capital projects – nuclear operations

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

CAPITAL PROJECTS – NUCLEAR OPERATIONS 1

2 1.0 PURPOSE 3

This evidence provides a project listing and the business case summaries (“BCS”) that support 4

the capital expenditures and the in-service amounts for the Nuclear business unit (excluding 5

the Darlington Refurbishment Program which is addressed in Ex. D2-2-1) during the IR term. 6

These capital expenditures reflect the nuclear capital budget presented in Ex. D2-1-2. 7

8

The evidence also provides project specific summaries of new major capital projects (Tier 1 9

projects) since EB-2016-0152 and consistent with the OEB’s Decision and Order in EB-2016-10

0152, divides the discussions as between those that at the Development or Definition phases, 11

and those at or beyond Execution phase. 12

13

In Section 3.5, OPG discusses how its customer engagement process informed planning for 14

capital projects in the portfolio. Section 4.1 provides in-service variances explanations. 15

16

2.0 CAPITAL PROJECTS LISTING 17

The following tiered reporting structure, consistent with the OEB’s filing guidelines, has been 18

used to present the evidence for all capital projects that have budgeted expenditures in the IR 19

term or in-service amounts during the bridge year or IR term, or have been completed since 20

EB-2016-0152. 21

22

Tier 1: 23

Individual projects with a total cost of $20M or more. For these projects, summary level 24

information is provided in Ex. D2-1-3, Tables 1a – d, and BCSs1 are provided in Attachment 25

1 to this exhibit. Consistent with past applications, business case summaries are not provided 26

for security-related projects, however, Attachment 1 provides a brief description of security-27

related projects included in Ex. D2-1-3, Table 1a-d. 28

1 BCS amounts generally reflect point estimates. For projects in early definition stage, the BCS estimate may be based on a range, or no estimate may be provided. In these instances the current estimate of the total project cost is provided in Ex. D2-1-3 Table 1a-d.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

There are 79 Tier 1 projects comprising three categories: Ongoing Projects from EB-2016-1

0152; Completed/Deferred/Cancelled Projects from EB-2016-0152; and New Projects 2

approved since EB-2016-0152. Further information on Tier 1 projects is provided in Section 3

3.0 below. 4

5

All of the Tier 1 projects listed in Ex. D2-1-3, Table 1a-d, with 17 exceptions, have a final in-6

service date before or during the IR term. The final in-service amounts for all projects are 7

provided in Ex. D2-1-3, Table 1a-d along with the in-service amount for the IR term. The 17 8

exceptions are as follows: 9

• #31524 Darlington Roof Replacement Project - November 2027 10

• #80022 Darlington OH180 Aging Management Hardware Installation - June 2028 11

• #80078 Darlington Digital Control, Common Process and Sequence of Events Monitoring 12

Computer Aging Management - February 2028 13

• #80122 Darlington Main Power Output Protection System Replacement - August 2027 14

• #80123 Darlington Group II Pressure Transmitter Replacement - January 2028 15

• #80148 Darlington Fuel Handling Control Computer Input/Output Subsystem (Multiplexer) 16

and Interprocessor Communication Replacement - April 2027 17

• #82883 Darlington Class 1 I Rectifier Replacement - December 2032 18

• #82947 Darlington Fuelling Machine Head Major Component Replacement - May 2027 19

• #83052 Darlington Fuel Handling Power and Signal Cable Catenary Replacement - 20

January 2027 21

• #83076 Darlington Phase 2 Station Battery Replacement - December 2028 22

• #83298 Darlington Secondary Systems High Priority Control Valve Replacements - 23

December 2027 24

• #83480 Darlington 4kV Motor Refurbishment and Replacement - June 2028 25

• #83484 Darlington Isolated Phase Bus Refurbishment - June 2028 26

• #84009 Darlington Air Operated Valve Replacements - December 2028 27

• #84551 Darlington Motor Operated Valve Replacements - December 2028 28

• #83299 DN Condenser Steam Discharge Valve Control System Replacement – December 29

2027 30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

• #31716 DN Neutron Over-Power Ion Chamber & In-Core Flux Detector Amplifier 1

Replacement (Reactor Regulating System, Shutdown System 1 & Shutdown System 2) – 2

April 2027 3

4

As noted in Ex. D2-1-2, there is one capital non-portfolio expenditure during the IR term for the 5

capitalization of the Darlington Water Treatment Plant Finance Lease with a total cost in excess 6

of $20M. This is further described in Section 3.2 of this exhibit. 7

8

In addition to Total Project Cost and In-Service Amounts, Ex. D2-1-3, Tables 12 includes Total 9

Project Cost in EB-2016-0152 and Total Cost per First Execution BCS (if available). 10

11

Tier 2: 12

Individual projects with a total cost of $5M to $20M, for which summary level information is 13

provided in Ex. D2-1-3, Tables 2a through 2g. There are 91 Tier 2 projects listed in Ex. D2-1-14

3, Tables 2a through 2g. 15

16

Tier 3: 17

Individual projects with a total cost of less than $5M, for which aggregated information is 18

provided in Ex. D2-1-3, Table 3. There are 117 Tier 3 projects listed in Ex. D2-1-3, Table 3. 19

20

There are a further 53 projects in the project portfolio (unallocated) category (as described in 21

Ex. D2-1-2), which are projects in the project identification or project initiation phases. These 22

projects are presented in Ex. D2-1-3, Tables 5a and 5b. OPG expects that during the IR term, 23

some of these projects (or other projects yet to be identified) will move from the project 24

identification and initiation phases into the project definition or execution phase as part of the 25

ongoing portfolio management process (Ex. D2-1-1, Section 3.1). As indicated in Ex. D2-1-3, 26

2 The project total cost figure is the estimate contained in the most recent, approved BCS available at the time OPG’s evidence was developed. That estimate can increase or decrease as the project is refined through planning. The planned in-service cost during the IR Term is based on the information supporting OPG’s 2020-2026 Business Plan and may reflect a more recent forecast than the estimate included in the BCS. The Total Project Cost of Completed/Deferred/Cancelled Projects (from EB-2016-0152) at the time of preparing the 2020-2026 Business Plan, represent actual costs.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Tables 5a and 5b, preliminary forecasts indicate that 12 of these projects will have a total 1

project cost greater than $20M. 2

3

3.0 PROJECT-SPECIFIC INFORMATION - TIER 1 PROJECTS 4

Exhibit D2-1-1, Section 3.2, provided details on OPG’s asset management and investment 5

planning process that identifies the need for new projects, assesses project options and then 6

prioritizes the selected new projects to move forward. As stated in Ex. D2-1-1, Section 3.2.1, 7

the identification of new projects involves a rigorous process that considers asset reliability, 8

maintenance practices and asset performance trends to assess obsolescence and the need 9

for project funding. Exhibit D2-1-1, Attachment 1 also provides a more detailed description of 10

the Project Lifecycle and Management, along with a chart setting out the Association for the 11

Advancement of Cost Engineering (“AACE”) Estimate Class and Accuracy Ranges. 12

13

Consistent with the OEB’s directive in EB-2016-0152 that OPG file the costs for each major 14

capital project based on the first execution business case,3 the information for Tier 1 projects 15

has been divided into two sub-categories: 16

17

i. Tier 1 Projects at the Initiation, Development or Definition Phase 18

These are projects that have an approved development or definition phase BCS but for 19

which execution has not been approved. Projects in the development and definition phases 20

are undergoing review of alternatives, delivery strategy, baseline scope, and are 21

considered to be at a planning stage. For this reason the total project cost forecast 22

associated with these projects can have a large variance as depicted by the project’s AACE 23

estimate class and corresponding accuracy range. 24

25

ii. Tier 1 Projects at, or beyond, the Execution Phase 26

These are projects that have an approved execution BCS, reflecting the approval to move 27

forward with physical construction and commissioning of the work. At this phase, detailed 28

engineering, procurement, and detailed construction/installation planning have been 29

completed and therefore the total project cost estimate has a higher level of definition and 30

3 EB-2016-0152, Decision and Order, p. 22.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

accuracy than projects in the earlier phases. Projects in execution phases are still subject 1

to known and unknown risks, this uncertainty can result in cost (and schedule) variances 2

as described in the AACE estimate class and accuracy ranges. 3

4

Thirty-six Tier 1 projects are listed in Ex. D2-1-3, Table 1a-d as new projects that have been 5

approved for development, definition or execution since EB-2016-0152. Project #84235, 6

Darlington Primary Heat Transport Liquid Relief Valve Modifications (Waterhammer), was 7

listed in EB-2016-0152 as Project OM&A (#38933 Darlington Primary Heat Transport Liquid 8

Relief Valve Modifications (Waterhammer) and was subsequently re-classified as capital. 9

Details of these projects are presented in Section 3.1 below. 10

11

Additionally, the following seven projects previously identified at Tier 2 in EB-2016-0152 are 12

now classified as Tier 1 projects based on updated estimates. Detailed descriptions of these 13

projects and associated variances are presented in Section 3.6. 14

• #31426 Darlington Fuel Handling Inverter Replacement 15

• #31516 Darlington Station Lighting Retrofit 16

• #80023 Darlington Steam Generator Level Control Valves Replacement 17

• #80036 Darlington R22 Refrigerant Air Conditioning Unit Replacement: 18

• #80063 Darlington Standby Generators Protective Relay Replacement 19

• #33258 Darlington Replacement of Emergency Power System Uninterruptible Power 20

Supply 21

• #40691 Pickering B Emergency Power Generator and Main Output Power Protective Relay 22

Replacement. 23

24

Business case summaries for all Tier 1 projects, with the exception of security projects, 25

addressing project need, alternatives considered, assessment of key risks, projected cash 26

flows and projected total cost, and project cost variances, are provided in Attachment 1 to this 27

exhibit. 28

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

3.1 New Tier 1 Projects 1

2

3.1.1 New Tier 1 Projects at the Initiation, Development or Definition Phase 3

4

Project #80122 Darlington Main Power Output Protection System Replacement. The 5

Main Power Output system consists of main generators, main output transformers, unit service 6

transformers, station service transformers and transmission lines. The electromechanical 7

protective relays are aged and obsolete, with limited spares available. Functional failure of the 8

protective relays impacts both grid reliability and the power supply to the plant safety systems. 9

In addition to replacement of the protective relays, the project includes modifications to ensure 10

compliance with Independent Electricity System Operator (“IESO”), Market Rules (NERC 11

PRC-002-2), and to install protection against a loss of phase event, which has led to unit 12

shutdowns and primary heat sink loss at three non-OPG nuclear stations in recent years. The 13

total project cost is estimated at $65M based on its BCS. Planned final in-service is August 14

2027 with an in-service amount during the IR term of $75.0M. 15

16

Project #80123 Darlington Group II Pressure Transmitter Replacement. Hundreds of 17

existing pressure transmitters are nearing their end of service life at Darlington Nuclear 18

Generating Station. The transmitters are obsolete and few spares are available. The reliability 19

of these electronic devices degrades with age. Failure rates of these components result in 20

impairments in nuclear process and safety systems including the Moderator System, 21

Emergency Coolant Injection, Negative Pressure Containment, Liquid Injection Shutdown 22

System and Shutdown System 2. If failure occurs and spares are not readily available, OPG 23

will need to take forced outages or an extended outage. The total project cost is forecast to be 24

$47.7M. Planned final in-service is January 2028 with an in-service amount during the IR term 25

of $29.0M. 26

27

Project #80148 Darlington Fuel Handling (“FH”) Control Computer Input/Output (“I/O”) 28

Subsystem (Multiplexer) and Interprocessor Communication Replacement. The 29

objective of this project is to replace the obsolete fuel handing computer input/output 30

subsystems. The obsolete computer components are no longer manufactured and 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

repair/refurbishment of defective components is not a viable strategy. If these subsystems are 1

not replaced, Darlington fuel handling would experience frequent failure with potential lower 2

generation due to derating of units and eventual shutdown as the units could not be fueled. 3

The total project cost is forecast to be $23.4M. Planned final in-service is April 2027 with an 4

in-service amount during the IR term of $21.0M. 5

6

Project #80150 Darlington Fire Resistant Fluid (“FRF”) Pump Improvement. The 7

Darlington FRF power package is designed to supply pressurized and conditioned fluid to 8

control the steam turbine valves and devices in the governing, trip and over speed protection 9

circuits. Fire resistant fluid is vital for turbine protection, operation and control. The Darlington 10

FRF power package is obsolete with no spares. Replacement of the FRF power package will 11

also reduce the risk of varnish build-up and other deposits that can plug the filters on turbine 12

control equipment and result in reduced system reliability due to unplanned outages. The total 13

project cost is forecast to be $30.0M. Planned final in-service is November 2025 with an in-14

service amount during the IR term of $25.0M. 15

16

Project #82883 Darlington Class I Rectifier Replacement. The objective of this project is 17

to replace 60 Class I rectifiers, which are obsolete and approaching end of service life. These 18

rectifiers supply critical loads with Class I DC power from the Class II AC busses. Class I Power 19

is very important for maintaining safety, as it provides an uninterruptible DC power to support 20

proper operation of various safety systems. The reliability of these rectifiers is essential for 21

reliable normal power supply to charge Class I battery banks, thereby ensuring uninterruptible 22

power supply to nuclear system related loads and overall maintenance of system health. The 23

total project cost is forecast to be $42.3M. Planned final in service is December 2032 with an 24

in-service amount during the IR term of $17.0M. 25

26

Project #82890 Darlington Transformer Control Cabinet Wiring System Replacement. 27

The objective of this project is to replace transformer control cabinets, which connect cables 28

to the system control panel. The transformer control cabinets are in degraded condition and 29

are obsolete. The total project cost is forecast to be $26.8M. This project has been deferred 30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

subsequent to the completion of the current BCS and no in-service amounts are forecast during 1

the IR term. A bridging solution is in place until the replacement is completed. 2

3

Project #82947 Darlington Fuelling Machine Head Major Component Replacement. The 4

objective of this project is to refurbish the eight fuelling machine heads to ensure sustained 5

reliability until the end of commercial operations at Darlington. The major components in the 6

fuelling machine heads have not been replaced since commissioning and are beginning to 7

show wear. Failure of any of these components could result in stranding a fuelling machine on 8

reactor during fuelling. Proactive replacement will mitigate against this risk and ensure high 9

reliability. Additionally, key mechanisms will be updated with modern technology as the current 10

technology is obsolete. The total project cost is forecast to be $98.0M. Planned final in-service 11

is May 2027 with an in-service amount during the IR term of $59.0M. 12

13

#83039 Darlington Rapid Delivery Machine. Routine inspection of the fuel channels is a 14

Canadian Nuclear Safety Commission (“CNSC”) reactor operating license condition. The 15

objective of this project is to design, fabricate and commission a pressure tube inspection 16

machine that will replace the aging Channel Inspection and Gauging Apparatus for Reactors 17

(“CIGAR”). The expected key benefits from completing this project include: 18

• reducing the time required to perform fuel channel inspections; 19

• decreasing the length of the regular planned outages, which will increase generation; and 20

• reducing the amount of manual work and radiation dose required for fuel channel 21

inspections and fuel handling maintenance. 22

This project will allow for more available critical path time for fuelling machine maintenance 23

during unit outages. Increasing maintenance will improve fuel handling reliability and reduce 24

the potential for forced outages as fuel machine reliability has historically been a frequent 25

cause of forced outages. The total project cost is forecast to be $162.2M. Planned final in-26

service is May 2025 with an in-service amount during the IR term of $113.2M. 27

28

Project #83052 Darlington Fuel Handling Power and Signal Cable Catenary 29

Replacement. The power and signal cable catenaries supply power to the fuel handling trolley 30

and bridge systems and connect them to the control room. The existing cables are approaching 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

their expected service life. Degraded cables can affect fuel handling reliability, leading to 1

increased maintenance and possible production losses. The total project cost is forecast to be 2

$24.6M. Planned final in-service is January 2027 with an in-service amount during the IR term 3

of $8.7M. 4

5

Project #83297 Darlington Large Moderator Temperature Control Valve Replacement. 6

This project is to replace the large moderator temperature control valves (“TCV”) valves across 7

all four Darlington units (16 in total). The moderator TCVs perform the critical function of 8

precisely controlling the cooling of the moderator during unit operation and these have 9

experienced an increasing trend of reliability and maintenance issues. Complete replacement 10

with redesigned valves and digital positioners will provide more reliable operation and require 11

lower maintenance, as well as allowing online condition monitoring. Total project cost is 12

forecast to be $36.9M. Planned final in-service is June 2026 with an in-service amount during 13

the IR term of $26.2M. 14

15

Project #83298 Darlington Secondary Systems High Priority Control Valve 16

Replacements. The objective of this project is to replace high priority control valves in the 17

boiler feedwater, condenser air extraction and powerhouse upper level service water systems 18

which are obsolete and have experienced an increasing trend of reliability and maintenance 19

issues. The replacement of these control valves reduces the long term maintenance 20

associated with maintaining specified system margins ensuring overall plant reliability. Total 21

project cost is forecast to be $35.4M. Planned final in-service is December 2027 with an in-22


24

Project #83299 Darlington Condenser Steam Discharge Valves Control System 25

Upgrade. The objective of this project is to replace the actuators and associated controls to 26

improve reliability. The Condenser Steam Discharge Valves bypass main steam to the 27

condensers when the turbine is unavailable, maintaining steam generator and primary heat 28

transport temperature and pressure, and thereby maintain cooling of the reactor fuel. Total 29



Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Project #83480 Darlington 4kV Motors Refurbishment and Replacement. The purpose of 1

this project is to proactively replace or refurbish approximately 130 4kV motors to avoid motor 2

failure. These motors have been in service for over 25 years. The project will be undertaken 3

over a period of 8 to 10 years and will support station operation over its planned service life. 4

These motors are for various systems including nuclear systems and reactor safety systems 5

including motors used in the primary heat transport (“PHT”) feed pump and turbine generator 6

lube oil systems. The project will initially consist of a pilot to undertake seven strategically 7

selected 4kV motor replacements to obtain operating experience. This pilot will provide better 8

definition of scope and costs and minimize risk prior to proceeding with the remaining 9

replacements. Depending on the system in which the motor(s) are installed, motor failure could 10

result in a lengthy forced outage/shutdown of reactor units. Total project cost is forecast to be 11

$278.8M. Planned final in-service is June 2028 with an in-service amount during the IR term 12

of $89.8M. 13

14

Project #83484 Darlington Isolated Phase Bus Refurbishment. The Isolated Phase Bus 15

System conveys unit generator power to the main output and station service transformers, and 16

provides inputs for protective relaying, voltage regulation, synchronizing, metering, and fault 17

current limiting. The project goal is to extend the service life of this system as well as ensure 18

continued integrity, functionality, and reliability until station end of life. The total project cost is 19

forecast to be $62.4M. Planned final in-service is June 2028 with an in-service amount during 20

the IR term of $22.9M. 21

22

Project #83558 Darlington Fuel Handling Service Area Bridge F5 Ball Screw Assembly 23

Replacement. The objective of this project is to replace the service area bridge ball screw 24

assemblies in the East Fuelling Facility Auxiliary Area (“EFFAA”). The service area bridge 25

supports the fuelling machine head, suspension and catenaries for operations in the EFFAA 26

such as discharge of irradiated fuel, loading of new fuel and calibration/outage work. The ball 27

screws raise and lower the service area bridge to allow access to the appropriate port for these 28

operations. A component condition assessment determined that the ball screws are 29

approaching end of service life. Total project cost is forecast to be $28.2M. Planned final in-30

service is June 2025 with an in-service amount during the IR term of $11.8M. 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Project #83664 Darlington Unit 2 Turbine Control and Auxiliary Systems Upgrade. The 1

replacement of the Unit 2 turbine generator, control cards, electro-hydraulic controllers, 2

generator excitation control cards, and generator auxiliary skids is required to mitigate the 3

aging effects of the components, eliminate financial impact due to unexpected production loss, 4

and ensure U2 operation until station end of life. 5

6

The Turbine Controls and Auxiliary System replacement is being completed on Units 1, 3 and 7

4 through the DRP. As discussed in EB-2016-0152, installation of the Unit 2 Turbine Controls 8

was excluded from Unit 2 scope in order to mitigate risk given that Unit 2 was the first unit to 9

be refurbished. Incorporating this large first-of-a kind modification on the conventional side 10

would have introduced unnecessary additional risk into the planning and execution of the Unit 11

2 refurbishment involving primarily reactor side components. The complexity of this scope 12

requires two outages to replace the system on Unit 2 as it reaches end of life, and to ensure a 13

consistent control system for all of the turbine sets in Units 1-4. The total project cost is forecast 14

to be $112.7M. The planned final in-service is July 2025 with an in-service amount during the 15

IR term of $102.1M. 16

17

Project #83828 Fleet Monitoring Initiative (Monitoring and Diagnostic Centre). This 18

project is to implement the use of online equipment condition monitoring sensors at OPG’s 19

generating and support facilities to improve plant performance by improving equipment 20

reliability (see also discussion on the Right Time, Right Work, Right Value nuclear fleet initiative 21

in Ex. F2-1-1 Section 3.5.2). The Monitoring and Diagnostic Centre future plans are to apply 22

data from new sensors to perform diagnostics on equipment such as generators, motors and 23

transformers as well as thermal performance. This will be done using machine learning, 24

advanced analytics and physics based modeling to provide early warning of degradations and 25

diagnosis of specific failure mechanisms that are causing plant efficiency losses or could lead 26

to equipment failures. The project delivers benefits through avoided costs of equipment failures 27

and the optimization of maintenance programs. The total project cost is forecast to be $29.3M. 28

Planned final in-service is July 2023 with an in-service amount during the IR term of $16.0M. 29

30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Project #83916 Darlington Fuel Handling Calibration Facility Component Replacement 1

Project. There are 9 fuel handling calibration facilities for fueling machine heads located in the 2

pressure test facility and fueling facility auxiliary area. Each calibration facility has electrical 3

and mechanical components, which are at the end of their service life. The majority of the 4

components are obsolete with no spares available. The fueling machine calibration facilities 5

are needed to maintain reliable operations and avoid unplanned failures of the fueling 6

machines that would lead to unit derate or unit shutdown. This project will replace the 7

calibration facility components with new components or by replicating obsolete components 8

through reverse engineering. The total project cost is forecast to be $22.4M. The planned final 9

in-service is July 2025 with an in-service amount during the IR term of $22.4M. 10

11

Project #84009 Darlington Air Operated Valve Replacements. Darlington has over 7,000 12

air operated valves (“AOV”s), of which, approximately 500 are critical. The objective of this 13

project is to replace a subset (294) of the critical AOVs that are approaching the end of their 14

service lives. Many of these valves are no longer supported by the original equipment 15

manufacturer and this results in a challenge to meet operational or nuclear safety margin 16

requirements. The replacement of these AOVs is necessary to preserve specified system 17

margins and ensure overall plant reliability. The total project cost is forecast to be $85.7M. The 18

planned final in-service is December 2028 with an in-service amount during the IR term of 19

$39.5M. 20

21

Project #84551 Darlington Motor Operated Valve Replacement. Darlington has over 1,200 22

motor operated valves (“MOV”s), of which, approximately 150 are critical. The Darlington’s 23

critical MOVs are approaching end of service life. Many of these valves are obsolete and 24

overall equipment reliability is declining. During a review of MOVs OPG determined that some 25

critical valves have limited margins to perform their intended safety functions. The proposed 26

valve/actuator upgrades will increase the safety margin for these valves. This project is 27

intended to eliminate obsolescence, regain capability margins and sustain long-term operation 28

to station end of life. Where applicable, digital controls will be used to allow for condition based 29

maintenance. The replacement of these MOVs is necessary to preserve specified system 30

margins and ensure overall plant reliability. The total project is forecast to be $44.5M the 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

planned final in-service date is December 2028 with an in-service amount during the IR term 1

of $29.3M. 2

3

Project # 84939 Darlington Revenue Metering Transformer Replacement. The objective 4

of this project is to update the revenue metering system to meet the IESO Market Rules and 5

Measurement Canada regulations, as well as ensure continued reliable operation over station 6

service life. The scope includes replacing the revenue metering current transformers and 7

capacitor voltage transformers at both the main output transformer and station service 8

transformer. The total project cost is forecast to be $35.9M. The planned final in-service date 9

is October 2026 with an in-service amount during the IR term of $25.5M. 10

11

3.1.2 New Tier 1 Projects with Execution Phase BCS 12

13

Project #80124 Darlington Obsolete Controller Replacement. The objective of this project 14

is to replace the approximately 350 controllers used to monitor and control process variables 15

such as temperature, pressure, level and flow, in various systems in the station, including 16

nuclear and special safety systems. In accordance with Integrated Aging Management 17

requirements, OPG must undertake component condition assessments on systems, structures 18

and components to evaluate the health of critical components. Following which, OPG must 19

address aging related issues, obsolescence management and strategic and critical spares (Ex. 20

