REMA.3.3G :3.TS SCHED:LE - files.opg.com

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

Exhibit D2 Tab 2

Schedule 5 of 17

REMAINING UNITS SCHEDULE 1

1.0 OVERVIEW 2

This exhibit provides the integrated Darlington Refurbishment Program (“DRP” or “Program”) 3

schedule and the current schedules for the refurbishment outages of Units 3, 1, and 4 (the 4

“Remaining Units”). 5

6

Section 2 begins by discussing the approach OPG employed to develop a fully integrated 7

schedule for the four-unit DRP at the time of the Release Quality Estimate (“RQE”) and the 8

Unit 2 Execution Estimate (“U2EE”). Section 3 starts by describing the development of the 9

updated integrated Program schedule for the Remaining Units. Discussion of the Remaining 10

Units’ schedule continues with a review of the Lessons Learned from the execution of Unit 2 11

and how these have been applied to the planning of the Remaining Units to produce more 12

refined schedules, with decreased uncertainties around the duration of critical path activities. 13

14

The approach used to mitigate schedule risks associated with the first-of-a-kind (“FOAK”) 15

turbine-generator controls scope to be installed in the Remaining Units is also discussed. This 16

exhibit then explains the integration of schedule logic1 for more than one unit in the period of 17

planned overlaps between the refurbishment outages of Units 3 and 1, and Units 1 and 4. It 18

concludes by comparing the planned schedule for Unit 3 to the actual schedule achieved for 19

Unit 2 and explaining the major elements that have allowed OPG to decrease the planned 20

duration of Unit 3 relative to Unit 2. 21

22

The Level 1 Working Schedule for each of the Remaining Units’ refurbishment outages are 23

provided as attachments. 24

1 Schedule logic refers to the logical interrelationships between activities and milestones in the schedule.

Specifically, that all of the predecessor activities required to facilitate completion of a successor activity are scheduled appropriately. For example, for fluid containing systems, all activities required to ensure that that system is airtight or watertight (depending on the system), including all appropriate testing, must be completed before the system is filled with fluid.

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Exhibit D2 Tab 2

Schedule 5 of 17

2.0 SCHEDULE DEVELOPMENT AND MANAGEMENT 1

OPG developed and maintains a fully integrated Program schedule that reflects the total 2

estimated duration of the individual tasks included within the Program scope. The integrated 3

Program schedule includes the individual Remaining Units’ refurbishment schedules and is a 4

critical tool used to properly strategize, plan and prepare for upcoming project work, determine 5

resource requirements, understand how work is progressing and apply corrective actions if, 6

and when, required. 7

8

2.1 Schedule Development and Management at the RQE 9

The overall planning and scheduling process involves two major stages.2 These stages are: 10

(1) formation of the baseline schedule; and (2) schedule management, including monitoring, 11

analysis, reporting, and risk mitigation. 12

13

2.1.1 Formation of the Baseline Schedule 14

OPG developed the baseline schedule in multiple phases leading up to the RQE. During the 15

development of the RQE, OPG project teams established a work breakdown structure that was 16

deliverable-oriented and addressed all of the project work, down to the individual work package 17

level. The work breakdown structure aligned with the corresponding contracting strategies so 18

that work scope, budgets and contractual rights and obligations were clearly and fairly 19

allocated between OPG and its contractors. OPG and its contractors then collaborated to 20

develop detailed schedules with inputs from appropriate project stakeholders, employing a 21

multi-level scheduling framework. 22

23

These detailed schedules included: 24

• the scope of work to be completed; 25

• identification of all key activities including their start and finish dates, duration and 26

resources required; 27

• the sequence and logical interrelationship of activities and milestones; and, 28

• identification and optimization of the critical path. 29

2 EB-2016-0152, Ex. D2-2-6.

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Exhibit D2 Tab 2

Schedule 5 of 17

After development of the initial schedules, project team members and key project stakeholders 1

reviewed them through an iterative process and approved them when they met process and 2

quality requirements. These reviews considered technical constraints, project and Program 3

constraints, milestones, resource requirements, and critical path approving the schedules. 4

5

As noted in Ex. D2-2-2, and previously in EB-2016-0152, OPG utilizes two schedules: (1) a 6

Working Schedule; and, (2) a High Confidence Schedule. The Working Schedule is based on 7

best estimates of the time required to complete the scheduled work tasks and is of shorter 8

duration than the High Confidence Schedule. The Working Schedule is used to manage day-9

to-day activities, allowing for early escalation of issues, and is used by OPG to calculate 10

performance metrics, e.g., the Schedule Performance Index. 11

12

The High Confidence Schedule includes schedule contingency amounts that are determined 13

based on a detailed evaluation of risks and uncertainties for critical path activities in the 14

schedule. OPG’s commitments to its Board of Directors and to external stakeholders, such as 15

the Independent Electricity System Operator, are based on the High Confidence Schedule. 16

The High Confidence Schedules for Units 3, 1, and 4 are the underlying basis for OPG’s 2020-17

2026 Business Plan and, therefore, of the approvals requested in this application. In EB-2016-18

0152, the Unit 2 High Confidence Schedule underpinned OPG’s requested approvals and the 19

amounts the OEB approved for Unit 2. 20

21

2.1.2 Schedule Management 22

To facilitate schedule management and control, OPG prepares project schedules with up to 23

four levels of detail, from Level “0”, which contains the Program milestones managed by OPG 24

and which identify the major deliverables and timelines for the overall DRP, to Level “3”, which 25

shows individual work components at the task level. See Attachment 1 for an explanation of 26

the multi-level scheduling approach used by OPG. 27

28

An accurate, detailed and realistic schedule facilitates risk mitigation because it allows precise 29

monitoring of progress. Progress monitoring against the Working Schedule allows for early 30

identification of potential schedule deviations, whether delays or early completion of activities, 31

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Exhibit D2 Tab 2

Schedule 5 of 17

and the development of strategies and appropriate adjustments to upcoming activities. 1

Examples of these adjustments are: 2

1. Reallocation of resources as required to address emergent issues; 3

2. Revising the timing of onboarding of resources for upcoming activities; 4

3. Reviewing and potentially revising the schedule logic for upcoming activities; and, 5

4. Re-assessments to determine if certain activities, which had been planned to be executed 6

in series, could be fully or partially executed in parallel. 7

8

During the execution of Unit 2, OPG employed all of the above listed actions at various times 9

to adjust the schedule to reflect the impact of delays or early completion of specific work 10

activities, and to help manage unforeseen challenges. The actions taken on Unit 2 informed the 11

schedules for the Remaining Units. Section 3.2 explains the important role that such information 12

played in the refinement of the schedules for the Remaining Units. 13

14

3.0 REMAINING UNITS SCHEDULE 15

This section presents the changes to the Program schedule and explains the drivers behind 16

those changes. It addresses the process used to refine the individual units’ working schedules, 17

by using phased milestones established for schedule development and introducing 18

refinements for the Remaining Units. 19

20

Figure 1 shows a simplified overview of the major critical path steps in the schedule of 21

refurbishing a unit. The critical path refers to the longest sequence of activities in a project plan 22

that must be completed on schedule for the timely delivery of the overall project. Subsequent 23

activities on the critical path cannot be started until predecessor activities are complete. For 24

example, if an activity on the critical path were completed one day earlier than planned, the 25

entire project would be completed one day ahead of plan, provided all subsequent critical path 26

activities were completed in their planned durations. As shown in Figure 1, the major critical 27

path steps are: 28

• Reactor shutdown 29

• Defuel reactor 30

• Drain systems and isolate from containment (and the other operating units) 31

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Exhibit D2 Tab 2

Schedule 5 of 17

• Fuel channel removal, inspection and cleaning and installation (includes feeder removal 1

and installation) 2

• Refuel 3

• Refill and re-establish normal containment boundary 4

• Commission and return to service 5

6

Figure 1: Major Steps in Refurbishing a Darlington Nuclear Unit 7

8 As part of the planning efforts described in Ex. D2-2-3: 9

1. The Program schedule (planned start dates and end dates and milestones for each of 10

the Remaining Units) has been updated; and 11

2. The Working and High Confidence Schedules for each of the Remaining Units have been 12

updated. 13

14

3.1 Remaining Units Program Schedule 15

Figure 2 shows the Program’s High Confidence Schedule per the final Unit 3 Execution 16

Estimate (“U3EE”).3 17

3 As discussed in Ex. D2-2-3, the final U3EE reflects the schedule impact of OPG’s response actions to COVID-19

that included deferring the start date of the Unit 3 refurbishment in 2020 and correspondingly revising the start dates for Units 1 and 4.

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Exhibit D2 Tab 2

Schedule 5 of 17

Figure 2: High Confidence Schedule at Final U3EE 1

2 The main drivers of the changes from the RQE/U2EE schedule to the final U3EE schedule 3

were the slight delay to the completion of Unit 2 and the deferrals of the start dates of each of 4

the Remaining Units in response to the COVID-19 pandemic. In response to the Unit 2 delayed 5

finish, OPG had made a strategic decision to defer the start of Unit 3 in order to manage 6

resources and to avoid introducing risks into the last segment of the Unit 2 refurbishment 7

outage. OPG also managed the risks to the overall Program by similarly moving the Unit 1 and 8

Unit 4 start dates to avoid potential schedule logic and resource conflicts risks. In response to 9

the COVID-19 pandemic, OPG decided to further shift the start date of the refurbishment 10

outage of Unit 3, by four months, to September 2020.4 This decision also necessitated a 11

corresponding shift in the start dates of the Units 1 and 4 refurbishment outages by four 12

months.5 13

14

3.2 Unit Schedules – Development and Refinement 15

As discussed in Ex. D2-2-3 (Section 3.3), a set of integrated Program, Segment and Window 16

Milestones were established to manage and monitor the progress of planning for each of the 17

4 The Unit 3 refurbishment outage is now in progress, with an actual start date of September 3, 2020. 5 As a result of the deferred DRP schedule, OPG moved a regular planned outage from 2020 to 2021 and also

added a regular planned outage in 2021 to support Unit 4 operation until its start of refurbishment. See Ex. E2-1-2 for further discussion.

