NRC-89-0201, Provides Addl Clarification & Replaces Repts to NRC on Compliance of Plant Design to Reg Guide 1.97,Rev 2.Design of Instrumentation Required to Assess Plant & Environ Condition During & Following Accident,Meets Reg Guide 1.97,Rev 2
| ML20247H947 | |
| Person / Time | |
|---|---|
| Site: | Fermi  |
| Issue date: | 09/12/1989 |
| From: | Orser W DETROIT EDISON CO. |
| To: | NRC OFFICE OF INFORMATION RESOURCES MANAGEMENT (IRM) |
| References | |
| CON-NRC-89-0201, CON-NRC-89-201, RTR-REGGD-01.097, RTR-REGGD-1.097 NUDOCS 8909200159 | |
| Download: ML20247H947 (38) | |
Text
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September 12, 1989 NRC-89-0201 U. S. Noclear Regulatory Commission Attn: Document Control Desk Washington, D. C.
20555
References:
- 1) Fermi 2
'NRC Docket No. 50-341 NRC License No. NPF-43
- 2) Regulatory Guide 1.97, " Instrumentation for Light Water Cooled Nuclear Power Plants to Assess Plant and Environs Conditions Daring and Following an Accident",
Rev 2 dated December 1980.
- 3) Detroit Edison Letter RC-LG-85-0050, " Regulatory Guide 1 97 Compliance Report, dated September 30, 1985.
- 4) NRC Letter, " Fermi 2 Emergency Response Capability -
Conformance to Regulatory Guide 1.97, Revision 2 (TAC
^
No. 59620)", dated September 1, 1987
- 5) NRC Generic Letter Wo. 82-33, Supplement 1 to NUREG-0737, Requirements for Emergency Response Capability, dated December 17, 1982.
- 6) Detroit Edison Letter.to NRC, EF2-66,759, " Additional Environmental Qualification Information Requested by the NRC", dated January 16, 1984.
- 7) Detroit Edison Letter NRC-87-0198, " Additional Clarification of Fermi 2 Emergency Response Capability
- Conformance to R. G. 1.97, Rev 2 (TAC-59620)", dated October 15, 1987
- 8) ANSI /ANS-4.5-1980, American National Standard Criteria for Accident Monitoring Functions in Light Water Cooled Reactors, December 31, 1980.
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USNRC 4
9, September 12, 1989 NRC-89-0201 Page 2
- 9) Detroit Edison Letter NRC-89-0148, " Additional Clarification To Fermi 2 Compliance To Regulatory Guide 1.97, Revision 2" dated June 19, 1989
- 10) Detroit Edison Letter, EF2-63,882, " Summary of Post Accident Sampling Analytical Procedures" dated May 3, 1983
- 11) License Event Report 50-341/89-009
Subject:
Regulatory Guide 1.97, Revision _2 Design Review This letter provides additional clarifications and replaces the previously submitted reports to the NRC on compliance of Fermi 2 design to Regulatory Guide 1.97, Revision 2 (References 3 and 7). A
. complete design review of primary containment isolation valve position indication against Regulatory Guide 1.97, Revision 2, Category 1 requirements _was performed earlier and adequate justification for deviations is provided in Reference 9 A complete design review of other_ variables has now been completed and justification for deviations is provided herein. The re-reviews were performed because of concerns that arose following the event reported in Reference 11' that were not associated with the reportable issue. This letter and Reference 9 jointly provide the Fermi 2 design compliance report to Regulatory Guide 1.97, Revision 2.
Based on the clarifications and justifications provided herein, the Fermi 2 design of instrumentation required to assess plant and environs conditions during and following an accident, as identified in Table 1 of Regulatory Guide 1.97, Revision 2, meets the objectives of Regulatory Guide 1.97, Revision 2.
If there are any questions Detroit Edison would be happy to meet with the NRC on this topic. Contact Lynne Goodman at (313) 586-4211 to arrange a meeting or with any questions.
Sincerely, AAEl Enclosure
e o-USNRC September 12, 1989 NRC-89-0201 Page 3 cc:
A. B. Davis R. C. Knop W. G. Rogers J. F. Stang
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USNRC September'12, 1989 NRC-89-0201 Page 4 w/o Encl.