D2-1-1). OPG has determined that the controllers identified through this process must be 21

proactively replaced to support safe and reliable plant operation over Darlington’s station 22

service life due to obsolescence of spare parts, aging, reduced reliability and to avoid forced 23

outages. These controllers have also been identified as obsolete by the original equipment 24

manufacturer. The total project cost is forecast to be $38.0M. Planned final in-service is 25

December 2026 with an in-service amount during the IR term of $13.1M. 26

27

Project #80126 Darlington Emergency Power Generator 1 and 2 Replacement. The 28

objective of this project is to replace Darlington’s Emergency Power Generator (“EPG”) 1 and 29

EPG2 in accordance with commitments to the CNSC through the Integrated Implementation 30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Plan.4 OPG’s component condition assessments have concluded that several critical 1

components are degraded and require repair or replacement. OPG cannot perform the 2

required repairs as there are no spare parts on hand and the components to be repaired are 3

not commercially available due to outdated technologies and obsolescence. Replacement is 4

required to ensure reliability of EPG1 and EPG2 over station service life. The total project cost 5

is forecast to be $176.2M. Planned final in-service is May 2022 with an in-service amount 6

during the IR term of $89.4M. 7

8

Project #83049 Darlington Copper Piping Replacement. The objective of this project is to 9

replace copper piping used in the low pressure service water and powerhouse upper level 10

service water system with stainless steel piping. There have been numerous functional failures 11

due to erosion, corrosion and turbulence effects. Additionally, as the existing piping does not 12

meet modern codes and standards, it has required a variance from the Technical Standards 13

and Safety Authority. The original BCS planned for the installation of new copper piping for 44 14

locations within the station with an estimated project cost of $29.8M. Scope was added to this 15

project through a superseding BCS to complete the installation of another 16 locations (4 per 16

unit) on critical pumps in the station resulting in an increase of project cost of $15.3M. The total 17



20

Project #83053 Darlington Shutdown Cooling Heat Exchanger Powerhouse Upper Level 21

Service Water Piping Replacement. The objective of this project is to replace 1,000 to 1,250 22

feet (per unit) of large diameter service water supply and return lines to the shutdown cooling 23

heat exchangers as well as other selected lines. Due to microbiologically induced corrosion, 24

the walls of these lines are thinning and eventually will fall below code minimums. Failure could 25

impair the function of the shutdown cooling system, which is the primary shutdown heat sink 26

for the reactor fuel. The total project cost is forecast to be $75.2M. Planned final in-service is 27

January 2025 with an in-service amount during the IR term of $50.5M. 28

4 As part of CNSC licencing of Darlington, a Periodic Safety Review is prepared that includes an assessment against modern codes and standards, a safety factor review, a global assessment report, and an ensuing Integrated Implementation Plan for the corrective actions and safety improvements, as discussed at Ex. D2-2-1, Section 4.4.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

#83072 Pickering Buried Blowdown Pipe Replacement. The objective of this project is to 1

replace buried carbon steel piping that recent inspections have determined is degraded and 2

could fail during operation. Replacing this pipe is necessary to address operational and steam 3

safety concerns. Failure of the piping would necessitate an extended forced outage to repair 4

or replace the failed section. The total project cost is forecast to be $20.9M. Planned final in-5

service is December 2020 with no in-service amounts during the IR term.5 6

7

Project #83076 Darlington Phase 2 Station Battery Replacement. The objective of this 8

project is to replace the lead-calcium batteries installed in Class I power and emergency power 9

systems between 2001 and 2009. The existing batteries are approaching end of service life. 10

This project will ensure continued reliable operation of the back-up power system at Darlington. 11

The total project cost is forecast to be $34.5M. Planned final in-service is December 2028 with 12

an in-service amount during the IR term of $18.6M. 13

14

Project #83088 Pickering Low Pressure Feedwater Heat Exchangers Replacement 15

The objective of this project is to replace the low pressure feedwater heat exchangers in 16

Pickering Unit 1 and Unit 4. Inspections in 2013/2014 confirmed tube leaks and significant 17

degradation of the tubes, which resulted in the need to plug various tubes. Heat exchangers 18

of this type are designed with additional tubes so that, in the event of a leak, the leaking tube(s) 19

can be plugged and still maintain design heat transfer. However, as the number of tubes 20

plugged in each heat exchanger increases, there are fewer extra tubes available to address 21

leaking tubes that are plugged. Increased plugging also accelerates degradation and increases 22

risk of heat exchanger unavailability, which has the potential to result in extended forced unit 23

outage. The total project cost was $22.0M. Final in-service was May 2018.6 24

25

Project #83296 Darlington Main Output Transformer and Unit Service Transformer 26

Replacement. The objective of this project is to proactively replace the three main output 27

transformer phases and the unit service transformer in each Darlington unit to ensure reliable 28

5 While the planned final in-service date occurs within the EB-2016-0152 IR term; this new project was approved after the EB-2016-0152 application was filed. 6 Ibid.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

operation over station service life. Industry experience indicates that the service life of 1

transformers of this size and rating is 30 to 40 years with typical operating and maintenance 2

practices. The existing transformers are now entering that range. A limited failure would result 3

in unit shutdown for a prolonged period and significant loss of production. In the event of a 4

catastrophic failure, due to the absence of inter-phase blast walls, there would be significant 5

damage to two or more phases as well as the potential for work place injuries. Consequently, 6

it is prudent to replace the transformers to minimize production and safety risks. Total project 7

cost is forecast to be $170.1M. Planned final in-service is June 2024 with an in-service amount 8

during the IR term of $98.4M. 9

10

Project #83556 Darlington Turbine Hall Crane Controls Upgrade. This project is to upgrade 11

the controls systems on the two turbine hall cranes. The control systems are currently obsolete 12

and approaching end of service life. This project will address this obsolescence and ongoing 13

reliability issues by upgrading the crane controls to technology that is prevalent in the industry. 14

The total project cost was estimated to be $19.7M in the first execution BCS. A Project Over-15

Variance Approval was authorized in July 2020 to increase the total project estimate to $23.6M 16

to account for the discovery of out-of-specification components that increased the scope of the 17

replacements and the need to upgrade original equipment manufacturer materials to meet 18

nuclear quality requirements. Planned final in-service is December 2020 with no in-service 19

amounts during the IR term.7 20

21

Project #83559 Darlington Irradiated Fuel Bay Permanent Fuel Inspection Equipment in 22

East and West Fuelling Facility Auxiliary Area. The objective of this project is to install a 23

new inspection facility for irradiated fuel bundles and to upgrade the existing inspection/test 24

facility. Darlington has committed to the CNSC to inspect 20 irradiated used fuel bundles per 25

year per unit. The current inspection equipment is prone to failures due to equipment end of 26

life and lack of support for obsolete technology, resulting in its becoming increasingly 27

unavailable to conduct inspections. The total project cost is forecast to be $25.0M. Planned 28

final in-service is May 2022 with an in-service amount during the IR term of $8.9M. 29

7 Ibid.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Project #83668 Pickering High Pressure (“HP”) Turbine Spares. This project is to purchase 1

High Pressure Turbine Spindle spares. During 2016 inspections, stress corrosion cracks were 2

discovered in the Unit 7 high pressure spindle body. The cracks are not repairable. The lead 3

time for new turbines is 12-16 months, so obtaining spares minimizes future operating risk to 4

Pickering. The total project cost is forecast to be $21.3M. Final in-service was August 2019 5

with no in-service amount during the IR term.8 6

7

Project #84235 Darlington Primary Heat Transport Liquid Relief Valve Modifications 8

(Waterhammer). The objective of this project is to modify the Primary Heat Transport Liquid 9

Relief Valves to address an ongoing regulatory issue. While necessary modifications to the 10

valves were implemented following initial commissioning of Darlington (i.e., 1989-1992) to 11

address operational issues, as part of the Darlington Integrated Implementation Plan, OPG 12

committed to the CNSC to replace these valves. The total project cost is forecast to be $86.8M. 13

Planned final in-service is July 2026 with an in-service amount during the IR term of $43.5M. 14

15

Project #84799 Darlington Primary Heat Transport Pump Rotor Inspect/Replace. This 16

project is part of Darlington’s Integrated Implementation Plan commitment to replace one PHT 17

pump per unit (internal components) as required. The failure of any of the 4 PHT pumps in a 18

unit would lead to a forced outage, which, depending on the extent of the failure, could be 19

lengthy. To take advantage of a refurbishment outage window, the first inspection took place 20

on Unit 2, where one pump was identified for replacement. OPG will attempt to schedule the 21

work for the remaining units during refurbishment windows if lead times for materials, planning, 22

and execution allow. Additional replacements may be required, depending upon the condition 23

of the inspected pumps. The total project cost is forecast to be $89.2M, including contingency 24

for the replacement of an additional three pumps should it be required. Should use of this 25

contingent funding be required, approval will be sought through a future BCS. The planned 26

final in-service date is October 2026 with an in-service amount during the IR term of $46.4M. 27

8 Ibid.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

3.2 Darlington Water Treatment Plant Finance Lease 1

The existing water treatment plant (“WTP”) at Darlington is approaching its end of service life 2

and needs to be replaced to ensure a reliable supply of ultra-pure demineralized water is 3

available for Darlington’s ongoing operations. This water is essential to Darlington’s operations 4

and its supply is critical to maintaining station reliability for the life of the station. 5

6

Based on the assessment of options and financial analysis presented in Attachment 2, the 7

WTP will be built using a Design, Build, Finance, Operate and Maintain (“DBFOM”) contracting 8

strategy, which outsources the construction, operations and maintenance of the plant to a third 9

party specializing in high purity demineralized water management. 10

11

The location selected as best for the new WTP is north of the sally port on the east side of the 12

station. A separate WTP Interconnections Project (Attachment 1, Tab 7, project #31535) will 13

construct and commission station tie-ins designed to segregate the WTP, enabling it to be built 14

outside the security fence. 15

16

Following a 2018 Request for Proposal, OPG selected a preferred vendor for the DBFOM 17

strategy to negotiate an agreement for the supply of ultra-pure demineralized water for the next 18

30 years. The proposed agreement consists of fixed monthly payments for capital, fixed 19

operations and scheduled rehabilitation, plus a monthly variance payment for consumables 20

driven by water usage. Under the DBFOM contracting model, the vendor will be the legal owner 21

the new WTP. 22

23

In accordance with US GAAP, the underlying demineralized water supply agreement will 24

represent a finance lease arrangement, requiring recognition of a finance liability and capital 25

asset, which will be subject to depreciation. The asset and liability value is to be calculated as 26

the sum of present value of eligible payments under the contract, per US GAAP. Any 27

contractual payments not included in the calculation of the asset and liability value would be 28

Updated: 2021-07-09 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

treated as Nuclear Operations Base OM&A. The 2020-2026 Business Plan includes an initial 1

estimate of $138.6M for the WTP asset.9 2

3

For ratemaking purposes, OPG has included the WTP asset in its proposed rate base, as 4

consistent with the financial accounting treatment and contemplated in the OEB Accounting 5

Procedures Handbook.10. 6

7

As discussed in Attachment 2, some of the details of the DBFOM proposed agreement that 8

determined the WTP asset value are subject to the completion of negotiations with the vendor 9

and the Power Workers’ Union (“PWU”) related to the operations and maintenance of the WTP, 10

but this is not expected to have a material impact on the economic analysis, which selected 11

the DBFOM as the preferred option. 12

13

3.3 Completed Projects 14

Sixteen Tier 1 projects have been completed since EB-2016-0152. Business Case Summaries 15

for all projects are provided in Attachment 1 to this exhibit. 16

17

Project #25619, Darlington Operations Support Building Refurbishment, was completed 18

under budget at $61.3M versus forecast total project cost of $62.7M (EB-2016-0152, Ex. D2-19

1-3, Table 1). 20

21

Project #25609, Security Physical Barrier System, was completed on budget at $67.2M 22

versus forecast total project cost of $62.7M (EB-2016-0152, Ex. D2-1-3, Table 1). 23

24

Project #31508, Darlington Fukushima Phase 1 Beyond Design Basis Event Emergency 25

Mitigation Equipment, was completed over budget at $55.5M versus forecast total project 26

cost of $52.9M (EB-2016-0152, Ex. D2-1-3, Table 1). This project was included in a 27

9 Finalization of planning assumptions including as they relate to the details of the DBFOM agreement and in-service schedule may result in changes in the projected asset value, including through reclassifications with Base OM&A expenses as determined in accordance with US GAAP. 10 Article 425 of the OEB Accounting Procedures Handbook discusses finance lease treatment and considerations. Indicators of a finance lease are discussed at Article 425, p. 4. Regulatory treatment is discussed at Article 425, p. 8.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

programmatic approval with projects #49158, Pickering 5 - 8 Fukushima Phase 1 Beyond 1

Design Basis Event Emergency Mitigation Equipment and #49299, Pickering 1 and 4 2

Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment. Unused 3

contingency from the Pickering projects was re-allocated to this project to increase the 4

approved funding to $55.9M. The overall Fukushima Phase 1 Beyond Design Basis Event 5

Emergency Mitigation Equipment program was completed under-budget ($114.1M versus 6

forecast total program cost of $115.6M). 7

8

Project #31717, Darlington Maintenance and Computer Development Facility (Capital), 9

was completed under budget at $35.6M versus forecast total project cost of $43.2M (EB-2016-10

0152, Ex. D2-1-3, Table 1). 11

12

Project #31552 Darlington Condenser Cooling Water (“CCW”) and Low Pressure Service 13

Water (“LPSW”) Travelling Screens Replacement, was completed under budget at $33.0M 14

versus forecast total project cost of $37.6M (EB-2016-0152, Ex. D2-1-3, Table 1). 15

16

Project #32202, Darlington Fukushima Phase II Beyond Design Basis Event Emergency 17

Mitigation Equipment was completed under budget at $23.1M versus the forecast total 18

project cost of $28.0M (EB-2016-0152, Ex. D2-1-3 Table 2d).11 19

20

Project #33955 Darlington Shutdown System (“SDS”) Computers Aging Management, 21

was completed on budget at $20.3M versus forecast total project cost of $20.3M (EB-2016-22

0152, Ex. D2-1-3, Table 1). 23

24

Project #36001, Darlington Purchase of PHT Pump Motor Capital Spares was completed 25

under budget at $27.6M versus forecast total project cost of $30.8M (EB-2016-0152, Ex. D2-26

1-3, Table 1).27

11 Project was incorrectly identified as a Tier 2 project in EB-2016-0152, Ex. D2-1-3, Table 2d.

Updated: 2021-07-09 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Project #41023, Pickering Unit 1 and 4 Fuel Channel East Pressure Tube Shift Tooling 1

(Capital), was completed under budget at $27.7M versus forecast total project cost of $38.6M 2

(EB-2016-0152, Ex. D2-1-3, Table 1). 3

4

Project #41027, Pickering Fukushima Phase 2 Beyond Design Basis Event Emergency 5

Mitigation Equipment, was completed over budget at $49.7M versus forecast total project 6

cost of $46.3M (EB-2016-0152, Ex. D2-1-3, Table 1). This project was included in a 7

programmatic approval with project #32202, Darlington Fukushima Phase II Beyond Design 8

Basis Event Emergency Mitigation Equipment. Unused contingency from the Darlington project 9

was re-allocated to this project to increase the approved funding to $50.5M. The overall 10

Fukushima Phase 2 Beyond Design Basis Event Emergency Mitigation Equipment program 11

was completed under-budget ($72.9M versus forecast total program cost of $74.3M). 12

13

Project #46634, Pickering Fuel Handling Single Points of Vulnerability Equipment 14

Reliability Improvement Project (Capital), was completed on budget ($21.2M versus 15

forecast total project cost of $27.3M (EB-2016-0152, Ex. D2-1-3, Table 1). 16

17

Project #49158, Pickering Fukushima Phase 1 Beyond Design Basis Event Emergency 18

Mitigation Equipment, was completed under budget ($41.7M versus forecast total project 19

cost of $44.0M). This project was included in a programmatic approval with projects #31508, 20

Darlington Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment 21

and #49299, Pickering 1 and 4 Fukushima Phase 1 Beyond Design Basis Event Emergency 22

Mitigation Equipment. Unused contingency from the Pickering projects was re-allocated to the 23

Darlington project to increase its approved funding as discussed above. The Fukushima Phase 24

1 Beyond Design Basis Event Emergency Mitigation Equipment program was completed 25

under-budget ($114.1M versus forecast total program cost of $115.6M). 26

27

Project #66600, Pickering Machine Delivered Scrape Project was completed over budget 28

($27.0M versus forecast total project cost of $26.1M) (EB-2016-0152, L-04 2-1 Staff 043). 29

Updated: 2021-07-09 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Project #73706, Darlington Holt Road Interchange Upgrade, was completed under budget 1

($26.7M versus forecast total project cost of $28.6M (EB-2016-0152, Ex. D2-1-3, Table 1). 2

3

Project #80111 Darlington Generator Stator Core Capital Spare was completed under 4

budget ($30.8M versus forecast total project cost of $35.0M) (EB-2016-0152, Ex. D2-1-3, 5

Table 1). 6

7

Project #40976 Pickering B U58 Fuel Handling Reliability Improvement Project was 8

completed over budget ($40.4M versus forecast total project cost of $37.3M) (EB-2016-0152, 9

Ex. D2-1-3, Table 1). The increase of $3.1M was mainly due to project management costs and 10

additional interest associated with the extension of the project to 2018. Additionally, costs 11

related to construction, safety and quality oversight for multiple additional outages and online 12

no-fuel windows were incurred. 13

14

3.4 Deferred/Cancelled Projects 15

There are no deferred or cancelled projects from EB-2016-0152. 16

17

3.5 Customer Engagement – New Capital Projects 18

In 2018 and 2019, OPG engaged Innovative Research Group Inc. (“Innovative”) to undertake 19

a customer engagement process. The goal of this process was to obtain feedback on 20

outcomes that matter to customers to help inform the business plan underlying this application. 21

Detailed information on the customer engagement process is provided in Ex. A2-2-1 with 22

further details provided in Innovative’s report, which is filed as Attachment 4 to Ex. A2-2-1. 23

24

As part of the customer engagement process, Innovative sought customer feedback on several 25

potential nuclear capital investments. OPG and Innovative limited the consultation to three 26

representative nuclear capital projects that, at the time, were beginning the identification and 27

prioritization stage without an approved BCS: 28

• Darlington Vapour Recovery System (“VRS”) 29

• Darlington Air Compressors Replacement 30

• Darlington Crane Project 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Customer feedback on capital investment decisions varied. Among the example projects, none 1

of the options considered were favoured by a clear majority of customer groups. 2

3

On the VRS, there was a slight preference by both residential and business customers for the 4

more expensive option of replacing the system entirely. However, OPG has determined that 5

the optimal investment is to improve the existing system. This approach will allow OPG to 6

address a critical operational and safety risk and provide redundancy related to breathing air 7

restrictions when two units are undergoing refurbishment. In contrast, system replacement 8

would not provide redundancy and would extend system down time. Moreover, improving the 9

existing VRS system is expected to result in substantial savings compared to a system 10

replacement. 11

12

On the Air Compressors Replacement project, residential customers favoured replacing all of 13

the identified compressors proactively, while business customers were essentially split 14

between proactive replacement and maintaining an inventory of spares. OPG is planning to 15

proactively replace all 19 air compressors at Darlington in alignment with customer feedback. 16

This investment would mitigate operational risk as the identified compressors’ condition is 17

expected to deteriorate. 18

19

On the Crane Project, residential customers were split between comprehensive and partial 20

replacement approaches, while business customers preferred the partial replacement 21

approach by a 10% margin. In alignment with customer feedback, OPG is planning to refurbish 22

up to 14 cranes during the IR term and defer refurbishment of the remaining cranes. 23

24

The three projects presented to customers are listed in Ex. D2-1-3, Tables 5a and 5b, as 25

potential Portfolio Projects (Unallocated). OPG anticipates that these projects will proceed to 26

be funded through the unallocated component of the project portfolio.12 27

28

12 Identified in Ex. D2-1-3 as the following projects: Breathing, Instrument and Service Air Compressor Replacement, Powerhouse Cranes Refurbishment, and Vault and Containment Vapour Recovery Systems Component Replacement.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

3.6 Project Variance Explanations 1

There are seventeen ongoing Tier 1 projects for which total forecast project cost variances 2

currently exceed 10% as compared to total forecast project cost provided in EB-2016-0152.13 3

4

Project cost variances will occur as the project moves through the five phases of a project 5

lifecycle (Ex. D2-1-1, Attachment 1), primarily due to issues such as changes in project scope 6

and/or schedule, including: 7

• Proactive disposition of constructability issues: The goals of the definition phase of a 8

project life cycle as discussed at Ex. D2-1-1, Attachment 1, include defining the project and 9

demonstrating readiness for execution. Among the activities undertaken in this phase are 10

development of the project cost estimate and execution plan, assessment of risk and 11

development of mitigation plans. Applying Collaborative Front End Planning (“CFEP”) 12

during the definition phase includes supplemental constructor input, which, in some cases 13

identifies construction execution risk leading to proactive scope increases affecting project 14

cost and or schedule. Ex. D2-1-1 further describes the CFEP process. 15

• Optimization of schedule to optimized unit condition: Installation of plant modifications 16

are best achieved during optimized unit conditions such as unit outages, system outages 17

or appropriate sequencing of other activities. During the definition phases of the project 18

lifecycle when cost estimates and scheduling are being developed, assumptions related to 19

unit outages, system outages or sequencing are based on the then planned outage 20

schedule. As outages are scheduled and completed, this can lead to changes in the original 21

assumptions underpinning cost and scheduling estimates. 22

• Pilots: OPG may implement a pilot to review and incorporate appropriate lessons learned 23

prior to the project execution phase. This ensures efficiency gains are achieved in 24

subsequent parts of a project. Pilots also facilitate a risk-based analysis on the scope of a 25

project to identify any deficiencies in approach before substantial resources are committed 26

for full execution. In some cases, realized risk may result in scope increases that affect the 27

cost and schedule reflected in the execution phase estimate. 28

13 Total project costs as provided in BCSs filed in EB-2016-0152, Ex. D2-1-3 Attachment 1;L-4.2-1 Staff-28, Staff-40, Staff-41, and Staff-43; L-4.2-13 PWU-006; and Ex. J15.5.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

As projects proceed through the life cycle phases, project costs will vary within an accuracy 1

range based on the level of definition and the associated class of estimate,14 as defined by the 2

industry best practices (AACE) due to increased definition of the project scope and cost. While 3

the estimated cost of several Tier 1 projects has increased since the estimate provided in EB-4

2016-0152, the estimated cost at completion remains within the accuracy range associated 5

with the level of definition at the time of the previous estimate. OPG has identified in the project 6

variance explanations set out below those projects with variances within the accuracy range 7

and those projects that have progressed to an execution BCS. As described in Section 3.0 8

above, projects in the early lifecycle stages have a greater variance in their cost estimates as 9

the scope, engineering and strategy is still being defined. Individual project cost variance 10

analysis for each of the seventeen Tier 1 projects with greater than 10% variance are 11

discussed below. 12

13

As with Section 3.0, and consistent with the OEB’s directive in EB-2016-0152 that OPG file the 14

cost of each major capital project based on the first execution business case and the final 15

proposed amount for which OPG is seeking approval, variance explanations are subdivided 16

into two sections: 17

• Projects that were in the Initiation, Development or Definition Phase when presented in 18

EB-2016-0152; and 19

• Projects that had an Execution Phase BCS when presented in EB-2016-0152. 20

21

3.6.1 Projects in the Initiation, Development or Definition Phase in EB-2016-0152 22

23

Project # 31524 Darlington Roof Replacement Project. The current total project cost is 24

forecast to be $116.9M, which is an increase of $78.6M from the Initiation Phase Class 5 25

estimated total project cost of $36.3M provided in EB-2016-0152.15 The Class 5 estimate filed 26

in EB-2016-0152 reflects a preliminary project definition typical for the phase of the project at 27

14 Ex. D2-1-1, Attachment 1, for more information about estimate class and accuracy range. 15 Total project cost set out in EB-2016-0152, Ex. D2-1-3, Table 1 incorrectly identified total project cost for Project #31524 as $38.3M.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

that time. Planned final in-service is November 2027, with an in-service amount during the IR 1

term of $66.2M. This project continues to be in the definition phase. 2

3

This project is to replace flat roofs on the main powerhouse and other area buildings within the 4

nuclear protected area. The roofs are approaching the end of their service life and need to be 5

replaced to protect various nuclear and conventional systems in the station. 6

7

In 2013, OPG sent out a request for proposal to the Extended Services Master Services 8

Agreement16 (“ESMSA”) vendors. The ESMSA vendors responded with compliant quotations, 9

which were reviewed by OPG’s estimating group who confirmed that the prices were 10

reasonable and within industry estimating guidelines. As the contract price was higher than 11

expected, OPG proceeded with a phased approach and only awarded the preliminary design 12

phase of this project to the selected ESMSA vendor. The balance of the project was deferred 13

to accommodate priorities within the nuclear capital portfolio, as discussed in EB-2016-0152. 14