Sep 2020 Unit 3 - 40 months Jan 2024

Feb 2022 Unit 1 - 38 months Apr 2025

Sep 2023 Unit 4 - 37 months Oct 2026

Total Duration = 73 months

20262022 2024 202520232020 2021

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Exhibit D2 Tab 2

Schedule 5 of 17

Remaining Units. As a part of that process, milestones were established to manage and 1

monitor the progress of schedule development. 2

3

The schedule evolves through four formal revisions with an increasing level of rigour and detail 4

in each revision. The timing and level of detail required in each of these schedules is specified 5

in OPG’s Refurbishment Unit Planning Milestones Governance (Ex. D2-2-3, Attachment 2). At 6

a high-level, the four formal revisions of the schedule for each unit’s refurbishment result in 7

progression from a Level 1 schedule overview depicting the key components of the critical path 8

and providing the overall duration and layout of the unit’s refurbishment outage, to a Level 3 9

schedule with full details of the critical path, major maintenance and modification activities, and 10

including detailed scripting of work sequences. This schedule, known as Revision 0,6 serves 11

as the baseline schedule against which performance will be measured. Each revision of the 12

schedule also supports the evolution of the cost estimates for each unit. 13

14

Refinement of the individual schedules for the Remaining Units is focused on four main areas: 15

1. Incorporating Lessons Learned from the work executed to date; 16

2. Incorporating Strategic Improvements; 17

3. Developing robust schedule logic, resources and duration for the new turbine generator 18

controls scope in the Remaining Units, and identifying and mitigating the risks introduced 19

by this new scope; and 20

4. Examining the periods where unit refurbishment outages overlap to ensure that there are 21

no unacceptable plant configurations, resource conflicts, or other logistical conflicts. 22

23

Each of these areas is elaborated upon in Sections 3.2.1 to 3.2.4 below. 24

25

3.2.1 Lessons Learned 26

The process of incorporating Lessons Learned in planning for the Program is detailed in Ex. 27

D2-2-3, Section 4. Specific to scheduling, the Lessons Learned exercises conducted after 28

6 Because of the changes to the Unit 3 start date, the baseline schedule for Unit 3 is a Revision 2 schedule. See

Attachment 2.

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Exhibit D2 Tab 2

Schedule 5 of 17

completion of each Unit 2 execution work activity were of critical importance in informing the 1

development of the Remaining Units’ schedules. 2

3

As explained in Ex. D2-2-3, Section 4, the Lessons Learned program examined each 4

completed work activity for Unit 2, with a particular focus on critical path activities, to 5

understand in detail the drivers of good performance (for those activities that took less time 6

than scheduled), and the causes of below target performance (for those activities where actual 7

durations exceeded the planned durations). This detailed understanding of the underlying 8

reasons for better than plan or worse than plan performance on Unit 2 work activities, facilitated 9

adjustments to the planned durations of similar activities in each of the Remaining Units’ 10

schedules. When compared to the original planned durations at the RQE/U2EE, the planned 11

duration of activities was reduced in some instances and increased in others. 12

13

In performing the detailed analysis of work activities on Unit 2, there was a particular focus on 14

understanding the causes of any delays in work execution as well as the causes of lower-than-15

plan or higher-than-plan productivity. Many delays were assessed to be one-time events and, 16

therefore, not expected to recur on the Remaining Units. The remaining delays were reviewed 17

to refine the assumptions about how an activity would be completed and, therefore, to adjust 18

the planned duration for that activity in the Remaining Units’ schedules. 19

20

OPG reviewed the causes of higher-than-plan and lower-than-plan productivity on Unit 2 work 21

activities, particularly critical path activities, in depth. Where higher-than-plan productivity rates 22

were assessed to be fully or partially repeatable on the Remaining Units, these rates were then 23

either partially or fully built into duration assessments for similar activities on the Remaining 24

Units. Where lower-than-plan productivity was achieved, tactical changes (e.g., changes to 25

work procedures) were implemented to facilitate increased productivity for similar activities on 26

the Remaining Units. Section 3.2.2 below discusses three specific Strategic Improvements 27

which are expected to reduce delays and to drive increased productivity on the Remaining 28

Units. 29

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Exhibit D2 Tab 2

Schedule 5 of 17

3.2.2 Strategic Improvements 1

OPG is implementing, or has implemented, a number of Strategic Improvements for the 2

Remaining Units which have more overarching impacts on the Program than the typical 3

Lessons Learned. Six Strategic Improvements are described in Ex. D2-2-3, Section 5. Three 4

of the Strategic Improvements which have positively impacted schedule are explained below: 5

• Radiation Protection Improvements: Improvements to radiation protection are a major 6

contributor to schedule improvements. Over one hundred specific actions have been 7

implemented under the Radiation Protection Strategic Improvement (Ex. D2-2-3, Section 8

5.1.4), the majority of which aim to eliminate or reduce delays. Examples of these actions 9

include: (1) ensuring that the demand for radiation protection coordinators is integrated into 10

the schedule and tied to specific tasks which require a radiation exposure permit, thereby 11

eliminating delays caused by the lack of a radiation protection coordinator; (2) 12

implementing self-issue of electronic personal dosimeters to reduce the wait times for field 13

personnel who require radiation dose measuring instruments to perform their work; (3) 14

developing a new qualification and changing procedures to allow contractors to perform 15

self-protection for low risk activities. 16

• Training: The focus of the Training Strategic Improvement (Ex. D2-2-3, Section 5.1.5) is to 17

improve productivity. Specific examples are: (1) intensively training a smaller group on 18

troubleshooting, and the ability to understand the intricacies of the work series, 19

contingencies, the tooling, and the overall process (facilitated by implementation of the 20

hybrid schedule as discussed in the next bullet); and, (2) better aligning training schedules 21

with execution schedules, thereby having the training fresh in the minds of the 22

tradespersons as they prepare to execute the tasks in the field. 23

• Hybrid Schedule: A significant focus of the implementation of the Hybrid Schedule Strategic 24

Improvement (see Ex. D2-2-3, Section 5.1.6 for a detailed discussion) is on achieving 25

improved productivity on the Remaining Units. Two examples are: (1) the Hybrid Schedule 26

will require fewer trades to be trained and allow more time for training on the reactor mock-27

up, which will result in improved task execution proficiency; and (2) the Hybrid Schedule 28

will mean that each tradesperson will spend more time in the field in experiential learning, 29

which is expected to result in a shorter learning curve, as well as higher, and more 30

sustained, peak performance. 31

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Exhibit D2 Tab 2

Schedule 5 of 17

3.2.3 Developing Robust Schedule Logic 1

OPG employs many processes to verify the quality of its schedules and improve the robustness 2

of the schedule logic. 3

4

A key process is a review of the work which is scheduled to be done in parallel, with particular 5

focus on periods when there is more than one work team scheduled to work in the same area 6

of the plant. These reviews, known as vertical slice reviews, identify potential conflicts in very 7

specific work areas of the plant (e.g., the North-East Reactor Vault, Elevation 104). In a 8

workshop setting, all of the stakeholders involved in executing the work activities review the 9

schedule in detail. Conflicts can arise in many ways when more than one work group is 10

scheduled to work in the same area. For example, conflicts may arise in the use of breathing 11

air, when radiography is scheduled (radiography interrupts the work of other work groups), in 12

electrical needs for the different work packages, and in radiation protection requirements. 13

14

During the latter stages of the Unit 2 refurbishment outage, OPG deployed for the first time a 15

technique known as “4D scheduling.” This technique utilizes computer graphics to create a 16

visual simulation of an area of the plant or a piece of major equipment. The visual simulation 17

is tied to, and driven by, the schedule logic built for that particular activity. Using this technique 18

allows the people who are planning and executing the work to view a simulation of the 19

sequence of activities in the schedule prior to executing the activities in the field, thereby 20

becoming better equipped to identify and resolve potential issues. An additional benefit of 4D 21

scheduling is that it can be used to improve the training for a sequence of activities. 22

23

Another on-going process reviews the optimal timing of efficient work package execution. This 24

process particularly applies to work that is off critical path, where greater flexibility exists to 25

review and make adjustments to the sequence of work activities. Reviews are conducted 26

frequently to identify work that could be completed earlier in the refurbishment outages of the 27

Remaining Units, which would reduce the risk of this work becoming critical path. For example, 28

opportunities are regularly assessed to maximize any work that could be done on each unit 29

before breaker open, thereby reducing risks associated with the volume of work, and facilitating 30

a more manageable work load and resource profile, during the refurbishment outage itself. 31

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Exhibit D2 Tab 2

Schedule 5 of 17

3.2.4 Reviewing the Overlapped Periods 1

The degree of overlap between the prior and subsequent unit refurbishments is subject to a 2

number of constraints that must be evaluated in detail. For example, bulkhead installation on 3

a unit that is being readied for the mechanical removal of the fuel channels and feeders 4

(Segment 1 - Lead In - Defuelling and Containment Isolation) cannot take place concurrently 5

with bulkhead removal on a unit that is being prepared to be returned to service (Segment 4 -6

Plant Restoration Start-up) because of reactor safety considerations. 7

8

Potential resource constraints also must be taken into account. For example, work activities 9

across units that are operator intensive should not overlap to a degree that would cause 10

operator resource availability to affect execution. Also, scheduling two infrequently performed 11

technical evolutions at the same time, requires carefully assessing the executing organizations’ 12

capacity to undertake those evolutions safely and with quality, and determining whether 13

changes to the schedule may be necessary to mitigate risk. 14

15

A Strategic Improvement directly related to managing overlapping refurbishment outages is 16

Workstream Specialization, which was introduced in Ex. D2-2-3, Section 5.1.1, and is 17

explained in detail in Ex. D2-2-8, Section 2.2. Workstream Specialization involves the 18

development of highly trained specialized work crews to execute the same series of work by 19

moving directly from one unit’s refurbishment outage to the next. For example, this sequencing 20

of work allows the crew which has just completed the feeder removal series of work activities 21

on one unit, to move to the next unit and complete the same series. The expectation is that 22

this team will continuously improve their high proficiency levels through specialization and 23

repetition. Implementation of Workstream Specialization requires careful attention to how 24

activities are overlapped. Figure 3 shows that similar segments of consecutive refurbishment 25

outages on the Remaining Units are never overlapped, thereby allowing the same team to 26

execute the same work on each of the Remaining Units. 27

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Exhibit D2 Tab 2

Schedule 5 of 17

Figure 3: Remaining Units Schedule Showing No Overlaps of Lead In, 1 Removal, Installation and Lead Out Work Activities on Consecutive Units2

3 4

3.3 Remaining Units Schedules 5

Chart 1 provides the High Confidence Schedule dates and durations for the Remaining Units. 6

High confidence durations have not changed since RQE. 7

8

Chart 1: High Confidence Schedule Dates 9 for Units 3, 1, and 4 Refurbishments 10

