ML18268A114

Industry Initiative on Open Phase Condition, Revision 2

ML18268A114
Person / Time
Site:	Nuclear Energy Institute
Issue date:	09/20/2018
From:	Pitesa B Nuclear Energy Institute
To:	Ho Nieh Office of Nuclear Reactor Regulation
References
Download: ML18268A114 (1)

Text

BILLPITESA Chief Nuclear Officer 1201 F Street, NW, Suite 1100 Washington, DC 20004

~I NUCLEAR ENERGY INSTITUTE P: 202.739.8081 jwp@nei.org nel.org September 20, 2018 Mr. Ho Nieh, Jr.

Director, Office of Nuclear Reactor Regulation U.S. Nuclear Regulatory Commission Washington, DC 20555-0001

Subject:

Industry Initiative on Open Phase Condition, Revision 2 Project Number: 689

Dear Mr. Nieh:

On March 16, 2015, the Nuclear Energy Institute (NEI)1 informed the NRC that the industry had formally approved revision one to the OPC Initiative to address the open phase condition in the off-site power circuits.2 Since that time, many plants have completed instaliation of their Open Phase Isolation System (OPIS) with other plants scheduled to complete during 2018. Monitoring data to date indicates that installed OPIS would have experienced spurious actuations if the automatic trip functions had been activated. Some spurious actuation causes are unknown and resolutions are still being pursued. Additionally, due to the limited monitoring period remaining before December 31, 2018, there is some uncertainty that all existing and potentially new plant/ grid configurations can be reliably handled by the various OPIS designs without inducing spurious actuations. As a result, the industry has recognized the need for an extended monitoring period necessitating a second revision to the industry initiative.

To provide adequate time for implementation of the necessary modifications to the plants and to accommodate an adequate monitoring time afterwards, we have revised the implementation schedule.

Specifically, we have established a revised implementation date of December 31, 2019 with a minimum of 24 months for the completion of the associated monitoring period. We anticipate that a majority of plants will meet this implementation date, however, plants that h~ve not accumulated 24 months of monitoring time by December 31, 2019 may extend the monitoring period into 2020 until they reach 24 months. This monitoring period will allow for the collection and application, including completion of any design 1

Toe Nuclear Energy Institute (NEI) is responsible for establishing unified policy on behalf of its members relating to matters affecting the nuclear energy industry, Including the regulatory aspects of generic operational and technical issues. NEI's members include entities licensed

. to operate commercial nudear power plants in the United St.ates, nuclear plant designers, major architect and engineering firms, fuel cycle facilities, nuclear materials licensees, and other organizations involved In the nuclear energy Industry.

2 ML15075A456 NUCLEAR. CLEAN AIR ENERGY

Mr. Ho Nieh, Jr.

September 20, 2018 Page 2 adjustments, of station-specific Operating Experience through one operating cycle and two seasonal periods and ensure that industry-wide Operating Experience can be evaluated and applied.

Additional changes in the revision include allowing for UFSAR and Technical Specification changes to follow the station's modification process and updating several actions that have been completed.

The industry's chief nuclear officers have voted to approve this revision to the NEI Open Phase Conditions Initiative. A copy of the approved initiative revision is attached for your information. The initiative is a formal commitment by NEI member companies that operate nuclear power plants to follow a specific policy or plan of action; If you or your staff has any questions, please feel free to contact me or Stephen Geier (seg@nei.org; (202) 739-8111).

Sincerely, Bill Pitesa Attachment c: Mr. Jessie F. Quichocho, NRR/DE/EEOB, NRC Mr. Eric J. Benner, NRR/DE, NRC Ms. Margaret M. Doane, OEDO, NRC Mr. Brian J. McDermott, NRR, NRC

Open Phase Condition Initiative September 2018, Revision 2 Goal An open phase condition will not prevent functioning of important-to-safety structures, systems and components. An open phase condition is defined as an open phase, with or without a ground, which is located on the high voltage side of a transformer connecting a general design criterion (GDC) 17 off-site power circuit to the transmission system.

Objectives

• Operating nuclear power plant licensees de.monstrate that important-to-safety functions remain available given an open phase condition or install plant modifications to detect and isolate from the open phase condition. If the open phase condition prevents the functioning of important-to-safety structures, systems, and components, the engineered safeguard buses should be transferred to an alternate source.

