Issued by RPP-WTP PDC Library/New... · RPP-WTP PDC 09-14-15. 24590-WTP-ICD-MG-01-011, Rev 7 ... Table 1 Revised to reflect the new formatting changes, added new column “Interface

Document title: ICD 11 Interface Control Document for Electricity

Document number: 24590-WTP-ICD-MG-01-011, Rev 7

Contract:

Department:

NOTE:

Approved by:

Issue Status:

Date Issued:

River Protection Project Waste Treatment Plant 2435 Stevens Center Place Richland, WA 99354 United States of America Tel: 509 371 2000

DE-AC27-01RV14136 Contract deliverable: C.9.1

Project Management

All Interface Partner concurrence signatures found on the following

page shall be obtained prior to approval of this ICD.

1;/4/;~ 1 Date •

BNI Area Project Manager

Approved

NOTE: This document defines current service needs, future needs, and service gaps. The identified service levels do not represent contractual obligations between service recipient and providers. Future contractual and funding actions to close service gaps will be accomplished by integration between the federal offices as part of the budget planning process.

24590-MGT-F00022 Rev 2 (Revised 5/12/2015) Ref: 24590-WTP-GPP-MGT-003

Issued byRPP-WTP PDC

09-14-15

24590-WTP-ICD-MG-01-011, Rev 7 ICD 11 lntelface Control Document for Electricity

Interface Partner Concurrence Interface partners, as appropriate, will sign this concurrence sheet indicating their concurrence with the ICD contents. These concurrence signatures signify that the ICD accurately reflects the current baselines of interface partner's contracts, except as indicated in Appendix A, Open ICD 11 Issues and Actions. This ICD shall not be approved until all required concurrence signatures on this page have been obtained.

' Organization

WTP Contractor

WTP Contractor

TOC

MSC

PRC

RL

ORP-WTP

ORP-TF

ORP-WSC

ORP-TF

ORP-WTP

Position

ICD 11 Team Lead and Principal Author

Prime Contracts Manager

ICD 11 Interface Owner



Name

Jaideep Singh

Elizabeth Winkelman

Rick Tedeschi

Randy Adkins

NIA

ICD 11 Interface Owner Sharee Dickinson

ICD 11 Interface Owner Kaylin Burnett

ICD 11 Interface Owner NIA

Assistant Manager for WTP Startup, Commissioning and Inte ration

Assistant Manager for Tank Farms Project

Assistant Manager for WTP Project

Ben Harp

Tom Fletcher

Bill Hamel

24590-MGT-F00022 Rev 2 (Revised 5/12/2015)

NIA

NIA

Signature Date

'1-1- JS"

9-/{J --/:J

NIA

NIA

Page ii Ref: 24590-WTP-GPP-MGT-003

24590-WTP-ICD-MG-01-011, Rev 7

ICD 11 Interface Control Document for Electricity

Page iii

24590-MGT-F00022 Rev 2 (5/12/2015) Ref: 24590-WTP-GPP-MGT-003

History Sheet

Rev Date Reason for revision Revised by A 16 July 2001 Issued for ORP concurrence R Parazin

0 14 March 2002 Provided for ORP Contracting Officer to issue as Operative ICD. Upon issuance this document will supersede BNFL-5193-ID-11, Rev 6.

N Barangan

1 15 Nov 2002 Provided for ORP Contracting Officer to issue as Operative ICD as part of the required ICD update. Incorporated ICF 24590-WTP-ICF-E-02-001, Rev 0.

R Ciolli

2 15 Nov 2003 Provided for ORP Contracting Officer to issue as Operative ICD as part of the required ICD update. Incorporated ICF 24590-WTP-ICF-ENG-02-003.

R Ciolli

3 06 Jun 2008 Periodic update. Transitioned tracking of all Issues and Action Items to the Action Tracking System (ATS) as follows:

Issue A11-15 → 24590-WTP-ATS-QAIS-07-1037, Initiate power service for operations

C Chan

4 13 Jul 2009 ORP Letter to N. F. Grover dated Aug 1, 2008, Contract No. DE-AC27-01RV14136 - Direction to Make Changes and Re-Issue Interface Control Documents (ICD) 5, 6, 9, 11, 12, and 19 (CCN 183784)

Incorporate maximum electrical load information from current Load Flow Analysis.

C Chan

5 16 Apr 2012 Periodic update. Incorporated current information regarding projected WTP power supply and demand.

ICF 24590-BOF-ICF-ENG-03-002 has been addressed by this revision, and the provisions of the ICF have been superseded by the new ICD revision.

N Schertz

6 01/09/2014 Periodic update. Incorporated information regarding IEEE 765 compliance. Added sections for interface protocols and for startup and commissioning interface implementation.

J Wilkins

7 09/17/2015 Periodic update. Reformatted document in accordance with updated Interface Control Procedure (24590-WTP-GPP-MGT-003, Rev 10). No revision bars are used to indicate changes, however, changes are described in the Revision Description. Closed ICD Issues A11-17, A11-18, and A11-19. Closed Open Items #0002 and #0003.

J Singh

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Revision Description

ICD Section Description

All The document has been reformatted in accordance with the requirements of Interface Control Procedure (24590-WTP-GPP-MGT-003, Rev 10).

Page i Coversheet revised to reflect ICD approval by the BNI Area Project Manager.

Page ii Interface Partner Concurrence Sheet revised to reflect the changes associated with Interface Control Procedure (24590-WTP-GPP-MGT-003, Rev 10).

Page iii History Sheet revised to describe the reason for changes.

Pages iv, v, vi Provided Revision Description of changes associated with Revision 7

Page vii Revised table of contents to reflect format changes in accordance with the requirements of Interface Control Procedure (24590-WTP-GPP-MGT-003, Rev 10).

Page viii Revised Acronyms to include Commissioning and Training Organizations (C&T), Electronic Suspense Tracking and Routing System (ESTARS), Interface Control Document Review Team (ICDRT), Plateau Remediation Contractor (PRC), and U.S. Department of Energy, Richland Operations Office (RL).

1.2 Revised to reflect the changes to Table 1 in accordance with the requirements of Interface Control Procedure (24590-WTP-GPP-MGT-003, Rev 10).

Table 1 Revised to reflect the new formatting changes, added new column “Interface Functional Requirement” as required by Interface Control Procedure ( 24590-WTP-GPP-MGT-003, Rev 10), and revised item 5 to include the new functional requirement to limit power consumption to 0.5 MW at the T43/47 area

2.1 Renumbered from previous Section 1.3; Revised to include: “Construction power is also provided from overhead transmission lines that feed the T43/47 area, from power pole number C8X869 located alongside the road, west of T-43, that is then fed underground to a 500 kVA, 13.8 kV to 480V substation, numbered C6924P, per references BNI 2014a, BNI 2014b, and BNI 2015d.” Revised second paragraph to include discussion of interface boundaries for the Building 87 cabling and duct banks as referenced in Appendix C, Open Item 0007. Added: “The capacity of the proposed additional PPS will be determined later, based on the safety loads identified by the WTP Emergency Generator Sizing (BNI 2010) calculation and the Calculation, Power System Load Flow Analysis (BNI 2011). The exact capacity of the PPS can only be determined when safety loads for the HLW and PTF facilities are finalized.”

Figure 1 Moved to Section 2.1 from end of document.

Figure 2 Moved to Section 2.1 from end of document.

2.2 Renumbered from previous Section 1.4.

2.2.1 Renumbered from previous Section 1.4.4. Revised title to “Interface Schedule” per new format requirements.

2.2.1.1 Renumbered from previous Section 1.4.4.1. Revised title to “Milestone 11A – Initiate Power Service for Construction”.

2.2.1.2 Renumbered from previous Section 1.4.4.2. Revised title to “Milestone 11B – Initiate Power Service for Operations”. Revised Milestone 11B date from “10/02/14” to “04/20/2016”.

