest possible cost. In order
to achieve this objective, Manitoba Hydro conducts system simulation studies to determine feasible
transmission system improvements for efficient energy transmission and reduced power losses. Bipole
III will provide increased efficiency by means of reducing HVDC transmission losses in Manitoba’s three
HVDC bipoles. Transmission voltage upgrades have also been implemented to reduce losses.
2.1.8 Address Aging Infrastructure
Replacement or repair of aging infrastructure is often required to attain a reliable transmission system.
Refurbishment of aging transmission lines, the reconstruction of high voltage transmission circuits and
the replacement of circuit breakers that have reached their end-of-life are examples. Re-construction
of Scotland Station, Pointe du Bois line upgrades, and replacement of St. James station, are further
examples. Manitoba Hydro’s Transmission business unit has also started a condition assessment
program for its major assets and, based on initial results, has established sustainment programs for its
transformer, circuit breaker and transmission line wood pole structure assets as part of its capital plan
to fund proactive replacements and refurbishments.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 52.2 Planning Process
Planning of the Manitoba Hydro transmission system is performed by the System Planning
Department. The primary objective of the planning process is to ensure the transmission system
can economically meet the current and future energy needs of the province in compliance with all
applicable local, regional and international reliability standards and requirements. The North American
Electric Reliability Corporation (NERC)1 Planning Standards require that a transmission system
performs in a reliable manner not only under normal system operating conditions but also following
a range of system disturbances using year 1 and year 5 models for the present and near-term
assessment and year 10 model for long-term assessment. As a member of the Midwest Reliability
Organization (MRO)2 , Manitoba Hydro complies with the NERC Transmission Planning Standards by
completing an annual Transmission System Performance Assessment and submitting to the MRO a
study report and documentation of any planned transmission system upgrades. Manitoba Hydro also
coordinates planning activities with other neigbouring utilities and jurisdictions.
Planning begins with concepts that are developed in response to the annual long term provincial
load forecast, the annual Transmission System Performance Assessment, requests for generation
interconnections, transmission usage requests, and bulk load connection requests. These concepts
are studied and refined into alternatives in consultation with various stakeholders, and the
alternative that represents the best overall value to the customer is chosen for implementation as a
capital investment project.
Public consultation and regulatory approvals are required to implement the selected plan if it involves
development of a new station site, a new transmission corridor, and/or a new international or inter-
provincial connection. Manitoba Hydro follows a Site Selection and Environmental Assessment process
which includes public consultations to select locations for stations and routes from transmission lines
and obtain the regulatory licenses necessary for construction of new facilities. Manitoba Hydro also
conducts Environmental Impact Assessment and develops a comprehensive Environment Protection
Plan for each facility proposed.
The newly identified capital investments are added to the list of active and future capital investments, and
this portfolio of projects is prioritized over the ten-year forecast window. The goal of the prioritization
process is to optimize the scheduling of capital investments to achieve the best net value possible with
the resources available. The factors that are considered during prioritization are as follows:
a) a project’s matrix score under the Capital Budget Ranking Tool,
b) a project’s risk profile determined via the System Reliability Risk Model (i.e., the ∆EUE),
c) a project’s readiness to execute,
d) the options available to mitigate the risks associated with deferral of an investment.
Each of these is explained in the following paragraphs:
a) The Capital Budget Ranking Tool was developed in 2006 as a means of ranking the relative
importance of Transmission’s capital investments using common criteria that are linked to
business unit goals. The tool provides a matrix framework for scoring projects based on the
degree to which they contribute to the goals of safety, service and reliability, transfer capacity,
a positive financial impact, and/or a positive environmental impact. The more goals to which
1 The North American Electric Reliability Corporation is a not-for-profit international regulatory authority whose mission is to assure the
reliability of the bulk power system in North America.
2 Midwest Reliability Organization (MRO) is a non-profit organization dedicated to ensuring the reliability and security of the bulk power
system in the north central region of North America, including parts of both the United States and Canada. MRO is one of eight regional
entities in North America operating under authority from regulators in the United States through a delegation agreement with the North
American Electric Reliability Corporation and in Canada through arrangements with provincial regulators. The primary purpose of MRO is to
ensure compliance with reliability standards and perform regional assessments of the grid’s ability to meet the demands for electricity.