• New reactor licensees, combined license (COL) applicants and design centers for active

• safety features plant designs demonstrate that important-to-safety functions remain available given an open phase condition or install plant modifications to .detect and isolate from the open phase condition. If the open phase condition prevents the functioning of important-to-safety structures, systems and components, the engineered safeguard buses should be transferred to an alternate source.

Criteria Notes:

• Design features have not been developed to protect against an adverse open phase condition for all plant designs and configurations. This section will only address the criteria for dealing with an adverse open phase condition. The design features (if not yet available) will be developed to meet the criteria noted below.

• Based on recent operating experience, two open phases must be considered when addressing the criteria below. Thus, the term "open phase" in the remainder of this document will mean one or two open phases. Preliminary analysis shows that two open phases is not a limiting condition, but this must be documented.

Detection. Alarms and General Criteria An open phase condition must be detected and alarmed in the control room unless it can be shown that the open phase condition does not prevent functioning of important-to-safety structures, systems and components. For example, some licensees believe they can show no impact due to transformers that are oversized for their loading conditions. Sufficient "robust calculational bases or tests must be provided to show that the open phase condition will not adversely affect important-to-

• safety equipment performance. Testing is preferred if this is possible without challenging on line or September 2018, Revision 2 1

1 shutdown risk profiles.

If the licensee can demonstrate that the open phase condition does not prevent the functioning of important-to-safety structures, systems and components, then detection of the open phase condition should occur within a reasonably short period of time (i.e., 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />). The licensee must document how detection and correction of the open phase condition will occur.

Detection circuits for the open phase condition, which prevents the functioning of important-to-safety structures, systems and components, must be sensitive enough to identify an open phase condition for credited loading conditions (i.e., high and low loading).

Note: It is recognized that some transformers have very low or no loading when in the

. standby mode. Automatic detection may not be possible in this condition; however, automatic detection must happen as soon as loads are transferred to this standby source.

Additionally, if automatic detection is not possible, shiftly surveillance requireme~ts must be established to look for evidence of an open phase.

If open phase condition actuation circuits are required, the design should minimize misoperation or spurious action that could cause separation from an operable off-site GDC 17 source. Additionally, the protective scheme should not separate the operable off-site GDC 17 source in the range of voltage unbalance normally expected in the transmission system. Licensees inust demonstrate that the additional actuation circuit design does not result in lower overall plant operation reliability.

These devices must be coordinated with other protective devices in both the transmission system and the plant's electrical system (e.g., fault protection, overcurrent, etc.).

Detection and actuation circuits may be non-Class-1E. While it is recognized that a Class-1E solution is preferable, a non-Class-1E solution may be more effective. A non-Class-1E solution will enable timely implementation and will provide reasonable levels of reliable functionality given the low likelihood of adverse impacts from open phase events. Additionally, there is regulatory precedent in using_non-Class-1E circuits in newly identified nuclear plant vulnerabilities (e.g., anticipated transient without scram (ATWS) circuits). New non-Class-1E circuits will not be allowed to replace existing Class-1E circuits.

The Updated Final Safety Analysis Report (UFSAR) must be updated to discuss the design features and analyses related to the effects of, and protection for, any open phase condition design vulnerability. This update would typically be to chapter 8.

September 2018, Revision 2 2

Protective Actions If an open phase condition occurs\ the following design requirements are to be satisfied:

1. With no accidentc:ondition signal present, the licensee must demonstratethat:

1.1. The open phase condition does not adversely affect the function of important-to-safety structures, systems and components; or *

• 1.2. Technical Specification (TS) Limiting Conditions for Operation (LCOs) are maintained or the associated TS Actions are met without entry into TS LCO 3.0.3 (or the equivalent).

This provision applies to TS equipment affected by the open phase condition (I.e., not just the specifications related to the off-site power source); and 1.3. Important-to-safety equipment is not damaged by the open phase condition; and 1.4. Shutdown safety is not compromised .

. Notes:

• Provision 1.1 or provisions 1.2, 1.3 and 1.4 must be maintained_.

• *For operating modes where power is supplied from the main generator through unit auxiliary transformers, the licensee must evaluate provisions 1.1, 1.2 and 1.3 assuming that the main generator is lost and loads must be transferred to the alternate

• source(s). Load transfer cases w_ill include reactor trips with and without accident conditions present. The accident transfer cases are used for assessment of Criterion 2 below.