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2.2.2 Renumbered from previous Section 1.4.1. Revised title to “Power Forecasts”. First paragraph revised to clarify that the average annual energy and peak demand forecast will be a rough order of magnitude (ROM), non-binding estimate for the next 10 years and will be provided by May 1 each year by WTP. The forecast will be sent to ORP and will include TOC, MSC, and RL on distribution. Last paragraph revised to add the following: “Construction power required at the T43/47 area, from power pole number C8X869 located alongside the road, west of T-43, that is then fed underground to a 500 kVA, 13.8 kV to 480V substation, numbered C6924P, per references BNI 2014a, BNI 2014b, and BNI 2015d. Power requirement at T43/T47 is estimated to be 0.5 MW”

Table 2 Removed from ICD 11

Table 3 Removed from ICD 11

2.2.2.1 Previously Section 1.4.2.1; Removed from ICD 11

2.2.3 Renumbered from previous Section 1.4.2. Revised text to clarify the issue of adequate margin between power demand and substation supply capacity as presented in Load Flow Calculation, 24590-WTP-E1C-MVE-00004. Text revisions also address ICD Issue A11-17 (Appendix B, A11-17, ESTARS task ORP-AMWTP-2013-0079), WTP power demand and A6 substation supply capability.

2.2.4 Renumbered from previous Section 1.4.2 and revised text to state that WTP will utilize the process described in MSC-PRO-478, “Electrical Utilities Customer Service Requests Process”.

2.2.5 Renumbered from previous Section 1.4.5 and revised the statement regarding notification by the WTP Contractor prior to energizing the switchgear building from the A6 substation.

2.2.6 Renumbered from previous Section 1.4.6 and revised to state that WTP will utilize the process described in MSC-PRO-478, “Electrical Utilities Customer Service Requests Process”.

2.2.7 Renumbered from previous Section 1.4.7 and changed safety analysis reports to documented safety analyses.

2.2.8 Renumbered from previous Section 1.4.8

2.2.9 Renumbered from previous Section 1.4.9 and revised text to state that Richland Operations will assist BNI in determining the reliability of the electrical system.

2.2.10 Renumbered from previous Section 1.4.10 and deleted reference to Appendix A, Issue A11-18 and Issue A11-19.

2.3 Renumbered from previous Section 1.5 and revised title to “Electricity Acceptance”.

2.4 Renumbered from previous Section 1.7 and renumbered Table 4 to Table 2.

2.5 Renumbered from previous Section 1.6 and revised text to delete reference to Appendix C, Open Item 0006. Added: “This does not affect energization of Building 87 or DFLAW configuration of plant operation.”

3 Deleted the following references: BNI. 2008. BOF Facilities Power Distribution (MVE) Main Single Line Diagram, 24590-BOF-E1-MVE-00001, Rev 6. March 2008. Bechtel National, Inc., Richland, WA, USA. BNI. 2010. Letter from R. W. Bradford (BNI) to D. E. Knutson (ORP-WTP), WTP Electrical Load Analysis Estimate, CCN 208943, December 21, 2010. Bechtel National, Inc., Richland, WA, USA. BNI. 2011a. Basis of Design, 24590-WTP-DB-ENG-01-001, Rev 1Q. August 2011. Bechtel National, Inc., Richland, WA, USA. BNI. 2012c. Safety Requirements Document Volume II, 24590-WTP-SRD-ESH-01-001-02, Rev 6, August, 2012. Bechtel National, Inc., Richland, WA, USA. BNI. 2013c. One System Waste Treatment and Immobilization Plant Operational Readiness Support Plan, 24590-WTP-PL-MGT-12-0006, Rev 0

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ICD Section Description (RPP-52365). July, 2013. Bechtel National, Inc., Richland, WA, USA. DOE. 2009a. Letter from J. R. Eschenberg (ORP) to R. W. Bradford (BNI), Contract DE-AC27-01RV14136 - Waste Treatment and Immobilization Plant (WTP) Project Load Analysis Contingency 09-WTP-100, CCN 200152, May 27, 2009. U.S. Department of Energy, Office of River Protection, Richland, WA, USA. FDNW. 2007. 200 East Area Electrical Utilities Switching Diagram, H-13-000079, sheet 14, Rev 1. October 2007. Fluor Daniel Northwest, Richland, WA, USA. FDNW. 2009. 200 East Area Electrical Utilities Switching Diagram, H-2-2126, sheet 7, Rev 19. January 2009. Fluor Daniel Northwest, Richland, WA, USA

Added the following new references: BNI. 2010. Emergency Generator Sizing, 24590-WTP-E1C-MVE-00012, Rev B, April 2010. Bechtel National, Inc., Richland, WA, USA. BNI. 2013c. BOF Facilities Power Distribution (MVE) Main Single Line Diagram, 24590-BOF-E1-MVE-00001, Rev 7. July 2013. Bechtel National, Inc., Richland, WA, USA. BNI. 2014a. RPP/WTP T-43/T-47 Electrical Service Plan, 24590-CM-HC1-UA11-00001-04-00072, Rev B00, April 2014, Bechtel National, Inc., Richland, WA, USA. BNI. 2014b. RPP/WTP T-43/T-47 Electrical Service Transformer Details, 24590-CM-HC1-UA11-00001-04-00068, Rev B00, April 2014, Bechtel National, Inc., Richland, WA, USA. BNI. 2014c. Managed Improvement Plan, 24590-WTP-PL-MGT-14-0006, Rev 1. August 2014. Bechtel National, Inc., Richland, WA, USA. BNI. 2014d. Basis of Design, 24590-WTP-DB-ENG-01-001, Rev 2. October 2014. Bechtel National, Inc., Richland, WA, USA. BNI. 2015d. RPP-WTP Site Construction Facility Arrangement, 24590-WTP-FSK-CON-T-01-001, Rev 029, March 2015, Bechtel National, Inc., Richland, WA, USA. BNI. 2015j. WTP Operational Readiness Support Plan, 24590-WTP-PL-MGT-12-0006, Rev 2 (RPP-52365). August 2015. Bechtel National, Inc., Richland, WA, USA. BNI. 2015g. Safety Requirements Document Volume II, 24590-WTP-SRD-ESH-01-001-02, Rev 7e. April 2015. Bechtel National, Inc., Richland, WA, USA. BNI. 2015h. Electrical Design Criteria, 24590-WTP-DC-E-01-001, Rev 15. June 2015. Bechtel National, Inc., Richland, WA, USA. DOE 2009. Letter from D. L Noyes (ORP) to R. W. Bradford (BNI), Response to Proposed U. S. Department of Energy Risk Assignments, CCN 206911, September 28, 2009.” MSA. 2011. Electrical Utilities Customer Service Requests Process, MSC-PRO-478, Rev 1. September 2011. Mission Support Alliance, Richland, WA, USA. MSA. 2015. Electrical Utilities Alarm Response Procedure, UE-R-22.01, Rev 3. March 2015. Mission Support Alliance, Richland, WA, USA. FDNW. 2007. 200 East Area Electrical Utilities Distribution Map, H-13-000079, sheet 14, Rev 2. May 2015. Fluor Daniel Northwest, Richland, WA, USA. FDNW. 2015. 200 East Area Electrical Utilities Switching Diagram, H-2-2126, sheet 7, Rev 27. August 2015. Fluor Daniel Northwest, Richland, WA, USA.

Appendix A Changed column headings as follows: “Issue/Action” to “Issue/Action Description” and “Baseline” to “Contract or Baseline” and “Pages’ to “Affected Pages” and added the following note: “TOC Baseline referenced here is the lifecycle Performance Measurement Baseline (PMB) which includes both WRPS and ORP owned scope. The approved ICDs are one of the baseline documents that comprise the technical scope for the TOC Life-Cycle PMB.” These changes are the result of the new format requirements associated with the requirements of Interface Control Procedure (24590-WTP-GPP-MGT-003, Rev 10). Closed ICD Issues A11-17, A11-18 and A11-19 based on resolutions provided in Appendix B.

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Appendix B Revised to address closure of ICD Issue A11-17, WTP future power demand may exceed substation supply capability (BNI 2015k, CCN 282945); A11-18, WTP to specify the support needed from MSC in order to satisfy readiness requirements related to energizing Building 87 from Substation A6, (24590-WTP-ATS-MGT-13-0540); and ICD Issue A11-19, TOC coordinate with MSC to specify the support needed from WTP in order to satisfy readiness requirements related to energizing Building 87 from Substation A6, (WRPS-TECHNICAL INTER-2013-0001).