15

In 2018, based on the completed preliminary design, the estimated total project cost had 16

increased to $116.9M. A pilot was undertaken for a limited number of station roofs to validate 17

the estimate and further evaluate the approach on the project scope, cost, contracting strategy 18

and schedule, thereby optimizing future phases of the project. The results of the pilot are being 19

finalized, with an expectation of a reduced project cost, and will be factored into the Execution 20

Phase BCS, which is planned to be submitted for approval in Q1 2021. The level of project 21

definition along with the optimal contracting strategy to be established through the pilot will 22

provide a more accurate class of estimate. 23

24

Project #31544 Darlington Radiation Detection Equipment Obsolescence. The current 25

total project cost is forecast to be $45.0M. The scope of this project originally included the work 26

that now comprises projects #84400 and #84399.17 However, in order to ensure that adequate 27

resources are available to provide design and execution due to the varying needs of each 28

system grouping, and in order to gain cost and schedule efficiencies, approval was obtained 29

16 See Ex. D2-1-1, Section 3.4 for further description of the ESMSA contracts. 17 Projects #84399 and #84400 are Tier 2 projects as shown in D2-1-3, Table 2F.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

to execute the scope as three separate projects, which will be completed by three separate 1

Engineering, Procurement, and Construction (“EPC”) vendors. The total project cost estimate 2

for all three projects is $78.0M (of which $45.0M is attributed to the remaining scope of project 3

#31544), which is an increase of $31.1M from the Definition Phase Class 5 estimated total 4

project cost of $46.9M provided in EB-2016-0152. Planned final in-service is September 2023, 5

with an in-service amount during the IR term of $22.3M. The forecast increase to total project 6

forecast of $78.0M is within the Class 5 estimate accuracy based on the project definition level 7

at the time of EB-2016-0152. This project continues to be in the definition phase. 8

9

Seven of the radiation detection systems that are required to ensure regulatory compliance, 10

protect the public, and facilitate daily operation are at the end of their service life. This 11

equipment requires replacement due to obsolescence and aging management issues. 12

13

The scope in project #31544 includes the Post Accident Radiation Monitoring System and 14

Stack Monitoring system. The Post Accident Radiation Monitoring System provides monitoring 15

capability to facilitate reporting to the public and calculation of evacuation zones. Stack 16

Monitoring monitors stack emissions as required in the Power Reactor Operating License. 17

18

The total project cost estimate provided in EB-2016-0152 was from a partial definition BCS 19

based on early conceptual engineering phase releases. Following completion of preliminary 20

engineering, the subsequent BCS incorporated a more complex design than initially assumed, 21

augmented with a more accurate and detailed estimate provided by a third party. The cost 22

increase relates to the increased design and procurement cost associated with the equipment, 23

as well as the more complex design requiring additional engineering review. 24

25

Project #31716 Darlington Neutron Over-Power (NOP) and Ion Chamber (IC) Amplifier 26

Replacement (Reactor Regulation System (RRS), Shutdown System #1 (SDS1) and 27

Shutdown System #2 (SDS2)). This project is now in the execution phase. The current total 28

project cost is forecast to be $23.8, which is an increase of $6.1M from the Definition Phase 29

Class 4 estimate provided in EB-2016-0152 of $17.7M. The increase in the total project 30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

forecast cost is within the accuracy range of a Class 4 estimate. Planned final in-service is 1

April 2027, with an in-service amount during the IR term of $9.6M. 2

3

Neutron Over-Power, In-Core Flux Detector, and the Ion Chamber amplifiers convert very 4

small current signals from neutron detectors in the nuclear reactor into voltage signals used by 5

the Shutdown System #1 (“SDS1”), Shutdown System #2 (“SDS2”) and Reactor Regulation 6

System (“RRS”) computers. The amplifiers are a critical component of these systems that 7

regulate and shut down the reactor. The existing amplifiers are obsolete and maintaining 8

system reliability is increasingly challenging due to limited spare units and parts. 9

10

The original strategy was to source the amplifiers from the original equipment manufacturers. 11

OPG subsequently determined that the original equipment manufacturers no longer support 12

the technology used at Darlington. In order to maintain diversity between the two Shutdown 13

Systems, two independent equipment vendors will be used, which will prevent any potential 14

design flaws from impacting both shutdown systems. The replacement amplifiers will have the 15

same fit, form and function as the old amplifiers. 16

17

The increase in total project cost is due to enhanced engineering oversight required on the 18

highly specialized engineered equipment vendors. This oversight was required to ensure the 19

equipment met the complex technical specifications for this safety system. Due to the project 20

risk relating to reactor safety impacts, additional OPG resources were also required to leverage 21

operations knowledge for field oversight and installations in performing critical steps of the 22

project installation. 23

24

Project #80078 Darlington Digital Control, Common Process and Sequence of Events 25

Monitoring Computer Aging. The current total project cost is forecast to be $77.5M, which is 26

an increase of $30.2M from the Definition Phase Class 5 estimated total project cost of $47.3M 27

provided in EB-2016-0152. The increase in the total project cost forecast is within the Class 5 28

estimate accuracy range. Planned final in-service is February 2028, with an in-service amount 29

during the IR term of $42.2M. This project continues to be in the definition phase. 30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

The primary reason for the increased cost is due to higher than expected costs for reverse 1

engineering and design due to the complexity of the overall system. These cost increases were 2

discovered during engineering work resource reviews of the project; during which additional 3

specialized vendor engineering resources were needed to reverse engineer the components. 4

In addition, there was a scope increase to include the transfer of control relays and additional 5

computer boards and devices within the project scope. 6

7

Project #31516 Darlington Station Fluorescent Lighting Fixtures Retrofit. This project is 8

now in the execution phase. The current total project cost is forecast to be $20.7M, which is 9

an increase of $9.3M from the Class 4 estimated total project cost of $11.4M provided in EB-10

2016-0152 where this was a Tier 2 project. The Class 4 estimate filed in EB-2016-0152 11

reflected the preliminary project definition available at that time. Planned final in-service is 12

January 2023, with an in-service amount during the IR term of $3.9M. 13

14

The objective of the project is to replace obsolete fluorescent lighting in the powerhouse with 15

new, efficient LED lights. The existing lighting at Darlington is over 30 years old and is now 16

reaching its end-of-life. These fixtures and lamps were installed in critical areas such as unit 17

hallways, turbine halls, reactivity decks and the east and west irradiated fuel bays. The station's 18

ability to maintain reliable lighting with these aging fixtures is being severely challenged by: 19

• Unavailability of magnetic ballasts (rendered obsolete by government regulations on 20

energy efficient ballasts). Electronic ballasts are still available, but have low efficiency and 21

a short lifespan requiring frequent replacements. 22

• Deteriorating lighting luminescence and declining florescent lamp output requiring frequent 23

lighting replacements, which diverts resources from other important station work. 24

• Higher energy costs for existing low efficiency fluorescent lighting. 25

• The requirement to dispose of fluorescent lights containing mercury as hazardous waste. 26

27

The estimate provided in EB-2016-0152 was based on historical maintenance data for 28

replacement of lights with standard fluorescent lamp kits. Early in the project, a pilot was 29

launched to further refine the estimate, validate assumptions and characterize the resources 30

required to perform this project in a construction environment. The pilot uncovered installation 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

issues because Darlington was constructed with fixtures that are not compatible with standard 1

retrofit kits. 2

3

In addition, after evaluating the technology and availability of LED lights, the project 4

recommended using LED lights for all replacements rather than a mix of LED and fluorescent 5

lights as was contemplated in the original developmental BCS. Custom LED retrofit kits were 6

explored, however the most reliable and cost effective approach was determined to be 7

replacement of the entire light and light fixtures. As a result, scope was re-evaluated to 8

accommodate the shift from fluorescent to LED lights and to replace full fixtures rather than 9

retrofit. 10

11

The pilot determined that many of the lights requiring replacement were in the reactivity deck 12

area. Replacement of these lights was prioritized due to safety concerns surrounding overall 13

light output in that work area. The prioritization of reactivity deck lighting replacements added 14

complexity and cost. Accessing the lights over the reactivity deck is difficult and requires 15

complex scaffolding along with enhanced radiation protection procedures in this work area. 16

17

Project #80023 Darlington Steam Generator Level Control Valves Replacement. The 18

current total project cost is forecast to be $38.6M, which is an increase of $22.3M from the 19

Definition Phase Class 5 estimated total project cost of $16.3M provided in EB-2016-0152 20

where this was a Tier 2 project. The class 5 estimate filed in EB-2016-0152 reflected the 21

preliminary project definition available at that time. Planned final in-service is June 2026, with 22

an in-service amount during the IR term of $38.5M. This project continues to be in the definition 23

phase. 24

25

The objective of this project is to retrofit the 32 large standby generator (“SG”) level control 26

valves (“LCV”) (8 per unit; 2 per SG) and 16 small SG LCV (4 per unit; 1 per SG) with new 27

components (i.e., new actuators and associated ancillary components including positioners, 28

valve trim and packing). The new components have more robust designs to ensure reliable 29

operation, reduce maintenance, and minimize generation and safety risks. The existing valves 30

have a history of excessive maintenance requirements and degradation. Failure of both large 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

SG LCV in a boiler quadrant, which can occur if one valve fails when the other is already out 1

of service for maintenance, results in the loss of feedwater supply to the SG, causing a forced 2

outage. Since a large SG LCV is typically out of service for corrective maintenance between 3

four and six weeks per year per unit, the risk of a forced outage from a second valve failing is 4

significant. 5

6

The cost increase included in this application is primarily due to the movement of 16 small SG 7

LCV from Project #83298 to Project #80023. This change was to ensure overall system 8

reliability and to take advantage of anticipated project execution efficiencies by implementing 9

the same design and installation solution for all LCV replacements. While this scope transfer 10

has increased cost for Project #80023, costs for Project #83298 will be lower due to its reduced 11

scope. 12

13

Project #80036 Darlington R22 Refrigerant Air Conditioning Unit Replacement. The 14


Definition Phase Class 5 estimated total project cost of $14.9M provided in EB-2016-0152 16

where this was a Tier 2 project. The project class 5 estimate filed in EB-2016-0152 reflected 17

the preliminary project definition available at that time. Planned final in-service is January 2026, 18

with an in-service amount during the IR term of $27.1M. This project continues to be in the 19

definition phase. 20

21

The objective of this project is to replace 51 air conditioning/dehumidifying units containing 22

R22refrigerant with units using approved non-ozone depleting refrigerant. These units provide 23

cooling to critical equipment, laboratories, control rooms, and other areas, as well as process 24

uses for normal operations and post-main steam line/feedwater line break incident conditions. 25

Existing air conditioning units (“ACUs”) are also degraded and approaching their end of life. 26

Replacement will ensure maintainable and reliable ACUs to the end of station life. 27

28

Under the Ozone Depleting Substances and Halocarbon Alternatives Regulations, 2016 and 29

subsequent amendments, gradual reduction of the production and import of oxygen depleting 30

substances is required according to the fixed schedule established by the Montreal Protocol. 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Per this schedule, availability of R22 will be phased out completely by 2020. While the units 1

containing R22 can still be operated, after 2020, OPG will be unable to acquire R22 to replace 2

current stock. 3

4

Unanticipated cost increases have occurred for this project related to the need to replace 5

Portable Vault Vapour Recovery Dryers and higher quotes for the ACUs. During the 6

Development phase of this project, OPG determined that the Portable Vault Vapour Recovery 7

Dryers had a flaw in the original design which required their replacement. 8

9

With respect to the ACUs, in 2017, after development of the Definition BCS, OPG sent out a 10

request for proposals to the ESMSA vendors to perform this project under an EPC contract. 11

Based on preliminary engineering, the proposal assumed installation of ACU units using the 12

original equipment manufacturer’s existing design. The ESMSA vendors responded with 13

compliant quotes, which were higher than OPG expected in the Definition BCS. These quotes 14

were reviewed by OPG’s estimating group, which confirmed that the prices were reasonable 15

and within industry estimating guidelines. 16

17

During the definition phase, the original equipment manufacturer was unable to produce ACU 18

units that complied with modern nuclear standards based on the preliminary engineering. As 19

a result, OPG and ESMSA vendors collaboratively determined to change strategies and use 20

other suppliers who were able to comply with modern nuclear standards. This also resulted in 21

an unforeseen cost increase to the project. 22

23

Project #80063 Darlington Standby Generators Protective Relay Replacement. The 24


Definition Phase Class 5 estimated total project cost of $9.9M provided in EB-2016-0152, 26

where this was a Tier 2 project. The class 5 estimate filed in EB-2016-0152 reflects the 27

preliminary project definition available at that time. Planned final in-service is February 2023, 28

with an in-service amount during the IR term of $15.8M. This project continues to be in the 29

definition phase. 30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

This project is to replace electro-mechanical relays with digital relays for the protection of the 1

SG. This replacement is necessary to address relay obsolescence issues and to ensure that 2

spare parts are available for the continued reliable operation of Darlington. 3

4

More than 60% of the SG protective relays and auxiliary/ancillary devices are currently 5

obsolete. There is no original equipment manufacturer support for the existing relays and no 6

spares are available in stock. After-market refurbishment and repair support is very limited due 7

to the lack of original equipment manufacturer repair/maintenance documentation. The lack of 8

spare parts will continue to degrade the station's ability to maintain the existing equipment, 9

which will negatively affect reliability and system health. 10

11

At the time of the Definition Phase estimate, the engineering strategy for this project was to 12

use “off-the-shelf” materials to avoid customizations. However, EPC vendor estimates for 13

detailed design to accommodate the integration and installation of the “off-the-shelf” materials 14

were greater than estimates made at the time of the preparation of the Definition BCS. The 15

EPC vendor estimates were assessed by OPG’s estimating group, who confirmed that the 16

price was reasonable and within industry estimating guidelines. 17

18

Project #31426 Darlington Fuel Handling Inverter Replacement.18 This project is now in 19

the execution phase. The current total project cost is forecast to be $26.2M, which is an 20

increase of $11.8M from the Class 3 estimated total project cost of $14.4M provided in EB-21

2016-0152, as a Tier 2 project. While characterized as a project Class 3 estimate when filed 22

in EB-2016-0152, the level of project definition was reflective of a Class 5 estimate, which 23

would have been typical for the phase the project was in at that time. Planned final in-service 24

is April 2021, with no amounts coming into service during the IR term. 25

26

The objective of this project is to replace the 14 fuel handling inverters which provide power 27

for the operation of critical components required to fuel the reactors and to perform mandatory 28

online and outage maintenance activities. These 14 inverters have been in service since the 29

18 Project #31426 was a combination of Definition Phase/Execution Phase BCS in EB-2016-0152.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

early 1980’s. Of the 14 inverters, two support operations at the Pressure Testing Facility - and 1

12 support operations of the 6 trolley half systems. The deficiencies for the fuel handling 2

inverters include reaching end-of-life, obsolete technology, depleted spare parts, unavailability 3

of components and increased maintenance requirements. New fuel handling inverters are 4

more reliable and longer lasting, and will reduce required maintenance resources, while 5

increasing system monitoring, diagnostics, troubleshooting and reliability. Inverter failures 6

could result in decreased fueling capacities, increase risk of unit derates, and disruptions in 7

the fueling machine overhaul program, all of which would result in lower generation and 8

increased maintenance costs. 9

10

OPG began the process to assess replacement of fuel handling inverters prior to the decision 11

to proceed with a fuel handling refurbishment program at Darlington.19 A decision was 12

subsequently made to defer the Pressure Testing Facility installation from 2014 to 2017 to 13

better align with the FH refurbishment program and to ensure optimal configuration of the FH 14

equipment. The need to align with the FH refurbishment program resulted in project scope 15

expansion to incorporate FH inverter software process improvements, which increased project 16

costs, but ensured Darlington would have improved fuel handling capability. 17

18

Pressure Testing Facility installations were completed in the first phase of this project. Lessons 19

learned from the first phase were evaluated to optimize future project phases. Among the 20

lessons learned was to increase the use of station staff to leverage operational knowledge and 21

manage the significant technical risk associated with commissioning the trolley inverter 22

replacements. While this approach will increase cost, it is necessary to successfully execute 23

this first of a kind installation for Darlington. 24

25

In summary, the primary contributors to the variances have been: 26

• scope addition for software and operational data deliverables 27

• additional costs for OPG project oversight 28

• new tooling for trolley inverter setup 29

19 The FH refurbishment program consists of a number (approximately 17) individual projects with the objective of improving fuel handling capability and reliability at Darlington.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

• increased station support for engineering and field work due to scope addition 1

• increased third party vendor costs for trolley installations 2

• additional third party engineering costs to incorporate past operating experience for new 3

installations. 4

5

3.6.2 Projects with Execution Phase BCS in EB-2016-0152 6

7

Project #31412 Darlington Class II Uninterruptable Power Supply Replacement. The 8

current total project cost is forecast to be $63.6M, which is an increase of $8.5M from the Class 9

3 estimated total project cost of $55.1M provided in EB-2016-0152. The forecast total project 10

cost of $63.6M is within the Class 3 estimate accuracy presented in EB-2016-0152. Planned 11

final in-service is March 2025, with an in-service amount during the IR term of $25.2M. 12

13

The objective of the project is to restore the Darlington Uninterruptible Power Supply (“UPS”) 14

Class II power system to a reliable and maintainable state. Class II UPS supplies critical loads 15

to 27 critical station systems including safety systems instrumentation, digital control 16

computers, emergency lighting, cooling for critical equipment and other uses. The project 17

started with a pilot to confirm the optimal installation sequence strategy. Valuable lessons 18

learned during the pilot changed the installation strategy to a phased delivery to minimize the 19

risk to plant operations. The change in installation sequence resulted in the need to 20

accommodate unit work schedules and system availability resulting in the following cost 21

increases: 22

• additional project management and OPG oversight costs, 23

• additional Engineering, Procurement, Construction contract costs, and 24

• foreign exchange rate variance. 25

26

Project #31532 Darlington Powerhouse Water Air Conditioning Units Replacement. This 27

project is now in the execution phase. The current total project cost is forecast to be $38.2M, 28

which is an increase of $11.6M from the Class 4 estimated total project cost of $26.6M provided 29

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

in EB-2016-0152.20 The total project forecast is within the Class 4 estimate accuracy based on 1

the project definition level at the time of EB-2016-0152. Planned final in-service is January 2

2023, with an in-service amount during the IR term of $3.1M. 3

4

The ACUs in the Powerhouse are approaching end of service life. Cooling coil leaks (due to 5

inadequate condensate drainage resulting in corrosion) and loose fan blades have caused the 6

ACUs to be unavailable on multiple occasions. The preferred alternative is to replace 90 ACUs 7

with new units to improve equipment reliability and maintainability. 8

9

The cost variance on this project is primarily attributable to cost increases to accommodate 10

reactor safety restrictions associated with ACU installations. These restrictions require on-11

going station support (e.g., radiation protection and reactor safety), to ensure availability of 12

ACUs during the installation phase, which is necessary to maintain the design basis of critical 13

safety equipment. 14

15

Additional cost is also associated with re-engineering of the ACUs during the definition phase 16

as well as modifications to structural steel supports required to accommodate heavier ACUs. 17

18

Project #33621 Darlington Secondary Control Area Air Conditioning Unit Replacement. 19

The current total project cost is forecast to be $36.0M, which is an increase of $7.7M from the 20

Class 3 estimated total project cost of $28.3M provided in EB-2016-0152. The forecast total 21

project cost of $36.0M is within the Class 3 estimate accuracy presented in EB-2016-0152. 22

Planned final in-service is August 2025, with an in-service amount during the IR term of $9.6M. 23

24

The Secondary Control Area (“SCA”) air conditioning system comprises 10 air conditioning 25

units, two per SCA. The purpose of the air conditioning system is to provide a suitable 26

environment for the reliable operation and long service life of the electrical and electronic 27

equipment, comfortable working conditions for operating personnel, and emergency smoke 28

removal. 29

20 The BCS included in L-04.2-1 Staff-028 was designated as being in the execution phase although the total project cost was a class 4 estimate.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

These ACUs are at end of life and are experiencing high functional failures. In addition, the 1

ACUs used across the station are from four different manufacturers so parts are not 2

interchangeable. As three of the four manufacturers are no longer in business, a complete set 3

of spare parts cannot be procured. The decreasing reliability of these ACUs, increasing 4

difficulty in obtaining spare parts and increasing maintenance workload all contribute to an 5

enhanced risk to unit operation, which could result in a complete station shutdown. The project 6

is to replace all SCA ACUs with reliable units supplied by a single manufacturer. 7

8

Additional scope was added to include the installation of improved Emergency Service Water 9

piping to resolve inadequate Emergency Service Water flow. Larger Emergency Service Water 10

supply and return lines will be installed, which will bring the system back to design conditions 11

and significantly reduce the risk of a forced outage due to elevated SCA temperatures. The 12

engineering piping and piping design packages required revisions as a result this additional 13

scope, which increased construction cost. 14

15

Project #33819 Darlington Vibration Monitoring System Replacement for Major Pump-16

sets. This project is now in the execution phase. The current total project cost is forecast to be 17

$55.4M, which is an increase of $31.6M from the Class 5 estimated total project cost of $23.8M 18

provided in EB-2016-015221. The class 5 estimate filed in EB-2016-0152 reflects the 19

preliminary project definition available at that time.. Planned final in-service is November 2026, 20

with an in-service amount during the IR term of $18.0M. 21

22

Darlington’s Vibration Monitoring System components have been failing due to age, radiation 23

and other environmental factors. In addition, the existing Vibration Monitoring System does not 24

provide adequate vibration monitoring to maintain the reliability of various station-critical 25

components and equipment. 26

21 The BCS submitted in EB-2016-0152 was designated as being in the execution phase but the class estimate and related accuracy reflects a project definition phase.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

The project involves the replacement of Vibration Monitoring System for all 12 major pump-1

sets with commercially available equipment, replacement and commissioning of the Data 2

Acquisition and Analysis System and ensuring spares are available. 3

4

The cost variance in this project is attributed to scope additions to the preliminary scope such 5

as the inclusion of Vibration Monitoring System on new critical auxiliary shutdown cooling 6

pumps, and connecting the Vibration Monitoring System to OPG’s Local Area Network. 7

Unforeseen complexities relating to ground fault installations required additional construction 8

and design efforts, which extended the project duration, and resulted in increased project 9

management and interest costs. 10

11

Project #33973 Standby Generator Controls Replacement. The current total project cost is 12

forecast to be $46.3M, which is an increase of $6.7M from the Class 3 estimated total project 13

cost of $39.6M provided in EB-2016-0152. The forecast total project cost of $46.3M is within 14

the Class 3 estimate accuracy presented in EB-2016-0152. Planned final in-service is March 15

2021, with an in-service amount during the IR term of $0.4M. 16

17

Four Darlington standby generators provide backup power for designated nuclear safety 18

support systems. Darlington’s power operating license requires standby generators to be 19

available whenever there is nuclear fuel within the reactor core. In the event that none of the 20

standby generators can be made available within a 24 hour period, a controlled shutdown of 21

all four units must be initiated. 22

23

Various control and monitoring components for the standby generators have become obsolete. 24

Manufacturers of the original components no longer provide replacement parts or service the 25

equipment. This project involves the replacement of obsolete control and monitoring 26

equipment on Darlington’s standby generators, which will ensure standby generator reliability, 27

and availability as required by the power reactor operating license. The new equipment will 28

also provide data logging and diagnostic capability for effective standby generator 29

maintenance. 30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

The increase of $6.7M was associated with the design and construction costs required to 1

address discovery work related to SG 2 and 3. In addition, remediation for fuel control valves 2

on SG 1 and vibration issues on SG 4 that resulted in the need to replace the gas generator 3

were added to the scope. 4 5 Project #38948 Darlington Zebra Mussel Mitigation Improvements 6

The current total project cost is forecast to be $36.6M, which is an increase of $7.3M from the 7

Class 2 estimated total project cost of $29.3M provided in EB-2016-0152 (Ex. J15.5, 8

Attachment 2). Planned final in-service is December 2021, with no amounts coming into 9

service during the IR term. 10

11

Zebra mussel fouling has impaired the reliability of plant systems that use lake water, due to 12

the undesired presence of the invasive freshwater mussel. These service water systems 13

provide cooling water to a number of safety and safety related loads such as shutdown cooling, 14

heat exchangers, shutdown cooling pump motor coolers, moderator heat exchangers, liquid 15

zone control, and critical air conditioning units. Zebra mussel fouling can, and has, result in 16

equipment unavailability that can lead to unit derates and shutdowns. 17

18

A chlorination system was previously installed to control zebra mussels, but the frequencies of 19

chlorination dosing were not adequate and over time the zebra mussels adapted to the dosing. 20