6 LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission Systema project may be linked, and the greater degree to which a project is likely to contribute to
a goal, the higher the score it will achieve. Projects with high matrix scores should receive
funding allocations ahead of those with lower scores.
b) The System Reliability Risk Model is a sophisticated tool developed in 2015 by System
Planning with the aim of quantifying the risk associated with a capital project or group of
projects in terms of potential impacts to the reliability of the transmission system. The
tool models the operation of the transmission system with and without the additional or
replacement assets for a given project or group of projects, and compares the expected
unserved energy (EUE) for various potential failures on the related system network. The
model factors in the system topology, load data, equipment reliability data, and network-
specific conditions (e.g., tapped lines, special protection schemes, common-mode outages,
etc), and averages the results over a five-year window. The difference between the EUE
without the new assets and the EUE with the new assets is referred to as the delta EUE (or
∆EUE). The ∆EUE represents the risk to the reliable operation of the system that would be
mitigated with the implementation of the project. Projects with high ∆EUEs should receive
funding allocations ahead of those with lower ∆EUEs.
c) A project’s readiness to execute is based on such elements as the availability of labour
resources, the status of licensing and property requirements, and the status of material
delivery and construction contracts. A project may have a high matrix score and/or a large
∆EUE but yet may still have a later in-service date under CEF16 than it did under CEF15,
due to one or more of these elements causing a delay to the schedule. In such cases the
change to the project’s in-service date is recorded as a delay rather than a deferral, since it
is an outcome of project logistics rather than a decision by management. Knowledge about
these delays will play a part in determining whether a project’s funding needs to be protected
in the near-term portfolio plans or may be released to some other project.
d) The options available to mitigate the risks associated with a project deferral has to do with
the number of ways and ease with which operators can make real-time adjustments to the
system in order to avoid dropping load or causing voltage issues. In some cases the options
are very limited, are complex to implement, or would introduce problems elsewhere on the
system, such that they would be the option of last resort. A project that addresses a problem
area that has little to no operating flexibility should receive funding ahead of those that may
be mitigated more easily.
Once all approvals and corporate funding are in place, detailed engineering, material procurement,
construction and commissioning will take place. The project implementation phase for new facilities
can take several months to several years, depending on the scope and complexity of the project.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 7Transmission Planning Process
Provincial Transmission Asset
Load System Performance Condition
Forecast Assessment Assessments
Transmission Bulk Load Generation
Service Connection Connection
Request Request Request
IDENTIFY
REQUIREMENTS FOR
CAPITAL INVESTMENT
PROJECT
DEFINITION
& APPROVAL
PORTFOLIO
PORTFOLIO
PRIORITISATION
OPTIMISATION
MITIGATION IF DEFERRED
20 YEAR
CAPITAL EXPENDITURE FORECAST
Transmission Planning Process
8 LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System3. Transmission System Projects
The following projects reported in the 2015 plan have been completed:
• Neepawa 230/66 kV Station.
• Rockwood East 230/115 kV Station
• Keeyask Construction Power
The following transmission system developments presented in this chapter, approved in Manitoba
Hydro’s Capital Expenditure Forecast, are required to keep the transmission system operating reliably.
While these represent the bulk of projects, numerous smaller enhancement projects are also included
in the Capital Plan.
The project diagrams included with the project descriptions in this chapter are conceptual diagrams. As
such, these diagrams do not illustrate transmission facility siting or routing. Manitoba Hydro follows a
Site Selection and Environmental Assessment process to select locations for new stations and routes
for new transmission lines as discussed in Chapter 4.
3.1 Interconnections Projects
3.1.1 Manitoba - Minnesota Transmission Project (MMTP)
Studies have been completed with the Midcontinent Independent System Operator (MISO)
to determine the necessary transmission facilities needed to increase the firm Canada to U.S.
transmission export and import capability. Facilities study concluded that new facilities will increase the
MH-US export capability by 883 MW and the MH-US import capability by 698 MW.
MMTP project has the following components:
1. Development of a 500 kV AC Transmission Tie Line from Dorsey-U.S. border (approximately
215 km in length). The 500 kV AC transmission link to connect Dorsey Station to the U.S.
border will be located within the south loop corridor that currently is located to the south of
Winnipeg.
2. Addition of a second 500/230 kV transformer bank at Riel Station.
3. Addition of a phase shifting transformer at Glenboro 230 kV Station on Glenboro – Rugby
(U.S.) 230 kV Line (G82R). This device is being added to mitigate loop flow issues on the
Manitoba to U.S. interface.