Appendix C Revised to incorporate format changes and removed the following open items in accordance with the requirements of Interface Control Procedure (24590-WTP-GPP-MGT-003, Rev 10) Step 5.5.4 that requires: removal of open items from Appendix C in the next ICD revision following their introduction:

Open Item 0001: WTP investigate applicability of, and compliance with, IEEE Standards (IEEE 308, 741, 765) (Refer to 24590-WTP-PIER-MGT-12-0147-C and 24590-WTP-PIER-MGT-12-0207). This item was closed in Revision 6 of ICD 11. This item was removed from ICD 11 in this revision.

Open Item 0002: WTP provide an updated electrical power forecast for construction and operations as soon as practicable following re-baselining. This item was closed in this revision of the ICD 11 based on disposition provided in Appendix C.

Open Item 0003: MSC Electrical Utilities establish communication protocols with WTP on electrical system conditions/changes that may affect the reliability or availability of the off-site power source. This item was closed in this revision of the ICD 11 based on disposition provided in Appendix C.

Open Item 0004: The 7 MW of temporary construction power may, at some point in the future, become permanent power. This requirement is not currently in the contract baseline for any contractor. This item remains open and was assigned a WTP Action Tracking System number 24590-WTP-ATS-MGT-15-0369;

Open Item 0005: The bulleted statement in Section 2.2.4 (formerly 1.4.4): “Peak demand may be 7 MW through 2028” is a conservative estimate for MSC planning purposes only. A temporary construction power peak demand of 7 MW beyond 2019 is not currently accounted for in the contract baseline for any contractor. This item remains open and was assigned a WTP Action Tracking System number 24590-ATS-MGT-15-0204;

Open Item 0006: WTP to specify the additional Preferred Power Source (PPS) requirements for compliance with IEEE 765. This specification will include a determination (coordinated with the Interface Partners) of the physical and administrative interface points for the additional PPS. MSC and DOE will begin planning, estimating and budgeting for the additional PPS upon receipt of the specified requirements. Requirements need to be communicated to MSC at least 3 financial years in advance of when the additional PPS is needed to be operational for them to complete design and construction. This item remains open and was assigned a WTP Action Tracking System number 24590-ATS-MGT-15-0205.

Open Item 0007: Once Building 87 has been turned over from Startup to Operations, a change to the interface boundaries, between MSC and WTP, for the 13.8kV cabling and duct banks will be implemented; that is, the boundaries will be moved to the line side of the Building 87 switchgear. This transfer is contingent upon the development of a process between WTP and MSC to allow the transfer of the cables and its associated technical baseline documentation. This item will be tracked both by WTP and MSC as an open item. An Action Tracking System number 24590-ATS-MGT-15-0426 has been assigned for WTP tracking. An ESTARS Task Number MSA-SIU EU-2015-0002 has been assigned for MSC tracking.

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Open Item 0008: With the improvements regarding margin management having been incorporated into WTP Engineering processes and procedures (as stated in BNI 2014c, MIP-43, Margin Management Improvements, 24590-WTP-PL-MGT-14-0006, Rev 1), a revision to the Load Flow calculation (BNI. 2011. Calculation, Power System Load Flow Analysis, 24590-WTP-E1C-MVE-00004) will be prepared to address, in part, the issue of adequate margin between power demand and substation supply capability. This item remains open and was assigned a WTP Action Tracking System number 24590-ATS-MGT-15-0441.

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Contents History Sheet ................................................................................................................................ iii

Revision Description .................................................................................................................... iv

Acronyms ...................................................................................................................................... xi

1 Interface Description .............................................................................................................1

1.1 Interface Definition ................................................................................................................................ 1

1.2 Functional Requirements ...................................................................................................................... 1

2 Interface Information ............................................................................................................4

2.1 Physical Interfaces ................................................................................................................................. 4

2.2 Administrative Interfaces ...................................................................................................................... 7 2.2.1 Interface Schedule ...................................................................................................................... 7 2.2.2 Power Forecasts ......................................................................................................................... 8 2.2.3 Electrical Power Requirement for WTP .................................................................................... 8 2.2.4 Schedule of Electrical Outages for Maintenance ....................................................................... 9 2.2.5 Permanent Electrical Power Connection .................................................................................. 10 2.2.6 Interface Protocols ................................................................................................................... 10 2.2.7 Integrated Safety Management System (ISMS) ....................................................................... 10 2.2.8 Authorization Basis (AB) ........................................................................................................ 10 2.2.9 Reliability, Availability, Maintainability, and Inspectability (RAMI) ..................................... 10 2.2.10 Startup and Commissioning Interface Implementation ............................................................ 10

2.3 Electricity Acceptance.......................................................................................................................... 11

2.4 Configuration Management Items ...................................................................................................... 11

2.5 IEEE Standards .................................................................................................................................... 12

3 References ............................................................................................................................12

Appendices Appendix A - Open ICD 11 Issues and Actions ..................................................................... A-1

Appendix B - Issues and Actions Closed Since Last Revision ...............................................B-1

Appendix C - ICD 11 Open Items List .................................................................................... C-1

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Tables Table 1 Requirements for the Electricity Interface ..................................................................... 2

Table 2 Interface Configuration Management Items ................................................................ 12

Figures Figure 1 Physical Interface .............................................................................................................. 5

Figure 2 Electrical Interface ........................................................................................................... 6

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Acronyms

AB Authorization Basis

AC Alternating Current

ANSI American National Standards Institute

ATS Action Tracking System

BNI Bechtel National, Incorporated

BOF Balance of Facilities

BPA Bonneville Power Administration

C&T Commissioning and Training Organizations

CCN Correspondence Control Number

DOE U.S. Department of Energy

ESTARS Electronic Suspense Tracking and Routing System

ORP U. S. Department of Energy, Office of River Protection

FDNW Fluor Daniel Northwest

FDNW and NHC Fluor Daniel Northwest and Numatec Hanford Corporation

ICDRT Interface Control Document Review Team

IEEE Institute of Electrical and Electronics Engineers

ICD Interface Control Document

IO Interface Owner

ISMS Integrated Safety Management System

Hz Hertz

kV Kilovolt (1 thousand volts)

MIP Managed Improvement Plan

MSC Mission Support Contractor

MW Megawatt (1 million watts)

N/A Not Applicable

NEC National Electrical Code

OARS ORP Action Reporting System

PF Power Factor

PHMC Project Hanford Management Contractor

PMB Performance Measurement Baseline

PPS Preferred Power Source

PRC Plateau Remediation Contractor

RAMI Reliability, Availability, Maintainability, and Inspectability

RL U.S. Department of Energy, Richland Operations Office

ROM Rough Order of Magnitude

RPP River Protection Project

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TF Tank Farm Project

TOC Tank Operations Contractor

WTP Hanford Tank Waste Treatment and Immobilization Plant

WRPS Washington River Protection Solutions

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1 Interface Description

1.1 Interface Definition

Electricity for construction and “operations” (startup, commissioning, and permanent operations) will be provided to the River Protection Project (RPP) – Hanford Tank Waste Treatment and Immobilization Plant (WTP) Contractor’s site electrical distribution system. Power supplied will be rated 13.8 kV, 60 Hz 3-phase. NOTE: Providing power from the Emergency Turbine Generator and Standby Diesel Generator to

support WTP facilities will be the responsibility of the WTP Contractor, and it is not included as part of this ICD.

1.2 Functional Requirements

Table 1 presents the interface requirements for each responsible organization. Column 1 presents the interface functional requirements. Column 2 presents the WTP Contractor interface responsibilities within the current WTP Contract scope. Column 3 presents the TOC interface responsibilities within the current TOC baseline. Column 4 presents interface actions for the MSC. Column 5 summarizes actions for the U.S. Department of Energy (DOE) necessary to support this interface.

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Table 1 Requirements for the Electricity Interface

Interface Functional Requirement The Waste Treatment Plant Contractor Shall…

The Tank Operations Contractor Shall… The Mission Support Contractor Shall… DOE Will...

1 The WTP Contractor will provide annual updates on the amount of AC power required for operations (startup and commissioning) and facility construction. (ICD Section 2.2.2)

1 Provide to the DOE and TOC updates and other information on the amount of AC power (average and peak loads) required for its operations and facility construction.