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R. Ballis w/ enc 1.
C. Borr (WPSC, Inc.) w/ encl.
S. G. Catola/G. Cranston L:
P. Fessler/R. Anderson D. R. Gipson L. S. Goodman.w/ encl.
D. Hahn (Michigan Dept./Public Health) w/ encl.
R. Matthews l
R. McKeon/J. Plona-I W. McNeil w/ encl.
C. A. Naegeli W. S. Orser A. C. Settles R. B. Stafford F. J. Svetkovich B. R. Sylvia R. Thorson G. M. Trahey W. Tucker Information Management - 140 NOC w/ encl.
Secretary's Office.(2412 WCB) w/ encl.
NRR Chron File w/ enc 1.
ISEG Coordinator (316 NOC)
NSRG Secretary RACTS Coordinator UFSAR Coordinator w/ encl.
Author - A. Khan w/ encl.
Routing Copy
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Enclosura September 12, 1989 NRC-89-0201 Page 1 REGULATORY GUIDE 1.97, REVISION 2 DESIGN REVIEW
Background
The guidance provided by NRC Regulatory Guide 1.97, Revision 2 stipulates that indications of plant variables are required by the Control Room operating personnel during an accident situation to (1) permit the operator to take preplanned manual actions to acccmplish safe plant shutdown; (2) determine whether the reactor trip, engineered safety feature systems and manually initiated safety systems and other systems important to safety are performing their intended functions; and (3) provide information to the operators that will enable them to deterniine the potential for causing a gross breach of the barriers to radioactivity release and to determine if a gross breach of a barrier has occurred. Table 1 to Regulatory Guide 1.97, Revision 2 provides a listing of plant variables that support these requirements and delineate quality aspects for each variable.
NUREG-0737 and its Supplement 1 (Generic Letter 82-33) provide additional clarifications regarding Regulatory Guide 1.97, Revision 2, and specify acceptable means for meeting the basic requirements provided therein. The Generic Letter requires that deviations from the R. G. 1.97, Revision 2 guidance be justified.
Regulatory Guide 1.97, Revision 2 covers basically two broad classes of instrumentation, namely 1.
Accident Monitoring Instrumentation l
l 2.
Systems Operation Monitoring and Effluent Release Monitoring Instrumentation.
l-The accident monitoring instrumentation is divided into 3 types:
Type A - Those variables to be monitored that provide the primary information required to permit the Control Room Operator to take specific manually controlled actions for which no automatic contrul is provided and that are required for safety systems to accomplish their safety functions for design basis accident events.
Type B - Those variables that provide information to indicate whether plant safety functions are being accomplished. The plant safety functions are (1) Reactivity Control, (2) Core
r-4 6
- Enclo;ura September 12, 1989 NRC-89-0201 Page 2 Cooling, (3) Maintaining Reactor Coolant System Integrity, and (11) Maintaining Containment Integrity.
Type C - Those variables that provide information to indicate the potential for breaching or the actual breach of the barriers to fission product release. The barriers are (1) Fuel Cladding, (2) Primary Coolant Pressure Boundary, and (3)
Containment.
The systems operation monitoring and effluent release monitoring instrumentation is divided into 2 types:
Type D - Those variables that provide information to indicate the operation of individual safety systems and other systems important to safety.
l Type E - Those variables to be monitored as required for use in determining the magnitude of the release of radioactive materials and continually assessing such releases.
l' Table 1 of Regulatory Guide 1.97, Revision 2 lists all the variables of types B, C, D, and E with their respective ranges and qualification criteria category. Regulatory Guide 1.97, Revision 2, Table 1 does not explicitly define any Type A variables; rather, it specifies that these are plant specific and that they should be qualified to Category 1 criteria. Detroit Edison developed a list of Type A variables by a joint effort of Engineering and Production personnel. Fermi 2 Type A variables are based on BWR Owners Group recommendations and are generic for the BWR design. The Fermi 2 Type A variables list was provided to che NRC by Reference 7 As indicated in Table 1 of R.G.
1.97, Rev. 2, each variable is required to be designed and qualified to Category 1, 2 or 3 requirements.