To address the continuing risk posed by the invasive Zebra mussel, the project scope involved 21

implementation of a Zebra Mussel Mitigation Improvement system that allows for continuous 22

chlorination across all 4 units, as well as installation of new piping and a permanent de-23

chlorination system to reduce the chlorine concentration at the outfall to meet environmental 24

limits. Consistent with industry recommended practices (e.g., World Association of Nuclear 25

Operators), the system design required integration with the main control room for appropriate 26

integration of the Zebra Mussel Mitigation Improvement system with Nuclear Operations. 27

28

The increase of $7.3M was primarily a result of further modifications to the original design 29

based on field discovery issues where construction sequence and methodology required 30

revision. Accommodating for these adjustments extended the duration of the project, resulting 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

in increased costs for OPG project management and engineering oversight, as well as 1

increased interest expense. 2

3

Project #33258 Darlington Replacement of Emergency Power Supply Uninterruptable 4

Power Supply. The current total project cost is forecast to be $24.6M, which is an increase of 5

$8.0M from the Class 3 estimated total project cost of $16.6M provided in EB-2016-0152 as a 6

Tier 2 project. Planned final in-service is February 2022, with an in-service amount during the 7

IR term of $2.1M. 8

9

The project objective is to restore the reliability of the Emergency Power System (“EPS”) by 10

replacing life-expired uninterruptible power supplies. The EPS uninterruptible power supply 11

system is a seismically qualified alternate electrical power supply and distribution system to 12

Group 2 Nuclear Safety related loads. It must be operable and available during normal and 13

shutdown unit conditions per Operating Policies and Principles. 14

15

Deteriorating system reliability has been attributed to aging static component failures. 16

Maintaining the system has become increasingly difficult due to a lack of spare parts. Although 17

a base maintenance initiative was implemented in 2008, it did not include circuit breaker, 18

magnetic component, peripheral and capacitor replacement, all of which are required to 19

provide reliable system operation until station end of life. The project involves the continued 20

replacement of Uninterruptible Power Supply units to improve system health. The selected 21

Uninterruptible Power Supply systems are more reliable, have tighter output tolerances and 22

possess self diagnostic and monitoring features. 23

24

The increase of $8.0M since EB-2016-0152, is a result of increased efforts that were required 25

for EPS installation and removal work primarily attributed to: 26

• Increased OPG project management oversight costs due to additional design oversight 27

as well as project delay because of scheduling conflicts with other electrical work 28

programs combined with station resource challenges. 29

• Increased installation costs from changes in design and work packages based on 30

experience from previous installations. 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

• Increased vendor costs of EPS Uninterruptible Power Supply system installation on 1

Unit 3 and Unit 4. 2

3

Project #40691 Pickering B Emergency Power Generator (EPG) and Main Output Power 4

(MOP) Protective Relay Replacement. The current total project cost is forecast to be $29.7M, 5

which is an increase of $18.7M from the Class 2 estimated total project cost of $11.0M provided 6

in EB-2016-0152 as a Tier 2 project. Planned final in-service is October 2019, with no amounts 7

coming into service during the IR term. 8

9

The initial scope of the project was to replace the existing electro-magnetic relays with 10

microprocessor based multifunction relays or modern replacements on the EPGs and Main 11

Output Power units on Pickering Units 5-8 and to ensure spares are readily available. The 12

existing electromechanical relays are obsolete and there are no spares. Failure of a relay could 13

result in EPG unavailability, unit forced outages or forced extensions to planned outages. 14

Additionally, replacement of the protective relaying schemes was required to ensure that OPG 15

complied with Northeast Power Coordinating Council (“NPCC”)/IESO regulatory requirements. 16

17

The North American Electric Reliability Corporation oversees the reliability of the bulk 18

electricity systems in North America. The IESO and OPG are members of one of its regional 19

entities – NPCC, and the IESO is the Reliability Coordinator that enforces compliance. Under 20

NPCC regulations, the step up transformer, main output transformer, and station service 21

transformers have been identified as bulk power systems elements in Ontario. As this project 22

was making changes to the protection systems of bulk power system elements, these changes 23

must be acceptable to the NPCC Task Force on System Protection. 24

25

A review by the NPCC Task Force on System Protection and IESO raised the following issues: 26

i. Protection Circuit A/B of all Pickering Main Output Power share a neutral current 27

transformer; and 28

ii. Pickering 5-83088 Sequence of Event recorder is tied to the Unit(s) Digital Control 29

Computer time but not synchronized to within 2 milliseconds of Universal Coordinated 30

Time. 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

To address these issues, OPG installed a second neutral grounding current transformer in 1

each of Pickering Units 5-8 and installed equipment for time synchronisation on the Sequence 2

of Events recorder. 3

4

4.0 CAPITAL PROJECT IN-SERVICE INFORMATION 5

OPG’s actual and forecast in-service capital additions for the period 2016-2026 are 6

summarized in Ex. D2-1-3, Table 4a-4b. The forecast in-service amounts in the bridge years 7

and test period represent a combination of projected in-service amounts for specific (Tier 1, 2 8

and 3) projects as presented in Ex. D2-1-3, Tables 1a, 1b, 1c, 1d, 2a, 2b, 2c, 2d, 2e, 2f, 2g 9

and 3, and a supplemental in-service amount, which is a forecast of in-service declarations 10

that can be expected in the bridge and test years22 consisting of: 11

• Undefined projects: the supplemental in-service amount is primarily a forecast of in-service 12

amounts for currently undefined projects that make up the Portfolio Projects (Unallocated) 13

portion of capital expenditures. The supplemental in-service amount assumes currently 14

undefined projects will eventually become approved projects, and therefore, consistent 15

with the project specific in-service forecast amount, excludes any project contingency 16

amounts. 17

• Timing: The timing of in-service project-specific (Tier 1, 2 and 3) forecast amounts could 18

change as completed work packages for specific projects may be deemed ready for service 19

earlier or later than forecast. 20

21

Exhibit D2-1-3, Table 4a-4b includes actual to forecast (or OEB Approved) variance analysis 22

for 2016, 2017, 2018 and 2019, which are discussed in Section 4.1 below. For completeness, 23

Table 4a-4b also includes planned minor fixed asset expenditures, which are placed in-service 24

in the year of acquisition. 25

26

4.1 In-Service Amount Variance Explanations 27

Numerous factors can affect both the amount of an in-service declaration and its timing. In-28

service amounts can vary relative to forecast year-over-year, driven by changes in the level of 29

22 Supplemental forecast to reconcile BCS in-service estimates to final business plan.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

capital expenditures and the timing of project installations which are frequently tied to specific 1

unit or station outages. Also, if a project that is forecast for completion in a particular year is 2

delayed by even a month or two such that it carries into the following year, it has a significant 3

impact on actual in-service amounts for both years. Resolution of final project acceptance 4

issues may also shift in-service timing. 5

6

The amount of the in-service declaration can also be directly affected by project cancellation 7

decisions. After a project is cancelled, alternative replacement projects will be pursued; 8

however, it is not always possible to advance an alternative project to the installation stage 9

(e.g., if the work requires a specific outage for execution). When alternative replacement 10

projects are pursued, the in-service date may ultimately be at an earlier or later date then the 11

cancelled project. 12

13

Overall, based on 3 years of actuals and 2 years of budget information, OPG expects capital 14

in-service additions to exceed the OEB approved amount, and to be roughly equal to OPG’s 15

forecast before OEB in-service forecast adjustment as provided in EB-2016-0152. 16

17

Further details regarding annual in-service variances are provided below. The variance 18

explanations are based on the reforecast in-service amounts that were the basis for the 19

response to Undertaking J21.1 in EB-2016-0152 that were ultimately reflected in the approved 20

nuclear payment amounts. The reforecast included in-service amounts for new projects that 21

were listed in EB-2016-0152, Ex. D2-1-3, Table 5a and 5b. 22

23

2019 Actual versus 2019 OEB Approved 24

The decrease in actual in-service amounts in 2019 compared to the OEB Approved amounts 25

(-$20.8M) is due to reduced amounts in Operations and Project Support (-$39.8M) and 26

Darlington (-$35.2M), as well as the elimination of the Supplementary In-Service Forecast 27

budgetary allowance (-$16.6M), and OEB’s forecast adjustment (-$38.5M), offset by increased 28

amounts in Pickering (+$27.0M), Minor Fixed Assets (+$4.5M) and Pickering Extended 29

Operations (+$0.8M). 30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

The decrease in the Operations and Project Support in-service amount is due mainly to Project 1

#83039 Darlington Rapid Delivery Machine (-$44.3M), where the variance is attributable to a 2

schedule shift at the start of the project, which delayed the in-service of the final machines. 3

4

The decrease in Darlington in-service amounts is due mainly to Project #80126 Darlington 5

Emergency Power Generator 1 and 2 Replacement (-$36.2M), where the variance is 6

attributable to design drawings revisions necessary to reflect as found conditions prior to 7

installation of the EPGs. 8

9

The increase in Pickering in-service amounts is due to 29 projects with higher than planned in-10

service amounts (+$31.3M total), offset by six projects with reduced in-service amounts in the 11

period (-$4.2M total). The most notable variance is Project #83668 Pickering High Pressure 12

Turbine Spindle (+$10.7M) for the second of two turbine spindles that was not included in the 13

previous submission. 14

15

There were no capital projects approved in EB-2016-0152 for the Pickering Extended 16

Operations initiative. Subsequently, OPG determined that Project #84792 Pickering Extended 17

Operation Firewater Buried Ring Header South (+$0.8M) met the criteria for capitalization. 18

Additionally, there were initiative-specific Minor Fixed Asset acquisitions (+$5.0M). 19

20

2019 Actual versus 2018 Actual 21

The decreased in-service amounts in 2019 compared to 2018 (-$64.2M) are due to decreased 22

in-service declarations in Pickering (-$29.6M), Darlington (-25.3M) and Operations and Project 23

Support (-$11.9M), which were offset slightly by increases in Minor Fixed Assets (+$1.8M) and 24

Pickering Extended Operations (+$0.8M). 25

26

The decrease in Pickering in-service amounts is due to 25 projects with lower than planned in-27

service amounts (-$43.0M), offset by 22 projects with increased in-service amounts in the 28

period (+$13.4M). The most notable change is Project #83088 Pickering Low Pressure 29

Feedwater Heat Exchangers Replacement (Capital) (-$18.5M), due to completion of the field 30

installation of the heat exchangers in 2018. 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

The decrease in Operations and Project Support in-service declarations is due mainly to 1

Projects #66600 Pickering Machine Delivered Scrape Project (-$4.7M) and #60168 Nuclear 2

Waste Management Tritium Deuterium Oxide Transportation Package Replacement (-$3.6M), 3

due to completion of the projects in 2018 as well as Project #83051 Darlington Feeder and 4

Fuel Channel Baseline Inspections (-$2.3M) which was partially completed in 2018. 5

6

The decrease in Darlington from 2018 to 2019 in-service declarations is due to 43 projects with 7

decreases (-$165.2M) partially offset by 37 projects with increases (+140.2M). Most notable 8

decreases include Projects #38948 Darlington Zebra Mussel Mitigation Improvements (-9

$34.8M) which was completed in 2018; #73566 Darlington Primary Heat Transport Pump 10

Motor Replacement (-$15M); and, #84235 Darlington Primary Heat Transport Liquid Relief 11

Valve Modifications (Waterhammer) (-$14.0M) due to substantial completion of Unit 2 scope 12

in 2018. Notable increases include Projects #80126 Darlington Emergency Power Generator 13

1 and 2 Replacement (+$19.4M) due to completion of Emergency Power Generator 2 electrical 14

auxiliaries installation; and, #80144 Darlington Primary Heat Transfer Pump Motor Overhaul 15

(+$12.9). 16

17

The increase in Pickering Extended Operations is due to the partial in-service declaration of 18

Project #84792 Pickering Extended Operation Firewater Buried Ring Header South (+$0.8M) 19

in 2019. 20

21


The increased capital in-service amounts in 2018 compared to 2018 OEB Approved (+$71.1M) 23

are due to higher in-service of Darlington projects (+$69.5M), Pickering projects (+$18.9M), as 24

well as an increase in Minor Fixed Assets (+$1.7M), and OEB’s forecast adjustment (-$35.5M). 25

The increases are offset by Operations and Project Support projects (-$29.5M), and the 26

Supplemental In-Service Forecast (-$24.9M).23 27

23 In EB-2016-0152, the 2018 OEB Budget in-service amounts for approved projects totalled $309.8M but the in-service forecast assumed per the business plan that the in–service amount would be $334.7M, based on assumption that undefined projects would eventually become approved projects, and be in-service in that year. Therefore there was a positive supplemental in-service adjustment of $24.7M. Actual 2018 in-service was $355.9M.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

At Darlington, in-service declarations for projects included in EB-2016-0152 (+$69.5M) were 1

higher than the OEB Approved amounts. Notable variances from EB-2016-0152 include: 2

• Project #38948 Darlington Zebra Mussel Mitigation Improvements (+$34.6M). The in-3

service variance is due to delay in completing the improvements, originally planned for 4

2017 (+$26.4M) and increases in the cost of the project (+$8.2M) arising from resolution 5

of field discovery issues as well as increased project management and interest cost due to 6

the extended duration. 7

• Project #31426 Darlington Fuel Handling Inverter Replacement (+$12.6M). The variance 8

is due to delays in completing the replacements as planned in 2017 and 2018, 9

incorporation of operating experience into the design as well as increased project 10

management and interest costs due to the extended duration. 11

• Project #73566 Darlington PHT Pump Motor Replacement (+$15.3M). The variance is 12

primarily due to an increased number of new motors (versus refurbished motors) being 13

installed as replacements and advancement of the schedule to complete the replacements 14

to December 2019 instead of June 2022. 15

• Project #31710 Darlington Shutdown Cooling Heat Exchanger Replacement (+$9.3M). 16

Variance is due to delays arising from a significant increase in field execution time from 17

heat stress and additional design and analysis to address design issues, quality 18

requirements and the requirement for additional temporary supports. 19

• Project #31508 Darlington Fukushima Phase 1 Beyond Design Basis Event Emergency 20

Mitigation Equipment (+$8.6M). Variance is due to a lack of available installation resources 21

and additional design changes that pushed completion of the modifications into 2018. 22

• Project #38942 Tritium Removal Facility Tritium Emissions Reduction Project (-$4.6M). 23

Variance is due to cancellation of the project. 24

• Project #31520 Darlington Replacement of Obsolete Online Chemistry Analysers (-$4.7M). 25

Variance is due to operational constraints that limited the number of analysers that could 26

replaced in parallel, thereby increasing the overall installation period and delaying the final 27

in-service. 28

• Project #31524 Darlington Roof Replacement Project (-$6.0M). The variance is due to a 29

change in project strategy whereby only a pilot replacement was done in 2018 to gain 30

experience and address issues identified. 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

• Project #33819 Darlington Vibration Monitoring System Replacement for Major Pump-sets 1

(-$6.3M). Variance is due to delays related to issues with establishment of safe working 2

conditions for installation of the upgrades and delays in the window for the installation in 3

Unit 2. 4

• Project #31701 Darlington Tritium Removal Facility Cryogenic Refrigeration System 5

Turbine Oil Supply System / Turbine Replacement (-$7.4M). Variance is due to 6

identification of several issues during design review ultimately resulting in project deferral 7

in 2019. 8

• Project #31544 Darlington Radiation Detection Equipment Obsolescence (-$7.6M). 9

Variance is due to the need for increased internal and vendor engineering, which has 10

delayed the acquisition and installation of the new radiation detection equipment. 11

12

At Pickering, in-service declaration is higher than the OEB Approved amount (+$18.9M). 13

Notable variances from EB-2016-0152 include: 14

• Project #41044 Pickering A Standby Generator Protective Relay Upgrade (-$2.8M). 15

Variance is due to rescheduling of installation on 034 SG2 to 2019 due to unavailability of 16

034 SG1. 17

• Project #80069 Pickering A Firewater Buried Ring Header Replacement (North Loop) (-18

$3.6M). Variance is due to de-scoping of the South Loop portion of the project due to high 19

risks associated with field execution. 20

• Project #40972 Pickering A Standby Generator Reliability Upgrades (-$3.9M). Variance is 21

due to rescheduling of upgrade work following discovery of issues during the first upgrade. 22

• Project #46634 Pickering A Fuel Handling Single Point of Vulnerability Equipment 23

Reliability Improvement Project - Capital (-$4.3M). Variance is due to deferral of work by 24

the station from outages in 2017 and 2018 to later years. 25

• Project #40976 Pickering B Fuel Handling Reliability Modifications (+$2.4M). Variance is 26

due to rescheduling of outage work by the station from 2016 and 2017 to 2018. 27

• Project #40691 Pickering B Emergency Power Generator and Main Output Power 28

Protective Relay Replacement (+$2.1M). Variance is due to the station moving the 2017 29

outage to 2018. 30

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

• Project #40977 Pickering Daily Tritium Sampler Replacement (+$1.8M). Variance is due to 1

the addition of an additional sampler to the scope of the project, which increased the cost 2

and moved the final in-service to 2018. 3

• Project #41027 Pickering Fukushima Phase 2 Beyond Design Basis Event Emergency 4

Mitigation Equipment (+$1.8M). Variance is due to delays in the 2017 outage program work 5

and a large number of open available for service actions completed in 2018. 6

7

In-service amounts for new projects (+$23.0M) accounted for the rest of the Pickering variance, 8

primarily Project #83088 Pickering Low Pressure Feedwater Heat Exchangers Replacement 9

(Capital) (+$13.4M) and Project #83668 Pickering High Pressure Turbine Spares (+$10.7M). 10

11

In Operations and Project Support, in-service declarations for projects listed in EB-2016-0152 12

were lower than the OEB Approved amounts (-$29.5M). In-service declarations for new 13

projects were -$37.4M lower, notably Project #82929 Security Project B (-$18.3M) and Project 14

#82930 Security Project C (-$18.3M). 15

16


The decrease in capital in-service amounts in 2018 compared to 2017 (-$74.1M) is due to 18

lower in-service amounts for Pickering projects (-$113.9M), Operations and Project Support 19

projects (-$26.2M) and Darlington Spacer Retrieval (-$5.8M). These decreases are slightly 20

offset by higher in-service amounts for Darlington Projects (+$81.8M), and Minor Fixed Assets 21

(-$9.9M). 22

23

Decreased in-service amounts at Pickering (-$113.9M) are due to the following projects being 24

fully placed in-service in 2017: #41027 Pickering Fukushima Phase 2 Beyond Design Basis 25

Event Emergency Mitigation Equipment (-$45.5M), #49158 Pickering B Phase 1 Beyond 26

Design Basis Event Emergency Mitigation Equipment (-$29.6M), and #49299 Pickering A 27

Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment (-$11.2M). 28

Additionally, Project #40976 Pickering B Fuel Handling Reliability Modifications (-$14.4M), and 29

Project #49146 Pickering Fire Code Compliance for Relocatable Structures (-$13.9M) had 30

significant amounts placed in-service in 2017 compared to 2018. 31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

The Operations and Project Support projects in-service amounts decrease in 2018 compared 1

to 2017 (-$26.2M) mainly due to Project #66600 Pickering Machine Delivered Scrape Project 2

(-$17.1M), and Project #25918 Sally Port Physical Barrier Installation (-$9.6M). 3

4

The increase of in-service amounts at Darlington (+$81.8M) is mainly due to Project #38948 5

Darlington Zebra Mussel Mitigation Improvements (+$34.8M) which shifted from 2016 to 2018 6

due to discovery work and scope changes, and new Project #84235 Darlington Primary Heat 7

Transport Liquid Relief Valve Modifications (+$19.2M), which had significant in-service 8

amounts in 2018. 9

10

The decreased in-service amount for Darlington Spacer Retrieval (-$5.8M) reflects the 11

completion of this project in 2017. 12

13


The increase in actual capital in-service amounts in 2017 compared to the OEB Approved 15

amounts (+$33.3M) is due to increased in-service amounts at Pickering (+$7.5M) increased 16

Minor Fixed Asset acquisitions (+$5.6M). and OEB’s forecast adjustment (-$47.9M), offset by 17

reduced in-service amounts at Darlington (-$22.1M), Operations and Project Support (-$6.6M), 18

Darlington Spacer Retrieval (-$0.6M) 19

20

The reduction in Darlington in-service amounts compared to the 2017 OEB Approved amounts 21

is due primarily to Project #38948 Darlington Zebra Mussel Mitigation Improvements 22

(-$26.4M), which was placed on hold for commercial issues in 2016, causing the project to 23

miss its planned in-service in 2017 following resumption of work. 24

25

The reduction in Operations and Project Support in-service amounts is due primarily to delayed 26

in-service dates in Project #66600 Pickering Machine Delivered Scrape Project (-$3.1M), 27

Project #83051 Darlington Feeder and Fuel Channel Baseline Inspections (-$2.1M) and 28

Project #80131 Nuclear Waste Management ISO Transportation Package/Trailer 29

Replacement (-$1.8M). 30

31

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

The increase in Pickering in-service amounts compared to the OEB Approved amounts is 1

primarily due to the Fukushima Projects #41027 Pickering Fukushima Phase 2 Beyond Design 2

Basis Event Emergency Mitigation Equipment (+$8.9M), Project #80069 Pickering A Firewater 3

Buried Ring Header Replacement (North Loop) (+$4.7M), Project #49298 Pickering A 4

Replacement of Unit 1, Unit 4 and Irradiated Fuel Bay (IFB)-A Stack Monitors (+$3.8M), Project 5

#46634 Pickering A Fuel Handling Single Point of Vulnerability (SPV) Equipment Reliability 6

Improvement Project – Capital (+$3.6M), and Project #49158 Pickering B Fukushima Phase 1 7

Beyond Design Basis Event Emergency Mitigation Equipment (+$3.2M). These increases 8

were offset by delayed in-service amounts in Project #83088 Pickering Low Pressure 9

Feedwater Heat Exchanger Replacement (Capital) (-$8.0M) and other projects. 10

11


The increased capital in-service amounts in 2017 compared to 2016 (+$178.0M) are due to 13

higher in-service amounts for Pickering projects (+$132.4M), increased Minor Fixed Asset 14

spending (+15.4M), increased Darlington Spacer Retrieval (+$5.0M) and Operations and 15

Project Support projects (+$40.8M), which are slightly offset by lower in-service amounts at 16

Darlington (-$16.3M) 17

Increased in-service amounts at Pickering (+$132.4M) are mainly due to the timing of in-18

service of the Fukushima Projects #41027 Pickering Fukushima Phase 2 Beyond Design Basis 19

Event Emergency Mitigation Equipment (+$47.6M), Project #49158 Pickering B Phase 1 20

Beyond Design Basis Event Emergency Mitigation Equipment (+$27.8M), Project #40976 21

Pickering B Fuel Handling Reliability Modifications (+$20.1M), Project #49299 Pickering A 22

Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment (+$12.3M), 23

and Project #49146 Pickering Fire Code Compliance for Relocatable Structures (+$12.1M). 24

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

The decreased in-service amounts at Darlington (-$16.3M) are due to Project #34000 1

Darlington Auxiliary Heating System (-$87.6M) and Project #73706 Darlington Holt Road 2

Interchange Upgrade (-$24.9M), which were both placed fully in-service in 2016. This was 3

offset by the 33 projects placed in-service in 2017, notably Project #31508 Darlington 4

Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment (+$38.2M), 5

Project #32202 Darlington Fukushima Phase II Beyond Design Basis Event Emergency 6

Mitigation Equipment (+$19.2M), Project #73566 Darlington Primary Heat Transport (PHT) 7

Pump Motor Replacement (+$12.3M), and Project #36002 Darlington Main Output 8

Transformer Capital Spares (+$8.6M). 9

10

The increased in-service amounts for Operations and Project Support (+$40.8M) are due to 11

Project #66600 Machine Delivered Scrape (+$21.8M), Project #25918 Sally Port Physical 12

Barrier Installation (+$10.1M), and Project #66594 Channel Inspection and Gauging Apparatus 13

for Reactors Gap System and Drive Reliability (+$8.3M). 14

The increase in Darlington Spacer Retrieval in-service amount (+$5.0M) is due to the 15

in-service of the tooling scheduled for 2016 being delayed until 2017. 16

17

2016 Actual versus 2016 Budget 18

The decrease in capital in-service amounts in 2016 compared to 2016 Budget (-$210.7M) is 19

due to lower in-service of Darlington Projects (-$105.6M), Pickering projects (-$98.0M), 20

Operations and Project Support projects (-$34.2M), as well as a decrease in Minor Fixed 21

Assets (-$14.7M). The increases are slightly offset by the increased Supplemental In-Service 22

Forecast (+$41.8M).24 23

24

The decreased in-service amounts at Darlington (-$105.6M) are due to 44 projects, with a total 25

decrease of (-$108.3M) primarily from projects Project #38948 Darlington Zebra Mussel 26