1 Use the WTP Contractor’s projected AC power needs to plan, coordinate and budget electrical supply system upgrades and modifications.

1 Review forecasts of WTP electrical power requirements, determine and document if it is within the capabilities of the system. Plan any changes needed if current capacity is not sufficient. Provide cost estimate to TOC; execute when funded. Distribute defined quantity of power to WTP.

1 Evaluate and approve the TOC plan for electrical supply system upgrades and modifications. Provide funding and up to the forecasted quantity of operations and facility construction power.

2 The DOE, MSC, and the WTP Contractor agree to work together to develop mutually beneficial electrical system coordination in an attempt to achieve optimum levels of protection and selectivity. (ICD Section 2.2.3)

2 Maintain coordination of protective devices.

2 No Action 2 Maintain coordination of electrical protective devices on the MSC side of the interface with electrical protective devices on the WTP side of the interface.

2 No Action

3 Temporary electrical power supply (13.8 kV, 3 phase, 60 Hz, 7 MW peak capacity @ PF 0.95) is required during construction of the WTP facilities. (ICD Section 2.2.1)

3 Limit power consumption to 7 MW of construction power at the defined interface point.

3 Use the WTP Contractor estimated power usage (7 MW) to estimate and budget construction power usage costs and advise ORP Finance.

3 Deliver up to 7 MW of power @ PF 0.95 or greater at the defined parameters (13.8 kV, 60 Hz, 3-phase) to support the WTP Contractor’s construction power in accordance with the WTP Contractor’s approved baseline schedules. Monitor and record electrical power delivery and report to TOC on request.

3 Provide funding and up to 7 MW of construction power.

4 Provide up to 2 MW of power, required intermittently for Pit 30 aggregate mining, between 2013 and 2019, as indicated in the ICD 28 (BNI 2012a). It is currently not anticipated that there will be any need for electrical power, for the above mentioned operations, after 2019. (ICD Section 2.2.2)

4 Limit power consumption to 2 MW of power at Aggregate Pit 30.

4 Use the WTP Contractor estimated power usage (up to 2 MW) to estimate and budget Aggregate Pit 30 power usage costs and advise ORP Finance.

4 Deliver up to 2 MW of power at the defined parameters (13.8 kV, 60 Hz, 3-phase) to support contractor’s Aggregate Pit 30 power demand in accordance with the contractor’s approved baseline schedules. Monitor and record electrical power delivery and report to TOC on request.

4 Provide funding and up to 2 MW of Aggregate Pit 30 power.

5 Maximum construction power requirement at the T43/47 area (500 kVA, 13.8 kV to 480V substation (numbered C6924P) will be 0.5 MW, from 2015 through 2019. (ICD Section 2.2.2)

5 Limit power consumption to 0.5 MW at the T43/47 area.

5 Use the WTP Contractor estimated power usage (up to 0.5 MW) at the T43/47 area to estimate and budget power usage costs and advise ORP Finance.

5 Deliver up to 0.5 MW of power at the defined parameters (13.8 kV, 60 Hz, 3-phase) to support contractor’s power demand at the T43/47 area in accordance with the contractor’s approved baseline schedules. Monitor and record electrical power delivery and report to TOC on request.

5 Provide funding and up to 0.5 MW of power at the T43/47 area.

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Table 1 Requirements for the Electricity Interface

Interface Functional Requirement The Waste Treatment Plant Contractor Shall…

The Tank Operations Contractor Shall… The Mission Support Contractor Shall… DOE Will...

6 Each utility substation transformer and associated load group switchgear feeders are sized to provide power to the entire WTP plant electrical load (up to 62 MVA) if the other utility substation transformer or load group switchgear is unavailable. (ICD Section 2.2.3)

6 Limit power consumption during operations such that the capacity rating of a single transformer in the substation A6 is not exceeded. Monitor and record electrical power consumption and report to TOC.

6 Use the WTP Contractor estimated power usage (50.8 MW1 @ PF 0.909 excluding unknown design growth and contingencies) to estimate and budget “operations” power usage costs and advise ORP Finance. Resolve issues and discrepancies between WTP and MSC reported data.

6 Deliver up to 62 MVA at the defined parameters (13.8 kV, 60 Hz, 3-phase) to support testing, startup, and operation of the WTP, in accordance with the WTP Contractor’s approved baseline schedule. This equates to the nameplate rating of each of the existing substation A6 step-down transformers.

Deliver power to the WTP Contractor’s site electrical interface point.

Maintain electrical distribution at the defined capacity to the WTP Contractor’s site electrical interface point.

Monitor and record electrical power delivery and report to TOC on request.

6 Provide funding as necessary to meet the operational load requirements of the WTP.

7 The electrical interface for permanent electrical power to the WTP Contractor will be the 13.8 kV feeder cable attachment bus on the load-side of the MSC feeder breakers in substation A6 located in Building 251E. (ICD Section 2.1)

7 Perform system service connections at defined electrical interface points for operations (startup and commissioning) power.

7 No Action 7 Support WTP system service connections at defined electrical interface points.

Deliver power to the WTP Contractor’s Site perimeter.

7 No Action

8 The MSC shall make all reasonable efforts to provide continuity of service to the WTP site before performing any switching of the MSC-provided electrical power supply system. (ICD Section 2.2.4)

8 Notify MSC Electrical Utilities Dispatch at least 48 hours in advance of scheduled changes in load greater than 5 MW during operations, including any periodic testing of Standby or Emergency Generators.

Notify the MSC, as soon as practical, of unscheduled, significant changes in load.

8 No Action 8 Notify the WTP Contractor at least 28 days in advance of scheduled changes in WTP power supply configuration including interruption of services and maintenance that is expected to reduce redundancy or reliability.

8 No Action

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2 Interface Information

2.1 Physical Interfaces

Construction Power The physical interface for the supply of construction power to the WTP Contractor is switch C8X747 at the power pole location shown as Node 12 on the Interface Control Drawing (BNI 2013b). Construction power is also provided from overhead transmission lines that feed the T43/47 area, from power pole number C8X869 located alongside the road, west of T43, that is then fed underground to a 500 kVA, 13.8 kV to 480V substation, numbered C6924P, per references BNI 2014a, BNI 2014b, and BNI 2015d. Permanent Plant Power As illustrated in Figure 1, the physical interface for permanent (“operations”) electrical power to the WTP Contractor will be the end of the MSC controlled duct banks from switchgear building 251E, shown as Nodes 7A and 7B on the Interface Control Drawing (BNI 2013b). As illustrated in Figure 2, the electrical interface for permanent electrical power to the WTP Contractor will be the 13.8 kV feeder cable attachment bus on the load-side of the MSC feeder breakers in substation A6 located in Building 251E. The substation is located on the east side of the WTP site. There are underground duct banks from switchgear building 251E to the MSC/WTP physical interface point that the WTP Contractor has used to run permanent electrical cable to the electrical interface point in the 251E breaker panels. Per Appendix C, Open Item 0007, when Building 87 is turned over from Startup to Operations, the interface boundaries for the 13.8kV cabling and duct banks, between MSC and WTP, will be moved to the line side of the Building 87 switchgear, with the WTP scope starting at the line side of the switchgear in Building 87 and continuing downstream The WTP Contractor determined that an additional Preferred Power Source (PPS) is required for WTP’s Building 89 (safety system switchgear building) that is geographically diverse from the existing power sources from the A6 substation. A preliminary option for providing this additional PPS for Building 89 is from the A8 substation. The capacity of the proposed additional PPS will be determined later, based on the safety loads identified by the WTP Emergency Generator Sizing (BNI 2010) calculation and the Calculation, Power System Load Flow Analysis (BNI 2011). The exact capacity of the PPS can only be determined when safety loads for the HLW and PTF facilities are finalized. The additional PPS would be separate from the construction power supply described above. The specific physical interfaces for the power source will be included in the resolution of Appendix C, Open Item 0006. MSC, in consultation with the Interface Partners, will further evaluate the additional PPS requirements from WTP upon receipt of the requirements. Other options may require consideration dependent upon ORP’s future direction for mitigating the risk of WTP’s future power demand exceeding substation supply capability (Appendix C, Item 0006).