Category 1 basic design requirements as stated in R. G. 1 97, Revision 2 are summarized as follows:
a.
The instrumentation from the sensor to the display is to be environmentally qualified (EQ) in accordance with Regulatory Guide 1.89 and the methodology of NUREG-0588. The seismic portion of qualification should be in accordance with Regulatory Guide 1.100.
b.
No single failure within either the accident monitoring instrumentation, its auxiliary supporting features, or its power sources concurrent with the failures that are a condition or result of a specific accident should prevent the operators from being presented the information necessary for them to determine
Enclorura September 12, 1989 NBC-39-0201 Page 3 the safety status of the plant and to bring the pla to and esintain it in a safe condition following that accident.
Redundant or diverse channels should be electrically independent and physically separated from each other and from equipment not classified important to safety in accordance with R. G. 1.75, up to and including any isolation device. Within each redundant divisfon of a safety system, redundant monitoring channels are not needed.
c.
The instrumentation should be energized from station Standby Power sources as provided in Regulatory Guide 1 32, " Criteria for Safety-Related Electric Power Systems for Nuclear Power Plants",
and should be backed up by batteries where momentary interruption ir rim tolerable.
d.
The instrumentation channel should be available prior to an accident except as provided in paragraph 4.11, " Exemption", as defined in IEEE Standard 279 or as specified in Technical Specifications.
e.
The recommendations of Regulatory Guides 1.28, 1 30, 1.38, 1.58, 1.64, 1.74, 1.88, 1.123, 1.144 and 1.146 pertaining to Quality Assurance (QA) should be followed.
f.
Continuous indication (it may be by recording) display should be provided. Where two or more instruments are needed to cover a particular range, overlapping ranges should be provided.
g.
Recording of instrumentation readout information should be provided on a dedicated recorder if information is essential for operator action. Otherwise, it may be continuously updated, stored in computer memory and displayed on demand.
h.
Instruments for Category 1 and 2 should be specifically identified on the control panels so that the operator can easily discern that they are intended for use under accident conditions.
- i. The instrumentation should have a program of periodic checking, testing, servicing, adjusting, replacing, calibration, etc., in accordance with the applicable portions of Regulatory Guide 1.118. To the extent practicable, monitoring instrumentation inputs should bs from sensors that directly measure the desired variables. An indirect measurement should be made only when it can be shown by analysis to provide unambiguous information. To the extent practicable, the same instruments should be used for
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Enclosura
-September. 12, 1989 NRC-89-0201 Page 4 a
accident monitoring as' are used for the normal operations of the plant.
J. Table 1 of Regulatory Guide 1.97, Revision 2 provides the instrument range for'the accident monitoring instrumentation..
ic Category 2 basic design requirements as stated in R. G. 1 97, Revision 2, paragraph C.1 3 2, are similar to those for Category 1 Instrumen-tation as identified above with the following exceptions:
- 1. There is no' requirement to meet the single failure criteria;
- 2. Power supplies do not necessarily have to be standby power, but should be backed up by batteries where momentary interruption is not tolerable;
- 3. Seismic Qualification per Regulatory Guide 1.100 may be needed provided the instrumentation is part of a safety related system.
- 4. The quality assurance guides, as identified in Item e above, should be followed unless the instrumentation is less important to safety than,other instrumentation, and in that. case it may not be necessary to apply the same quality assurance measures to all instrumentation.
- 5. No unique identification on control panel is needed if the variables are Type D or E.
Category 3 basic design requirements, as stated in Regulatory Guide 1.97, Revision 2, Paragraph C.1 3 3, are summarized below.
- a. The instrumentation should be of high quality commercial grade and should be selected to withstand the specified service l
' environment.
- b. The method of display may be by dial, digital, CRT or strip-chart recorder indication. Only effluent radioactivity monitors, area radiation monitors, and meteorology monitors should be recorded. A dedicated recorder is required if information is essential for operator information or action.
Otherwise, it may be continuously updated, stored in computer memory, and displayed on demand.
- c. Periodic checking, testing, calibration and calibration verification should be in accordance with the applicable portions of Regulatory Guide 1.118. The monitoring instrumentation inputs should be from sensors that directly
x Enclecura
.g September-12,.1989 NRC-89-0201 1
Page 5 measure the desired variables and should be designed to-facilitate recognition, location, replacement, service, adjustment and repair.