High Confidence Schedule

Start End Duration (Months)

Unit 3 3-Sep-20207 2-Jan-2024 40

Unit 1 15-Feb-2022 18-Apr-2025 38

Unit 4 15-Sep-2023 16-Oct-2026 37

11

The Level 1 Working Schedules for the Remaining Units with details of the planned start dates, 12

durations, end dates and of critical path activities are provided as Attachments 3, 4, and 5 for 13

Units 3, 1, and 4 respectively. These are the high-level Working Schedules that OPG uses to 14

manage day-to-day performance on the unit refurbishment outages. 15

7 Actual start date of the Unit 3 refurbishment outage.

Lead Out

UN

IT 1

UN

IT 4

Lead In Removal Installation

Lead In Removal Installation Lead Out

UN

IT 3

Lead In Removal Installation Lead Out

20262022 2024 202520232020 2021

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Exhibit D2 Tab 2

Schedule 5 of 17

3.4 Unit-Over-Unit Efficiencies 1

As shown in Chart 1, and consistent with the RQE and U2EE, OPG is planning to achieve 2

improvements in the High Confidence Schedule durations as the refurbishment outages of 3

Units 3, 1, and 4 are executed. The planned High Confidence durations decrease from 40 4

months on Unit 3, to 38 months on Unit 1, to 37 months on Unit 4. Given the actual achieved 5

duration of just over 43.5 months on Unit 2, these planned durations represent substantial 6

improvements of 3.5 months, 5.5 months and 6.5 months for Units 3, 1, and 4 respectively, 7

when compared to Unit 2. 8

9

Similarly, the Working Schedules for Units 3, 1, and 4, which OPG will use to manage day-to-10

day performance on the unit refurbishment outages, are 36 months, 33 months, and 32 months 11

respectively. These durations represent improvements of 7.5 months, 10.5 months and 11.5 12

months for Units 3, 1, and 4 respectively, when compared to the actual achieved duration of 13

just over 43.5 months on Unit 2. 14

15

Chart 2 shows a high-level comparison of the planned durations of major critical path work 16

activities for Unit 3 versus the durations achieved on the same activities on Unit 2. 17

18

Chart 2: Major Critical Path Series on Unit 3 19 Planned Improvements versus Unit 2 Actuals8 20

21 22

Chart 2 shows Working Schedule planned durations for Unit 3 being shorter than the Unit 2 23

actual achieved durations in 7 of the 8 major phases. On a plan-versus-plan basis however, 24

not all activities for Unit 3 are being planned with shorter execution durations than those 25

achieved on Unit 2. Chart 3 provides examples of select critical path work activities which are 26

8 The Unit 2 actuals are compared against the planned durations in the Unit 3 Working Schedule.

Shutdown and

Defuelling

Vault Prepara-

tion

Feeder Removal

Fuel Channel Removal

Calandria Tube

Installation

Fuel Channel

Installation

Feeder Installation

Vault Restora-

tion

Run-up and Syn-chronize

Total

Days Difference -1 -35 -4 -58 -32 -30 -63 -17 12 -230Improvement 2% 19% 6% 26% 18% 19% 30% 9% -49% 17%

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Exhibit D2 Tab 2

Schedule 5 of 17

planned to be shorter, and examples of activities planned to be longer for the Unit 3 plan 1

compared to the Unit 2 plan. 2

3

Chart 3: Select Examples of Critical Path Durations - 4 Unit 3 Plan vs. Unit 2 Plan 5

Unit 3 Critical Path Activities Forecast Shorter than U2 Days Unit 3 Critical Path Activities

Forecast Longer than U2 Days Defuel Reactor -23 Bulkhead Installation +8 Install Shielding -19 Remove Bridge/Install Retube

Tooling Platform +13

Pressure Tube Removal* -34 End Fitting Removal +10 Calandria Tube Insert Release -8 Lower Feeder Installation +47 Tube Sheet Bore Cleaning -7 Lower Body Tubing Install +31 Airlock Close and Pressure Test -10 Bulkhead Removal -7 *Pressure Tube Removal will be done concurrently with Calandria Tube Removal for Unit 3, saving 34 days on the schedule compared to Unit 2. This Darlington 3 Innovations Project Strategic Improvement is described in Ex. D2-2-3, Section 5.1.3.

6

Contributing to OPG’s confidence in achieving Unit-over-Unit efficiencies is OPG’s 7

implementation of the Hybrid Schedule for the Remaining Units. In the Hybrid Schedule, the 8

number of working days are fewer than the elapsed calendar days. As discussed in Ex. D2-2-9

3, for those work activities executed utilizing a 24 hours per day/5 days per week schedule, 10

weekends provide opportunities to perform near critical path work and to recover lost time on 11

critical path, as required. For example, in the case of Unit 3, the number of elapsed days in the 12

Working Schedule of 36 months, is 1,096 calendar days; however, the number of working days 13

is 930 days. Sections 3.2.1 and 3.2.2 explain that the application of Lessons Learned and the 14

implementation of Strategic Improvements are expected to address challenges experienced 15

on Unit 2 and to result in improved productivity. In addition, Ex. D2-2-3, Section 5.1.3 describes 16

the Darlington Unit 3 Innovations Project (“D3IP”) Strategic Improvement. 17

18

Chart 4 summarizes OPG’s analysis of the contributors to the improved schedule duration for 19

Unit 3. Comparing the planned High Confidence Schedule duration for Unit 3 of 1216 days to 20

the achieved duration of 1,328 days for Unit 2, the difference is 112 days. Comparing the 21

planned Working Schedule duration for Unit 3 of 1096 days to the achieved duration of 1,328 22

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Exhibit D2 Tab 2

Schedule 5 of 17

days for Unit 2, the difference is 232 days. Comparing the planned working days for Unit 3 of 1

930 days to the achieved duration of 1,328 days for Unit 2, the difference is 398 days. 2

3

4

Resolved challenges are issues that were experienced on Unit 2 that are not expected to recur 5

because, utilizing Lessons Learned, mitigation has been put in place or procedures modified 6

to avoid the occurrence of these items. Chart 4 shows a reduction of 205 days from resolved 7

challenges when comparing Unit 3 planned working days to Unit 2 actuals. Some examples of 8

these resolved challenges and the resulting reduction in the number of days are: (a) feeder 9

installation challenges because of welding issues (99 days); (b) fuel channel installation delays 10

due to various issues such as hoisting and tooling breakdowns (58 days); (c) calandria tube 11

installation delays due to various issues such as leak testing and issues with positioning the 12

tubes (15 days); and, (d) bulkhead installation delays attributed to issues related to counter 13

balance lifting beam (16 days). 14

15

OPG is forecasting performance or productivity improvements totalling 115 days through the 16

application of Lessons Learned and the implementation of Strategic Improvements when 17

comparing Unit 3 planned working days to Unit 2 actuals. Some examples of the number of 18

schedule improvement days for certain work activities, include: (a) the fuel channel install 19

Chart 4: Contributors to Unit-Over-Unit Efficiencies - Unit 2 Actual vs. Unit 3 Planned

Days Unit 2 Achieved Duration 1328

Forecast Improvements for Unit 3 Resolved Challenges (i.e. not expected to recur) 205

Performance Improvements (Productivity) 115

D3IP Tooling/Methods Improvement 78

Unit 3 Planned Working Days 930

Unit 3 Planned Working Schedule (Calendar Days) 1096 Unit 3 Planned High Confidence Schedule (Calendar Days) 1216

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Exhibit D2 Tab 2

Schedule 5 of 17

series (30 days); (b) calandria tube removal, tube sheet bore cleaning and bellows inspections 1

(10 days). 2

3

The improved tooling initiatives under the D3IP are expected to yield a total of 78 days 4

improvement. The contributors to this 78 day improvement are: (a) pressure tube and calandria 5

tube combined removal (34 days); (b) modified installation worktables (36 days); (c) use of 6

double tool sets (4 days), and; (d) bellows cut tool enhancement (4 days). 7

8

In conclusion, OPG has carefully developed the schedules for the Remaining Units, based on 9

detailed analysis of its actual performance on Unit 2, and the application of Lessons Learned 10

and Strategic Improvements. OPG has high confidence in being able to achieve the forecasted 11

unit-over-unit efficiencies and overall duration improvements reflected in these schedules. 12

13

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Exhibit D2 Tab 2

Schedule 5 of 17

ATTACHMENTS 1

2

Attachment 1: OPG’s Multi-Level Scheduling Approach 3

Attachment 2: Unit 3 Level 1 Working Schedule 4



7

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

Exhibit D2 Tab 2

Schedule 5 Attachment 1

Page 1 of 2

Attachment 1: OPG’s Multi-level Scheduling Approach 1

2

The ability to validate, integrate, oversee and ultimately to retain control over the program 3

schedule is one of the key factors that has driven OPG’s Darlington Refurbishment Program 4

(“DRP”) strategy. OPG developed a fully integrated Program schedule, which incorporates the 5

project schedules for each of the major work bundles that are detailed down to the individual 6

work packages and work tasks within each bundle. OPG effectively leverages the control it 7

retains over the Program schedule to ensure Program success since the schedule has a direct 8

impact on Program costs. This Attachment describes OPG’s multi-level scheduling approach. 9

10

Multi-level Scheduling Approach 11

Based on recommended practices, OPG established its initial schedule using a multi-level 12

scheduling approach. OPG continues to apply the same approach as the schedule is 13

redeveloped and refined. As shown in Figure 1 below, project schedules are prepared with up 14

to four levels of detail, from Level “0”, which contains the Program milestones managed by 15

OPG and which identify the major deliverables and timelines for the overall DRP, to Level “3”, 16

which shows individual work components at the task level. For example, projects where most 17

of the work will be performed by contractors utilize detailed Level 3 schedules. OPG as the 18

owner performs project management and control activities utilizing Level 0 to 2 schedules. 19

20

Figure 1 21

Multi-level Scheduling Framework 22

Level 0: Program Milestone Schedule, controlled by OPG Senior

Management.

Level 1: Program Integrated Master Schedule, controlled by OPG Senior

Management. Program Level 1 contains all Control Accounts from all

Projects as well as for Program Management work.

Level 2: Program Coordination & Control Schedules, controlled by OPG

Program/Project teams. Program Level 2 contains all Work Packages in

the Program and they are interrelated.

Level 3: Project Detailed Production Schedules, controlled at the project

level, by contractors or OPG (for OPG executed projects).