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Figure 1 Physical Interface

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Figure 2 Electrical Interface

ELECTRICAL INTERFACE POINT(Connection to MSC Breaker Panel)

MSC SCOPE WTP SCOPE

BLOCK DIAGRAM - POWER DISTRIBUTION:ELECTRICAL INTERFACE (per 24590-BOF-E1-MVE-00001)

SWITCHGEARLOAD GROUP “A”

230-13.8kVTRANSFORMER37.5/50/62/MVA

OA/FA/FA

13.8kV, 3000AUTILITY BUS #1

LOAD GROUP “A”SWITCHGEAR

LOAD GROUP “A”

13.8kV, 2000ASWITCHGEAR

LOAD GROUP “A”


LOAD GROUP “A”

230-13.8kVTRANSFORMER37.5/50/62/MVA

OA/FA/FA SWITCHGEARLOAD GROUP “B”

SWITCHGEARLOAD GROUP “B”


LOAD GROUP “B”


LOAD GROUP “B”

TIE TIE

TIE

WTPLOADS

WTPLOADS

WTPLOADS

WTPLOADS

A

A13.8kV, 3000AUTILITY BUS #2

LOAD GROUP “B”

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2.2 Administrative Interfaces

2.2.1 Interface Schedule

Temporary electrical power supply (13.8 kV, 3 phase, 60 Hz, 7 MW peak capacity @ PF 0.95) is required during construction of the WTP facilities. Temporary construction power will not have a redundant source. After 2019, there is uncertainty regarding power demand. However, for planning purposes the following conservative assumptions can be made:

Power demand due to construction activities will diminish to zero at some undetermined time after 2019.

There is a possibility that the current temporary 7 MW power supply will be converted to a permanent power source for operations (See Appendix C, Open Item 0004).

Peak demand may be 7 MW through 2028 (See Appendix C, Open Item 0005).

Electrical power use associated with Pit 30 (up to 2 MW) is not considered a subset of the total 7 MW construction power (BNI 2012a). Similarly, electrical power (up to 0.5 MW) associated with T43/47 area is not considered a subset of the total 7 MW. The MSC will provide permanent electrical power for operations to the WTP site prior to the start of the commissioning and testing phase of the project. Permanent power will be used as scheduled by the WTP Contractor. Regarding removal of temporary wiring, the WTP will comply with the National Electric Code (NEC 1999). WRPS, as part of the TOC Performance Measurement Baseline (PMB) development, has been requested to coordinate and budget electricity costs associated with both construction and operation of the WTP. The ORP approved baseline schedules for the TOC and the WTP Contractor define the interface milestones and integrated schedule for this ICD. Activity IDs referenced are from the respective contractor or in the case of completed activities, the predecessors from the approved baseline. 2.2.1.1 Milestone 11A – Initiate Power Service for Construction

This completed milestone represents the actual start for using electrical power for construction. For the TOC, it represents that the line and connection is available to the WTP site, the line has been connected and tested, and funds are available to support construction phase. For the WTP Contractor, it represents the actual date that the connection with the line provided was completed and the beginning of power service during construction. Power was made available through the use of an electrical service request to the MSC Electrical Utilities group; power utilization began on December 5, 2001.

Contractor Activity ID Title Actual Date

WTP 4DBZZ00015 BOF [Balance of Facilities] – Initiate Power Service for Const (ICD11)

12/5/2001 A

TOC T8IC1104P Complete Construction/Startup Elect Sys 7/24/2001 A

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2.2.1.2 Milestone 11B – Initiate Power Service for Operations

This milestone represents the planned date to begin startup testing and commissioning. For the WTP, it represents the planned date to begin operations power utilization to support startup testing and commissioning. For the TOC, there are no Activity IDs milestones related to the estimating and budget of power usage costs. Any associated milestone(s) will be added to future revisions of this ICD.

Contractor Activity ID Title Date

WTP 5HBC2CD11B BOF [Balance of Facilities] – C&T Init. Power Service; Ops (ICD11B)

04/20/2016

2.2.2 Power Forecasts

The WTP Contractor will provide annual updates on the amount of AC power required for operations (startup and commissioning) and facility construction. The average annual energy and peak demand forecast will be a rough order of magnitude (ROM), non-binding estimate for the next 10 years, and will be provided by May 1 each year by WTP. The forecast will be sent from WTP to ORP as a formal letter that will be assigned a CCN number and will include TOC, MSC, and RL on distribution. This forecast commitment is tracked by 24590-WTP-ATS-MGT-13-0492 in the WTP Action Tracking System. The TOC will provide ORP an estimate of the MSC utilities support costs related to the possible increases in total operating power (e.g., upgrades) as supplied from the WTP Contractor. This estimated funding will be withheld from the TOC to pay the MSC directly through RL. Regarding the 2 MW of power required for Pit 30 aggregate mining operations, the forecast in ICD 28 (BNI 2012a) indicates that up to 2 MW may be intermittently required between 2013 and 2019, and no mining operations (or need for electrical power) are currently anticipated after 2019. Construction power required at the T43/47 area, is from power pole number C8X869 located alongside the road, west of T43, that is then fed underground to a 500 kVA, 13.8 kV to 480V substation, numbered C6924P, per references BNI 2014a, BNI 2014b, and BNI 2015d. Power requirement at T43/47 area is estimated to be 0.5 MW. 2.2.3 Electrical Power Requirement for WTP

The maximum electrical power demand for operation of all the WTP facilities was estimated in 2011 at 48.8 MW @ PF 0.909 excluding design growth and contingencies (BNI 2011). The same calculation (BNI 2011) added an estimated 2.0 MW for known “To-be-Designed-Buildings”, bringing the total to 50.8 MW @ PF 0.909. With the improvements regarding margin management having been incorporated into WTP Engineering processes and procedures (as stated in BNI 2014c, MIP-43, Margin Management Improvements, 24590-WTP-PL-MGT-14-0006, Rev 1), a revision to the Load Flow calculation (BNI 2011, Calculation, Power System Load Flow Analysis, 24590-WTP-E1C-MVE-00004) will be prepared, in part, to address the issue of adequate margin between power demand and substation supply capability. This revision is addressed in a future activity - Schedule ID 3ED1600055, currently scheduled to be completed in November 2018, and will only address the impacts from DFLAW at this time. Impacts from HLW and PTF will be addressed in a future revision of this calculation. This forecast commitment will be tracked by ATS item 24590-WTP-ATS-MGT-15-0441 (Appendix C, Open Item 0008).

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Section 8.2.1 of the WTP Basis of Design (BNI 2014d) states, “Each utility substation transformer and associated load group switchgear feeders are sized to provide power to the entire WTP plant electrical load if the other utility substation transformer or load group switchgear is unavailable.” Therefore, each utility substation transformer and associated load group switchgear feeders must be capable of providing power to the entire WTP plant electrical load (up to 62 MVA). Per Appendix B, Resolution for Issue/Action A11-17 and ESTARS task ORP- AMWTP-2013-0079 completed 10/07/2014, it was concluded that there is no concern that the load demand will exceed A6 Substation Capacity of 55 MW. However, as design continues, it is expected that changes to the high-level waste/pre-treatment technical issues could change the WTP power requirements. Some solutions may require additional power, while others greatly reduce power demands. DOE will provide ongoing oversight as the WTP design progresses. Electrical design features between the WTP and MSC have been coordinated by sharing/reviewing design information (e.g., breaker/relay type and set points) for the main breakers on both sides of the interface. The DOE, MSC, and the WTP Contractor agree to work together to develop mutually beneficial electrical system coordination in an attempt to achieve optimum levels of protection and selectivity. If there is an issue with the settings, protection of MSC transmission and distribution systems and cables between the DOE and WTP, MSC protection will come before WTP selectivity. Any changes to the set points during startup shall be mutually agreed upon and maintained thereafter following the electrical system energization (Milestone 11B). 2.2.4 Schedule of Electrical Outages for Maintenance