Mitigation Improvements (-$18.9M), Project #31508 Darlington Fukushima Phase 1 Beyond 27

24 In EB-2016-0152, the 2016 Budget in-service amounts for approved projects totalled $460.5M, even though the expected in-service amount for approved projects totalled $507.9M. An adjustment of $47.4M was reflected as a negative supplemental in service amount in 2016. The forecast of in-service amounts for approved projects was therefore reduced to $460.5M. Actual in-service was $270.2M as much of the capital that was expected to be placed in-service in 2016 was actually placed in-service in 2017.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Design Basis Event Emergency Mitigation Equipment (-$16.4M), Project #36002 Darlington 1

Main Output Transformer Capital Spares (-$7.6M), Project #32202 Darlington Fukushima 2

Phase 2 Beyond Design Basis Event Emergency Mitigation Equipment (-$6.9M), Project 3

#80144 Darlington Primary Heat Transport (PHT) Pump Motor Overhaul (-$6.0M), Project 4

#33224 Darlington Auxiliary Boiler Feed Pump Seal Cooling (-$5.3M), and Project #33973 5

Darlington SG Controls Replacement (-$5.0M). This was offset by four projects totalling 6

(+$2.9M), primarily Project #73706 Darlington Holt Road Interchange Upgrade (+$2.5M). 7

8

Decreased in-service amounts at Pickering (-$98.0M) are mainly due to the timing of in-service 9

of the Fukushima Project #49158 Pickering B Phase 1 Beyond Design Basis Event Emergency 10

Mitigation Equipment (-$12.7M), Project #40976 Pickering B Fuel Handling Reliability 11

Modifications (+$11.5M), Project #49146 Pickering Fire Code Compliance for Relocatable 12

Structures in Un-Zoned Area for Pickering Station (-$10.4M), Project #41023 Unit 1 and 4 Fuel 13

Channel East Pressure Tube Shift Tooling (Capital) (-$7.7M), and Project #41027 Pickering 14

Fukushima Phase 2 Beyond Design Basis Event Emergency Mitigation Equipment (-$7.3M). 15

16

The decreased in-service amounts at Nuclear Support Divisions (-$34.2M) are due to Project 17

#66600 Machine Delivered Scrape (-$18.9M), Project #25918 Sally Port Physical Barrier 18

Installation (-$8.8M), and Project #66594 Channel Inspection and Gauging Apparatus for 19

Reactors Gap System and Drive Reliability (-$4.5M). 20

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

LIST OF ATTACHMENTS 1

2

Attachment 1: Business Case Summaries and Supporting Information 3

4

Attachment 2: Darlington Water Treat Plant Business Case Justification Memo 5

6

Note: Business Case Summaries included in Attachment 1 are marked “Confidential” or 7

“Internal Use Only”, however, OPG has determined them to be non-confidential either in their 8

entirety or with redactions as indicated. 9

10

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

Attachment 1 1

2

1.0 Business Case Summaries 3

Section 3.0 below provides a list of capital projects with a total project cost (actual or forecast) 4

of $20M or greater. The business case summaries (“BCS”) for the projects listed are 5

attached.25 Business case summaries are provided for all projects, with the exception of 6

Security projects, as discussed in Section 2.0 below. 7

8

2.0 Security Project Description and Need 9

This section provides a brief project description of any security-classified nuclear projects 10

included in D2-1-3, Table 1a-d for which BCSs are not provided. 11

12

In all cases, these security projects are being undertaken to meet Canadian Nuclear Safety 13

Commission security requirements (Ex. A1-6-1, Section 8), which are common to both OPG 14

nuclear stations (Pickering and Darlington). 15

16

Project #82929 Security Project B. This project is to proactively replace obsolete 17

components within the security systems at Darlington. Total project cost is $32.7M. Planned 18

final in-service is September 2021. 19

20

Project #82930 Security Project C. This project is to proactively replace obsolete 21

components within the security systems at Pickering. Total project cost is $22.9M. Planned 22

final in-service is March 2021. 23

25 OPG has requested confidential treatment of certain business case summaries under the OEB’s Practice Direction for Confidential Information

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

3.0 Business Case Summary Index 1

Tab No

Project Number

Business Case Summary (Title) BCS Approval

Date

ONGOING PROJECTS FROM EB-2016-0152

1 31412 Darlington Class II Uninterruptible Power Supply Replacement Nov-17

2 31426 Darlington Fuel Handling Inverter Replacement Aug-18

3 31516 Darlington Station Lighting Retrofit Mar-19

4 31518 Darlington Restore Emergency Service Water Margins Sep-18

5 31524 Darlington Roof Replacement Project Mar-19

6 31532 Darlington Powerhouse Water Air Cooling Unit (ACU) Replacements May-19

7 31535 Darlington Water Treatment Plant Interconnections Jun-19

8 31542 Darlington Install Multi-Gas Analyzers on Transformers MOT/SST/UST Jun-18

9 31544 Darlington Radiation Detection Equipment Obsolescence ((Stack Monitoring & Post Accident Radiation Monitoring System (PARMS))

Jan-18

10 31710 Darlington Shutdown Cooling Heat Exchanger Replacement Feb-18

11 31716 Darlington Neutron Over-Power (NOP) and Ion Chamber (IC) Amplifier Replacement (Reactor Regulation System (RRS), Shutdown System #1 (SDS1) and Shutdown System #2 (SDS2))

May-18

12 33258 Darlington Replacement of Emergency Power System (EPS) Uninterruptible Power Supply May-17

13 33621 Darlington Secondary Control Area Air Conditioning Unit Replacement Oct-18

14 33631 Darlington Chiller Replacement to Reduce CFC Emissions Sep-10

15 33819 Darlington Vibration Monitoring System Replacement for Major Pump-sets Jul-20

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

16 33973 Darlington Standby Generator Controls Replacement Oct-17

17 33977 Darlington Digital Control Computer (DCC) Replacement Oct-17

18 34000 Darlington Auxiliary Heating System Facility May-16

19 38948 Darlington Zebra Mussel Mitigation Improvements Jan-18

20 73566 80144 36001

Darlington Primary Heat Transport Pump Motor Replacement Overhaul and Capital Spare26 Jul-17

21 80022 Darlington OH180 Aging Management Hardware Installation Sep-19

22 80023 Darlington Steam Generator Level Control Valve Replacement Nov-19

23 80036 Darlington R22 Refrigerant Air Conditioning Unit (ACU) Replacement

Jul-19

24 80063 Darlington Standby Generators Protective Relay Replacement

Jun-20

25 80078 Darlington Digital Control, Common Process and Sequence of Events Monitoring Computer Aging Management

May-18

26 40691 Pickering B Emergency Power Generator (EPG) and Main Output Power (MOP) Protective Relay Replacement Dec-17

COMPLETED/DEFERRED/CANCELLED FROM EB-2016-0152

27 25619 Darlington Operations Support Building Refurbishment Aug-15

28 31508 49158 49299

Fukushima Phase 1 Beyond Design Basis Event (BDBE) Emergency Mitigation Equipment (EME)27

Aug-16

29 31552

Darlington Condenser Cooling Water (CCW) & Low Pressure Service Water (LPSW) Travelling Screen Replacement

Dec-16

30 31717 Darlington Maintenance and Computer Development

Facility (Capital) Mar-12

26 Projects 73566, 36001 and 80144 are combined in a single Business Case Summary. 27 Projects 31508, 49158 and 49299 are combined in a single Business Case Summary.

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

31 32202 41027

Fukushima Phase ll Beyond Design Basis Event Emergency Mitigation Equipment28

Aug-16

32 33955 Darlington Shutdown System (SDS) Computers Aging Management

Jul-16

n/a29 36001 Darlington Purchase of Primary Heat Transport Pump Motor Capital Spares

Jul-17

33 73706 Darlington Holt Road Interchange Upgrade Feb-14

34 80111 Darlington Generator Stator Core Capital Spare Sep-15

35 41023 49247

Pickering A Fuel Channel Reconfiguration & East & West Shift Tooling

Sep-14

36 40976 Pickering B U58 Fuel Handling Reliability Improvement Project

May-16

37 46634 Pickering A Fuel Handling Single Point of Vulnerability (SPV) Reliability Improvement Capital

May-12

38 66600 Pickering Machine Delivered Scrape Project Oct-17

PROJECTS NOT IN EB-2016-0152

39 80122 Darlington Main Power Output Protection System Replacement May-18

40 80123 Darlington Group II Pressure Transmitter Replacement May-20

41 80124 Darlington Obsolete Controller Replacement Feb-19

42 80126 Darlington Emergency Power Generator 1 and 2 Replacement May-18

43 80148 Darlington Fuel Handling Control Computer Input/Output Subsystem (Multiplexer) & and Interprocessor Communication Replacement

Feb-19

44 80150 Darlington Fire Retardant Fluid (FRF) Pump Improvement May-18

45 82883 Darlington Class 1 Rectifier Replacement May-18

46 82890 Darlington Transformer Control Cabinet Wiring System Replacement Jan-19

28 Projects 32202 and 41027 are combined in a single Business Case Summary 29 Tab 20

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

47 82947 Darlington Fueling Machine (FM) Head Major Component Replacement Oct-18

48 83049 Darlington Copper Piping Replacement Aug-19

49 83052 Darlington Fuel Handling (FH) Power & Signal Cable Replacement Apr-19

50 83053 Darlington Shutdown Cooling Heat Exchanger Powerhouse Upper Level Water Piping Replacement (PULSW) Piping Replacement

Jul-18

51 83076 Darlington Phase 2 Station Battery Replacement Jul-19

52 83296 Darlington Main Output Transformer and Unit Service Transformer Replacement Jul-19

53 83297 Darlington Large Moderator Temperature Control Valve Replacement May-17

54 83298 Darlington Secondary Systems High Priority Control Valve Replacements Mar-19

55 83299 Darlington Condenser Steam Discharge Valves Control System Upgrade Nov-18

56 83480 Darlington 4kV Motors Refurbishment and Replacement May-18

57 83484 Darlington Isolated Phase Bus Refurbishment Jul-20

58 83556 Darlington Turbine Hall Crane Controls Upgrade Jul-20

59 83558 Darlington Fuel Handling (FH) Service Area Bridge F5 Ball Screw Assembly Replacement, and DN Fuel Handling SAB Ball Screw and Jack Assembly Capital Spares

Oct-18

60 83559 Darlington Irradiated Fuel Bay (IFB) Permanent Fuel Inspection Equipment in East & West Fueling Facility Auxiliary Area

Mar-18

61 83664 Darlington Unit 2 Turbine/Generator Electronic Controls and Generator Auxiliaries Upgrade Dec-19

62 83916 Darlington Fuel Handling Calibration Facility Component Replacement Project Feb-19

63 84009 Darlington Air Operated Valve (AOV) Replacements Mar-20

64 84235 Darlington Primary Heat Transport Liquid Relief Valves Modifications 2 Dec-18

65 84551 Darlington Motor Operated Valve (MOV) Replacements Mar-20

Filed: 2020-12-31 EB-2020-0290

Exhibit D2 Tab 1

Schedule 3 of 59

66 84799 Darlington Primary Heat Transport (PHT) Pump Rotor Inspect / Replace (RECL) May-20

67 84939 Darlington Revenue Metering Transformer Replacement Nov-19

68 83072 Pickering Buried Boiler Blowdown Pipe Replacement Jul-19

69 83088 Pickering A LP Feedwater Heat Exchangers Replacement (Capital) Mar-18

70 83668 Pickering High Pressure Turbine Spares Nov-17

71 83039 Darlington Rapid Delivery Machine (RDM) Aug-18

72 83828 Fleet Monitoring Initiative (Monitoring and Diagnostic Centre) Mar-20

1

Numbers may not add due to rounding. Filed: 2020-12-31EB-2020-0290

Exhibit D2 Tab 1 Schedule 3

Table 1a

Total TotalFinal Project Project Total In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-Service

Line Project Start In-Service Cost2 Cost - EB-2016-0152 In-Service LTD14 IR Term 2020 2021 2022 2023 2024 2025 2026

No. Facility Project Name Number Category Date Date13 ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M)(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) (n) (o) (p) (q) (r) (s) (t)

ONGOING PROJECTS FROM EB-2016-01521 DN DN Class II Uninterruptible Power Supply Replacement 31412 Sustaining Jan-11 Mar-25 63.6 55.1 38.4 38.4 62.0 29.2 25.2 0.0 7.5 13.9 5.9 0.0 5.4 0.12 DN DN Fuel Handling Inverter Replacement 31426 Sustaining Nov-11 Apr-21 26.2 14.4 13.9 n/a 26.1 23.7 0.0 1.0 2.5 0.0 0.0 0.0 0.0 0.03 DN DN Station Fluorescent Lighting Fixtures Retrofit 31516 Sustaining Dec-12 Jan-23 20.7 11.4 6 16.9 n/a 19.8 9.6 3.9 3.1 3.2 1.4 2.5 0.0 0.0 0.04 DN DN Restore Emergency Service Water and Firewater Margins 31518 Regulatory Dec-12 Aug-19 28.5 47.1 28.5 n/a 10.5 9.7 0.0 0.8 0.0 0.0 0.0 0.0 0.0 0.05 DN DN Station Roofs Replacement 31524 Sustaining Nov-12 Nov-27 116.9 36.3 7 n/a n/a 116.8 21.5 66.2 11.9 12.7 12.8 12.0 14.2 15.2 12.06 DN DN Powerhouse Water Air Condition Units Replacement 31532 Sustaining Oct-12 Jan-23 38.2 26.6 8 26.6 26.6 30.7 13.9 3.1 3.7 10.2 2.9 0.2 0.0 0.0 0.07 DN DN Water Treatment Plant Interconnections 31535 Sustaining Sep-11 Sep-24 53.2 57.8 n/a n/a 53.2 0.0 53.2 0.0 0.0 0.0 0.0 53.2 0.0 0.08 DN DN Transformer Multi-Gas Analyzer Installation 31542 Sustaining Oct-12 Dec-20 23.8 22.7 15.2 15.2 22.5 22.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.09 DN DN Radiation Detection Equipment Obsolescence 31544 Sustaining Jan-14 Sep-23 45.0 46.9 n/a n/a 41.3 0.0 22.3 0.0 19.0 15.0 7.0 0.3 0.0 0.0

10 DN DN Shutdown Cooling Heat Exchanger Replacement 31710 Sustaining Nov-12 Dec-21 111.4 112.8 9 56.1 56.1 74.1 72.1 0.0 0.0 1.8 0.0 0.0 0.0 0.0 0.0

11 DNDN Neutron Over-Power Ion Chamber & In-Core Flux Detector Amplifier Replacement (Reactor Regulating System, Shutdown System 1 & Shutdown System 2)

31716 Sustaining Jul-13 Apr-27 23.8 17.7 23.8 n/a 17.9 1.2 9.6 1.6 2.5 1.6 1.4 2.0 2.2 2.4

12 DN DN Replacement of Emergency Power Supply Uninterruptible Power Supply 33258 Sustaining Feb-10 Feb-22 24.6 16.6 15.2 15.2 24.8 13.9 2.1 1.7 7.1 2.1 0.0 0.0 0.0 0.0

13 DN DN Air Conditioning Unit Replacement for Secondary Control Area 33621 Sustaining Feb-09 Aug-25 36.0 28.3 12.3 12.3 34.1 24.4 9.6 0.0 0.0 5.1 2.2 0.0 2.2 0.214 DN DN Chiller Replacement to Reduce Chloroflurocarbon Emissions 33631 Regulatory Jan-04 Dec-17 30.0 30.0 14.9 14.9 21.6 21.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.015 DN DN Major Pump-sets Vibration Monitoring System Upgrades 33819 Sustaining Mar-06 Nov-26 55.4 23.8 12.8 n/a 48.2 10.4 18.0 11.2 9.0 5.0 5.0 4.0 2.0 2.016 DN DN Standby Generator Controls Replacement 33973 Sustaining Dec-06 Mar-21 46.3 39.6 21.8 21.8 46.1 44.1 0.4 0.0 1.6 0.4 0.0 0.0 0.0 0.0

17 DN DN Digital Control Computer Replacement / Refurbishment / Upgrades 33977 Sustaining Sep-03 Dec-21 26.5 24.9 22.1 22.1 26.5 23.1 0.3 1.1 2.1 0.3 0.0 0.0 0.0 0.0

18 DN DN Auxiliary Heating System - Phases 1 & 2 Alternative Heating 34000 Regulatory Mar-06 Jun-18 107.1 107.2 10 45.6 45.6 102.1 102.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.019 DN DN Zebra Mussel Mitigation Improvements 38948 Sustaining Nov-12 Dec-21 36.6 29.3 12 21.5 21.5 36.5 34.8 0.0 1.4 0.4 0.0 0.0 0.0 0.0 0.020 DN DN RS Primary Heat Transport Pump Motor Replacement4 73566 Sustaining Jul-15 May-21 84.0 129.5 26.7 26.7 71.4 68.0 0.2 0.0 3.1 0.2 0.0 0.0 0.0 0.021 DN DN OH180 Aging Management Hardware Installation 80022 Sustaining Dec-14 Jun-28 60.9 90 11 60.9 n/a 38.0 11.6 16.0 3.1 5.9 4.1 3.9 2.9 2.1 2.922 DN DN Steam Generator Level Control Valve Replacement 80023 Sustaining Jan-15 Jun-26 38.6 16.3 n/a n/a 38.5 0.0 38.5 0.0 0.0 0.0 9.6 9.6 9.6 9.623 DN DN R22 Refrigerant Air Conditioning Unit Replacement 80036 Regulatory Dec-15 Jan-26 36.1 14.9 n/a n/a 37.8 2.0 27.1 2.9 5.9 2.3 6.7 7.1 6.5 4.524 DN DN Standby Generators Protective Relay Replacement 80063 Sustaining Dec-15 Feb-23 20.0 9.9 n/a n/a 15.8 0.0 15.8 0.0 0.0 11.7 3.0 0.7 0.3 0.0

25 DN DN Digital Control, Common Process and Sequence of Events Monitoring Computer Aging Management 80078 Regulatory Nov-15 Feb-28 77.5 47.3 n/a n/a 56.5 0.9 42.2 0.0 0.0 2.0 4.7 7.1 18.5 9.9

Notes:12

point estimates or, if range estimate or no estimate is provided in lieu of a point estimate, the current estimate of total project cost34

5 The designation of "n/a" means the project has not advanced to a First Execution BCS6 EB-2016-0152 L-04.4-15 SEC 0487 Total project cost set out in EB-2016-0152, Ex. D2-1-3, Table 1 incorrectly identified total project cost for Project #31524 as $38.3M.8 EB-2016-0152 L 04.2-2 Staff 0289 EB-2016-0152 J15.5 Attachment 1

10 EB-2016-0152 L-04.4-15 SEC 046 11 EB-2016-0152 J15.5 Attachment 312 EB-2016-0152 J15.5 Attachment 213 Final In-Service Date means either the current forecast of the final date for in-service and close out of project, or the historical final project in-service date (but not the final project close out date which may not have yet occurred).14 Life Time to Date (LTD) means in service amounts as of Dec 31, 2019

Table 1aCapital Project Listing - Nuclear Operations Facility Projects

Projects ≥ $20M Total Project Cost1

Projects 31508, 49158 and 49299 are combined in a single Business Case Summary.

project 73566 and project 80144 were included in Ex D2-1-3 Table 1 with a combined project cost of $129.5M, while #36001 project cost was $30.8M. First execution BCS amounts are derived from the combined amount

Projects 73566 ($84.0M), 36001 ($27.6M) and 80144 ($53.3M) are combined in a single Business Case Summary ($164.9M). In EB-2016-0152

Total Project Cost reflects BCS amounts at the time of preparing the Amended 2020-2026 Business Plan, with the exception of Completed/Deferred/Cancelled Projects (for which actual costs are shown). BCS amounts reflectProjects with expenditures during IR term OR In-Service Amounts in Bridge or IR term, AND Completed/Deferred Projects at the time of preparing the Amended 2020-2026 Business Plan (from EB-2016-0152 or subsequent).

1st Execution Business Case5

1st Execution Business Case- EB-2016-01525

Numbers may not add due to rounding. Updated: 2021-07-09EB-2020-0290


Table 1b

Total TotalFinal Project Project Total In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-Service

Line Project Start In-Service Cost2 Cost - EB-2016-0152 In-Service LTD11 IR Term 2020 2021 2022 2023 2024 2025 2026

No. Facility Project Name Number Category Date Date10 (M$) (M$) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M)(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) (n) (o) (p) (q) (r) (s) (t)

ONGOING PROJECTS FROM EB-2016-015226 DN DN Primary Heat Transport Pump Motor Overhaul 7 80144 Sustaining Jul-15 Oct-21 53.3 129.5 102.8 102.8 43.8 34.1 0.0 3.5 6.2 0.0 0.0 0.0 0.0 0.0

27 PN PB Emergency Power Generator and Main Output Power Protective Relay Replacement 40691 Sustaining Feb-12 Oct-19 29.7 11.0 7.5 7.5 25.2 25.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

28 Subtotal 1,314.0 353.3 46.9 100.8 80.8 64.0 101.1 63.9 43.6

COMPLETED/DEFERRED/CANCELLED FROM EB-2016-015229 DN DN Operations Support Building Refurbishment 25619 Sustaining Mar-09 Nov-15 61.3 62.7 47.8 47.8 59.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

30 DN DN Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment 3

31508 Regulatory Sep-11 Apr-18 55.5 52.9 29.1 27.3 55.5 0.0 0.4 0.0 0.0 0.0 0.0 0.0 0.0

31 DN DN Condenser Circulating Water and Low Pressure Service Water Travelling Screens Replacement 31552 Sustaining May-13 Nov-18 33.0 37.6 24.4 24.4 33.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

32 DN DN Improve Maintenance Facilities at Darlington (Capital) 31717 Sustaining Aug-07 Nov-13 35.6 43.2 49.8 49.8 33.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

33 DN DN Fukushima Phase 2 Beyond Design Basis Event Emergency Mitigation Equipment 9

32202 Regulatory Oct-12 May-18 23.1 28.0 28.0 28.0 21.9 0.0 0.8 0.0 0.0 0.0 0.0 0.0 0.0

34 DN Shutdown System Computer Aging Management 33955 Sustaining Nov-06 Dec-15 20.3 20.3 17.2 17.2 20.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

35 DN DN Purchase of Primary Heat Transport Pump Motor Capital Spares 36001 Sustaining Apr-10 Oct-15 27.6 30.8 12.0 12.0 27.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

36 DN DN Holt Road Interchange Upgrade 73706 Value Enhancing Nov-13 Aug-16 26.7 28.6 31.0 31.0 26.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

37 DN DN Generator Stator Core Spare 80111 Sustaining Sep-15 Jul-19 30.8 35.0 35.0 35.0 30.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.038 PN PB Fuel Handling Reliability Modifications 40976 Sustaining Aug-12 Dec-18 40.4 37.3 29.0 29.0 39.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.039 PN Unit 1 & 4 Fuel Channel East Pressure Tube Shift Tooling 4 41023 Sustaining Oct-12 Dec-16 27.7 38.6 22.0 22.0 27.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

40 PN PN Fukushima Phase 2 Beyond Design Basis Event Emergency Mitigation Equipment 9

41027 Regulatory Oct-12 Nov-17 49.7 46.3 46.3 46.3 49.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

41 PN PA Fuel Handling Single Point of Vulnerabilty Equipment Reliability Improvement Project - Capital 46634 Sustaining Feb-11 Dec-18 21.2 27.3 27.0 27.0 20.9 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

42 PN PB Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment 3

49158 Regulatory Sep-11 Oct-17 41.7 58 6 29.3 29.3 41.7 0.0 0.6 0.0 0.0 0.0 0.0 0.0 0.0

43 SEC Physical Barrier System 25609 Regulatory Nov-05 Dec-13 67.2 67.2 37.0 37.0 67.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

44 IRI PN Machine Delivered Scrape 66600 Value Enhancing Feb-14 Oct-18 27.0 26.1 8 24.9 24.9 27.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

45 Subtotal 588.9 0.0 1.8 0.0 0.0 0.0 0.0 0.0 0.0

Notes:12

point estimates or, if range estimate or no estimate is provided in lieu of a point estimate, the current estimate of total project cost34

5 The designation of "n/a" means the project has not advanced to a First Execution BCS6 Project 49158 was combined with Project 49299 and Project 31508. Total project cost for project 49158 was $44.0M7 Projects 73566 ($84.0M), 36001 ($27.6M) and 80144 ($53.3M) are combined in a single Business Case Summary ($164.9M). In EB-2016-0152

project 73566 and project 80144 were included in Ex D2-1-3 Table 1 with a combined project cost of $129.5M, while #36001 project cost was $30.8M. First execution BCS amounts are derived from the combined amount8 EB-2016-0152 L-04.2-1 Staff 0439 Projects 41027 and 32202 were combined into a single BCS. First execution BCS amounts are derived from the combined amount 10 Final In-Service Date means either the current forecast of the final date for in-service and close out of project, or the historical final project in-service date (but not the final project close out date which may not have yet occurred).11 Life Time to Date (LTD) means in service amounts as of Dec 31, 2019

Projects 41023 and 49247 are combined in a single Business Case Summary. Project 49247 is from Ex. D2-1-3 Table 2 in EB-2013-0321

Total Project Cost reflects BCS amounts at the time of preparing the Amended 2020-2026 Business Plan, with the exception of Completed/Deferred/Cancelled Projects (for which actual costs are shown). BCS amounts reflect

Projects 31508, 49158 and 49299 are combined in a single Business Case Summary of $70M. First execution BCS amounts are derived from the combined amount.