Level 0

Level 1

Level 2

Level 3

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

Exhibit D2 Tab 2

Schedule 5 Attachment 1

Page 2 of 2 1

Level 0 consists of the Program/Project Milestone Schedule, and is used by OPG senior 2

management to provide the basis for establishing the master schedule. This includes program 3

release milestones, regulatory milestones, outage preparation milestones and outage 4

execution milestones. 5

6

The Level 1 schedule is the Program/Project Integrated Master Schedule that contains 7

particular work scopes, a time window and a responsible organization. The Level 1 schedule 8

provides a high-level management summary of the Program or project, represents all units, 9

phases and bundles, and is used by project managers, contractors and scheduling functions. 10

11

Level 2 schedules are the Program/Project Coordination & Control Schedules. This is the 12

schedule used by OPG to track the overall status of the Program. It is updated and controlled 13

by OPG and is based on the contractors’ detailed Level 3 schedules. 14

15

Level 3 schedules are Program/Project Detailed Production Schedules which further break 16

down work into detailed activities. Level 3 schedules are prepared by the group executing the 17

work (typically by contractors, and in some cases by OPG where OPG is self-performing work). 18

The lowest level of tasks to be executed are developed here. 19

20

Once approved, schedules are ‘baselined’ by the project owners as a benchmark for 21

measuring implementation performance. Baselined schedules are archived and are not 22

modified, except by means of a re-baselining process involving cost and schedule analysis 23

and only through authorized change control. 24

Unit 3 Refurbishment – DNRU3 Level 1 Overview Revision 2August 31, 2020

60% CP Complete

REMOVAL SEGMENT – 2A REMOVAL SEGMENT – 2BLEAD IN SEGMENT INSTALL SEGMENT LEAD OUT SEGMENT

State 1 State 2 State 3a State 3b State 4a State 4b State 5

Outage Day 10800 96020 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 680660 700 720 740 760 780 800 820 840 860 880 900 920 940 980 10201000 1040 1060 1100

SEP 2023

JUL2023

SEP 2020

JAN 2021

OCT 2020

JUL2021

APR 2021

MAR 2021

MAY 2021

FEB 2021

JUN 2021

AUG 2021

JUL 2022

OCT2021

NOV2021

JAN2022

APR 2022

MAR 2022

SEP 2021

MAY 2022

DEC 2021

FEB 2022

JUN 2022

AUG2022

OCT 2022

NOV 2022

JAN 2023

SEP 2022

DEC 2022

FEB 2023

MAR2023

APR 2023

MAY 2023

JUN 2023

AUG 2020

AUG 2023

NOV 2020

DEC 2020

196

TG Modification and Maintenance Scope

SDC Valves East Side

125BU16 Maintenance

Transformer& Bus

Maintenance

T10/12 BU10/12

To TPDS & Even E lect rical Outage

To VVRS Commissioning & Even Electrical Outage

009 VVRS Mods and Rehab

Critical Path WindowsElectrical Windows Reactivity Device Windows

Heat Transport System Windows

Turbine/Generator & Conv Layup

Gross Air Leak Test5d

005 EPS MCC Rehab

Inst Air Mtce

057 LPSW Outage

Moderator Testing

035HTS Aux Vac Dry

Mod Drain & Flush

EP Mods & Run Vac Hose

To Mod Drain & EP

Mods

Temp Fission Chamber Guide Tube Install

Remove Vac Dry Equip

054Hold out Warm er Temp

To Gross A irLeak Test

To RCHP 1

Connect to HTS System

038

048

079

081

056 PULSW Outage

123

104 Vault Projects

Hold out for Cooler Tem ps

029 HTS Vac Dry

SDC Valves & PULSW Line Replacement & ASDC Pumps

Temp Fission Chamber Install

HTSVac Dry Pre-Req’s 105 Vault Projects

Hold out for TCB declared &

Tem p Vault ACU’s Installed

P&IC & SDC Purge HTS Rehab - Outside Vault

Tem p Power Req’d for South Side Drai nage Sum ps

To RCHP 5

Remove SG Layup

ECI NV Inspections

195 RCW Work

To RCHP 4

(Layup)

FH Bridge Upgrade Complete

029

067

208

034 Install SG Layup Primary Side

032 LZCS

Remove Mod Dry Equip & Reconnect Mod Pipework

038

Isolate Calandria & Hookup Drying Equip.

045 076 Upper & Middle Feeder Installation

073 HFD Replacements

078

089

Hold out unt il 6 months before ATC

To RCHP 5

RCHP2

To RCHP 5

RCHP4

Decl arat ion that Reactor Core is Defueled Before Entering S tate 3a

Unit 1 Refurbishment Outage (DNRU1)

Moderator Windows

To RCHP 4

SDS1 Computer Replacements

Overhaul A/I Skid

103

121

Vac Dry Lower Mod Pipework

051 CL IV Elec. Maintenance

122 Moderator Valve Rehab

108103 Purge

Hold out for Bkrs & Relays from Cl I II

055 CCW Rehab

From VF Ds Removed

Secondary Side SG Clean & Install Access Ports

PULSW P iping R-015 124 Aux. SDC Pump InstallationASDC Interference Removal

From Isolate Calandria & Hookup Drying Equi p Perm it Appl ied

040 CL II Elec. Maintenance BUS A & C040 CL I I Elec. Maintenance BUS B

041 CL I II Elec. Maintenance

147147 ECI Valve Mtce

028 Removal

From SG Access Ports, EHS O utside Vaul t & HTS Pump Insp

To Repl ace Adjuster Rods

Clean Vault (FM E) Conditi ons In-E ffect

029

037128

Clean Vault (FM E) Conditi ons In-E ffect

Cooldown A fter Vac Dry

From Mod Valve Rehab

To Complete EHS (E. Vaul t)

064 South ACU 4&3

Complete Emergency Heat Sink Pipework (E. Vault)

From South ACU 4 replacem ent

& Vaul t Projects

007

Fill Calandria 5d

080

To LPSW, PULSW, CLIV E lec. Mtce

Hold O ut for Valve/IRI Resources

From Fuel Channel Install

Purge to be applied prior to CTI release and m aintai ned unti l all CT’s have been replaced

068

Feeder Cabinet Removal

Vessel Inspection

Fuel Channel Installation Series4 13027 47 1343910 12

Dummy FB Removal

Lower Feeder Install Series

Fuel LoadGroup 1,2,3 & Hanging Scaffold

4110 17

084

083119

192

111

074

51Defuel Reactor

017 Install APT & End Fitt ing Caps

90

012

Install Bulkhead

Containment Pre-test, Achieve Dew pt. & Containment Test

Bulk Interference Removals

- Final Comm issioning VVRS Phase 1- AL & TCD Logic Mods- Breat hing Air Tie-in

Remove FM Bridges & Install RTPs

11554411 268

024

137

027023

101

Full Vault Access

100

CCW

Pumpwell Cl eaning

To RCHP 5

Remove HTS Pump Motors

Vaul t Access rest rictions due to Critical Lifts

022

Pumps Lif ted into place.Hold out for motor availabili ty

Coordinate wi th Crit ical Path Work -Vaul t Access rest rictions due to Critical Lift s

060 Install PHT Pump Motors065 HTS Pump Impelle r Inspection

Miscellaneous WindowsConv Water Windows

058

Conventional Side Layup002

221RRS LM Replacements

To SDS2 Computers W007

Replace Vertical Flux Detectors

To SG SS M tce W037& EHS i nside HT P 4 Rm& HT Pum p Insp

SDS2 Computer Replacements007From HTS Bulk Drai n Complete

To RCHP 2

From W103 Purge

021 RemovalsReplace Adjuster Rods

To SG PS Clean & Install HTS Pumps

To RCHP 2

(ACU4 Complete)

Tied to FC Install F inish

To Lower Feeder Install

To RCHP 1

046 LISS Rehab

OPGSS in effect

From Instal l HTS Pump Motors & Adjuster Rods Removed and Inst Ai r Mtce

013 HTS Bulk Drain

To RCHP 7

008 MOT & UST Removal 008 MOT & UST Install

To W078 Remove Mod Dry Equip

From Inst A ir Mai nt

S/D1d

Crane Mtce

SFCR30d

D1932SFCR Jul 31/20 – Aug 30/20

U3Shutdown

HTS Operational Testing (includes ASDC)

RCHP7

RCHP6

RCHP5

190

RCHP3

RTP Removals, Bridge Replacement

19 6

Bulkhead Post-Reqs

097

7

ATC & Fission Chamber removal2d

6 23 13

092

7 20

Heat-up& Hot Condition

193

082

Replace HT Pump Seals

222 SG Wet Recirc Layup Removal Includes IUFT and N2 B lanket removal

1096 days

DNRU3StartAug 30, 2020

070 North ACU 1&2

To RCHP 4

SDC Valves West Side 050

& PULSW P iping R-016

From HTS Vac Dry Complete

From HTS Aux Vac Dry Complete

EHS Outside Vault106Hold out for P roj ect Resources

Inside HT P4 Rm

From VF D Removal

To HTS Pump Insp.

To Feeder Scanner Replacement (Removed f rom U 1 and O verhauled)

Install & Connect A ir Skid

To Remove Adjuster Rods

To RCHP 4

To W062 SG PS Cl ean

From Remove Adjuster Rods

From VF D Removal

To EHS (E.Vaul t)

316 10 6

090

087 Feeder Scanner Replacement To RCHP 4

From W058CCW Compl ete

Spares overhauled f rom D 2011

U1 Outage 2020 (D2011)

10

Skids commissioning complete

Fuel LoadGroup 4

RTP Config 1,OB Columns & Elec Removal

U2 Outage 2023 (D2321)

231

232

063 SG Nitrogen Blanket Install


Degas & Permitry

To Waterbox ECT S tart

From Waterbox ECT Compl ete

24/7 periods

24/6 periods

24/5 periods

Establish Upper Calandria Purge Flow & E/W Valve Mtce

RHP1

RHP2

RHP3

RCHP9

See Page 2 for TG Project Level 1 Overview

To DNRU1 W002 (IUF T Availabilit y)

11

36 Months

To RCHP 2

053 ESW Rehab

To RCHP 1

124

124

From W121 MO D Vac Dry

A

B

C

D

Page 1 of 2

TG Mi ni -Perm it

TG Main Perm it

From W256, W258 Fini sh to W198 Condensate Feedwater RTS

Permits Applied for OPS

resources

RCHP1: Moderator Fill

RCHP2: Fuel Load

RCHP3: Bulkhead Removal

RCHP4: Heat Transport System Fill

RCHP5: GSS Removal

RCHP6: Exceeding 1%FP

RCHP7: Turbine Testing & First Sync


RCHP9: Unit Available for Commercial Operation

SGECS Drained (after W012 Complete)

BWXT Resources

1.