During operations, the WTP electrical loads will be divided between load groups A and B. This division reflects a general concept of providing power for the plant electrical loads from two independent, MSC-furnished transformers supplied via looped transmission lines, as described in the conceptual design report (FDNW and NHC 1997). The allocation of power supply is also described in the Basis of Design (BNI 2014d). Therefore, every practical effort is made to make the MSC-provided power supplies, WTP loads, and WTP cables and raceways affiliated with each load group less affected by single point failures. The MSC will provide the WTP Contractor at least a 28-day advance notice before conducting planned maintenance, or other load interruptions, that are expected to reduce redundancy or reliability of the MSC-provided electrical power supply system during construction and operations. The MSC shall make all reasonable efforts to provide continuity of service to the WTP site before performing any switching of the MSC-provided electrical power supply system. The WTP Contractor shall notify the MSC 48 hours in advance of any planned changes of 5 MW or greater in the operations electrical load, including any periodic testing of WTP Contractor Standby or Emergency Generators when operating the generators in parallel with offsite power; the WTP Contractor will also notify the MSC as soon as practical of unscheduled, significant changes in load. The WTP Contractor will utilize the process described in MSC-PRO-478, “Electrical Utilities Customer Service Requests Process” (MSA 2011), to request specific work or assistance from the MSC. The on-shift electrical system operational points of contact are as follows:

MSC Electrical Utilities Dispatch ........... 373-2321

WTP Shift Manager ................................ 373-8043 or 420-3597 (c)

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2.2.5 Permanent Electrical Power Connection

The MSC has provided electrical conduits and duct banks from the MSC-provided switchgear up to the MSC/WTP physical interface point. The WTP Contractor has extended these duct banks from the interface point to the WTP switchgear building. The WTP Contractor has pulled the required feeder cables between the two switchgear buildings, installed the stress cones, tested the cables, terminated, and de-terminated the cables in the WTP switchgear building (Building 87). MSC Electrical Utilities has made the cable connection at the breakers inside Building 251E, the substation A6 switchgear building (the electrical interface point). Since that time, in order to accommodate lockout / tagout requests by the WTP, the cables were de-terminated and grounded by WTP personnel. Following that, the cables at the breakers inside Building 251E were landed and loosely connected. On, or after, the Milestone 11B date shown above, and after completion of the appropriate turnover process, ORP will be notified by the WTP Contractor 48 hours prior to energizing the WTP switchgear building from the A6 substation in the initial application of sustained power. Following this notification, the WTP Contractor will request that MSC energize the 13.8 kV feeders within 24 hours of the request. 2.2.6 Interface Protocols

WTP startup and operating procedures for Building 87 and MSC operating procedures for substation A6 should include steps and any necessary information to facilitate communications and interactions between WTP and MSC personnel. WTP will utilize the process described in MSC-PRO-478, “Electrical Utilities Customer Service Requests Process” (MSA 2011), to request specific work or assistance from the MSC. 2.2.7 Integrated Safety Management System (ISMS)

The respective organizations’ design processes include integrated safety management principles, and are communicated through the interface in the configuration-managed documents (such as documented safety analyses), which will be identified in Table 2, as available. 2.2.8 Authorization Basis (AB)

No new hazard or accident scenarios are expected to be introduced through this interface that are not adequately controlled by the interface partners and through controls placed across this interface. The physical and administrative controls to mitigate these risks, using a graded approach, have been or will be adequately addressed through requirements on each partner’s authorization basis. 2.2.9 Reliability, Availability, Maintainability, and Inspectability (RAMI)

RL will provide reliability data of the electrical service provided to assist BNI in determining the reliability of the system. 2.2.10 Startup and Commissioning Interface Implementation

Operational Readiness includes incremental achievement and verification of readiness as facilities and systems reach completion and are placed into service. Readiness activities for ICD 11 include those identified in the WTP Operational Readiness Support Plan, 24590-WTP-PL-MGT-12-0006, Rev 2 (RPP-52365) (BNI 2015j) to analyze ICDs and ensure that appropriate agreements are developed and implemented prior to placing the ICD controlled interface into active service.

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WTP and MSC will exchange objective evidence demonstrating that:

Their personnel, facilities, and processes are adequate to support the energization and sustained operation of Building 87.

Their associated interface processes and protocols are adequate to support the energization and sustained operation of Building 87.

2.3 Electricity Acceptance

Voltage (13.8 kV) measured at each substation A6 transformer secondary shall be maintained in accordance with ANSI C84.1-2006, Table 1 (ANSI 2006) as follows: Voltage Range A 14,490-13,460 VAC

Voltage Range B 14,520-13,110 VAC

2.4 Configuration Management Items

This section identifies the referenced documents that further define the physical and/or administrative details of the interface. Interface affecting changes to the documents listed in Table 2 will be provided to the affected parties by the responsible Interface Owner.

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Table 2 Interface Configuration Management Items

WTP Documents Interfacing Organization Documents

24590-WTP-E1C-MVE-00004, Calculation, Power System Load Flow Analysis (BNI 2011)

24590-WTP-E1C-MVE-00008, Protective Devices & Relay Coordination - Building 87 BOF 13.8 KV Switchgear and 480 V Power Panels (NON-ITS) (BNI 2012b)

24590-WTP-DC-E-01-001, Electrical Design Criteria (BNI 2015h)

HNF-2106, Design/Build Specification Project W-519 Privatization Phase I Infrastructure Support, Electrical Power System (FDNW 1999)

WTP Drawings Interfacing Organization Drawings

24590-BOF-E1-MVE-00001

BOF Facilities Power Distribution (MVE) Main Single Line Diagram (BNI 2013c)

24590-BOF-E0-E54T-00016

Electrical Duct Bank System Site Plan Area 5 (BNI 2013a)

24590-WTP-B2-C12T-00001

Interface Control Drawing (BNI 2013b)

H-2-829795, A6 230 KV & 13.8 KV Simplified One-Line (MSA 2013)

H-2-829806, Substation Conduit and Trench Plan (FDNW 2004)

H-2-829718, Electrical Construction Power Plan and Profile (FDNW 2000a)

H-2-829722, Electrical Construction Power Pole Assemblies (FDNW 2000b)

H-2-829733, Electrical Switching Diagram (Partial) (FDNW 2000c)

H-2-2126, sheet 7, 200 East Area Electrical Utilities Switching Diagram (FDNW 2009)

H-2-831247, sheet 1, A6-WTP Electrical Utilities Switching Diagram (MSA 2014)

H-13-000079, sheet 14, 200 East Area Electrical Utilities Switching Diagram (FDNW 2007)

2.5 IEEE Standards

There are at least three IEEE Standards that are important considerations regarding the WTP electrical interface with the MSC. IEEE Std 308-1991, Criteria for Class 1E Power Systems for Nuclear Power Generating Stations is named as an implementing standard in the WTP Safety Requirements Document, Volume II (SRD) (BNI 2015g). IEEE Std 741, IEEE Standard Criteria for the Protection of Class 1E Power Systems and Equipment in Nuclear Power Generating Stations and IEEE Std 765, IEEE Standard for Preferred Power Supply for Nuclear Power Generating Stations are both daughter standards of IEEE Std 308-1991. IEEE Std 765 is of particular importance to ICD 11 because it describes the measures that must be taken in order to ensure that the preferred power source to WTP (off-site power) achieves the required level of system reliability. The salient attributes for the electrical utility necessary to meet WTP’s requirements for the PPSs will be specified in a future revision of this ICD. This does not affect energization of Building 87 or DFLAW configuration of plant operation.

3 References

ANSI 2006. ANSI C84.1-2006, American National Standard for Electric Power Systems and Equipment — Voltage Ratings (60 Hertz). American National Standards Institute, New York, NY.

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BNI. 2009. Response to Proposed U.S. Department of Energy Risk Assignments, CCN 206911. September 2009. Bechtel National, Inc., Richland, WA, USA.

BNI. 2010. Emergency Generator Sizing, 24590-WTP-E1C-MVE-00012, Rev B, April 2010. Bechtel National, Inc., Richland, WA, USA.

BNI. 2011. Calculation, Power System Load Flow Analysis, 24590-WTP-E1C-MVE-00004, Rev 0, October 2011. Bechtel National, Inc., Richland, WA, USA.