- d. The ranges of instrumentation shall be per Table 1 of Regulatory Guide 1.97, Revision 2.
Previously, Detroit Edison performed a design review of primary containment isolation valve position indication and a compliance report of Fermi 2 design to R.G.-1.97, Rev. 2 was submitted to the NRC by Reference 9 This report will complete the design review of the "emaining variables of R.G. 1.97, Rev. 2 and furnishes a report to the NRC on compliance of remaining variables to R.G. 1.97, Rev. 2.
Objectives 1.
A design review of Fermi 2 Instrumentation required to assess plant and environs conditions during and following an accident shall be performed and any deviation from Regulatory Guide 1.97 Revision 2 requirements shall be identified.
2.
A technical justification of the deviations identified by the design review or any additional clarification for compliance to Regulatory Guide 1.97 requirements shall be provided.
3 If technical justification of the deviation cannot be provided, a modification shall be implemented to bring Fermi 2 into compliance.
Design Review Detroit Edison has completed a compliance design review of the balance of the Regulatory Guide 1 97, Revision 2 variables not covered in Reference 9 (Primary Containment Isolation Valve Positions). This review compared the current as-built configuration and Engineering Design Package (EDP) 1021 planned for implementation during the first refueling outage to the requirements of Regulatory Guide 1 97, Revision 2 for Category 1, 2, and 3 The review is summarized on Table 1 provided herein. During the design review, each component in the instrument channel, as well as any supporting element of a variable, were taken into consideration in determining the compliance with criteria of R. G. 1.97, Rev. 2.
The variable is considered in compliance when every element in the loop meets the requirement and compliance is identified with a notation "Y" in Table 1.
A super-script number is attached to the "Y" if an additional clarification note is deemed necessary to explain compliance to R.G. 1.97.
Similarly, the letter "N" is shown for criteria if any component in the instrument channel of a variable is not in full con.pliance with Y _ - ___-- ____
m;
'Encle;ura September 12, 1989' NRC-89-0201 Page 6 R.G. 1.97 criteria. A technical justification for acceptance of the design is provided for each deviation.
Results of Design Review Sixty-seven (67) of sixty-eight (68) variables of Regulatory Guide 1.97, Revision 2 were reviewed of which twenty-three (23) were Category 1, twenty-seven (27) were Category 2, and seventeen (17) were Category 3 The one (1) variable not reviewed in this task had previously been reviewed and results were submitted to the NRC (Reference 9).
All sixty-seven (67) variables reviewed meet the objectives of Regulatory Guide 1.97, Revision 2 with the appropriate clarification and/or justification.
Detroit Edison has provided.wenty-seven (27) clarification notes and nineteen (19) justifications for the variables. The clarification notes and justifications can be broken down into twelve groups. These groups are:
- 1) Environmental Qualification
- 2) Seismic Qualification
- 3) Single Failure
- 4) Power source
- 5) Out-of-service
- 6) Quality Assurance
- 7) Display Type
- 8) Display Method
- 9) Range
- 10) Industry Development
- 11) Not Applicable to Fermi 2
- 12) Variable Dropped From R.G. 1.97 Based on this design review, no requirement for any new plant modification is found. However, implementation of EDP 1021 was taken into consideration since it is planned for implementation during the first refueling outage. This EDP changes the Standby Liquid Control System boron to enriched boron. With or without this modification, Fermi 2 meets the objective of R.G. 1.97 for Reactor Coolant System soluble boron concentration (Table 1, Variable B3). Additionally, j-completion of EDP 6740 during the second refueling outage will eliminate an additional deviation.
Conclusion All exclusions and deviations are technically justified and no plant I
modification is needed.
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l Enclo:ura September 12, 1989 NRC-89-0201 Page 19 Clarification Notes:
- 1) Regulatory Guide 1.97, Revision 2, ?ositions C.1.3 1.(a) and C.13 2(a) require the instrument u.annel (i.e., from sensor to recorder) to meet environmental and seismic qualification standards referenced in the guide. The Fermi 2 recorders and indicators which provide the Control Room indication required by this regulatory guide meet the objectives of these requirements because:
- 1) L&N Speedomax recorders (Series M and W) which are seismically qualified via type testing in accordance with IEEE 344-1971;
- 2) Recorders and indicators are installed in the Control Center which is a mild environment.