2.

Restart Control

Hold PointRCHP

x

Reactor States

State 1: Reactor Shutdown Evolution

State 2: Guaranteed Shutdown with Irradiated Fuel Core

State 3a: Defueled State

State 3b: Defueled & Isolated from Containment State

State 4a: Non Irradiated Fuel & Isolated from Containment

State 4b: Non Irradiated Fuel State

State 5: Approach to Critical & Return to Service State

NOTES

RHP Regulatory Hold

Point

U4 Outage 2021 (D2141)

003 SG Layup

(Recirc. Skids)

5

Sever Bellows

113PT Sever

112Feeder Removal

042End Fitt ingRemoval

114CTI Release

098 CTI Removal

116

CT/PT Removal

117

28

Tube Sheet Bore Cleaning

149

Bellows Inspections

072

18Calandria Tube Install Series118

LBS Cabinet Frame Tie-in

233

Feeder Lower Body Tubing

235

096High Power Test ing& Turbine Test ing

Run-up & Sync & Balance

095

RCHP8

RHP4

127

270 MOT/UST Fire Protection Mod

031 SA & CA Rods

USCA ACU Line Replacements053

RCHP1

To DNRU1 Breaker Open

129 140

019

Connect Conventional Side Dryers

Condensate & Feedwater RTS

SEP 1, 2023

To 054 Inst Air Mtce

Primary Side SG Clean & Inspect062

U1S/D Feeder

Cabinet Removal Feeder Rem oval

PT Sever

Sever Bellows

End Fit ti ng Removal

CT/PT Removal

Dumm y FB Removal

Defuel Reactor InstallAPT Install Bulkhead

Containm ent Test Bulk Interference

Removals

Comm ission VVRS

Remove F M Bridges & Install RT Ps

Crane Mai ntenance

Install Shielding

CTI Release

CTI Removal

Vessel Inspection


Bellows Inspections

CT Install

A lignments Vac Dry

Install Lower Body Supports

230Bulkhead Removal

088

Operating Units Fuel Run

157- A/L Closed- Pressure Test- VVRS Balance

085

234

NPC Logic Restoration

1d

146

094Power Escalation

Heat-up & Low Power Test ing

093

028 Replacement

004 IPB/Switchyard Rehab To RCHP 7

To RCHP 1

To W029 HTS Vac Dry Commi ssioning

Establish GSS

216

HTS Air Hold, Fill & Pressure Test

To RCHP 4

From Upper & Mi ddle Feeder

Installati on, CWP 3197

MOT/UST Commissioning

Conventional Side Restoration

198

From fi nish W012 Defuel Reactor

from 062 P ri mary S ide SG Clean & Inspect

021 Replacements

Nozzle Inspection & Weld Prep


197 Nuclear Side Restoration

From W121, MO D Vac Dry

Complete

272

BUS 8 Fini shTo LPSW Outage

Hold out for Resources

Winter (need cooler temp for BU14)

Ensure S tat ion requirem ents for CCW Pumps availabilit y during D 2141

To RCHP 5

Segment 4 Exception for Rev1

Feeder Visuals

Winter (need cold tem ps - L15 work)

Install RVAS

To D2011 Outage

010 Condensate & Feedwater

155

AA Mech Removals

To W197Nucl ear Si de Restoration

From W189 Remove SG Layup

Hold out for Warmer T emps

To ESW Rehab

From CL lI II

To RCHP 5 From BUS 8 Fini sh

From W121, MO D Vac Dry

Complete

Hold out for S tart of PULSW O utage

W258

W242

W243W247

W259W256W249

W240W245 W246

AISC Project Exception for Rev1 (2)

To W250 S tator Rewi nd & Shaf t Line Maintenance

189

Filed: 2020-12-31, EB-2020-0290, Exhibit D2-2-5, Attachment 2, Page 1 of 2

https://opgreporting.sharepoint.opg.com/Nuclear/nucproj/nr/Documents/Unit 3 Level 1 Overview/SwitchBoards/196-U3-SwitchBoard.pdf























































































../../../Revision B Documents/19. Window Level 2s/032 LZCS Rehab/032 LZCS Outage R0.vsd



















































































Unit 3 Refurbishment – DNRU3 Level 1 Overview Revision 2August 31, 2020

60% CP Complete


State 1 State 2 State 3a State 3b State 4a State 4b State 5

Outage Day 10800 96020 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 680660 700 720 740 760 780 800 820 840 860 880 900 920 940 980 10201000 1040 1060 1100

SEP 2023

JUL2023

SEP 2020

JAN 2021

OCT 2020

JUL2021

APR 2021

MAR 2021

MAY 2021

FEB 2021

JUN 2021

AUG 2021

JUL 2022

OCT2021

NOV2021

JAN2022

APR 2022

MAR 2022

SEP 2021

MAY 2022

DEC 2021

FEB 2022

JUN 2022

AUG2022

OCT 2022

NOV 2022

JAN 2023

SEP 2022

DEC 2022

FEB 2023

MAR2023

APR 2023

MAY 2023

JUN 2023

AUG 2020

AUG 2023

NOV 2020

DEC 2020

Page 2 of 2

121

60

137

5

212

106

411

15

67

57

21

17

Degas; Apply

f irst perm it

First TG Permit

Applied

U3

B/O

Apply Addit ional

Bloc ksMain TG Permit

Applied

120

A

B

90

CD1/2/3 New Seal Install, Scaf fold Removal & Close, CCD

140

CD1/2/3 Open Waterboxes, Eddy Current, SCR Inspect ionsD

W248 Static Commissioning- TC-EC-Gen Aux Skids

From

W002

Conv S ide

Drain

IPB & Airbox Ins tall & CCD

77

W251 – Generator Reassembly

Final Inst rum entat ion Work & CCD

Cables Dis connects &

Panel s Di smantle

45

MCR, UCER & DCC Work

B

196

New Cabinets, Cable Pulling & Cable T erm inati on, Post-reqs & CCD

168

Termi nations, Verif ications , & Components Install

Cubic les & Equipment Ins tall , Cables Install & Termi nations, Post-reqs , CCD

Cables, Equipment & Cubic les R em oval

210

Skid Instal l, New M CC, Cable Pull & New Panel Install Acti vit ies, Post-reqs & CCD50

Pre-fab & Skid Removal Activ it ies

All Skids Instal l & CCD28B

196

CD 1/2/3 Open, Install Dance F loor, S trut Inspect ions & Replacements

C

MSR T B 1/4/5/6/7/8 Inspections Activ it ies, MSR 1/2 Close & Post A ir Hold

30

MSR 1/2 Open & P re Ai r Hold

W240 MOCPER Removal

W241 MOCPER-MCR-UCER Installation & Mods

W242 Turbine Control Hydraulics Removal and Install

W243 Excitation Controls Removal

W244 Excitation Controls Installation

W247 Hydrogen Cooling Skid Modif ication

W256 Condenser and MSR Maintenance

W246 Seal Oil Skid Modif ication

90

IPB & A irbox Rem oval

W249 – Generator Disassembly

168

Removal and Instal l of T SS & TC FI Components

W259 General Mods Work

180

18

GE Integration workFront Standard

Pre-fabs & P re-reqs50 24 70

Removal Act iv ities

Install, Cable T ie-ins and Connect ions, Post-reqs & CCD

W245 SCW Skid Modificat ionB

To RCHP 5 DNRU1 Breaker Open

A First TG Permit

B Second TG Permit

C CCW Outage Start

D CCW Outage Finish

Window Start Milestone

Window Finish Milestone

CCD

GE Integration w ork

Seal I ns ert ion

30

MSR Drains

30

Post-reqs & CCD

W258 – General Maintenance Activities

5

W250 – GE Execution

Generator Mtce

Center L ine Mtc e

Init ial

Airbox L inks

Remov al

Jacking Oi l PS

Pre-fabs & P re-reqs

B

B

W058 – CCW

W259 General Mods Work CON’T


To W248 Static Commissioning

Note: W248 Static Commissioning Exception for Rev 2


To Feeder Scanner Replacement (Removed f rom U 1 and O verhauled)

From W058CCW Compl ete U1 Outage 2020 (D2011) U2 Outage 2023 (D2321)U4 Outage 2021 (D2141)

DNRU1 Breaker Open

U1S/D Feeder

Cabinet Removal Feeder Rem oval

PT Sever

Sever Bellows

End Fit ti ng Removal

CT/PT Removal

Dumm y FB Removal

Defuel Reactor InstallAPT Install Bulkhead

Containm ent Test Bulk Interference

Removals

Comm ission VVRS

Remove F M Bridges & Install RT Ps

Crane Mai ntenance

Install Shielding

CTI Release

CTI Removal

Vessel Inspection


Bellows Inspections

CT Install


















Outage Day9600 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 740 760 780 800 820 840 860 880 900 920 940 980 10201000 1040 1060

Revision A1July 30, 2020

1080 1100

FEB 2022

MAR 2022

APR 2022

MAY 2022

JUN 2022

AUG 2022

JUL 2022

FEB 2023

NOV 2022

OCT 2022

DEC 2022

SEP 2022

JAN 2023

MAR 2023

APR 2023

MAY 2023

JUN 2023

AUG 2023

JUL 2023

FEB 2024

NOV 2023

OCT 2023

DEC 2023

SEP 2023

JAN 2024

MAR 2024

APR 2024

MAY 2024

JUN 2024

AUG 2024

JUL 2024

FEB 2025

NOV 2024

OCT 2024

DEC 2024

SEP 2024

JAN 2025

To RCHP 7




Moderator WindowsMiscellaneous WindowsConv Water Windows

SDC Valves East S ide

VVRS Mods and Rehab

Gross Leak Test5d

Inst Air Mtce

Moderator Test ing

P&IC & SDC PurgeHTS Aux Vac Dry

Mod Drain & Flush


To Tie-in for Mod Vac Dry

To Mod Drain



Hold out for warmer temps

To Gross Leak Test

Connect to HTS System HTS Vac Dry

048

079081

035

140

108

123

Vault Projects104

SDC Valves, PULSW Lines, & ASDC Pumps

Temp Fission Chamber Install

129HTSVac Dry Pre-Req’s

Vault Projects105

HTS Rehab - Outside Vault

Remove SG Layup

ECI NV Inspections

To RCHP 4(Layup)


RCHP1

029029

208


Isolate Calandria & Hookup Drying Equip.