BNI. 2012a. ICD 28 - Interface Control Document for Pit 30 Aggregate Supply for Construction, 24590-WTP-ICD-MG-01-028, Rev 3. April 2012. Bechtel National, Inc., Richland, WA, USA.

BNI. 2012b. Protective Devices & Relay Coordination - Building 87 BOF 13.8 KV Switchgear and 480 V Power Panels (NON-Safety), 24590-WTP-E1C-MVE-00008, Rev 0, February 16, 2012. Bechtel National, Inc., Richland, WA, USA.

BNI. 2013a. Electrical Duct Bank System Site Plan Area 5, 24590-BOF-E0-E54T-00016, Rev 5, May 2013. Bechtel National, Inc., Richland, WA, USA.

BNI. 2013b. Interface Control Drawing, 24590-WTP-B2-C12T-00001, Rev 2, June 2013. Bechtel National, Inc., Richland, WA, USA.

BNI. 2013c. BOF Facilities Power Distribution (MVE) Main Single Line Diagram, 24590-BOF-E1-MVE-00001, Rev 7, July 2013. Bechtel National, Inc., Richland, WA, USA.

BNI. 2014a. RPP/WTP T-43/T-47 Electrical Service Plan, 24590-CM-HC1-UA11-00001-04-00072, Rev B00, April 2014, Bechtel National, Inc., Richland, WA, USA.

BNI. 2014b. RPP/WTP T-43/T-47 Electrical Service Transformer Details, 24590-CM-HC1-UA11-00001-04-00068, Rev B00, April 2014, Bechtel National, Inc., Richland, WA, USA.

BNI. 2014c. Managed Improvement Plan, 24590-WTP-PL-MGT-14-0006, Rev 1, August 2014. Bechtel National, Inc., Richland, WA, USA.

BNI. 2014d. Basis of Design, 24590-WTP-DB-ENG-01-001, Rev 2, October 2014. Bechtel National, Inc., Richland, WA, USA.

BNI. 2014e. Inter-Contractor WTP Operational Readiness Committee (IORC) Meeting Minutes –December 11, 2014, CCN: 268119, December 2014. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015a. Inter-Contractor WTP Operational Readiness Committee (IORC) Meeting Minutes – January 13, 2015, CCN 268121, January 2015. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015b. Inter-Contractor WTP Operational Readiness Committee (IORC) Meeting Minutes – February 10, 2015, CCN 277705, February 2015. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015c. Inter-Contractor WTP Operational Readiness Committee (IORC) Meeting Minutes – March 25, 2015, CCN: 277711, March 2015. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015d. RPP-WTP Site Construction Facility Arrangement, 24590-WTP-FSK-CON-T-01-001, Rev 029, March 2015, Bechtel National, Inc., Richland, WA, USA.

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BNI. 2015e. Inter-Contractor WTP Operational Readiness Committee (IORC) Meeting Minutes – April 22, 2015, CCN: 277563, April 2015. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015f. OUO – Inter-Contractor WTP Operational Readiness Committee (IORC) Meeting Minutes – June 22, 2015, CCN 278734, June 2015. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015g. Safety Requirements Document Volume II, 24590-WTP-SRD-ESH-01-001-02, Rev 7f, June 2015. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015h. Electrical Design Criteria, 24590-WTP-DC-E-01-001, Rev 15, June 2015. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015i. Interface Management Plan, 24590-WTP-PL-MG-01-001, Rev 8, June 2015. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015j. WTP Operational Readiness Support Plan, 24590-WTP-PL-MGT-12-0006, Rev 2 (RPP-52365). August 2015. Bechtel National, Inc., Richland, WA, USA.

BNI. 2015k. ICDRT Expedited Review: 24590-WTP-ICD-MG-01-011, Rev 7, CCN 282945, August 2015. Bechtel National, Inc., Richland, WA, USA.

DOE. 2009. Letter from D. L Noyes (ORP) to R. W. Bradford (BNI), Response to Proposed U. S. Department of Energy Risk Assignments, CCN 206911, September 28, 2009. U.S. Department of Energy, Office of River Protection, Richland, WA, USA.

DOE. 2010. Letter of Direction to Proceed with Performing Analysis and Prepare Viable Options for Increasing Power Delivery up to Minimum of 70 Megawatts (MW) Capability Under the Worst Case Scenario to the U.S. Department of Energy, Office of River Protection (ORP), Waste Treatment and Immobilization Plant (WTP), 10-WTP-057/1000326, March 12, 2010.

FDNW and NHC. 1997. Summary Conceptual Design Report for Tank Waste Remediation System Privatization Phase I Infrastructure Support, Project W-519, HNF-1938, Rev 0. December 1997. Fluor Daniel Northwest and Numatec Hanford Corporation, Richland, WA, USA.

FDNW. 1999. Design/Build Specification Project W-519 Privatization Phase I Infrastructure Support, Electrical Power System, HNF-2106, Rev 0. February 1999. Fluor Daniel Northwest, Richland, WA, USA.

FDNW. 2000a. Electrical Construction Power Plan and Profile, H-2-829718, Rev 1. August 2000. Fluor Daniel Northwest, Richland, WA, USA.

FDNW. 2000b. Electrical Construction Power Pole Assemblies, H-2-829722, Rev 1. August 2000. Fluor Daniel Northwest, Richland, WA, USA.

FDNW. 2000c. Electrical Switching Diagram (Partial), H-2-829733, Rev 2. August 2000. Fluor Daniel Northwest, Richland, WA, USA.

FDNW. 2004. Substation Conduit and Trench Plan, H-2-829806, Rev 1. March 2004. Fluor Daniel Northwest, Richland, WA, USA.

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FDNW. 2015. 200 East Area Electrical Utilities Distribution Map, H-13-000079, sheet 14, Rev 2. May 2015. Fluor Daniel Northwest, Richland, WA, USA.

FDNW. 2015. 200 East Area Electrical Utilities Switching Diagram, H-2-2126, sheet 7, Rev 27. August 2015. Fluor Daniel Northwest, Richland, WA, USA.

MSA. 2011. Electrical Utilities Customer Service Requests Process, MSC-PRO-478, Rev 1. September 2011. Mission Support Alliance, Richland, WA, USA.

MSA. 2013. A6 230 KV & 13.8 KV Simplified One-Line, H-2-829795, sheet 1, Rev 6. February 2013. Mission Support Alliance, Richland, WA, USA.

MSA. 2014. A6-WTP Electrical Utilities Switching Diagram, H-2-831247, sheet 1, Rev 2. November 2014. Mission Support Alliance, Richland, WA, USA.

MSA. 2015. Electrical Utilities Alarm Response Procedure, UE-R-22.01, Rev 3. March 2015. Mission Support Alliance, Richland, WA, USA.

NEC. 1999. National Electrical Code (NFPA 70), 1999 Edition, Article 305. WRPS. 2010. Analysis of Power Delivery to the WTP to Achieve a Minimum of 70MW (76.4MVA). RPP-RPT-46992, Rev 0. September 2010. Washington River Protection Solutions, Richland, WA, USA.

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Appendix A - Open ICD 11 Issues and Actions

Issue / Action

# Tracking # Issue / Action Description

Contract or Baseline (In-Out-N/A) Affected

Page(s) WTP TOC MSC

A11-20

24590-WTP-ATS-MGT-13-0484 MSC ESTARS Number: BOYNTON_SCOTTA-2013-0001

Complete incorporation of the interface protocols described in Section 2.2.6 into the appropriate WTP and MSC startup and operating procedures in order to ensure that energizing the Building 87 busses from Substation A6 takes place as smoothly as possible.

In In In 7

Notes: 1 TOC Baseline referenced here is the lifecycle Performance Measurement Baseline (PMB) which includes both WRPS and ORP owned scope. The approved

ICDs are one of the baseline documents that comprise the technical scope for the TOC Life-Cycle PMB.