Projects with expenditures during IR term OR In-Service Amounts in Bridge or IR term, AND Completed/Deferred Projects at the time of preparing the Amended 2020-2026 Business Plan (from EB-2016-0152 or subsequent).

1st Execution Business

Case5


Case EB-2016-01525

First execution BCS amounts are derived from the combined amount

Table 1bCapital Project Listing - Nuclear Operations Facility Projects




Table 1c

TotalFinal Project Total In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-Service

Line Project Start In-Service Cost2 In-Service LTD5 IR Term 2020 2021 2022 2023 2024 2025 2026No. Facility Project Name Number Category Date Date4 (M$) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M)

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) (n) (o) (p) (q) (r)

PROJECTS NOT IN EB-2016-015246 DN DN Main Power Output Protection System Replacement 80122 Sustaining Sep-16 Aug-27 65.0 n/a 88.4 0.0 75.0 0.0 0.0 0.0 15.0 20.0 20.0 20.047 DN DN Group II Pressure Transmitter Replacement 80123 Sustaining Jan-16 Jan-28 47.7 n/a 37.5 0.0 29.0 0.0 2.0 5.8 5.8 5.8 5.8 5.848 DN DN Obsolete Controller Replacement 80124 Sustaining Jun-17 Dec-26 38.0 38.0 28.5 5.4 13.1 4.9 4.8 3.9 3.0 3.7 2.0 0.549 DN DN Emergency Power Generator 1 and 2 Replacement 80126 Regulatory Feb-17 May-22 176.2 176.2 180.8 19.4 89.4 72.0 0.0 89.4 0.0 0.0 0.0 0.0

50 DN DN Fuel Handling Computer Input/Output Subsystem and Interprocessor Communication Replacement 80148 Sustaining Dec-15 Apr-27 23.4 n/a 22.1 0.0 21.0 0.0 0.0 1.6 0.4 2.0 14.0 3.0

51 DN DN Fire Resistant Fluid Pump Improvement 80150 Sustaining Jan-16 Nov-25 30.0 n/a 25.0 0.0 25.0 0.0 0.0 8.5 6.5 5.0 5.0 0.052 DN DN Class 1 Rectifier Replacement 82883 Sustaining May-18 Dec-32 42.3 n/a 36.3 0.0 17.0 0.0 0.0 3.0 3.5 3.5 3.5 3.5

53 DN DN Main Power Output and Class IV Transformer Control Cabinet Wiring Replacement 82890 Sustaining Jan-19 Deferred 26.8 n/a 24.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

54 DN DN Fuel Handling Head Major Component Replacement 82947 Sustaining Oct-18 May-27 98.0 n/a 60.9 0.0 59.0 0.0 0.0 0.0 20.0 13.0 13.0 13.055 DN DN Copper Piping Replacement 83049 Sustaining Aug-16 Dec-22 45.1 29.3 43.7 28.7 6.0 2.7 6.3 6.0 0.0 0.0 0.0 0.056 DN DN Fuel Handling Power and Signal Cable Catenary Replacement 83052 Sustaining Apr-19 Jan-27 24.6 n/a 11.9 0.00 8.7 0.0 2.5 8.5 0.2 0.0 0.0 0.057 DN DN Powerhouse Upper Level Service Water Piping Replacement 83053 Sustaining Oct-16 Jan-25 75.2 55.7 66.7 16.2 50.5 1.9 0.0 13.0 16.5 2.5 16.0 2.558 DN DN Phase 2 Station Battery Replacement 83076 Sustaining Aug-16 Dec-28 34.5 18.9 26.2 0.3 18.6 1.3 2.7 4.9 3.9 3.5 3.2 3.059 DN DN Main Output Transformer & Unit Service Transformer Replacement 83296 Sustaining Jul-18 Jun-24 170.1 170.1 131.2 0.0 98.4 0.0 32.8 65.6 28.7 4.0 0.1 0.060 DN DN Large Moderator Temperature Control Valve Replacement 83297 Sustaining Nov-18 Jun-26 36.9 n/a 31.2 0.0 26.2 0.0 5.0 5.0 9.0 5.0 7.2 0.061 DN DN Secondary System High Priority Control Valve Replacement 83298 Sustaining Mar-18 Dec-27 35.4 n/a 29.6 0.0 26.5 0.0 3.2 3.2 9.5 8.5 5.3 0.0

62 DN DN Condenser Steam Discharge Valve Control System Replacement 83299 Sustaining Jan-19 Dec-27 29.7 n/a 22.8 0.0 18.5 0.0 0.0 5.3 2.6 7.9 2.6 0.0

63 DN DN 4kV Motor Refurbishment and Replacement 83480 Sustaining Oct-18 Jun-28 278.8 n/a 172.1 0.0 89.8 0.0 0.0 11.8 19.0 15.0 17.0 27.064 DN DN Isolated Phase Bus Refurbishment 83484 Sustaining Jul-20 Jun-28 62.4 n/a 36.5 0.0 22.9 0.0 0.0 0.0 0.0 8.8 0.0 14.265 DN DN Turbine Hall Crane Controls Upgrade 83556 Sustaining Dec-17 Dec-20 23.6 19.7 23.1 0.0 0.0 22.2 0.0 0.0 0.0 0.0 0.0 0.0

66 DN DN Fuel Handling Service Area Bridge F5 Ball Screw Assembly Replacement 83558 Sustaining Mar-18 Jun-25 28.2 n/a 12.5 0.0 11.8 0.0 0.0 0.0 4.6 5.4 1.8 0.0

67 DN DN East Irradiated Fuel Bay Permanent Fuel Inspection Equipment 83559 Regulatory Mar-18 May-22 25.0 25.0 17.9 0.0 8.9 0.0 9.0 8.9 0.0 0.0 0.0 0.068 DN DN Unit 2 Turbine Control & Aux Systems Upgrade 83664 Sustaining Dec-19 Jul-25 112.7 n/a 102.2 0.0 102.1 0.0 0.0 0.0 0.0 0.0 102.1 0.0

69 DN DN Fuel Handling Replacement of Fuelling Machine Calibration Facility 83916 Sustaining Feb-19 Jul-25 22.4 22.4 0.0 22.4 0.0 0.0 0.0 2.5 9.9 9.9 0.0

70 DN DN Air Operated Valve Replacement 84009 Sustaining Mar-20 Dec-28 85.7 n/a 82.9 0.0 39.5 0.0 0.0 12.5 0.0 8.0 13.5 5.5

71 DN DN Primary Heat Transport Liquid Relief Valve Modifications (Waterhammer) 84235 Regulatory Jan-19 Jul-26 86.8 85.9 70.5 24.422 43.5 2.6 0.0 11.5 13.7 2.9 12.2 3.3

Notes:12

point estimates or, if range estimate or no estimate is provided in lieu of a point estimate, the current estimate of total project cost3 The designation of "n/a" means the project has not advanced to a First Execution BCS4 Final In-Service Date means either the current forecast of the final date for in-service and close out of project, or the historical final project in-service date (but not the final project close out date which may not have yet occurred).5 Life Time to Date (LTD) means in service amounts as of Dec 31, 2019

Total Project Cost reflects BCS amounts at the time of preparing the Amended 2020-2026 Business Plan, with the exception of Completed/Deferred/Cancelled Projects (for which actual costs are shown). BCS amounts include minor removal costs and reflectProjects with expenditures during IR term OR In-Service Amounts in Bridge or IR term, AND Completed/Deferred Projects at the time of preparing the Amended 2020-2026 Business Plan (from EB-2016-0152 or subsequent).

Table 1cCapital Project Listing - Nuclear Operations Facility Projects



Case3

Numbers may not add due to rounding. Updated: 2021-07-09 Privileged and confidential. Prepared in contemplation of litigation. EB-2020-0290


Table 1d

TotalFinal Project Total In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-Service

Line Project Start In-Service Cost2 In-Service LTD5 IR Term 2020 2021 2022 2023 2024 2025 2026No. Facility Project Name Number Category Date Date4 (M$) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M)

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) (n) (o) (p) (q) (r)

PROJECTS NOT IN EB-2016-015272 DN DN Motor Operated Valve Replacement 84551 Sustaining Mar-20 Dec-28 44.5 n/a 37.5 0.0 29.3 0.0 0.0 7.0 7.0 5.3 7.0 3.273 DN DN Primary Heat Transport Pump Rotor Inspection and Replacement 84799 Sustaining May-20 Oct-26 89.2 89.2 46.4 0.0 46.4 0.0 0.0 0.0 15.3 12.5 18.4 0.274 DN DN Revenue Metering Transformer Replacement 84939 Regulatory Apr-20 Oct-26 35.9 n/a 25.5 0.0 25.5 0.0 0.0 0.0 0.0 3.4 6.9 15.275 PN PN P58 Buried Blowdown Piping Replacement 83072 Sustaining Nov-16 Dec-20 20.9 20.9 16.6 0.0 0.0 16.6 0.0 0.0 0.0 0.0 0.0 0.076 PN PA Low Pressure Feedwater Heat Exchanger Replacement 83088 Sustaining May-16 May-18 22.0 19.4 20.0 20.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.077 PN PN High Pressure Turbine Spindle Capital Spares 83668 Sustaining Nov-17 Aug-19 21.3 23.4 21.3 21.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.078 SEC Security Project B 82929 Sustaining Jun-16 Sep-21 32.7 32.7 28.8 0.8 0.1 3.1 24.8 0.1 0.0 0.0 0.0 0.079 SEC Security Project C 82930 Sustaining Jun-16 Mar-21 22.9 22.9 18.9 0.0 0.0 3.1 15.8 0.0 0.0 0.0 0.0 0.080 IRI DN Rapid Delivery Machine 83039 Sustaining Nov-14 May-25 162.2 n/a 118.4 0.0 113.2 5.2 0.0 0.0 83.6 0.0 29.5 0.081 ENG Fleet Monitoring Initiative (Monitoring & Diagnostic Centre) 83828 Sustaining Mar-18 Jul-23 29.3 n/a 23.7 0.0 16.0 2.7 5.0 6.0 10.0 0.0 0.0 0.082 Subtotal 2,205.8 1,153.2 138.2 114.0 281.4 280.4 155.6 316.0 119.8

83 Total 4,108.7 1,506.6 187.0 214.8 362.2 344.4 256.7 379.9 163.4

DIVISION TOTALS:84 Darlington 1,377.4 155.6 169.2 356.2 250.7 256.7 350.4 163.485 Pickering 0.0 17.3 0.0 0.0 0.0 0.0 0.0 0.086 Operations and Project Support 129.2 14.2 45.6 6.0 93.6 0.0 29.5 0.087 Total 1,506.6 187.0 214.8 362.2 344.4 256.7 379.9 163.4

Notes:12

point estimates or, if range estimate or no estimate is provided in lieu of a point estimate, the current estimate of total project cost3 The designation of "n/a" means the project has not advanced to a First Execution BCS4 Final In-Service Date means either the current forecast of the final date for in-service and close out of project, or the historical final project in-service date (but not the final project close out date which may not have yet occurred).5 Life Time to Date (LTD) means in service amounts as of Dec 31, 2019

Total Project Cost reflects BCS amounts at the time of preparing the Amended 2020-2026 Business Plan, with the exception of Completed/Deferred/Cancelled Projects (for which actual costs are shown). BCS amounts include minor removal costs and reflect


Case3


Table 1dCapital Project Listing - Nuclear Operations Facility Projects



Exhibit D2Tab 1

Schedule 3Table 2a

Total Final Project In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-Service

Line Project Project Start In-Service Cost2 IR Term 2020 2021 2022 2023 2024 2025 2026No. Facility Project Name Number Category Description Date Date3 ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M)

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k) (l) (m) (n) (o) (p)

ONGOING PROJECTS FROM EB-2016-0152

1 DN DN Active Liquid Waste System Upgrade 31403 RegulatoryAdd aeration and chemical addition to the active liquid waste management system to ensure compliance with discharge criteria.

Nov-09 Dec-22 12.1 6.9 0.0 0.0 6.6 0.4 0.0 0.0 0.0

2 DN DN Dryer Programmable Logic Controller Replacement 31420 Sustaining Replace obsolete programmable logic controllers. Feb-14 Aug-24 12.2 4.2 3.3 1.4 0.7 1.6 1.4 0.5 0.0

3 DN DN Pressurizer Heaters & Controllers Replacement Project 31422 Sustaining Replace electrical heaters in pressurizers that are at the end of their expected life. Apr-11 Dec-21 13.9 0.1 0.0 1.0 0.1 0.0 0.0 0.0 0.0

4 DN DN Containment Button-up Activity Monitors Replacement 31432 Sustaining

Replace aging and obsolete radioactivity monitors used to button up the Negative Pressure Containment System on high activity.

Nov-13 Mar-21 9.9 0.0 1.9 2.0 0.0 0.0 0.0 0.0 0.0

5 DN DN Computer Upgrade for Heavy Water Management System (Tritium Removal Faclity / Site Upgrader) 31436 Sustaining

Upgrade obsolete Heavy Water Management System computers that control Tritium Removal Facility and Station Upgrader operations.

Oct-12 Nov-21 8.2 0.0 0.0 2.4 0.0 0.0 0.0 0.0 0.0

6 DN DN Replacement of Obsolete Online Chemistry Analysers 31520 Sustaining Replace obsolete online chemistry analysers Oct-12 Jan-21 16.7 0.0 3.9 1.9 0.0 0.0 0.0 0.0 0.0

7 DN DN Tritium Removal Facility Deuterium Make-up System Electrolyzer Replacement 31522 Sustaining

Replace aged and obsolete TRF DMS Electrolyzer, to ensure reliability to the end of facility operation.

Nov-12 Oct-19 14.5 0.0 0.1 0.0 0.0 0.0 0.0 0.0 0.0

8 DN DN Feeder Scanner Replacement 31526 SustainingReplace the equipment that scans the feeders to locate channels containing failed fuel bundles.

Dec-12 Aug-22 18.9 2.3 0.0 3.0 2.3 0.0 0.0 0.0 0.0

9 DN DN Reactor Regulating System Logic Module Redesign 31534 Sustaining

Redesign the Regulator Regulating System logic modules to address spurious rod movements as well as addressing obsolescence of current modules.

Dec-13 Apr-23 9.9 1.2 0.0 2.9 0.0 1.2 0.0 0.0 0.0

10 DN DN Turbine-Generator Lube Oil Purifier Replacement 31536 SustainingReplace obsolete turbine lubricating oil purifier used to remove contaminants and metal from lubricating oil during operation.

Nov-12 Apr-18 7.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

11 DN DN Feedwater Chemistry Control Improvements 31548 SustainingInstall improved feedwater chemistry monitoring and connections for portable filtration.

Nov-13 Feb-20 14.0 0.0 0.8 0.0 0.0 0.0 0.0 0.0 0.0

12 DN DN Tritium Removal Facility Cryogenic Refrigeration System Turbine Oil Supply System / Turbine Replacement 31701 Sustaining

Replace the Tritium Removal Facility Cryogenic Refrigeration System turbine oil supply system and hydrogen expander turbine with a dynamic gas bearing (oilfree) turbine

Jan-14 Jun-25 12.9 3.1 0.0 0.0 0.0 0.0 0.0 3.1 0.0

Table continues on Ex. D2-1-3 Table 2b

Notes:12

point estimates or, if range estimate or no estimate is provided in lieu of a point estimate, the current estimate of total project cost3 Final In-Service Date means either the current forecast of the final date for in-service and close out of project, or the historical final project in-service date (but not the final project close out date which may not have yet occurred).

Table 2aCapital Project Listing - Nuclear Operations Facility Projects

Projects $5M - $20M Total Project Cost1

Projects with expenditures during IR term OR In-Service Amounts in Bridge or IR term, AND Completed/Deferred Projects at the time of preparing the Amended 2020-2026 Business Plan (from EB-2016-0152 or subsequent). Total Project Cost reflects BCS amounts at the time of preparing the Amended 2020-2026 Business Plan, with the exception of Completed/Deferred/Cancelled Projects (for which actual costs are shown). BCS amounts reflect


Exhibit D2Tab 1

Schedule 3Table 2b




ONGOING PROJECTS FROM EB-2016-0152 (Continued from Ex. D2-1-3 Table 2a)

13 DN DN Fuel Handling Power Track Platform & Maintenance Cut Out 31702 Sustaining

Construct a working platform and modify the power track structure to allow the power track equipment to be maintained during Unit 1 or Unit 4 outages as well as Unit 2 and Unit 3 outages.

Dec-13 Nov-19 6.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

14 DN DN Fuel Handling Obsolete Control Relay Re-Engineer/Replacement 31704 Sustaining

Replace the obsolete Fuel Handling control relays with relays of equal quality and near identical installation to mitigate challenges to FH System reliability.

Oct-13 Jul-24 5.8 5.4 1.1 1.5 0.0 3.1 2.3 0.0 0.0

15 DN DN Vapour Recovery Button-Up Valve Replacements 31706 SustainingReplace aging vapour recovery containment buttonup valves with new design less prone to passing.

Dec-13 Feb-24 16.2 16.2 0.0 0.0 0.0 15.2 0.9 0.1 0.0

16 DN DN Auxiliary Boiler Feed Pump Seal Cooling 33224 Sustaining

lnstall Gland Injection Cooling flush at both pump mechanical seals, for all eight ABFPs, as well as two new mechanical seals and two heat exchanger skids at each pump.

Mar-14 Dec-21 9.7 1.0 0.9 1.0 1.0 0.0 0.0 0.0 0.0

17 DN DN Hydrogen Cooling Temperature Control Valve TCV20 Redesign 33228 Sustaining

Replace Hydrogen Cooling temperature control system butterfly valve with a new type of control valve and controller, to address the reliability of the system during seasonal lake water temperature fluctuations.

Nov-12 Jun-21 16.2 0.3 0.0 1.0 0.3 0.0 0.0 0.0 0.0

18 DN Fuel Handling Computer Replacement 33815 Sustaining Replace obsolete components of the fuel handling system control computers. Aug-05 Nov-21 15.6 0.4 0.0 0.7 0.4 0.0 0.0 0.0 0.0

19 DN DN Central Services Area Sewage Line and Sump Emergency Connections 38466 Sustaining

Replace corroded and degraded sewage piping from Central Services Area and add emergency connections to allow sewage truck to empty sump in emergencies.

Jul-13 Dec-28 7.9 1.5 0.0 0.0 0.0 0.0 0.0 0.3 1.3

20 DN DN Feeder Scanner Replacement 80070 SustainingReplace permanent feeder scanner equipment with portable system that can be setup outside of containment prior to use.

May-14 Aug-22 18.9 2.1 0.0 5.5 2.1 0.0 0.0 0.0 0.0

21 DN DN Fire Hazard Assessment and Fire Safe Shutdown Analysis Modifications 80151 Regulatory

Implement modifications required for compliance to Canadian Standards Association N29307 Fire Protection for Nuclear Power Plants identified during the Integrated Safety Review and committed in the Integrated Implementation Plan.

Nov-15 Sep-21 20.0 0.5 0.0 11.7 0.5 0.0 0.0 0.0 0.0

22 DN DN Vault Cooling Coil Replacement 82816 Regulatory

Replace leaking and degraded cooling coils in the containment vault, which impairs the functions of maintaining vault temperatures during normal operation and removing heat from the steam-laden atmosphere in Loss of Coolant Accident conditions.

Dec-15 Jul-19 17.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

23 DN DN Irradiated Fuel Discharge Mechanism Major Component Replacement 82841 Sustaining

Replace the shuttle cylinders and other major components of the Irradiated Fuel Discharge system which are approaching end of design life.

Nov-15 Feb-24 5.9 2.3 0.0 1.7 0.0 0.0 2.3 0.0 0.0

Table continues on Ex. D2-1-3 Table 2c

Notes:12


Table 2bCapital Project Listing - Nuclear Operations Facility Projects




Exhibit D2Tab 1

Schedule 3Table 2c




ONGOING PROJECTS FROM EB-2016-0152 (Continued from Ex. D2-1-3 Table 2a)

24 PN PA Standby Generator Reliability Upgrades 40972 Sustaining

Improve reliability and availability of the unit 012/034 Standby Generators (SG) by addressing obsolescence, lack of spare parts, maintenance and performance issues.

Apr-12 Dec-21 19.0 0.0 4.7 6.7 0.0 0.0 0.0 0.0 0.0

25 PN PNGS Daily Tritium Sampler Replacement 40977 Regulatory

Replace unreliable, inaccurate and obsolete Airborne Tritium Samplers with improved models having silica gel column, to ensure reliable airborne tritium monitoring to the end of facility operation.

Apr-12 Aug-18 6.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

26 PN PN Replacement of Obsolete Online Chemistry Analysers 40985 Sustaining Replace obsolete online chemistry analyzers. Mar-13 Aug-19 18.5 0.0 1.2 0.0 0.0 0.0 0.0 0.0 0.0

27 PN PA Replacement of Auxiliary Irradiated Fuel Bay Supertool 40987 Sustaining

Replace the Auxiliary Irradiated Fuel Bay (AIFB) Supertool, which is a telescopic lifting tool used to irradiated fuel baskets and storage modules within the AIFB. Unavailability impacts fuelling activities and the movement of fuel into Dry Storage Modules.

May-12 Dec-20 5.2 0.0 1.2 0.0 0.0 0.0 0.0 0.0 0.0

28 PN PA Standby Generator Protective Relay Upgrade 41044 Sustaining Replace obsolete electromechanical protective relays with digital units. Jan-14 Oct-19 11.4 0.0 0.4 0.0 0.0 0.0 0.0 0.0 0.0

29 PN PB Replacement of Obsolete Instrumentation and Control Equipment 49154 Sustaining Replace critical obsolete instrumentation and

control equipment. Aug-11 Mar-21 6.8 0.0 1.9 0.9 0.0 0.0 0.0 0.0 0.0

30 PN PB Fukushima Emergency Telecommunications Enhancement 49161 Regulatory

Install a new telecommunications system that is portable and rapidly deployable at all onsite and offsite locations required for emergency response during a beyond design basis event.

Jun-12 Dec-17 5.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

31 Subtotal 363.2 47.7 21.5 45.4 14.0 21.5 7.0 3.9 1.3

Table continues on Ex. D2-1-3 Table 2d

Notes:12



Table 2cCapital Project Listing - Nuclear Operations Facility Projects




Exhibit D2Tab 1

Schedule 3Table 2d




COMPLETED/CANCELLED PROJECTS FROM EB-2016-0152

32 DN DN Passive Auto-Catalytic Recombiners 31306 Regulatory Install passive autocatalytic recombiners for longterm postaccident hydrogen mitigation. Dec-09 Nov-18 5.8 0.0 (0.1) 0.0 0.0 0.0 0.0 0.0 0.0

33 DN DN Tritium Removal Facility Cryogenic Refrigeration System Hydrogen Compressors Condition Monitoring System 31410 Value

Enhancing

Install a realtime condition monitoring system on the Cryogenic Refrigeration System (CRS) Hydrogen Compressors for predictive maintenance, to allow proactive intervention and thereby extend the operation time between planned TRF outages potentially from every 1.5 years to a target of every 2 years.

Oct-12 Oct-17 6.9 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

34 DN DN Fukushima Emergency Telecommunications Enhancement 31512 Regulatory

Install a new telecommunications system that is portable and rapidly deployable at all onsite and offsite locations required for emergency response during a beyond design basis event.

Jun-12 Dec-17 7.4 0.0 (0.1) 0.0 0.0 0.0 0.0 0.0 0.0

35 DN DN Permanent Detectors for Startup Instrumentation 31528 Value Enhancing

Install permanent startup instrumentation detectors, thereby eliminating outage time and worker dose to install and remove temporary detectors.

Oct-13 Cancelled 0.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

36 DNDN Main Output Transformer / Unit Service Transformer / System Service Transformer /10MVA Spare Transformer Storage Facility

31530 Sustaining

Construct a transformer storage facility within the unzoned area of the protected area, to ensure transportation to an affected unit within 5 days and minimize the impact of surveillance routines as well as periodic maintenance on spare transformers.