From HTS Vac Dry

Complete

Upper & Middle Feeder Installation

HFD Replacements

038

073

078

045 076


To RCHP 5

RCHP2

LZCS To RCHP 5

089


REMOVAL - SEGMENT 2A REMOVAL – SEGMENT 2BLEAD IN - SEGMENT 1 INSTALL – SEGMENT 3 LEAD OUT – SEGMENT 4


Overhaul Air Skid

Alignments

Vac Dry Lower Mod PipeworkModerator Valve Rehab

Alignments

103 Purge


PULSW P iping R-015 ASDC Interference Aux. SDC Pum p Install ation

Vac Dry

Primary Side SG Clean & Inspect062

ECI Valve Mtce

028

From SG Access Ports, EHS Outside Vaul t & HTS Pump Insp

Clean Vault Conditi ons In-E ffect

189

029

From Instal l HTS Pump Motors and Adjuster Rods Removed

Establish GSS

216

128



197Nuclear Side Restoration


To Complete EHS (E. Vault)

Complete EHS Pipework (E. Vault)From S outh A CU 4

replacem ent& V aul t Projects

007

State 3aState 1 State 2 State 4bState 3b State 4a State 5

Fill Calandria 5d

080


Purge to be applied pri or to CTI release and m aintai ned unti l all CT’s have been replaced


068


Vessel Inspection

Feeder Removal

PT Sever

Sever Bellows

End Fitt ingRemoval Fuel Channel Installation Series

CT/PT Removal

Dummy FB Removal



CTI Release

084

083119117098

116

112 113 114

111

042

074

Defuel Reactor

Install APT & End Fitting Caps

012

017

Install Bulkhead



- Final Commissioning VVRS Phase 1- AL & TCD Logic Mods- Breathing Air Tie-in


024

137

027

101Full Vault Access


Bellows Inspections

072

Calandria Tube Install Series118

122

To SDS2 Computers

W007


To SG SS M tce W037& EHS i nside HT P 4 Rm

Removal Replacement

SDS2 Computer Replacements007From HTS Bulk Drain Complete

From W103 Purge

ReplacementsRemovals021 021Replace Adjuster Rods

To SG Prim ary Side Clean & Install HT S Pumps

To RCHP 2

SouthACU 4&3

(ACU4 Complete)



To RCHP 1

From SG Primary Side Clean

LISS Rehab

OP GSS in effect

To Inst Ai rMtce

HTS Bulk Drain

013

To Remove Mod Dry Equip

From Inst Air Maint

HTS Operational Test ing (includes ASDC)

RCHP7

RCHP6

RCHP5


RCHP3


Bulkhead Post-Reqs

Bulkhead Removal

- Shielding Rem’d- A/L Closed- Pressure Test- VVRS Balance


1d

146

097

088

085

094




092095

096

093

High Power Testing & Turbine Test ing

Power Escalation


193

082


SG Wet Recirc Layup Removal

Includes IUFT and N2 B lanket removal

1010 days

222


235

NorthACU 1&2

To RCHP 4


Removal & PULSW P iping R-016

From HTS Vac Dry

Complete

From HTS Aux Vac Dry Complete

EHS Outside Vault106Hold out for

P roject Resources Inside HT P4 Rm

From VF D Removal E HS Inside Vault


To EHS (E.Vault)

Install Lower Body Supports

LBS Cabinet Frame Tie-in

Feeder Visual Inspections & Stairway Install

090

Fuel LoadGroup 4

RTP Config 1,OB Columns & Elec Removal

4 11624 42 120359 11 9 164590 5 105011 247 25 16 89 197 5 127 196 9 16939 27 37

VVRS Mods and Rehab

3 12 5

001U1 S/D 1d

Crane Maintenance 3d

015Install Shielding

22

DNRU1StartFeb 15/22

33 months

DNRU160% CP

Complete

CCW W058

054

From VF D Removal

Secondary Side SG Clean & Install Access Ports037 SG Nitrogen Blanket Install

Recal l Installed for Secondary Containm ent


RHP 1 RHP 4

RHP 2

RHP 3

RemoveHTS Pump Motors

Vaul t Access rest rictions due to Critical Lift s

022

Install HTS Pump MotorsHold out for motor availabili ty

Coordinate wi th Crit ical Path Work - Vaul t Access Restricti ons due to Crit ical Lif ts

060HTS Pump Impeller Inspect065

Pumps Lif ted into place


To RCHP 4

To SG PS Cl ean P re-req W062A

From Remove Adjuster Rods

From VF D Removal

028

124 124124

124

Page 1 of 2

Unit 1 Refurbishment – DNRU1 Level 1 Overview


190

025 149

192

234

231

232

233

023

230

121

147

009

063

046

032

064

103

070

To DNRU4 W002 (IUFT Availability)

Hold O ut BWXT Resources


158AA Mechanism

Removal

To Containm ent Press Test W024 &Replace Veri tcal F lux Detectors W028

SA & CA Rods

Install SG Layup Primary Side034

031

CTI Removal

RCHP8

Hold out as l ate as possi ble

RCHP9

RCHP4

067

To HTS Vac Dry Draining Boilers

SG Nit rogen B lanket Installed

EPS MCC RehabCL II Elec. Maintenance

005

CL IV Elec. MaintenanceHold out for Bkrs & Relays from Cl I II

From Isolate Calandria & Hookup Drying Equip

Perm it Appl ied

BUS A & C BUS B040

IPB/Switchyard Rehab

To RCHP 7

004Hold out for Warmer T emperatures

MOT/UST Removal MOT/UST Install008 008

CL III Elec. Maintenance041

051

MOT/UST Fire Protection270

040Hold out for Winter Months (BU13) From MO D Vac Dry

To LPSW/PULSW To RCHP 1

To RCHP 7

To RCHP 1

To RCHP 2

LPSW OutageWinter (need cold water tem ps – L15 work) 057

PULSW OutageHold out for Cooler Tem ps

Tem p Power Req’d for South Side Drai nage Sum ps

To RCHP 5

056

CCW RehabP umpwell Cl eaning

055

USCA ACU Line Replacements053ESW Rehab053

RCW Work195 To RCHP 4Hold out for Valve & IRI Resources

1.

2.

3.

Critical Window

Restart Contr ol Hold Point

Reac tor St ates


State 2: Guarant eed Shut down with Irr adiated Fuel Cor e



State 4a: Non Irr adiated Fuel & Isolated from Containment

State 4b: Non Irr adiated Fuel S tat e


NOTES

11 Duration (days)

Window #

Window Name SGs

Window #

Window Name

Non-Critical Window

084

Fuel Load

RHP

Regulat ory Hold Point

062

RCHPx


RCHP2: Fuel Load

RCHP3: Bulkhead R emoval

RCHP4: Heat Transpor t Syst em Fill

RCHP5: GSS Removal




RCHP9: Unit Available for Commercial Operation

4. RCHP

U2 Outage 2023 (D2321)

Feeder Cabinet Removal Feeder Rem oval

PT Sever

Dumm y FB Removal

Defuel Reactor

SD

InstallAPT Install Bulkhead

Containm ent Test


Final Comm issioning VVRS Remove F M Bridges &

Install RT Ps

Crane Mai ntenance

Install Shielding

Unit 4 Refurbishment Outage (DNRU4)Sever Bellows


Fuel Channel Installat ion Seri es Lower Feeder Install SeriesCalandria T ube Install SeriesBulkhead Removal

Fuel LoadGroup 1,2,3 & Hanging Scaffol d

Install Lower Body Supports Feeder Lower

Body Tubing

Bulkhead Post-Reqs

NPC Logic Restoration 1d ATC &

Fission Chamber removal


High Power Testi ng & Turbine Testi ng

Feeder V isual Inspections & Stairway Instal l

- A/L Closed- P ressure Test- VVRS Balance

Heat-up& Hot Conditi on Heat-up

& Low Power Testi ng

Power Escalati on

RTP Removals, B ri dge Replacem ent

LBS Cabinet Frame Tie -in

Operating Units Fuel Run Vessel

Inspection End Fit ti ngRemoval

CTI Removal

CT/PT Removal

CTI Release


Bellows Inspections Calandria T ube Install Series

DNRU360% CP

Complete

Conventional Side Restoration196

Condensate & Feedwater RTS198

To RCHP 5 & D2321 Outage

Perm its Applied for OPS Resources

003

DNRU3 W198 RTS complete

IUF T Avail abi lit y

SG Layup (Recirc. Skids)

Heat Sink – Boiler Ski ds

comm issioned, HP Demin Connected


CFW Drained, RV’s Removed & B locked

Condensate & Feedwater010

CCW058

Connect Conv Side Dryers019

106

MPO Protection Upgrade159

270MOT/UST FP

Commissioning

272MOT/UST Replacment

Commissioning

To LPSW/PULSW

From CLII I & MO D Vac Dry


Degas & Permitry

TG Stat ic Commissioning

To MOCPER Comm issioni ng



See Page 2 for TG Project Level 1To RCHP 5 & DNRU4A

B

C

DFirst TGPerm it

SC1

Second TGPerm it

Generator & Shaft line Mtce

From W241 Complete

From W249 Complete

From W256 Fini sh to W019 & W198 Condensate Feedwater RTS

Hold out for t raini ng post AA Rods


https://opgreporting.sharepoint.opg.com/Nuclear/strat/nr/Documents/Unit-1/Level%201%20Overview/SwitchBoards/048-U1-SwitchBoard.pdf
























































































































http://opgreporting.corp.opg.com/sites/BI/Nuclear/nucproj/nr/Documents/Level 1 Overview/Level 1 Overview/SwitchBoards/L1_LP_084.pdf













Outage Day9600 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 740 760 780 800 820 840 860 880 900 920 940 980 10201000 1040 1060