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Appendix B - Issues and Actions Closed Since Last Revision Issue / Action

# Tracking # Issue / Action

Date Closed

Resolution

A11-17

ESTARs task # ORP-AMWTP-2013-0079

WTP Future Power Demand May Exceed Substation Supply Capability (WRPS Report RPP-RPT-46992)(WRPS 2010). The estimated WTP operations electrical power demand is 50.8 MW. (See 2.2.3 ) Currently, a single substation A6 transformer with two cooling stages is limited to supplying 62 MVA which equates to approximately 55 MW @ PF 0.89. In March of 2010, ORP provided direction to WRPS (DOE 2010) to analyze and report viable options for increasing power delivery to WTP from a single transformer to a minimum of 70 MW (WRPS 2010). Additionally, based on the study, the current substation A6 single transformer capacity of 62 MVA may not support the electrical needs over the 40 years of WTP operations.

10/07/2014 ESTARS task # ORP-AMWTP-2013-0079 was completed and closed by signature of BNI/DOE issue owners on 10/07/2014. The evaluation concluded that approximately 95% of electrical loads (50.5 MW) are either confirmed or committed, and approximately 5% loads (2.5 MW) are in a preliminary status. The major technical issues were identified, solutions provided, and major load changes were determined to be unlikely. In addition, the estimated load demand included approximately 4000 HP (approximately 3.6 MW) motor load design margin. This includes margins which were provided in addition to the maximum process needs for air compressors, heating, ventilation, and air conditioning fans, chillers and water pumps. Based on the above, and the option of converting the 7 MW temporary construction power to permanent power, there is no concern that load demand will exceed A6 Substation capacity of 55 MW. It should be noted that ownership of the A6 Substation risk was reclassified as ORP Programmatic Risk, per BNI 2009 (CCN 206911). DOE-ORP and DOE-RL will determine the contingency and future growth for A6 substation based on future planned additions to WTP, if any, and the facilities outside of WTP. As design continues, it is expected that changes to the high-level waste/pre-treatment technical issues could change the WTP power requirements. Some solutions may require

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Issue / Action

# Tracking # Issue / Action

Date Closed

Resolution

additional power, while others greatly reduce power demands. DOE will provide ongoing oversight as the WTP design progresses. The action has been evaluated and resolved by the interface owners (BNI 2015k, CCN 282945).

A11-18

24590-WTP-ATS-MGT-13-0540

WTP to specify the support needed from MSC in order to satisfy readiness requirements related to energizing Building 87 from Substation A6.

12/17/2014 WRPS and MSC have instituted an Authorization Interface Agreement coordinating MSC support at the multi-contractor A6 Substation/Building 87 readiness meetings: TOC-AIA-OHC-00037 (12/17/2014). Subsequently, various Integrated Operational Readiness meeting minutes document MSC input to WTP for required readiness effort (CCNs 268119 [2014e], 268121 [2015a], 277563 [2015e], 277705 [2015b], 277711 [2015c], and 278734 [2015f]). MSC will continue to update required WTP effort as needed, as a viable member of the readiness process. The action has been evaluated and resolved by the interface owners (BNI 2015k, CCN 282945).

A11-19

WRPS-TECHNICAL INTER-2013-0001

TOC coordinate with MSC to specify the support needed from WTP in order to satisfy readiness requirements related to energizing Building 87 from Substation A6.

12/17/2014 WRPS and MSC have instituted an Authorization Interface Agreement coordinating MSC support at the multi-contractor A6 Substation/Building 87 readiness meetings: TOC-AIA-OHC-00037 (12/17/2014). Subsequently, various Integrated Operational Readiness meeting minutes document MSC input to WTP for required readiness effort (CCNs 268119 [2014e], 268121 [2015a], 277563 [2015e], 277705 [2015b], 277711 [2015c], and 278734 [2015f]). MSC will continue to update required WTP effort as needed, as a viable member of the readiness process. The action has been evaluated and resolved by the interface owners (BNI 2015k, CCN 282945).

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Appendix C- ICD 11 Open Items List NOTE: The Interface Management Plan, 24590-WTP-PL-MG-01-001, Rev 8 (BNI 2015i), defines ICD

Issues as a contract technical, regulatory or nuclear safety baseline incompatibility for a WTP interface partner across a WTP Interface, or an incomplete WTP interface. There are also items that may not meet the definition of ICD Issues. New open items are added to each ICD revision as Appendix C with a tracking number or schedule ID that would serve to track their completion outside the ICD. Open items are removed from the ICD in the next revision following their introduction.

Item #

Description Originator

Status Actionee

0002

WTP provide an updated electrical power forecast for construction and operations as soon as practicable following project re-baselining.

TOC, Stuart Arm WTP, Richard Garrett

CLOSED The WTP Contractor will provide annual updates on the amount of AC power required for operations (startup and commissioning) and facility construction. The average annual energy and peak demand forecast will be a rough order of magnitude (ROM), non-binding estimate for the next 10 years, and will be provided by May 1 each year by WTP. The forecast will be sent from WTP to ORP as a formal letter that will be assigned a CCN number and will include TOC, MSC, and RL on distribution. This is tracked by 24590-WTP-ATS-MGT-13-0492 in the WTP Action Tracking System.

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Item #


Status Actionee

0003

MSC Electrical Utilities establish communication protocols with WTP on electrical system conditions/changes that may affect the reliability or availability of the off-site power source.

WTP, Scott Oxenford WTP, Richard Garrett

CLOSED MSC has issued procedures - MSA 2015, Electrical Utilities Alarm Response Procedure, UE-R-22.01, Rev 3; and MSA, 2011, Electrical Utilities Customer Service Requests Process, MSC-PRO-478, Rev 1. The MSC utilizes the Electrical Utilities Alarm Response Procedure UE-R-22.01 to provide direction for alarm management for the off-site utilities supplying permanent power to WTP. The procedure includes specific actions and notifications for alarms generated at the A-6 (251-E) substation.

0004

The 7 MW of temporary construction power may, at some point in the future, become permanent power. This requirement is not currently in the contract baseline for any contractor.

ORP, Jason Young and Mazen Al-Wazani WTP, Gary Lucke

OPEN (WTP Action Tracking System 24590-WTP-ATS-MGT-15-0369)

0005

The bulleted statement in Section 2.2.1 (formerly 1.4.4), “Peak demand may be 7 MW through 2028” is a conservative estimate for MSC planning purposes only. A temporary construction power peak demand of 7 MW beyond 2019 is not currently accounted for in the contract baseline for any contractor.

ORP, Jason Young and Mazen Al-Wazani WTP, Rocky Johnson

OPEN (WTP Action Tracking System 24590-ATS-MGT-15-0204)

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Item #


Status Actionee

0006

WTP to specify the additional Preferred Power Source (PPS) requirements for compliance with IEEE 765. This specification will include a determination (coordinated with the Interface Partners) of the physical and administrative interface points for the additional PPS. MSC and DOE will begin planning, estimating and budgeting for the additional PPS upon receipt of the specified requirements. Requirements need to be communicated to MSC at least 3 financial years in advance of when the additional PPS is needed to be operational for them to complete design and construction.

WTP, Jeremy Wilkins WTP, Gary Lucke


0007

Once Building 87 has been turned over from Startup to Operations, a change to the interface boundaries, between MSC and WTP, for the 13.8kV cabling and duct banks, will be implemented; that is, the boundaries will be moved to the line side of the Building 87 switchgear. This transfer is contingent upon the development of a process between WTP and MSC to allow the transfer of the cables and its associated technical baseline documentation. This item will be tracked both by WTP and MSC as an open item.

WTP Richard Garrett MSC, Randy Adkins WTP, Marshall Miller

OPEN (WTP Action Tracking System 24590-WTP-ATS-MGT-15-0426, and ESTARS Task Number MSA-SIU EU-2015-0002 for MSC tracking)

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Item #


Status Actionee

0008

With the improvements regarding margin management having been incorporated into WTP Engineering processes and procedures (as stated in BNI 2014c, MIP-43, Margin Management Improvements, 24590-WTP-PL-MGT-14-0006, Rev 1), a revision to the Load Flow calculation (BNI 2011, Calculation, Power System Load Flow Analysis, 24590-WTP-E1C-MVE-00004, Rev 0) will be prepared to address, in part, the issue of adequate margin between power demand and substation supply capability. This revision is addressed in a future activity – Schedule ID 3ED1600055, currently scheduled to be completed in November 2018, and will only address the impacts from DFLAW at this time. Impacts from HLW and PTF will be addressed in a future revision of this calculation.

WTP, Richard Garrett WTP, Gary Lucke