Dec-12 May-17 6.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

37 DN Replacement of Obsolete Computer Components 33509 Sustaining Replace obsolete components of the digital control computers. Jun-00 Jun-19 9.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

38 DN DN Installation of partial discharge monitors 33623 SustainingProvide a means of assessing stator winding conditions in the Main Generator and Primary Heat Transport Pump Motors.

May-07 Feb-14 5.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

39 DN DN Main Outpur Transforment Capital Spares 36002 Sustaining

Mitigate the risk of a forced outage due to Main Output Transformer failure by acquiring two spare transformer phases to facilitate a planned refurbishment programme.

Aug-11 Mar-17 8.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

40 DN DN Emergency Power Generator Power Turbine Capital Spare 36004 RegulatoryPurchase a spare Emergency Power Generator power turbine to mitigate risk of engine failure.

May-13 Cancelled 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

41 DN Tritium Removal Facility Tritium Emissions Reduction Project 38942 SustainingInstall an adsorbent dryer system and improved stack monitoring to reduce tritium emissions

Oct-12 Apr-16 0.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

42 DN DN Emergency Service Water Pipe and Component Replacement

73397 SustainingReplacement of degraded Emergency Service Water piping, valves and tanks during the 2015 Vacuum Building Outage.

Feb-14 Jan-16 6.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

43 DN DN BU55/56 Maintenance 73399 Sustaining

Perform refurbishment of 0-553150-BU55 and -BU56, whose condition assessment identified the risk of failure due to connection/joint and insulation age-related degradation.

Jun-13 Cancelled 4.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

44 DN DN DX-750 Spacer Retrieval CFFA 82949 Regulatory Develop tooling for the retrieval of fuel channel spacer during unit refurbishment Sep-20 Nov-20 6.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

45 PN PB Main Generator Automatic Voltage Regulator and Protective Relay Upgrade 40680 Sustaining

Replace analog automatic voltage regulator and electromechanical protective relays with new digital devices.

Feb-10 Jul-15 18.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

46 PN PB Machine Guarding Improvement on Low Risk Equipment 40983 Regulatory Install machine guarding on equipment to comply with Ministry of Labour requirements. Nov-12 Apr-18 5.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

47 PN PA Emergency Core Injection Strainer Capacity Margin 40984 RegulatoryImprove capacity of the emergency coolant injection system strainers to improve design margins.

May-12 May-13 5.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

48 PN PN Emergency Power Generator Engine Replacement 41043 Sustaining Replace the Emergency Power Generator gas turbine engines. Dec-14 Dec-16 6.6 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Table continues on Ex. D2-1-3 Table 2e

Notes:12


Table 2dCapital Project Listing - Nuclear Operations Facility Projects




Exhibit D2Tab 1

Schedule 3Table 2e




COMPLETED/CANCELLED PROJECTS FROM EB-2016-0152

49 PN PA Passive Auto-Catalytic Recombiners 46605 Regulatory Install passive autocatalytic recombiners for longterm postaccident hydrogen mitigation. Jan-10 May-14 12.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

50 PN PB SG/EPG Fire Detection Upgrade and CO2 Suppression Removal 49116 Sustaining

Ensure fire compliance for the Standby Generator, Standby Generator Oil Pump and Emergency Water & Power System buildings including a reliiable and maintainable fire detection system.

Feb-10 Apr-16 8.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

51 PN PB RBSW Dechlorination & MISA Cleanup 49132 Regulatory

Replace temporary dechlorination system for the Reactor Building Service Water discharge with a permanent system with improved sampling points.

Feb-10 Nov-16 15.1 0.0 (0.1) 0.0 0.0 0.0 0.0 0.0 0.0

52 PN PB Replacement of Containment Box-up Monitors 49134 Sustaining Replace obsolete ventilation exhaust radioactivity monitors Dec-10 May-15 7.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

53 PN PB Screenhouse Trash Bar Screen Replacement 49140 SustainingUpgrade trash bar screens to handle the debris currently experienced from Lake Ontario.

Mar-11 Jul-15 7.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

54 PN PN Fire Code Compliance for Relocatable Structures in Un-Zoned Area for Pickering Station 49146 Regulatory

Ensure compliance with Canadian Standards Association N29307 Fire Protection for CANDU Nuclear Plants for relocatable structures in the unzoned area.

Dec-11 Dec-18 19.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

55 PN Unit 1 & 4 Fuel Channel East Pressure Tube Shift Tooling 49247 SustainingDevelop and implement tooling for the repositioning and reconfiguration of the Unit 1 & 4 pressure tubes.

Nov-09 Sep-17 8.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

56 PN PN Standby Boiler Capacity Improvement 49267 Regulatory Provide reliable backup heating steam. Dec-08 Nov-15 6.2 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

57 PN PN Administration Building Rehab 49284 SustainingComplete rehabilitation of the Administration Building to support operations and postoperations activities.

Nov-09 Dec-14 18.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

58 PN PA Class II Emergency Lighting 49296 RegulatoryUpgrade emergency lighting to meet electrical codes and address employee safety concerns.

Aug-11 Aug-15 4.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

59 PN PA Replacement of Unit 1, Unit 4 and Irradiated Fuel Bay-A Stack Monitors 49298 Sustaining Replace obsolescent stack monitors with

monitors used in Pickering B. Nov-12 May-18 12.4 0.0 (0.2) 0.0 0.0 0.0 0.0 0.0 0.0

60 PN PA Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment 49299 Regulatory

Provide capability to respond to Beyond Design Basis Events following the events at Fukushima Daiichi Nuclear Power Plant

Sep-11 Dec-17 16.9 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

61 PN PA Firewater Buried Ring Header Replacement (North Loop) 80069 Sustaining

Proactively replace buried sections of the Pickering Units 1 to 4 fire water header subject to frequent failures due to poor material selection.

Nov-14 Jul-19 9.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

62 SEC Security Project A 25918 Regulatory Security Protected Jun-12 Dec-17 10.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

63 IRI IMS CIGAR (Channel Inspection and Gauging Apparatus for Reactors) Gap System and Drive Reliability 66594 Sustaining

Improve the reliabiity, operability and functionality of CIGAR (Channel Inspection and Gauging Apparatus for Reactors) system..

Jun-12 Sep-18 11.7 0.0 0.2 0.0 0.0 0.0 0.0 0.0 0.0

64 Subtotal 272.7 0.0 (0.2) 0.0 0.0 0.0 0.0 0.0 0.0

Table continues on Ex. D2-1-3 Table 2f

Notes:12


Table 2eCapital Project Listing - Nuclear Operations Facility Projects




Exhibit D2Tab 1

Schedule 3Table 2f





65 DN DN Liquid Zone Control Valve Positioner Replacement 80113 Sustaining

Replace the positioners and current-to-pressure transducers on the Liquid Zone Control System control valves with digital positioners.

Dec-15 Apr-23 17.0 4.3 0.0 5.5 2.0 2.0 0.3 0.0 0.0

66 DN DN Fuel Handling Trolley Major Auxiliary Component Replacement 82842 Sustaining

Replace various major auxiliary components on the Fuel Handling trolleys that are approaching the end of their design lives. Component failures impact on fuelling availability and nuclear safety.

Jan-17 Feb-24 18.3 15.6 0.0 2.0 3.4 4.0 8.3 0.0 0.0

67 DN DN Buried Piping Sacrificial Anode Replacement 82881 SustainingReplace depleted cathodic protection anodes on buried piping systems, which could result in pipe degradation and failures if not addressed.

Jun-18 Nov-25 12.2 0.0 0.0 0.6 0.0 0.0 0.0 0.0 0.0

68 DN DN Fuel Handling Motor Replacement 82886 SustainingReplace fuel handing system motors critical for the operation of various fuel handling systems that are nearing the end of their design lives.

Jan-17 Apr-23 16.9 16.5 0.0 0.3 0.3 2.0 7.0 7.2 0.0

69 DN DN Liquid Injection Safey System Ball Position Detection System Replacement 82887 Regulatory

Replace obsolescent components of the Liquid Injection Safety System tank ball position detection system, which provides the main control room indication of the operational state of Shutdown System 2.

Dec-17 Mar-21 5.0 1.4 0.0 0.4 0.6 0.6 0.1 0.0 0.0

70 DN DN Post-Accident Water Cooling System Heat Exchanger Replacement 82891 Sustaining

Replace the heat exchangers which are degraded, with leaks and reduced thermal efficiency. Further degradation may result in unavailability of the heat exchangers, which could force a 4 unit shutdown.

Nov-18 Mar-23 6.3 0.0 2.4 0.1 0.0 0.0 0.0 0.0 0.0

71 DN DN Tritium Removal Facility Analyzer and Cryogenic Temperature Equipment Replacement 82893 Sustaining

Replace the oxygen analyzer and cryogenic temperature equipment, which are obsolescent, have legacy operational issues and are required for compliance with hydrogen codes and standards.

Jul-18 Jan-25 5.1 3.5 0.0 0.0 0.0 3.5 0.0 0.0 0.0

72 DN DN Heavy Water Management System Computer Distributed Control Units Replacement 83288 Sustaining

Upgrade and/or replace the Distributed Control Units required for the monitoring and control of TRF, Upgrader and Heavy Water Management Building systems.

Jan-18 Sep-24 18.8 8.4 0.0 2.4 0.0 4.5 0.0 3.9 0.0

73 DN DN Irradiated Fuel Bay Cooling and Purification Pump Replacement 83483 Sustaining

Replace the pumps used to circulate Irradiated Fuel Bay water through the cooling circuits and thereby remove the decay heat generated by the irradiated fuel.

Dec-17 Sep-21 6.9 6.1 0.0 0.7 0.0 3.5 2.6 0.0 0.0

74 DN DN Tritium Removal Facility Water Air Conditioning Units Replacement 83560 Sustaining

Replace the air conditioning units used to provide cooling for the environment in the control room and equipment rooms.

May-18 Dec-19 10.0 3.4 0.0 0.0 3.3 0.1 0.0 0.0 0.0

75 DN DN Tritium Removal Facility Training Simulator 83650 Sustaining Development and installation of a Tritium Removal Facility training simulator. Nov-17 Aug-25 6.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

76 DNDN Radiation Detection Equipment Obsolescence - Moderator Cover Gas Monitors & Fixed Area Alarming Gamma Monitors

84399 Sustaining

Replace both systems with new and modern equipment, since the existing equipment isobsolete and approaching the end of their useful design life.

Nov-19 Dec-23 18.0 11.3 0.0 0.0 0.0 11.3 0.0 0.0 0.0

77 DNDN Radiation Detection Equipment Obsolescence - Active Liquid Waste Liquid Effluent Monitor, D2O in H2O & Online Gas Chromatograph

84400 SustainingReplace the three systems with new and modern equipment, since the existing equipment is obsolete and approaching the end of their useful design life.

Nov-19 Sep-23 15.0 14.1 0.0 0.0 13.0 1.1 0.0 0.0 0.0

78 DN DN Shutdown System 1 and Reactor Regulating System Ion Chamber Replacements 83937 Sustaining

Replace the aging Shutdown System 1 and Reactor Regulating System ion chambers that measure neutron flux in the reactor for trip parameter and reactor regulation purposes.

Dec-18 Dec-28 11.3 2.3 0.0 0.4 0.4 0.4 0.5 0.6 0.4

Table continues on Ex. D2-1-3 Table 2g

Notes:12



Table 2fCapital Project Listing - Nuclear Operations Facility Projects




Exhibit D2Tab 1

Schedule 3Table 2g





79 DN DN Fuelling Maching Duct & Central Service Area Air Conditioning Unit Replacement 84006 Sustaining

Replace aging and degraded fan motors and cooling coils for the Fuelling Machine Duct and Central Service Area Air Conditioning Units (ACUs) nto ensure reliable operation.

Aug-19 Aug-21 18.3 0.0 0.4 0.0 0.0 0.0 0.0 0.0 0.0

80 DN DN Emergency Power System Enhancements 84378 Sustaining

Install improvements to Darlington Emergency Power Generator EPG3, to enhance operation and ensure long term reliability of the EPG3 machine for a safe station operation.

Apr-19 Apr-24 10.2 0.1 0.0 5.8 0.1 0.0 0.0 0.0 0.0

81 DN DN Containment Penetrations and Fiber Optics Installation 84586 Sustaining

Install new containment penetrations, with fibre optics and 120V power, to improve bandwidth and expand coverage of the existing communications network.

Sep-19 Oct-26 9.0 4.9 0.0 2.5 1.4 1.1 2.5 0.0 0.0

82 DN DN Main Power Output Transformer Fire Containment System Upgrade 86055 Sustaining

Install upgraded Darlington Main Power Output Transformers Fire Containment System to improve deluge functionality and comply with Fire Codes.

Jul-20 Aug-21 20.0 20.0 0.0 0.0 0.0 3.9 3.9 8.4 3.9

83 PN PN Emergency and Mobile Satellite Communication Systems Replacement 80130 Sustaining

Replace the obsolescent Emergency and Mobile Satellite Communication systems required for on- and off-site communications in the event of emergencies.

Feb-16 Mar-21 9.1 0.0 0.0 3.8 0.0 0.0 0.0 0.0 0.0

84 PN PN Stator Cooling Water Alkalization and Make-up Deoxygenation 83061 Sustaining

Install Alkalization and Makeup Water Deoxygenation for the Stator Cooling Water system, to reduce copper oxide fouling of copper conductors.

Dec-16 Feb-24 12.6 0.0 2.7 1.3 0.0 0.0 0.0 0.0 0.0

85 IRI PN SLAR (Spacer Location And Reposition) System Sustainability 83564 Sustaining

Upgrade obsolete components of the Spacer Location and Reposition system, by procuring a new control centre and transformer cart with cables, upgrading the existing control centre, and replacing associated computers.

Jan-19 Apr-22 6.1 0.0 0.5 0.0 0.0 0.0 0.0 0.0 0.0

86 IRI PN ANDE (Advanced Non-Destructive Examination) Reliability Improvements 83565 Sustaining

Improve the reliability of the Advanced Non-Destructive Examination system used to inspect fuel channels in Pickering Units 5 - 8 to minimize outage delays.

Dec-17 Jan-22 6.7 1.4 0.0 5.2 1.4 0.0 0.0 0.0 0.0

87 IRI PN Circumferential Wet Scrape Tool (CWEST) Enhancements 84140 Sustaining

Implement Circumferential Wet Scrape Tool (CWEST) enhancements, to address high priority areas for improvement and address CWEST Project #66600 open issues.

Nov-19 Dec-22 18.6 2.4 4.2 10.1 2.4 0.0 0.0 0.0 0.0

88 IRI IRI Steam Generator Manipulator & Automated Tube Plug 84888 Sustaining

Procure manipulators and automated tube plugging equipment, to address all obsolescence issues, reduce outage delays, improve productivity and allow for future equipment advancements.

Mar-20 May-20 8.2 3.6 1.6 1.2 3.5 0.1 0.0 0.0 0.0

89 DN DN Tritium Removal Facility Cold Box Vacuum System Obsolescence 80020 Sustaining

Address poor reliability and obsolescence of the TRF Cold Box Vacuum System that maintains high vacuum conditions for insulation and leak detection around the Low and High Tritium Distillation and Cryogenic Refrigeration systems.

Jan-16 Dec-22 9.6 9.1 0.0 0.0 8.7 0.4 0.0 0.0 0.0

90 DN DN Condensate Extraction Pump Pump Motor Spare 80117 Sustaining Acquire a capital spare motor for the Condensate Extraction Pumps. Jan-15 Dec-18 5.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

91 IRI DN Feeder and Fuel Channel Baseline Inspections 83051 Sustaining

Develop inspection capability, via procurement and assembly of inspection tooling and material handling equipment, to perform baseline inspections of feeders and fuel channels prior to the restart of refurbished Darlington units.

Aug-16 Oct-18 6.7 0.0 0.2 0.0 0.0 0.0 0.0 0.0 0.0

92 Subtotal 307.3 128.5 12.0 42.4 40.6 38.5 25.0 20.0 4.3

93 Total 943.2 176.2 33.3 87.8 54.6 60.0 32.0 23.9 5.5

DIVISION TOTALS:94 Darlington 168.7 14.7 58.6 47.3 59.9 32.0 23.9 5.595 Pickering 0.0 11.8 12.6 0.0 0.0 0.0 0.0 0.096 Operations and Project Support 7.5 6.8 16.5 7.4 0.1 0.0 0.0 0.097 Total 176.2 33.3 87.8 54.6 60.0 32.0 23.9 5.5

Notes:12



Table 2gCapital Project Listing - Nuclear Operations Facility Projects




Exhibit D2Tab 1

Schedule 3Table 3

Total Average In-Service In-Service In-Service In-Service In-Service In-Service In-Service In-ServiceLine Number of Project Cost of All IR Term 2020 2021 2022 2023 2024 2025 2026No. Sponsoring Division Projects Cost ($M) Projects ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M) ($M)

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)

1 Darlington 45 92.4 2.1 16.1 5.9 11.7 6.3 6.9 2.9 0.0 0.02 Pickering 64 128.3 2.0 0.0 5.9 8.2 0.0 0 0.0 0.0 0.0

3 Operations and Project Support 8 25.0 3.1 0.0 0.1 3.3 0.0 0 0.0 0.0 0.0

5 Total 117 245.6 2.1 16.1 11.9 23.2 6.3 6.9 2.9 0.0 0.0

Notes:

1

2 Operations and Project Support with capital projects includes Engineering, Inspection and Maintenance Services, and Security & Emergency Services.

Table 3Capital Project Listing - Nuclear Operations Facility Projects

Projects < $5M Total Project Cost1



Exhibit D2Tab 1

Schedule 3Table 4a

Line 2016 (c)-(a) 2016 (g)-(c) 2017 (g)-(e) 2017 (k)-(g) 2018 (k)-(i) 2018No. Business Unit Budget Change Actual Change OEB Approved1 Change Actual Change OEB Approved1 Change Actual

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)

1 Darlington NGS 325.9 (105.6) 220.3 (16.3) 226.1 (22.1) 204.1 81.8 216.4 69.5 285.82 Pickering NGS 146.0 (98.0) 47.9 132.4 172.8 7.5 180.3 (113.9) 47.5 18.9 66.43 Operations and Project Support2 36.0 (34.2) 1.8 40.8 49.2 (6.6) 42.6 (26.2) 45.9 (29.5) 16.44 Subtotal 507.9 (237.8) 270.1 156.9 448.2 (21.2) 427.0 (58.4) 309.8 58.8 368.6

5 Supplemental In-Service Forecast3 (41.8) 41.8 0.0 0.0 (1.6) 1.6 0.0 0.0 24.9 (24.9) 0.0

6 Total Portfolio In-Service Forecast 466.0 (195.9) 270.1 156.9 446.6 (19.6) 427.0 (58.4) 334.7 33.9 368.6

7 Darlington New Fuel 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.08 Darlington Water Treatment Plant Lease 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.09 Darlington Spacer Retrieval 4 0.0 0.0 0.0 5.8 6.4 (0.6) 5.8 (5.8) 0.0 0.0 0.0

10 Pickering Extended Operations 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

11 Minor Fixed Assets 31.0 (14.7) 16.3 15.4 26.0 5.6 31.6 (9.9) 20.0 1.7 21.7

12 In-Service Capital Additions before Disallowance 497.0 (210.7) 286.4 178.0 479.0 (14.6) 464.4 (74.1) 354.7 35.6 390.313 OEB Disallowance (47.9) (35.5)14 Total In-Service Capital Additions 497.0 (210.7) 286.4 178.0 431.1 33.3 464.4 (74.1) 319.2 71.1 390.3

Line 2018 (e)-(a) 2019 (e)-(c) 2019 (i)-(e) 2020 (i)-(g) 2020 (k)-(g) 2021No. Business Unit Actual Change OEB Approved1 Change Actual Change OEB Approved1 Change Budget Change Budget

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)

15 Darlington NGS 285.8 (25.3) 295.7 (35.2) 260.5 (84.4) 101.3 74.9 176.1 63.4 239.516 Pickering NGS 66.4 (29.6) 9.7 27.0 36.8 (1.8) 29.7 5.2 34.9 (14.1) 20.917 Operations and Project Support2 16.4 (11.9) 44.3 (39.8) 4.5 16.6 0.0 21.1 21.1 44.3 65.418 Subtotal 368.6 (66.8) 349.8 (48.0) 301.8 (69.6) 131.0 101.1 232.1 93.6 325.8

19 Supplemental In-Service Forecast3 0.0 0.0 16.6 (16.6) 0.0 (20.4) 78.8 (99.2) (20.4) (2.7) (23.1)

20 Total Portfolio In-Service Forecast 368.6 (66.8) 366.3 (64.5) 301.8 (90.0) 209.8 1.9 211.7 90.9 302.7

21 Darlington New Fuel 0.0 0.0 0.0 0.0 0.0 17.1 15.3 1.7 17.1 (17.1) 0.022 Darlington Water Treatment Plant Lease 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.023 Darlington Spacer Retrieval4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.024 Pickering Extended Operations 0.0 0.8 0.0 0.8 0.8 30.7 0.0 31.5 31.5 (26.4) 5.1

25 Minor Fixed Assets 21.7 1.8 19.1 4.5 23.5 (1.7) 19.5 2.4 21.9 2.2 24.1

26 Total In-Service Capital Additions 390.3 (64.2) 385.4 (59.3) 326.1 (43.9) 244.7 37.6 282.2 49.6 331.827 OEB Disallowance (38.5) (24.5)28 Total In-Service Capital Additions 390.3 (64.2) 346.9 (20.8) 326.107 (43.9) 220.2 62.0 282.2 49.6 331.8

Notes:1

234 Project #82949 DN X-750 Spacer Retrieval CMFA. OEB Approved amounts for Darlington Spacer Retreival per EB-2016-0152, Schedule 1, Staff-024, which were reflected in EB-2016-0152 Ex. J21.1, Attachment 2, Table 1.

Table 4aComparison of In-Service Capital Additions - Nuclear Operations ($M)

Includes Engineering, Inspection and Reactor Innovation, and Security & Emergency Services. Supplemental forecast to reconcile BCS in-service estimates to final business plan (see Ex. D2-1-3, Section 4.0).

In-service additions per EB-2016-0152, Ex. J21.1, Attachment 2, Table 2. Amounts in this schedule do not reflect OEB-ordered reductions for: Auxiliary Heating System in-service amount (EB-2016-0152 Decision and Order, p. 21); Operations Support Building in-service amount (EB-2016-0152 Decision and Order, p. 22). These reductions are reflected in total nuclear rate base amounts in Ex. B3-2-1, Table 1. The 2017-2020 sub-components within the total portfolio in service forecast has also been adjusted for reclassification of projects from Darlington to Operations and Projects Support with no change to total amount.


Exhibit D2Tab 1

Schedule 3Table 4b

Line 2021 (c)-(a) 2021 (e)-(c) 2022 (e)-(c) 2023 (g)-(e) 2024 (i)-(g) 2025No. Business Unit OEB Approved1 Change Budget Change Plan Change Plan Change Plan Change Plan

(a) (b) (c) (d) (e) (f) (g) (h) (i) (j) (k)

1 Darlington NGS 62.1 177.5 239.5 170.2 409.7 (92.2) 317.6 (26.0) 291.6 82.7 374.32 Pickering NGS 0.0 20.9 20.9 (20.9) 0.0 0.0 0.0 0.0 0.0 0.0 0.03 Operations and Project Support2 0.0 65.4 65.4 (52.0) 13.4 80.4 93.8 (93.8) 0.0 29.5 29.54 Subtotal 62.1 263.7 325.8 97.4 423.1 (11.8) 411.3 (119.7) 291.6 112.3 403.9

5 Supplemental In-Service Forecast3 100.2 (123.4) (23.1) 14.6 (8.5) 37.7 29.2 (16.1) 13.1 24.8 37.9

6 Total Portfolio In-Service Forecast 162.3 140.4 302.7 112.0 414.7 25.9 440.5 (135.8) 304.7 137.1 441.8

7 Darlington New Fuel 0.0 0.0 0.0 0.0 0.0 0.0 0.0 16.5 16.5 0.4 16.98 Darlington Water Treatment Plant Lease 0.0 0.0 0.0 0.0 0.0 0.0 0.0 138.6 138.6 (138.6) 0.09 Darlington Spacer Retrieval4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0

10 Pickering Extended Operations 0.0 5.1 5.1 (5.1) 0.0 0.0 0.0 0.0 0.0 0.0 0.0

11 Minor Fixed Assets 19.3 4.7 24.1 (4.4) 19.6 1.4 21.0 8.2 29.2 (10.6) 18.7

12 Total In-Service Capital Additions 181.6 150.2 331.8 102.5 434.3 27.3 461.6 27.4 489.0 (11.7) 477.313 OEB Disallowance (18.2)14 Total In-Service Capital Additions 163.5 168.3 331.8 102.5 434.3 27.3 461.6 27.4 489.0 (11.7) 477.3

Line 2025 (c)-(a) 2026No. Business Unit Plan Change Plan

(a) (b) (c)

15 Darlington NGS 374.3 (205.4) 168.916 Pickering NGS 0.0 0.0 0.017 Operations and Project Support2 29.5 (29.5) 0.018 Subtotal 403.9 (234.9) 168.9

19 Supplemental In-Service Forecast3 37.9 112.0 149.9

20 Total Portfolio In-Service Forecast 441.8 (123.0) 318.8

21 Darlington New Fuel 16.9 1.2 18.122 Darlington Water Treatment Plant Lease 0.0 0.0 0.023 Darlington Spacer Retrieval4 0.0 0.0 0.024 Pickering Extended Operations 0.0 0.0 0.0

25 Minor Fixed Assets 18.7 (7.3) 11.4

26 Total In-Service Capital Additions 477.3 (129.0) 348.3

Notes:1

234 Project #82949 DN X-750 Spacer Retrieval CMFA. OEB Approved amounts for Darlington Spacer Retreival per EB-2016-0152, Schedule 1, Staff-024, which were reflected in EB-2016-0152 Ex. J21.1, Attachment 2, Table 1.