Revision A1July 30, 2020

1080 1100

FEB 2022

MAR 2022

APR 2022

MAY 2022

JUN 2022

AUG 2022

JUL 2022

FEB 2023

NOV 2022

OCT 2022

DEC 2022

SEP 2022

JAN 2023

MAR 2023

APR 2023

MAY 2023

JUN 2023

AUG 2023

JUL 2023

FEB 2024

NOV 2023

OCT 2023

DEC 2023

SEP 2023

JAN 2024

MAR 2024

APR 2024

MAY 2024

JUN 2024

AUG 2024

JUL 2024

FEB 2025

NOV 2024

OCT 2024

DEC 2024

SEP 2024

JAN 2025


DNRU160% CP

Complete

Critical Path Windows

Page 2 of 2

Unit 1 Refurbishment – DNRU1 Level 1 Overview – TG Project

60

SC1

A First TG Permit

B Second TG Permit

To MOCPER Static Comm

SC2 To Excitation Static Comm

SC3 To SCW Static Comm

SC4 To Seal Oil Static Comm

SC5 To H2 Static Comm

SC6 To TSS Static Comm

SC7 From MOCPER Static Comm

C CCW Outage Start

D CCW Outage Finish



21

17

Degas; Apply

f irst perm it

First TG Permit

Applied

U1

B/O

Apply Addit ional

Bloc ks

Main TG Permit

Applied

TC MO CPER Panels SC

Jacking Oi l/SVs, PTs, N Ss SC

FRF Hy draulic s SC

Exc itat ion Controls SC

Seal O il Skid S C

TSS Modif ications SC

SCW Skid SC

H2 Skid SC

A

B

MO CPER Cables

Di sc onnects & Di smantle

MCR , UCER & DC C Work

Cabinets Ins tall

B

Cable Pulli ng & Termi nation Lights, Ins pec ti ons

& CCD

SC1

Components Removal Components Ins tall Termi nations, Veri fic ati ons,

Post-reqs

Cable

Remov alCubic les I nstall

Equipment

Remov al

Cubic les R em oval

Cables Install & Termi nations Post-reqs & CCD

SC2

Ol d Skid Removal N ew Skid I nstal l T ie-ins and Connec ti ons L ights, Post-

reqs & CCD

SC3

Cable & Panel Ins tall Act iv iti esSkid Rem ov al Act iv iti es Skid Ins tal l Act iv it ies Final Equipment Work

and CCD

SC5

All Ski ds R em ov al

All Ski ds M ec h Ins tall

All Ski ds I&C /

Elec Install

Seal O il

Skid CCD

B SC4

CD 1/2/3 Open &

Ins tall Danc e Fl oo rCD 1/2/3 Strut I nspections & Repair

CD1/2/3 Open W aterboxes, Eddy Current , SCR Inspec tions

C D

MSR TB 4/5/6

Ins pec ti ons Activ it ies

MSR 1/2 Open

& Pre Air Hold

SC4

SC5

SC7

SC2

SC6

HG 09 SC

W240 MOCPER Removal



W243 Excitation Controls RemovalW244 Excitation Controls Installation

W245 SCW Skid Modification


W247 Hydrogen Cooling Skid Modification


W246 Seal Oil Skid Modification

SC3

SC7

Air H old Tes t

Generator CCD

Dem ag , Seal O il Flus h &

Air H old Tes t Act iv it ies

IPB & Airbox Remov al

W249 Generator Disassembly

From W002

Conv S ide Drain

W250 Generator

MtceIPB & Airbox Ins tall

Remov al and Ins tall of TSS & TC FI Com ponents

SC6


W250 Shaft Line

Mtce

B

W251 Generator Reassembly

SC2

CD1/2/3 Seal Replac em ent &

Sc affol d Removal and Close

GE Mobilization &

Dedicated TH CR1

GE Dedicated

TH CR1 & CR2


TC FI CC D

DN RU1 TG

Pre-Reqs


Front Standard

GE Demobilization &

Dedicated TH CR1

Limited Access to U1 115 EL. TH Area

REMOVAL - SEGMENT 2A REMOVAL – SEGMENT 2BLEAD IN - SEGMENT 1 INSTALL – SEGMENT 3 LEAD OUT – SEGMENT 4

GE Generator & Shaft Line Maintenance

Valve Pos it ioni ng & CCD


PSS Probes

B

Post G E TS S Work

TSS CCD

SC1

SC5

MSR 1/2 Clos e

& Post Air H ol d

To RCHP 5

& DNRU4

Breaker Open

SC7

SC1

Seal O il

Mtce CCD

Condens er

CCD

MSR Post-req

& CCD

CCW W058 U2 Outage 2023 (D2321)

Feeder Cabinet Removal Feeder Rem oval

PT Sever

Dumm y FB Removal

Defuel Reactor

SD

InstallAPT Install Bulkhead

Containm ent Test


Final Comm issioning VVRS Remove F M Bridges &

Install RT Ps

Crane Mai ntenance

Install Shielding

Unit 4 Refurbishment Outage (DNRU4)Sever Bellows


Fuel Channel Installat ion Seri es Lower Feeder Install SeriesCalandria T ube Install SeriesBulkhead Removal

Fuel LoadGroup 1,2,3 & Hanging Scaffol d

Install Lower Body Supports Feeder Lower

Body Tubing

Bulkhead Post-Reqs

NPC Logic Restoration 1d ATC &

Fission Chamber removal



Feeder V isual Inspections & S tairway Instal l

- A/L Closed- P ressure Test- VVRS Balance



Power Escalati on


LBS Cabinet Frame Tie -in

Operating Units Fuel Run Vessel

Inspection E nd Fit ti ngRemoval

CTI Removal

CT/PT Removal

CTI Release


Bellows Inspections Calandria T ube Install Series

DNRU360% CP

Complete

















Outage Day9600 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 740 760 780 800 820 840 860 880 900 920 940 980 10201000 1040 1060

Revision A DRAFTJune 5, 2020

AUG 2023

JUL 2023

FEB 2024

NOV 2023

OCT 2023

DEC 2023

SEP 2023

JAN 2024

MAR 2024

APR 2024

MAY 2025

JUN 2025

AUG 2025

JUL 2025

FEB 2026

NOV 2025

OCT 2025

DEC 2025

SEP 2025

JAN 2026

MAR 2026

APR 2026

MAY 2026

JUN 2026

AUG 2026

JUL 2026

MAY 2024

JUN 2024

AUG 2024

JUL 2024

FEB 2025

NOV 2024

OCT 2024

DEC 2024

SEP 2024

JAN 2025

MAR 2025

APR 2025




Moderator WindowsMiscellaneous WindowsConv Water Windows

Review Purposes Only U2 Outage 2025 (D2521)

Unit 4 Refurbishment – DNRU4 Level 1 OverviewPage 1 of 2

Unit 1 Refurbishment Outage (DNRU1)Fuel Channel Installat ion Seri es Lower Feeder Install SeriesCalandria T ube Install Series

Bulkhead Removal

Fuel Load Group 1,2,3 & Hanging Scaffol dInstall Lower

Body Supports


Bulkhead Post-Reqs

NPC Logic Restoration 1d ATC & Fission

Chamber Rem ovalRun-up & Sync & Balance


Feeder V isual Inspect ions & S tairway Instal l

- Shielding Rem’d- A/L Closed- P ressure Test- VVRS Balance



P ower E scalati on


LBS Cabi net Frame Tie-in

VVRS Mods and Rehab

SDC Valves East S ide

125BU16 Maintenance

Transformer& Bus Maintenance

127

T10/12 BU10/12

To TPDS & Even/Odd Elect rical Outage

To VVRS Commi ssioning & Even/Odd Electrical Outage

Gross Leak Test5d

EPS MCC Rehab

Install SG Layup Primary Side

CL I I Elec. Maintenance

Inst Air Mtce

LPSW Outage

USCA ACU Line Replacements

Moderator Test ing

P&IC & SDC PurgeHTS Aux Vac Dry

Mod Drain & Flush


To Tie -in for Mod Vac Dry

To Mod Drain



Hold out for warmer temps

To Gross Leak Test

To RCHP 1

Connect to HTS System HTS Vac Dry

005

048

053

057

079081

PULSW Outage

035

108

123

Vault Projects104

Hold out for Cooler Tem ps

SDC Valves & PULSW Line Replacement & ASDC Pumps

Temp Fission Chamber Install129

HTSVac Dry Pre-Req’s

Hold out for TCB declared &

Tem p Vault ACU’s Installed

HTS Rehab - Outside Vault

Tem p Power Req’d for South Side Drai nage Sumps

To RCHP 5

Remove SG Layup

ECI NV Inspections

RCW Work195

To RCHP 4(Layup)


RCHP1

029029

056

067

208

LZCS


Isolate Calandria & Hookup Drying Equip.From HTS Vac

Dry Complete

HFD Replacements

032

038

073

078

045


To RCHP 5

RCHP2

To RCHP 5

RCHP4


To RCHP 4



Overhaul Air Skid

Alignments

121Vac Dry Lower Mod Pipework

CL IV Elec. Maintenance

Moderator Valve Rehab

Alignments

103 Purge


Hold out for Bkrs & Relays from Cl I II

CCW Rehab

PULSW P iping R-015 ASDC Interference Aux. SDC Pum p Install ation

Vac Dry

From Isolate Calandria & Hookup Drying Equi p Perm it Appl ied

040 BUS A & C BUS B

CL III Elec. Maintenance041

Primary Side SG Clean&Inspect062

147147 ECI Valve Mtce

028

From SG Access Ports


189

029

From Instal l HTS Pump Motors & Adjuster Rods

Removed

To RCHP 2

Establish GSS

216

128



Nuclear Side Restoration


To Complete EHS (E. Vault)

Complete EHS Pipework (E. Vault)From South ACU 4

replacem ent& Vaul t Projects

007


Fill Calandria 5d

080

SA & CA Rods031

To LPSW/PULSW

From MO D Vac Dry


Purge to be applied pri or to CTI release and m aintai ned unti l all CT’s have been replaced


068


Vessel Inspection

Feeder Removal

PT Sever

Sever Bellows

End Fitt ingRemoval

CTI Removal

Fuel Channel Installation SeriesCT/PT Removal

Dummy FB Removal



CTI Release

084

083119117098

116

112 113 114

192

111

042

074

Defuel Reactor

Install APT & End Fitt ing Caps

012

017

Install Bulkhead



- Final Commissioning VVRS Phase 1- AL & TCD Logic Mods- Breathing Air Tie-in


024

137

027

023101Full

Vault Access


149

Bellows Inspections

072

Calandria Tube Install Series118

Pumpwell Cl eaning

055

051

103

122

RRS LM Replacements

To SDS2 Computers

W007


To SG SS M tce W037& EHS i nside HT P 4 Rm

Removal Replacement

SDS2 Computer Replacements007

From HTS Bulk Drai n Complete

From W103 Purge

ReplacementsRemovals021 021Replace Adjuster Rods

To SG Primary S ide Clean

To RCHP 2

(ACU4 Complete)