• Operator action may be credited in the evaluation of provisions 1.3 and 1.4 if existing regulations and guidelines are met for the use of manual actions in the place of automatic actions.

• Item 1.4 is intended to ensure that an open phase event will not challenge fuel cooling during hot shutdown, cold shutdown and refueling modes of operation. Power supplied to spent fuel pool cooling systems must also be considered. The limiting conditions will be those where power is supplied from a single source or an alternate source is used that does not have open phase protection (such as a main power transformer back-feed source).

• Provision 1.2 must consider situations where alternate sources are removed from .

service if allowed by the _Technical Specifications.

• If provision 1.1 or provisions 1.2; 1.3 and 1.4 cannot be met with the existing plant 1

For plants. that have evaluated their specific designs and installations and have determined that there is no single credible failure that could cause an open phase condition, a full engineering evaluation must be developed and issued to document the basis for an open phase condition as a non-credible event. The Bruce Power and Forsmark operating experience must be considered as part of this analysis.

• September 2018, Revision 2 3

design features, modifications will be required to provide automatic features to ensure the provisions can be met.

2. With an accident condition signal present, the licensee must demonstrate:

2.1. Automatic detection and actuation will transfer loads required to mitigate postulated accidents to an alternate source and ensure that safety functions are preserved, as required by the current licensing bases.

2.2. Alternatively; a licensee may show that all design basis accident acceptance criteria are met with the open phase condition, given other plant design features. Accident assumptions must strn include licensing provisions associated with single failures. Typically, licensing bases will not permi~ consideration of the open phase condition as the single failure since this failure is in a non-safety system.

Note:

• It is not expected that accident analyses are updated when licensees add additional

• detection and mitigation circuitry. Actuation times needed to maintain equipment safety functions should be short enough to provide reasonable assurance that accident mitigation functions are maintained.

Periodic tests, calibrations, setpoint verifications or inspections (as applicable) must be established for any new protective features. The surveillance requirements must be added to the plant Technical Specifications if necessary to meet the provisions of 10CFRS0.36. Further industry guidance will be provided for the development of Technical Specifications as the design features are identified ..

Interim Actions (Operating Plants)

The Institute of Nuclear Power Operations (INPO) staff performed reviews of the industry action plans in response to the Level 2 INPO Event Report (IER) L2-12-14, "Automatic Reactor Scram

. Resulting from a Design Vulnerability in the 4.16-kV Bus Undervoltage Protection Scheme" and ensured that plant operators had identified compensatory actions needed to detect degraded off-site power sources due to open phase circuit conditions. INPO also ensured that plant operating procedures were either sufficient or actions were taken to enhance the procedures to help operators promptly diagnose and respond to open phase circuit conditions on off-site power supplies to Class-1E vital buses. The reviews were completed and satisfactory industry responses were received in.the 4th Quarter 2012.

INPO Follow-up Actions (Operating Plants)

Starting in 1st Quarter 2014, the engineering evaluators will review all recommendation responses in

• IER L2-12-14 during the plant evaluations and verify that the recommendations are fully implemented or that there is a reasonable due date and plan to fully implement the recommendations. Evaluators will verify that the compensatory measures originally taken are still in place and being effective. Evaluators will also review progress made and the milestones developed for the long-term corrective actiqns to provide automatic protection from open phase circuit .

September 2018, Revision 2 4

conditions for off-site power sources supplying Class-1E vital buses. They will also ensure a review and study of the station design basis and modeling has been conducted to obtain a complete understanding of plant and equipment response following an open phase event. Also, the final station configuration will be reviewed to ensure that the probability of losing the off-site (preferred) and the on-site power source is not increased. The ev91uator review andrconclusion of IER recommendations will be documented in evaluation products.

Regulatory Requirements GDC 17 provides criteria for the electric design of nuclear power plants for which a construction permit application was submitted after the Commission promulgated the GDC. The PSAR, FSAR and UFSAR document the implementation of the design criteria.

GDC 17 states:

An on-site electricpowersystem andan off-siteelectricpowersystemshallbe provided to permit functioningofstivctures, systems, andcomponents important to safety. The safetyfunction for each system (assuming the othersystem is notfunctioning)shallbe to provide sufficient capacity and capability to assure that: (1) specifiedacceptable fuel design limits and design conditions ofthe reactor coolantpressure boundary are not exceededas a result ofanticipatedoperational occurrences, and(2) the core is cooled and containment integrity and other vital functions are maintained in the event ofpostulated accidents.