Table 4bComparison of In-Service Capital Additions - Nuclear Operations ($M)

In-service additions per EB-2016-0152, Ex. J21.1, Attachment 2, Table 2. Amounts in this schedule do not reflect OEB-ordered reductions for: Auxiliary Heating System in-service amount (EB-2016-0152 Decision and Order, p. 21); Operations Support Building in-service amount (EB-2016-0152 Decision and Order, p. 22). These reductions are reflected in total nuclear rate base amounts in Ex. B3-2-1, Table 1. The 2017-2020 sub-components within the total portfolio in service forecast has also been adjusted for reclassification of projects from Darlington to Operations and Projects Support with no change to total amount.

Includes Engineering, Inspection and Reactor Innovation, and Security & Emergency Services. Supplemental forecast to reconcile BCS in-service estimates to final business plan (see Ex. D2-1-3, Section 4.0).

Filed: 2020-12-31EB-2020-0290

Exhibit D2Tab 1

Schedule 3Table 5a

PotentialLine StartNo. Project Name Category Date

(a) (b) (c)

Darlington NGS - Projects With Potential Cost < $20M1 Tritium Removal Facility / Heavy Water Management Interim Lfie Cycle Plan Implementation Sustaining 20212 Main Control Room HVAC Backup Instrument Air Compressor/Dryer Replacement Sustaining 20213 Low Pressure Service Water Pump Capital Spares Sustaining 20214 Room S-412 Heating / Ventilation / Air Conditioning Overhaul / Replacement Sustaining 20215 Tritium Removal Facility Cryogenic Refrigeration System Hydrogen Compressor Capital Spare Sustaining 20216 Emergency Service Water Pump Capital Spare Sustaining 20217 Steam Generators Waterlancing Optimization Sustaining 20218 Glycol Chiller Temperature Control Valve Replacement Sustaining 20229 Powerhouse Elevator Replacement (Passenger and Freight) Sustaining 202210 D2O Weigh Tank Instrumentation Replacement Sustaining 202211 Low Pressure Service Water Cooling Coil Replacement (Miscellaneous Air Conditioning) Sustaining 202212 Emergency Service Water Strainer Replacement Sustaining 202213 Water Based Air Conditioning Cooling Coils Replacement Sustaining 202214 Condenser Circulating Water Pump Capital Spare Sustaining 202215 Main Condensate Extraction Pump Capital Spares Sustaining 202216 Environmentally Qualified Cables Replacement Sustaining 202217 Fuel Handling Reactor Area Bridge and Carriage Mobile Platform Installation Sustaining 202218 Frazil Ice Gate Replacement Sustaining 202319 Lake Current Monitoring System Replacement Sustaining 202320 End Shield Cooling Expansion Tank Replacement Sustaining 202321 Active Liquid Waste Tank Liner Replacement Sustaining 202322 Fire Detection Panel Upgrade Sustaining 202323 Inactive Drainage Sump Pump Replacement Sustaining 202324 Emergency Service Water Travelling Screen, Motor and Bubbler Replacement Sustaining 202325 Switchyard Coupling Capacitor and Surge Arrestor Replacement Sustaining 202326 Post-Accident Water Cooling System Heat Exchanger Plate Pack Capital Spare Sustaining 202427 Negative Pressure Containment Upper Vacuum Chamber Pump Replacement Sustaining 202428 Unit 0 Class II 120/208VAC Motor Control Centre Replacement Sustaining 202429 Shutdown System 2 Ion Chamber Detector Replacement Sustaining 202430 Moisture Separator Reheater Tube Bundle Capital Spares Sustaining 202431 Dousing Water Heater Replacement (VBO) Sustaining 202432 Irradiated Fuel Bay Heat Exchanger Plate Pack Capital Spares Sustaining 202533 End Shield Cooling Heat Exchanger Plate Packs Replacement Sustaining 202534 Condenser Hotwell Sampling Pumps and Analyzer Replacement Sustaining 2025

Darlington NGS - Projects With Potential Cost ≥ $20M

35 Condenser Circulating Water, Emergency Service Water & Low Pressure Service Water Expansion Joints Replacement Sustaining 2021

36 Vault and Containment Vapour Recovery Systems Component Replacement Sustaining 202137 Tritium Removal Facility Life Extension Sustaining 202138 Tritium Removal Facility Cryogenic Refrirgeration System Hydrogen Compressor Upgrade Sustaining 202139 Public Address System Upgrade Sustaining 202240 Breathing, Instrument and Service Air Compressor Replacement Sustaining 202241 Shutdown System 1 Rod Drive Capital Spares Sustaining 202342 Standby Generator (SG) Fuel Oil Storage Tank Bottom Replacement Sustaining 202443 Turbine Lubricating Oil Cooler Replacement Sustaining 202444 Powerhouse Cranes Refurbishment Sustaining 202545 Ventilation & Air Conditioning Fans Replacement Sustaining 2025

Table continues on Ex. D2-1-3 Table 5b

Notes:1

Table 5aCapital Project Listing - Nuclear Operations

Portfolio Projects (Unallocated)1

Projects with potential expenditures during IR term.

Filed: 2020-12-31EB-2020-0290

Exhibit D2Tab 1

Schedule 3Table 5b

PotentialLine StartNo. Project Name Category Date

(a) (b) (c)

Inspection & Maintenance Services - Projects With Potential Cost < $20M46 Steam Generator Eddy Current Testing Auto-Analysis Software Sustaining 202147 Advanced Non-Destructive Examination MK1 Replication Tool Sustaining 202148 Fuel Channel Auto-Analysis Software Sustaining 202149 Feeder Cabinet Visual Inspect Tool Sustaining 202250 Steam Generator and Heat Exchanger Ultrasonic Tube Inspection System Upgrade Sustaining 202251 Laser-Induced Breakdown Spectroscopy for Hydrogen Characterization Sustaining 202252 Advanced Non-Destructive Examination MK3 Inspection Tool Sustaining 2023

Inspection & Maintenance Services - Projects With Potential Cost ≥ $20M

53 PRECISE-WET (PREcise CIrcumferential Sampling Equipment - WET) Machine Delivered Scrape Sustaining 2023

Notes:1

Table 5bCapital Project Listing - Nuclear Operations

Portfolio Projects (Unallocated)1

Projects with potential expenditures during IR term

Filed: 2020-12-31EB-2020-0290

Exhibit D2Tab 1

Schedule 3Table 6a

BCS BCSLine Project Approval BCS Status inNo. Facility Business Case Summary (BCS) Title Number Date Project Stage Status EB-2016-0152

(a) (b) (c) (d) (e) (f) (g)

ONGOING PROJECTS FROM EB-2016-0152 1 DN Darlington Class II Uninterruptlble Power Supply Replacement 31412 Nov-17 Execution Partial Execution Partial2 DN Fuel Handling Inverter Replacement 31426 Aug-18 Execution Full3 DN Darlington Station Lighting Retrofit 31516 Mar-19 Execution Full4 DN Restore ESW Margins 31518 Sep-18 Execution Full Definition Full5 DN DN Roof Replacement Project 31524 Mar-19 Definition Superseding Deferred Partial6 DN Powerhouse Water ACU Replacements 31532 May-19 Execution Full Definition Partial7 DN Darlington Water Treatment Plant Interconnections 31535 Jun-19 Definition Superseding Definition Full8 DN DN Install Multi-Gas Analyzers on Transformers MOT/SST/UST 31542 Jun-18 Close-out Over-Variance Execution Full

9 DN DN Radiation Detection Equipment Obsolescence (Stack Monitoring & PARMS) 31544 Nov-19 Definition Superseding Definition Partial

10 DN Darlington Shutdown Cooling Heat Exchanger Replacement 31710 Feb-18 Close-out Full Execution Partial11 DN DN NOP & IC Amplifier Replacement (RRS, SDS1 & SDS2) 31716 May-18 Execution Partial Definition Partial12 DN Replacement of EPS Uninterruptible Power Suppliers 33258 May-17 Execution Full13 DN DN Secondary Control Area Air Conditioning Unit Replacement 33621 Oct-18 Execution Superseding Execution Partial14 DN DNGD: Chiller Replacement to Reduce CFC Emissions 33631 Sep-10 Execution Full Execution Full15 DN DN Vibration Monitoring System Replacement for Major Pump-sets 33819 Jul-20 Execution Superseding Execution Partial16 DN DN SG Controls Replacement 33973 Oct-17 Execution Over-Variance Execution Partial

17 DN Darlington DCC Replacerrent 33977 Oct-17 Execution Over-Variance Execution Superceding

18 DN DN Auxiliary Heating System Facility 34000 May-16 Close-out Over-Variance Execution Partial19 DN Zebra Mussel Mitigation Improvements 38948 Mar-18 Close-out Superseding Execution Partial

20 DN DN PHT Pump Motor Replacement, Overhaul and Capital Spares 173566 80144 36001

Jul-17 Execution Full Execution Partial

21 DN OH180 Aging Management Hardware Installation 80022 Sep-19 Execution Partial Definition Full22 DN DN Steam Generator Level Control Valves Replacement 80023 Nov-19 Definition Superseding23 DN DN R-22 Refrigerant ACU Replacement 80036 Jul-19 Definition Superseding24 DN DN Standby Generators Protective Relay Replacement 80063 Jun-20 Definition Full

25 DN Darlington Digital Control, Common Process and Sequence of Events Monitoring Computer Aging Management 80078 Nov-19 Definition Partial Definition Partial

26 PN PB-EPG and MOP relay replacement. 40691 Dec-17 Close-out Full

1

Table 6aCapital Projects - Nuclear Operations

Listing of Business Case Summaries Filed

Projects 73566, 36001 and 80144 are combined in a single Business Case Summary

Filed: 2020-12-31EB-2020-0290

Exhibit D2Tab 1

Schedule 3Table 6b


(a) (b) (c) (d) (e) (f) (g)

COMPLETED/DEFERRED/CANCELLED FROM EB-2016-015227 DN Operations Support Building Refurbishment 25619 Aug-15 Complete Over-Variance Execution Full

28 DNFukushima Phase 1 Beyond Design Basis Event (BDBE) Emergency Mitigation Equipment (EME) 1

31508 49158 49299

Aug-16 Complete Full Execution Partial

29 DN DN - CCW and LPSW Travelling Screen Replacement 31552 Dec-16 Complete Full Execution Partial30 DN Darlington Maintenance and Computer Development Facility 31717 Mar-12 Complete Full Execution Full

31 DNFukushima Phase II Beyond Design, Basis Event Emergency Mitigation Equipment 2

32202 41027 Aug-16 Complete Full Execution Partial

32 DN DN SDS Computers Aging Management 33955 Jul-16 Complete Over-Variance Execution Superceding

33 DN DN Purchase of Primary Heat Transport Pump Motor Capital Spares 3 36001 Jul-17 Execution Full Execution Partial34 DN Holt Road Interchange Upgrade 73706 Nov-13 Complete Full Execution Full35 DN DN Generator Stator Core Capital Spare 80111 Sep-15 Complete Full Execution Full36 PN U58 Fuel Handling Reliability Improvement Project 40976 May-16 Close-out Full Execution Partial

37 PN PA Fuel Channel Reconfiguration & East & West Shift Tooling 41023 Sep-14 Complete Superseding Execution Superceding

38 PN Pickering A Fuel Handling SPV Reliability Improvement 46634 May-12 Complete Full Execution Full39 IRI Machine Delivered Scrape Project 66600 Oct-17 Complete Over-Variance Execution Partial PROJECTS NOT IN EB-2016-0152

40 DN DN / DNR1 / DNR4 Main Power Output Protection System Replacement 80122 Nov-19 Definition Superseding N/A

41 DN DN Group II Pressure Transmitter Replacement 80123 May-20 Definition Full N/A42 DN DN Obsolete Controller Replacement 80124 Oct-18 Execution Partial N/A43 DN DN Emergency Power Generator 1 and 2 Replacement 80126 May-18 Execution Partial N/A

44 DN Darlington Nuclear Fuel Handling Control Computer Input/Output Subsystem (Multiplexer) & Inter-Processor Communication Replacement 80148 Nov-19 Definition Partial N/A

45 DN DN FRF Pump Improvement 80150 May-18 Definition Full N/A46 DN Class 1 Rectifier Replacement 82883 May-18 Development Full N/A47 DN Transformer Control Cabinet Wiring System Replacement 82890 Jan-19 Deferred Full N/A48 DN DN FM Head Major Component Replacement 82947 Mar-20 Definition Partial N/A49 DN DN Copper Piping Replacement 83049 Aug-19 Execution Superseding N/A

1 Projects 31508, 49158 and 49299 are combined in a single Business Case 23 Projects 73566, 36001 and 80144 are combined in a single Business Case Summary

Table 6bCapital Projects - Nuclear Operations


Projects 41027 and 32202 are combined in a single Business Case Summary.

Filed: 2020-12-31EB-2020-0290

Exhibit D2Tab 1

Schedule 3Table 6c


(a) (b) (c) (d) (e) (f) (g)

PROJECTS NOT IN EB-2016-0152 (continued)50 DN FH Power & Signal Cable Replacement 83052 Apr-19 Definition Full N/A51 DN DN Shutdown Cooling Heat Exchanger PULSW Piping Replacement 1 83053 Jul-18 Execution Partial N/A52 DN Darlington Phase 2 Station Battery Replacement 83076 Jul-19 Execution Partial N/A

53 DN Darlington Main Output Transformer and Unit Service Transformer Replacement 83296 Apr-19 Execution Partial N/A

54 DN DN Large Moderator Temperature Control Valve Replacement 83297 Nov-19 Definition Full N/A55 DN DN Secondary Systems High Priority Control Valve Replacements 83298 Oct-19 Definition Full N/A56 DN DN- Condenser Steam Discharge Valves Control System Upgrade 83299 Feb-20 Definition Full N/A57 DN 4kV Motors Refurbishment and Replacement 83480 Dec-19 Definition Full N/A58 DN DN Isolated Phase Bus Refurbishment 83484 Jul-20 Development Full N/A59 DN DN Turbine Hall Crane Controls Upgrade 83556 Jul-20 Execution Over-Variance N/A

60 DN FH Service Area Bridge F5 Ball Screw Assembly Replacement, and DN Fuel Handling SAB Ball Screw And Jack Assembly Capital Spares 83558 Dec-19 Definition Full N/A

61 DN IFB Permanent Fuel Inspection Equipment in East & West FFAA 83559 Apr-20 Execution Partial N/A

62 DN U2 Turbine/Generator Electronic Controls and Generator Auxiliaries Upgrade 83664 Dec-19 Definition Full N/A

63 DN DN Fuel Handling Replacement of Fuelling Machine Calibration Facility 83916 Feb-20 Development Full N/A64 DN DN Air Operated Valve (AOV) Replacements 84009 Mar-20 Development Full N/A65 DN Darlington Primary Heat Transport Liquid Relief Valves Modification 84235 Jun-19 Execution Partial N/A66 DN DN Motor Operated Valve (MOV) Replacements 84551 Mar-20 Development Full N/A67 DN DN PHT Pump Rotor Inspect / Replace (RECL) 84799 May-20 Execution Partial N/A68 DN DN Revenue Metering Transformer Replacement (Cap) 84939 Apr-20 Development Full N/A69 PN Pickering Buried Boiler Blowdown Pipe Replacement 83072 Jul-19 Execution Full N/A70 PN PA LP Feedwater Heat Exchangers Replacement 83088 Mar-18 Close-out Full N/A71 PN Pickering High Pressure Turbine Spares 83668 Nov-17 Close-out Full N/A72 IRI Rapid Delivery Machine (RDM) 83039 Dec-19 Definition Superseding N/A73 ENG Fleet Monitoring Initiative (Monitoring & Diagnostic Centre) 83828 Mar-20 Definition Partial N/A

Notes1 Filed BCS is the initial approved #83053 - DN Powerhouse Upper Level Service Water Piping Replacement2 Filed BCS is the initial approved #38933, #83136, #83137, #83138, #83139,#83232, Darlington Primary Heat Transport Liquid Relief Valves Modifications

Table 6cCapital Projects - Nuclear Operations


Filed: 2020-12-31EB-2020-0290

Exhibit D2Tab 1

Schedule 3 Table 7a

In-Service Date Project Stageat Time of at Time of

Line Project EB-2016-0152 EB-2016-0152 Project Projected/ActualNo. Number Project Name Application Application Status In-Service Date

(a) (b) (c) (d) (e) (f)

1 31403 DN Active Liquid Waste System Upgrade Dec-17 Execution Execution Dec-22

2 31412 DN Class II Uninterruptible Power Supply Replacement Jun-25 Execution Execution Mar-25

3 31420 DN Dryer PLC Replacement Mar-22 Definition Execution Aug-24

4 31422 DN Pressurizer Heaters & Controllers Replacement Project Dec-19 Execution Execution Dec-21

5 31426 DN Fuel Handling Inverter Replacement Dec-18 Execution Execution Apr-21

6 31432 DN Containment Button-up Activity Monitors Replacement Oct-19 Execution Execution Mar-21

7 31508 DN Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment Sep-17 Execution Complete Apr-18

8 31518 DN Restore Emergency Service Water and Firewater Margins Sep-16 Definition Close-out Aug-19

9 31520 DN Replacement of Obsolete Online Chemistry Analysers Nov-17 Execution Execution Jan-21

10 31524 DN Station Roofs Replacement Deferred Deferred Definition Nov-2711 31532 DN Powerhouse Water ACUs Replacement Dec-19 Execution Execution Jan-2312 31535 DN Water Treatment Plant Replacement Deferred Definition Definition Sep-2413 31536 DN Turbine-Generator Lube Oil Purifier Replacement Apr-17 Execution Close-out Apr-1814 31542 DN Transformer Multi-Gas Analyzer Installation Mar-18 Execution Close-out Dec-2015 31544 DN Radiation Detection Equipment Obsolescence Dec-21 Definition Definition Sep-2316 31548 DN Feedwater Chemistry Control Improvements Nov-22 Execution Complete Feb-20

17 31552 DN Condenser Circulating Water and Low Pressure Service Water Travelling Screens Replacement Jun-18 Execution Complete Nov-18

18 31701 DN TRF CRS TOSS/Turbine Replacement Deferred Execution Execution Jun-2519 31706 DN Vapour Recovery Button-Up Valve Replacements Jun-18 Execution Definition Feb-2420 31710 DN Shutdown Cooling Heat Exchanger Replacement May-19 Execution Execution Dec-21

21 31716DN Neutron Over-Power & Ion Chamber Amplifier Replacement (Reactor Regulating System, Shutdown System 1 & Shutdown System 2)

Jul-22 Definition Execution Oct-26

22 32202 DN Fukushima Phase 2 Beyond Design Basis Event Emergency Mitigation Equipment Deferred Execution Complete May-18

23 33258 DN Replacement of EPS Uninterruptible Power Supply Nov-17 Execution Execution Feb-22

24 33509 DN Replacement of Obsolete Computer Components Jul-16 Execution Complete Jun-1925 80022 DN OH180 Aging Management Hardware Installation Dec-22 Definition Execution Jun-28

26 33621 DN ACU Replacement for Secondary Control Area (SCA) Apr-17 Execution Execution Aug-25

27 33631 DN Chiller Replacement to Reduce CFC Emissions Jan-13 Execution Execution Dec-1728 33815 FH Computer Replacement Deferred Execution Execution Nov-21

29 33819 DN Major Pump-sets Vibration Monitoring System Upgrades Jul-21 Execution Execution Nov-26

30 33973 DN SG Controls Replacement May-17 Execution Execution Mar-2131 34000 DN Auxiliary Heating System Apr-16 Execution Close-out Jun-1832 33977 DN DCC Replacement / Refurbishment / Upgrades Dec-18 Execution Execution Dec-2133 36004 DN EPG Power Turbine Capital Spare Mar-17 Execution Cancelled Jan-00

34 38466 DN CSA Sewage Line and Sump Emergency Connections Dec-17 Execution Execution Dec-28

35 38942 TRF Tritium Emissions Reduction Project Jun-17 Execution Cancelled Apr-1636 38948 DN Zebra Mussel Mitigation Improvements Jul-16 Execution Close-out Dec-2137 40691 PB EPG and MOP Protective Relay Replacement May-19 Execution Close-out Oct-1938 40972 PA SG Reliability Upgrades Nov-17 Execution Execution Dec-21

Table 7aCapital Projects - Nuclear Operations

Status of Projects > $5M with 2017 to 2021 In-Service Dates in EB-2016-0152

Current Project Status

Filed: 2020-12-31EB-2020-0290

Exhibit D2Tab 1

Schedule 3Table 7b

In-Service Date Project Stageat Time of at Time of

Line Project EB-2016-0152 EB-2016-0152 Project Projected/ActualNo. Number Project Name Application Application Status In-Service Date

(a) (b) (c) (d) (e) (f)

39 40976 PB Fuel Handling Reliability Modifications Jul-17 Execution Close-out Dec-18

40 40985 PN Replacement of Obsolete Online Chemistry Analysers Jun-17 Execution Execution Aug-19

41 41027 PN Fukushima Phase 2 Beyond Design Basis Event Emergency Mitigation Equipment Jun-17 Execution Complete Nov-17

42 41030 Pickering PDM Program Review Project (Capital) Dec-18 Execution Cancelled Jan-00

43 41043 PN Emergency Power Generator Engine Replacement Jun-17 Execution Complete Dec-16

44 41044 PA SG Protective Relay Upgrade May-17 Execution Execution Oct-19

45 46634 Pickering A Fuel Handling Single Point of Vulnerability Equipment Reliability Improvement Mar-16 Execution Complete Dec-18

46 49116 PN PB SG/EPG Fire Detection Upgrade and CO2 Suppression Removal Jul-16 Execution Complete Apr-16

47 49132 Pickering A Fuel Handling Single Point of Vulnerability Equipment Reliability Improvement Oct-16 Execution Complete Nov-16

48 49146 PN Fire Code Compliance for Relocatable Structures in Un-Zoned Area for Pickering Station Jul-16 Execution Complete Dec-18

49 49154 PB Replacement of Obsolete Instrumentation and Control Equipment Jun-18 Execution Execution Mar-21

50 49158 49299

PN Fukushima Phase 1 Beyond Design Basis Event Emergency Mitigation Equipment4,5 Aug-16 Execution Complete Apr-18

51 49298 PA Replacement of U1, U4 and IFB-A Stack Monitors Dec-17 Execution Complete May-1852 66594 IMS CIGAR Gap System and Drive Reliability Jun-17 Execution Complete Sep-1853 66600 PN Machine Delivered Scrape May-17 Execution Complete May-21

54 73566 80144

DN Primary Heat Transport Pump Motor Replacement/Overhaul Dec-22 Execution Execution May-21

55 80022 DN OH180 Aging Management Hardware Installation Dec-22 Definition Execution Jun-2856 80023 DN Large Steam Generator LCV Replacement Oct-22 Execution Definition Jun-2657 80036 DN R22 Refrigerant ACU Replacement Oct-21 Execution Definition Jan-26

58 80069 PA Firewater Buried Ring Header Replacement (North Loop) Dec-17 Execution Complete Jul-19

59 80070 DN Feeder Scanner Replacement (CMFA) Mar-19 Execution Execution Aug-22

60 80078 DN Digital Control, Common Process and Sequence of Events Monitoring Computer Aging Management Jun-25 Definition Definition Feb-28

61 80111 DN Generator Stator Core Spare Jul-19 Execution Complete Jul-1962 80151 DN FHA and FSSA Modifications Jan-19 Execution Execution Sep-2163 82816 DN Vault Cooling Coil Replacement Sep-20 Execution Close-out Jul-1964 82949 DN X-750 Spacer Retrieval CMFA Nov-18 Execution Complete Nov-18

Current Project Status

Table 7bCapital Projects - Nuclear Operations

Status of Projects > $5M with 2017 to 2021 In-Service Dates in EB-2016-0152

capital projects – nuclear operations

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