Furthermore, Regulatory Guide 1.97 requires that Category 1 and some Category 2 instrument channels should be qualified seismically per R.G. 1.100. Regulatory Guide 1.100 states that seismic qualification in accordance with IEEE-344-1975 is acceptable. Fermi 2 accident monitoring instrumentation design has some components which are seismically qualified to the standards effective at the time of procurement (i.e.,
IEEE-344-1971). The Fermi 2 seismic qualification program which was audited and approved by the NRC, reflects the use of IEEE-344-1971 for the seismic qualification of components procured prior to the issuance of the IEEE-344-1975 revision (Refer to Section 7 5.2 of NUREG-0798).
- 2) The accident monitoring instrumentation channels are demonstrated operable by performance of the channel check, channel functional check and channel calibration operations at a frequency identified in the appropriate Fermi 2 Technical Specification sections. The minimum number of instrument channels required operational during a particular operational condition are also specified in Fermi 2 Technical Specifications. However, instrument channels which are not part of Fermi 2 Technical Specifications do not have specific requirements or restrictions for out-of-service criteria.
- 3) ANSI /ANS 4.5-1980 is referenced from Section C of Regulatory Guide 1.97 and requires that the " accident monitoring displays... be distinguishable from other displays so that in an accident situation, the operator can rapidly identify the accident monitoring displays."
Detroit Edison originally planned to uniquely color code the accident monitoring displays to meet the criteria. However, a
4 e
Enclo;ur3 f
September 12, 1989 NRC-89-0201 Page 20 human factors evaluation of the Control Room determined that this additional color coding could potentially cause confusion and distractions to Operations personnel during an accident.
Therefore, the special identification required by Regulatory Guide 1.97 is not desirable and thus unique color coding was not implemented.
- 4) Regulatory Guide 1.97, Revision 2, Position C.1.5 requires periodic checking, testing, calibration and verification of accident monitoring instrument channels in accordance with Regulatory Guide 1.118.. The intent of Regulatory Guide 1.118 (i.e., IEEE Standard 338-1977) is met by the surveillance requirements in the Fermi 2 Technical Specifications.
Non-technical specification channels which are safety related are periodically checked, calibrated, repaired and serviced under the preventive and/or corrective maintenance program. Presently, no periodic testing is being performed on most of the non-safety related and non-technical specification channels because they are not considered as essential for plant safety. However, Fermi 2 has a program in place to eventually perform preventive maintenance on all instrument channels per Nuclear Production Procedure NPP-MA1-02. Thus the surveillance testing and preventive maintenance meet the Regulatcry Guide 1.97, Revision 2, Position C.1.5 criteria.
- 5) Detroit Edison was provided interim acceptance of the existing instrumentation by Reference 4.
Detroit Edison has participated in the BWR Owner's Group actively since its inception. The Owner's Group has examined the Neutron Monitoring System (NMS) instrumentation for post-accident design requirements and prepared a licensing topical report NEDO-31558. The BWR Owner's Group submitted this report to the NRC for review and approval. The topical report NED0-31558 concluded that "After evaluating the existing NMS equipment against the proposed criteria, it was concluded (subject to certain plant-unique confirmations) that the existing NMS design is generally adequate for every postulated event." Detroit Edison is performing the plant-unique confirmation to the functional criteria of NEDO-31558.
- 6) Regulatory Guide 1.97, Revision 2 requires that reactor coolant level measurement should be from bottom of core support plate
(-158.93d below top of active fuel (TAF)) to lesser of either top of vessel or centerline of main steam line (+292.19" above TAF).