MMTP connects to the Great Northern Transmission line (GNTL) project at the U.S. border. GNTL is
being constructed by Minnesota Power and consists of a 500 kV line between the border and Iron
Range (A new substation northwest of Duluth, Minnesota), a 500/230 kV transformer bank at Iron
Range as well as a series compensation station near Warroad, Minnesota. The final preferred route of
MMTP is shown in the figure below [https://www.hydro.mb.ca/projects/mb_mn_transmission/]. This
project is being constructed under the OATT.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 9The project is planned to be in-service by May 2020 and is expected to cost approximately $450
The project is planned to be in-service by May 2020 and the Manitoba portion of the project is
million.
expected to cost approximately $450 million.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 21
10 LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System500kV
Dorsey
Riel 345kV
230kV
NEW FACILITIES
G82R
MANITOBA
MINNESOTA
Glenboro Phase Shifter 300 M602F 60%
MVA +/- 80 degrees
New Tie
Transfer Level:
570 kms 883 MW South
D604I 698 MW North
Forbes Ironrange
1200MVA
Chisago
Arrowhead
Stone Lake
King
Eau Claire Arpin Gardiner Park
3.1.2 Manitoba-Saskatchewan Transmission Interface Project (MH-SPC)
Facility Studies are currently being finalized which will determine the necessary transmission facilities
needed to facilitate a 100 MW increase in Power exports from Manitoba to Saskatchewan.
MH-SPC Interface project has the following components:
1. Addition of a new 91 km, 230 kV transmission line between Birtle South 230 kV (Manitoba)
and Tantallon 230 kV (Saskatchewan) stations. MH portion of the new line is approximately
61 km (67%) at an estimated cost of $47.3 million.
2. Birtle South 230 kV Station (Manitoba) modifications/additions, including facility additions
associated with the termination of the 230 kV new transmission line and the replacement of
the 230 kV line B69R current transformer (CT) at an estimated cost of $7.7 million.
3. Upgrade of the MH section of the 230 kV line P52E to 100°C design rating including wave-
trap and riser replacement at The Pas-Ralls Island 230 kV Station (Manitoba) at an estimated
cost of $3.0 million.
The total cost for the required Network Upgrades in Manitoba is estimated to be approximately
$58.0 million dollars. It should be noted that this project also requires the conversion and
utilization of existing Brandon Unit #5 as a synchronous condenser. The in service date of the
project is June 2021.
This project is being evaluated under the Manitoba Hydro Open Access Transmission Tariff. It
becomes an official Manitoba Hydro Transmission project once a facility construction agreement
has been signed under the tariff, which is expected to happen in 2017.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 11Manitoba-Saskatchewan Interconnection Lines 12 LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System
3.1.3 Keeyask Generation Outlet Transmission Facilities
The new 695 MW Keeyask Generating Station (net 630 MW) consists of 7 units. The new outlet
transmission facilities (named Keeyask Transmission Project) are needed to integrate the Keeyask
generating station to the Manitoba Hydro grid at Radisson Converter station.
A new Keeyask Switching Station will be established to terminate seven new 138 kV lines including
four unit lines (approximately 3 km each) to receive the power from Keeyask Generating Station, and
three 138 kV transmission lines (approximately 38 km each) to convey the power to Manitoba Hydro’s
existing Radisson Converter Station.
A construction power station has been completed and fed primarily from a 138 kV transmission
line with an approximate length of 22 km tapped from existing line KN36. One of the Radisson-
Keeyask lines will be constructed earlier than the other two, in order to serve as a back-up source of
construction power. Station upgrades at the Radisson station will also be required including a new bay
to terminate new 138 kV lines and upgrades of 31 breakers. In addition to connecting new generation
to the system, the new facilities will improve the reliability of the overall transmission system.
Keeyask transmission is being constructed pursuant to the terms of the Open Access Interconnection
Tariff (OAIT), and construction has started after the Keeyask Hydropower Limited Partnership signed
an Interconnection and Operating Agreement (IOA) in May 2015. All of the transmission facilities will
be completed by August 2021 with an estimated cost of $247 million.