To RCHP 1

From SG Pri mary Side Clean

LISS Rehab046

OPGSS in effect

040 040

To Inst AirMtce

HTS Bulk Drain

013

IPB/Switchyard RehabTo RCHP 7

004Hold out for Warmer T emperatures

MOT/UST Removal MOT/UST Install008 008

To Remove Mod Dry Equip

From Inst Air Maint

HTS Operational Test ing (includes ASDC)

RCHP8

RCHP7

RCHP6

RCHP5


190

RCHP3


Bulkhead Post-Reqs

Bulkhead Removal

- Shielding Rem’d- A/L Closed- Pressure Test- VVRS Balance


1d

146

097

088

085

094




092095

096

093

High Power Test ing & Turbine Testing

Power Escalation


193

082


SG Wet Recirc Layup Removal

Includes IUFT and N2 B lanket removal

980 days

222


235

To RCHP 4


Removal & PULSW P iping R-016


From HTS Aux Vac Dry

Complete

Hold out for P roj ect Resources

From VF D Removal

EHS Inside Vault


230 Install Lower Body Supports

233LBS Cabinet Frame Tie-in

234Feeder Visual Inspections & Stairway Install

090

Fuel LoadGroup 4

RTP Config 1, OB Columns & Elec Removal

3 11223 41 116349 11 9 15444 104810 237 24 15 86 186 57 185 9 15938 26 363 12 5

001U4 S/D 1d

Crane Maintenance 3d

015 Install Shielding

02521

DNRU4StartSep 15/23

009

90

32 Months

DNRU460% CP

Complete

054

126

T9/11 BU9/11Transformer

& Bus Maintenance Hold out for winter months (BU13/BU14)

RHP 4RHP 1

RHP 3

From VF Ds Removed

Secondary Side SG Clean & Install Access Ports037063 SG Nitrogen Blanket Install


RemoveHTS Pump Motors

Vaul t Access rest rictions due to Critical Lift s

022

Install HTS Pump Motors

Coordinate wi th Crit ical Path Work - Vaul t Access Rest rictions due to Crit ical Li ft s

HTS Pump Impeller Inspect065

Pumps Lif ted into place


To RCHP 4

To SG PS Cl ean

From Remove Adjuster RodsFrom VF D

Removal

124

124

124124

ESW Rehab053

197

1.2.

3.

Critical Window

Restart Control

Hold PointRCHP

x

Reactor States








NOTES

11Duration (days)

Window #

Window Name

062SGs

Window #

Window Name

Non-Critical Window084

Fuel Load

Regulatory Hold

PointRHP

060

064 SouthACU 4&3

NorthACU 1&2

070

Upper & Middle Feeder Installation076

221

034

12

RHP 2

231

232

RCHP9

To Remove Adjuster Rods EHS Outside Vault Inside HT P4 Rm106

To EHS (E.Vault)

Vault Projects105

140

Winter (need cold water temps – L15 work)

003

089

BWXT Resources



RCHP2: Fuel Load

RCHP3: Bulkhead Removal

RCHP4: Heat Transport System Fill

RCHP5: GSS Removal




RCHP9: Unit Available for Commercial

Operation

Reviewed by:

Reviewed by:

Andrew Negenman, Outage Director

David Deveau, Outage Manager

REV A APPROVALS TO ISSUE

Updated by:Chris Stewart, Outage Section Manager

DRAFT

Defuel Completed

Hold out for Valve & IRI Resources

158AA Mechanism

Removal

To Containm ent Press Test W024 &Replace Veri tcal Flux Detectors W028

MPO Protection Upgrade159

SG Layup (Recirc. Skids)

Condensate & Feedwater RTS198

To RCHP 5 & D2521 Outage Perm its Applied for OPS Resources

DNRU1 W198 RTS complete

IUF T A vail abi lit y


CFW Drained, RV’s Removed & B locked

Condensate & Feedwater010

CCW058Connect Conv Side Dryers019


Degas & Permitry TG Stat ic Commissioning

To MOCPER Comm issioni ng



See Page 2 for TG Project Level 1To

RCHP 5A

B

C

DFirst TGPerm it

SC1

Second TGPerm it

Stator Rewind & Shaft Line Mtce

From W241 CompleteFrom W249

Complete From W256 Fini sh to W019 & W198 Condensate Feedwater RTS

Heat Sink – Boiler Ski ds

comm issioned, HP Demin Connected

196Conventional Side Restoration

Recal l Installed for Secondary Containm ent

To HTS Vac Dry Draining Boilers

MOT/UST Fire Protection270 270MOT/UST FP

Commissioning

272MOT/UST Replacment

Commissioning

To RCHP 7






































































https://opgreporting.sharepoint.opg.com/Nuclear/nucproj/nr/Documents/Unit 3 Level 1 Overview/SwitchBoards122/-U3-SwitchBoard.pdf







































































Outage Day9600 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 420 440 460 480 500 520 540 560 580 600 620 640 660 680 700 720 740 760 780 800 820 840 860 880 900 920 940 980 10201000 1040 1060

Revision A DRAFTJune 5, 2020

AUG 2023

JUL 2023

FEB 2024

NOV 2023

OCT 2023

DEC 2023

SEP 2023

JAN 2024

MAR 2024

APR 2024

MAY 2025

JUN 2025

AUG 2025

JUL 2025

FEB 2026

NOV 2025

OCT 2025

DEC 2025

SEP 2025

JAN 2026

MAR 2026

APR 2026

MAY 2026

JUN 2026

AUG 2026

JUL 2026

MAY 2024

JUN 2024

AUG 2024

JUL 2024

FEB 2025

NOV 2024

OCT 2024

DEC 2024

SEP 2024

JAN 2025

MAR 2025

APR 2025


DNRU460% CP

Complete

Critical Path Windows

Page 2 of 2Unit 4 Refurbishment – DNRU4 Level 1 Overview – TG Project



Assumptions:

This is a copy and paste from DNRU1. Stator Rewind hasn’t been

included

Level 1 is not a roll-up of the Level 3 schedule

Level 1 is only meant for planning purposes

Refer to P6 Schedule for actual execution timelines

Revised Permitry timelines still to be discussed and reviewed

GE scope of the work does not utilize any Execution Windows

All ties have not be confirmed and are still under review

IRI Resources review at a Program level has not been yet reviewed

Post-Maintenance layup scope (W261) is still to be determined

Unit 1 Refurbishment Outage (DNRU1)Fuel Channel Installat ion Seri es Lower Feeder Install SeriesCalandria T ube Install Series

Bulkhead Removal

Fuel Load Group 1,2,3 & Hanging Scaffol dInstall Lower

Body Supports


Bulkhead Post-Reqs

NPC Logic Restoration 1d ATC & Fission

Chamber Rem ovalRun-up & Sync & Balance


Feeder V isual Inspect ions & S tairway Instal l

- Shielding Rem’d- A/L Closed- P ressure Test- VVRS Balance



P ower E scalati on


LBS Cabi net Frame Tie-in

Reactor States








GE Generator & Shaft Line Maintenance

U2 Outage 2025 (D2521)

60

SC1

A First TG Permit

B Second TG Permit

To MOCPER Static Comm

SC2 To Excitation Static Comm

SC3 To SCW Static Comm

SC4 To Seal Oil Static Comm

SC5 To H2 Static Comm

SC6 To TC Hydraulics Static Comm

SC7 To FRF Static Comm

C CCW Outage Start

D CCW Outage Finish

SC8 To TSS Static Comm

SC9 From MOCPER Static Comm



21

17

Degas; Apply

f irst perm it

First TG Permit

Applied

U1

B/O

Apply Addit ional

Bloc ks

Main TG Permit

Applied

TC MO CPER Panels SC

Jacking Oi l/SVs, PTs, N Ss SC

FRF Hy draulic s SC

Exc itat ion Controls SC

Seal O il Skid S C

TSS Modif ications SC

SCW Skid SC

H2 Skid SC

A

B

MO CPER Cables

Di sc onnects & Di smantle

MCR , UCER & DC C Work

Cabinets Ins tall

B

Cable Pulli ng Cable Term ination L ights, Ins pec ti ons

& CCD

SC1

Components Removal Components Ins tall Termi nations, Veri fic ati ons,

Post-reqs

Cable

Remov alCubic les I nstall

Equipment

Remov al

Cubic les R em oval

Cables Install & Termi nations Post-reqs & CCD

SC2

Ol d Skid Removal N ew Skid I nstal l T ie-ins and Connec ti ons L ights, Post-

reqs & CCD

SC3

Cable & Panel Ins tall Act iv iti esSkid Rem ov al Act iv iti es Skid Ins tal l Act iv it ies Final Equipment Work

and CCD

SC5

All Ski ds R em ov al

All Ski ds M ec h Ins tall

All Ski ds I&C /

Elec InstallCCD

B SC4

CD 1/2/3 Open, Ins tall Danc e Fl oor

CD1/2/3 Strut I nspectionsCD1/2/3 Strut R epairCD 1/2/3 Strut I nspections

CD1/2/3 Open W aterboxes, Eddy Current , SCR Inspec tions

C D

MSR TB 4/5/8

Ins pec ti ons Activ it ies

MSR 1/2 Open

& Pre Air Hold

SC4

SC5

SC6

SC7SC6

SC9

SC2

SC8

HG09 SC

W240 MOCPER Removal



W243 Excitation Controls RemovalW244 Excitation Controls Installation

W245 SCW Skid Modification


W247 Hydrogen Cooling Skid Modification


W246 Seal Oil Skid Modification

SC3

SC9

Air H old Tes t

Generator CCD

Dem ag , Seal O il Flus h &

Air H old Tes t Act iv it ies

IPB & Airbox Remov al

W249 Generator Disassembly

From W002

Conv S ide Drain

Generator Mtce

IPB & Airbox Ins tall

Remov al and Ins tall of TSS & TC FI Com ponents

SC8


Shaft Line Mtce

B

W251 Generator Reassembly

SC2

CD1/2/3 Sc affol d Removal and Close

GE Mobilization &

Dedicated TH CR2

GE Dedicated

TH CR1 & CR2


TC FI CC D

DN RU4 TG

Pre-Reqs


Front Standard

GE Demobilization &

Dedicated TH CR2

Limited Access to U4 115 EL. TH Area

DRAFT for Review Purposes Only

Valve Pos it ioni ng

& CCDSC6

SC7


PSS Probes

B

Post G E TS S Work

TSS CCD

SC1

SC5

MSR 1/2 Clos e

& Post Air H ol d

To

RCHP 5

SC9

SC1

















REMA.3.3G :3.TS SCHED:LE - files.opg.com

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Transcript of REMA.3.3G :3.TS SCHED:LE - files.opg.com