Fermi 2 reactor water level instrumentation measures water level from -150" below TAF to +220" above TAF by safety grade instru-mentation. Based on Fermi 2 design for reactor water level controls, level will be maintained between Level "1" and Level "8" which is within measured range. Thus, no extended range is
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v Ni Enclorura
- September 12, 1989 NRC-89-0201 (3
Page 21' l
required. However, Fermi 2 design has a non-safety related instrument loop which has a range of 160" to 560" from TAF with indication in the control room and computer printout on demand from process' computer.
g
- 7) The transmitter G11N609 is calibrated to measure 20" from the bottom of the sump to 8" above the top of the sump and provides
. sump' level indication in the Control Room.: Regulatory Guide 1.97, Revision 2 requires level measurement from the bottom to the top of the ~ sump. The drywell sump has two pumps to pump out water.
These pumps trip when water ~ level falls below 22".
Thus, water f:
. level in'the drywell floor drain sump will always be more than 20".
Therefore, G11N609 transmitter range meets the intent of Regulatory Guide 1.97, Revision 2.
Also, as discussed in Justification d, the sumps are isolated by a LOCA signal.
- 8) Footnote 7 under _ Table 1 of Regulatory Guide 1.97, Revision 2 requires that the accuracy for the~ primary containment area radiation system should be within.a factor of 2 over the entire range. Based on vendor test report E-254-960 (EQ-Central File
- EQ2-EF2-009) and DER 88-1810 disposition, the primary containment area radiation monitors at Fermi 2 may have inaccuracy in measurement as high as a factor of 6.3 when the exposure rate is below 10 R/HR.. However, when the exposure rate is greater than 10
-R/HR the inaccuracy in reading is a factor of 0.43 to 0.74 and as the exposure rate goes up, the error percentage further goes down. Hence for exposure rates greater than 10 R/HR, the accuracy requirement of Regulatory Guide 1.97, Revision.2 is met.
TheinstalledradiationgetectoratFermi2(GeneralAtomicModel g
.RD-23) has a. range of 10 to 10 R/HR. Based on analytical calculation, there could be an average rate of normal radiation level of 51 33 R/hr inside the drywell. However, at full reactor power, the normal radiation level inside drywell was observed as 9 2 R/hr. After a DBA accident the radiation level inside drywell will almost instantaneously exceed the radiation level of 10 R/HR and no credit for operator action below 10 minutes can be taken to mitigate the accident. Furthermore, Fermi 2 design utilized the best available radiation detector in the market at that time. As stated above, since radiation monitor accuracy above 10 R/HR radiation level will be much less than a factor of 2, and since radiation in the drywell after an accident will exceed 10 R/HR almost instantaneously, Fermi 2 primary containment area radiation monitoring design meets the intent of Regulatory Guide 1.97, Revision 2.
9)- In addition to transmitter G11N609 there are two more level transmitters G11N150, G11N152 in drywell floor drain sump
t c ~
Enclorure
!g
(
' September. 12, 1989 NRC-89-0201 Page 22
.(unidentified leakage) and two level transmitters, G11N156 and G11N158 in drywell equipment. drain sump (identified leakage) which l
provide indication on local panels. However they have alarms in m
the main Control Room to alert the operator on Low-Lcw level, High-High. level, or excessive in-leakage rate in drywell floor drain sumps. In addition, equipment drain sump level has a computer point which can provide data to the operator.
The transmitters (G11N150, N152, N156, and N158) measure level from 12" above the bottom to the top of the sumps. As discussed in clarification Note 7, that sump pumps trip on Low-Low level which is equal to 22" from the bottom of the sumps. Thus, water level in sumps will always be more than 12".
Therefore, the existing range of sump level measurement meets Regulatory Guide 1.97, Revision 2 requirements. Also, as discussed in
' Justification d,'the sumps are isolated by a LOCA signal.
- 10) Reguletory Guide 1 97, Revision 2 requires suppression pool water level range from bottom of ECCS suction line to 5 feet above normal water level. According to Fermi 2 design, the ECCS lowest suction line is at elevation 546'-11.62" and 5 feet above normal water level becomes elevation 562'-0".
The suppression pool water level instrumentation provides measurement of water from elevation 545'-0" to 561'-8". 'Thus it falla short by 4" to meet Regulatory Guide 1.97, Revision 2 range requirement.
This shortage of 4" from top limit of water level span is justified based on the fact that the Mark I suppression pool has no specific physical structures located within the zone of
~
elevation 561'-8" to 562'-0".