The on-site electricpowersupplies, including the batteries, and the on-site electric distribution system, shallhavesufficientindependence, redundancyandtestabilityto perform theirsafety functions assuming a single failure.

Electricpowerfrom the transmission network to the on-site electric distribution system shall be supplied by two physically independent circuits {riot necessarily on separate rights of way) designed and located so as to minimize to the extent practical the likelihood of their simultaneous failure under operating and postulated accident and environmental conditions. A switchyard common to both circuits is acceptable. Each of these circuits shall be designed to be available in sufficient time following a loss ofall on- site alternating current power supplies and the other off-site electric power circuit, to assure that specified acceptable fuel design limits and design conditions ofthe reactor coolantpressure boundary are not exceeded One ofthese circuits shall be designed to be available within a few seconds following a loss-of-coolant accident to assure

. that core cooling, contalnmentintegrityandothervitalsafetyfunctionsaremaintained Provisions shall be included to minimize the probability of losing electric power from any of the remaining supplies as a result of, or coincident with, the loss of power generated by the nuclear power unit, the loss ofpower from the transmission network, or the loss ofpower from the on-site electricpowersupplies.

Pre-GDC plants have their principal design criteria specified in their UFSAR.

Schedule for Operating Plants (For Plants where License Amendments (LA) are not required to install any design changes. For plants where LAs are required, the design September 2018, Revision 2 5

change schedule will be as directed by the LA process.)

• May 15. 2013 NSIAC endorsement of the industry direction to resolve the open phase condition issue. Complete.

July 31. 2013 Draft NEI Initiative (what is required; industry criteria to address the open phase condition issue).

Complete.

Aug. 31. 2013 NSIAC approval of the NEI Initiative by a vote of 80% of CNOs. Complete.

• Dec. 31. 2013 Draft NEI guidance document (how to meet industry criteria; containing industry research, developments, pilots, technology, etc. to address the open phase condition issue). Complete.

Dec. 31. 2014 Demonstration of compliance with the open phase condition criteria through analysis or identify appropriate actions required to demonstrate compliance. Complete.

• March 2015 NSIAC approval of Revision 1 to the NEI Initiative. Complete.

Dec. 31. 2018 Implementation of design changes, if necessary, to comply with the open phase condition criteria.

The "active" actuation features of new technology designs may be installed in a monitoring mode, with adequate justification, to demonstrate reliability. During the monitoring period, further defined below, stations must implement an alarm respol"!se process for operators to take appropriate action if the system detects the presence of an OPC.

Monitoring Period If a monitoring period was deemed necessary, the period will run for at least 24 months. In order to capture industry-wide operating experience, the monitoring period for all plants will extend until December 31, *2019. Plants that have not accumulated 24 months of monitoring time by December 31, 2019, may extend the monitoring period into 2020 until they reach 24 months. This period of monitoring will ensure the collection and application, including completion of any design adjustments, .of station-specific Operating Experience through one operating cycle and two seasonal periods and ensure that.industry-wide Operating Experience can be evaluated and applied.

Upon completion of the monitoring period, design adjustments identified during the monitoring September 2018, Revision 2 6

period will have been performed and all "active" actuation features needed to demonstrate compliance with the open phase .condition criteria will be enabled. During the monitoring period, stations must implement an alarm response process for operators to take appropriate action if the system detects the presence of an OPC.

Additional Actions UFSAR Updates - Completion in conjunction with the timelines noted above and as required per the

• station's modification process.

Technical Specification Updates - Submitted by December 31, 2018, if required. If a TSTF Traveler is available, submitted within six months of issuance of an NRC approved TSTF Traveler.

Note 1: If Technical Specification updates are required for modification implementation, the schedule is expected to change based on NRC required review times; however, the station schedule should be maintained .as closely as possible with the timelines noted above.

Note 2: If a Technical Specification Bases-only change is identified, implementation of the change by stations is expected to be completed.as required per the station's modification process.

schedule for New Reactors COL Licensees Complete design changes and plant modifications, as needed, prior to fuel load.

COL Applicants Describe design features in the FSAR, if change to certified design is required.

Design Centers Provide design features in the Design Control Document/FSAR.

September 2018, Revision 2 7