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 13Simplified single line diagram of Keeyask Generation Outlet Transmission
KEEWATI-
NOHK
230 kV
LEGEND
PROPOSED
EXISTING
Simplified conceptual diagram of Keeyask Generation Connection to Northern Collector System
14 LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System3.2 Inter-Regional Projects
Inter-Regional Projects
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 15Inter-Regional Projects
Project Name I.S.D. Estimated
Cost (millions)
Sustainment Related Projects
1 Bipole II Thyristor Valve Replacements 2027/03 (multi) $236
2 Bipole I & II Major Refurbishment 2036/03 (multi) $198
* HVDC Transformer Sustainment Program 2037/03 (multi) $189
3 Dorsey Synchronous Condenser Refurbishment (extended) Annual/March (multi) $99
4 Bipole I & II DC Disconnects 2029/03 (multi) $89
* HVDC Transformer Sustainment (extended) 2036/03 (multi) $88
* Transmission Line Upgrades for Improved Clearance (NERC) 2023/03 $75
5 Dorsey Synchronous Condenser Refurbishment 2026/03 (multi) $74
* Transmission Transformers Sustainment Capital Program 2032/09 (multi) $64
* Transmission Line Footing Sustainment Program 2030/03 (multi) $50
* HVDC Smoothing Reactor Replacements 2023/10 (multi) $47
* Station Battery Bank Replacement Program 2022/03 (multi) $46
* Transmission Line Protection & Teleprotection Replacement 2018/05 (multi) $26
6 Bipole I & II Spacer Dampers Project (Phase 2) 2017/12 (multi) $24
* Transmission Line Wood Pole Sustainment Capital Program 2026/03 (multi) $24
* Mobile Radio System Modernization 2017/06 $24
7 Bipole I & II Communications Upgrade 2024/03 $21
* 115 kV Protection Upgrades 2023/03 (multi) $20
* Telecommunications 48VDC Upgrades 2036/03 (multi) $19
8 HVDC BP2 Valve Hall Wall Bushing Replace 2024/10 (multi) $19
* PCB Bushing Elimination Program 2024/03 (multi) $19
* HVDC Gapped Arrester Replacement 2021/11 (multi) $16
* Transmission Breaker Sustainment Capital Program 2033/03 (multi) $14
* HVDC Circuit Breaker Opp. Mechanical Replacement 2019/03 (multi) $14
* 13.2 kV Shunt Reactor Replacement Program 2018/11 (multi) $14
9 HVDC BP2 Refrigerant Condenser Replacement 2025/11 (multi) $13
10 HVDC BP1 DCCT Transductor Replacement 2028/10 (multi) $12
* HVDC System Transformer & Reactor Fire Protection 2017/06 $11
11 Bipole I & II DC Filter Protection 2025/03 $10
Growth Related Projects
12 Bipole III Reliability Project 2018/07 $5,042
• Bipole III - Converter Stations 2018/07 (multi) $2,781
• Bipole III - Transmission Line 2018/07 (multi) $1,958
• Bipole III - Collector Lines 2018/07 (multi) $247
• Bipole III - Community Development Initiative (CDI) 2018/07 (multi) $57
* Southern AC System Breaker Replacements 2017/06 (multi) $14
13 Winnipeg Area Capacitor Bank Additions (Phase 1) 2019/11 $11
14 Winnipeg Area Capacitor Bank Additions (Phase 2) 2026/10 $10
Items marked with * encompass multi-areas and are not indicated on map.
NOTE: Table does not include projects under $10 million. Projects indicated in red are currently in the Early Planning
Stage and subject to change.
16 LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System3.2.1 Growth
3.2.1.1 Bipole III Reliability Project
Enhancement of the reliability and
security of the existing Nelson
River HVDC transmission system
has been under investigation for
some time. The existing Bipole I &
II transmission lines carry 70
percent of Manitoba Hydro's
generating capacity and are
located on a common corridor,
895 km in length.
The southern converters of Bipole
I and II are both terminated at
the Dorsey Converter Station.
The Bipole I & II corridor and the
Dorsey Station are vulnerable to
low probability, but severe events
such as fire, wind bursts, tornadoes
and ice storms; that could cause
extended outages creating
severe hardship to Manitoba
Hydro customers and Manitoba.
One such event occurred on
September 6, 1996 when straight
line winds associated with a micro-
burst resulted in the collapse of
19 HVDC transmission towers
immediately north of the Dorsey
Converter Station taking both the
Bipole I and II out of service.
Manitoba Hydro has evaluated
various alternatives for enhancing
the reliability of the HVDC
transmission, namely the addition
of gas turbines in southern
Manitoba, the purchase of U.S.
generation via a new 500 kV
import line and a 2000 MW Bipole
III HVDC system. Manitoba Hydro
selected the Bipole III HVDC
system as the preferred reliability
enhancement project.
The 2000 MW Bipole III HVDC system currently includes:
• a ±500 kV 2000 MW HVDC overhead transmission line (west of Lake Winnipegois and Lake
Manitoba), about 1384 km long, from new Keewatinohk Converter Station to Riel Converter
Station
• a 2000 MW converter station in the north (new Keewatinohk Converter Station);
• One 52 km 230 kV transmission line from Long Spruce to Keewatinohk and associated
upgrades at Long Spruce Station
LONG-TERM DEVELOPMENT PLAN—2016 for Manitoba Hydro's Electrical Transmission System 17You can also read