In addition, no specific functional capability of the pool is compromised by the absence of level indication within this zone. Rather, a shorter span was deemed desirable tn maximize readability.
- 11) Regulatory Guide 1.97, Revision 2, Position C.1 3 2.f and C.1 3 3.b require the Category 2 and 3 effluent radioactivity monitors be recorded and continuously available. Fermi 2 provides continuous updated printed data at Control Room terminal on panel H11P812. Also provided is annunciation, sequence of events recording, and ERIS computer points.
The following effluent release pathways are isolated during a design basis accident: Service Building, On-Site Storage Building, Radwaste Building, Reactor Building and Turbine Building. These effluent systems isolate in accordance with Technical Specification limits and, therefore, do not constitute an accident release pathway.
+
Enclo;ura September 12, 1989' NRC-89-0201 Page 23 The standby gas treatment system operates during and subsequent to a Design Basis Accident (DBA).
- 12) The secondary containment area radiation sensors are located in a potentially harsh, accident-generated environment. The instruments, however, do not serve any safety function.
Therefore, they are not safety related and are not included in EQ program.
The area radiation monitors alarm in the Control Room on high radiation and provide information to the operators to assist in the identifying and locating of primary containment breaches.
Reactor and Turbine building isolation is initiated by separate instrumentation that is qualified in accordance with Regulatory Guide 1.89
- 13) Channels 6, 15, and 16 (D2IN106, D2IN115, AND D21N116) are the Technical Specification (Table 4.3 7 1-1) channels. Channel 17 (D21N117) is being treated as a Technical Specification channel in accordance with its Surveillance Procedure (NPP-44.080.301).
These channels are applicable to variables identified as items C14, E2, and E3 within Table 1 as noted.
- 14) Regulatory Guide 1 97, Revision 2, Paragraph 1 3 2.d requires that the quality assurance guides in paragraph 1 3 1.e be followed unless the instrumentation is less important to safety than other instrumentation, and in that case it may not be necessary to apply the same quality assurance measures to all instrumentation. The quality assurance requirements that are implemented should provide control over activities affecting quality to an extent consistent with the importance to safety of the instrumentation. The instrumentation of this variable has no safety function, is not safety related, and therefore is not designated Quality Assurance Level 1 at Fermi 2.
15)RegulatoryGuide1.97, Revision 2requirestherangeof10~l to 10 R/hr. Fermi 2 provided ranges determined by each application during normal operation.
All the ranges specified are in millirems. The deviation from the R. G. 1.97 requirements is judged acceptable since the range supplied for each application is designed to cover the expected radiation rate during normal power operation. Post-accident entry is not required and would be only performed after appropriate assessment of dose rates using portable equipment. This is consistent with known industry practice and compliance for this variable.
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- 16) Condensate Storage Tank (CST) Level is recorded from approximately
-2' to 36' (tank height is 0-36').
Regulatory Guide 1 97, Revision 2 requires CST level measurement from bottom to top. HPCI and RCIC systems pamps normally take suction from CST and deliver water to the reactor vessel. When water level in CST falls below 2'
-8", the suctions of these pumps are automatically switched over-to suppression pool. Thus, water level measurement capability for the CST below this switchover point is not significant from a safety viewpoint. Therefore, Fermi 2 CST level
[
measurement design meets the intent of R.G.1.97, Rev. 2.
- 17) Regulatory Guide 1.97, Revision 2 requires the range of 40 to 440 F.. Fermi 2 provides the range of 0-400 F by safety grade drywell temperature instrumentation. The Fermi 2 analyced design basis for.the drywell is 340 F.
Thus, 0 - 400 F range meets the intent of'R.G. 1.97, Rev. 2 range requirement.
- 18) Regulatory. Guide 1 97, Revision 2 requires a range of 0 to 110% of design flow. For Fermi 2, this is 0-550 gpm. Fermi 2 provides an extended range of 0-28,000 gpm which meets the intent of the Regulatory Guide but' presents less accurate reading. RHR pump discharge pressure indications and valve position indications for valves on the drywell spray piping provide the operator with added assurance of drywell spray flow.
- 19) Regulatory Guide 1 97, Revision 2 requires two ranges of 0-15" of water and 0 to 5 psid for Main Steam Isolation valve-Leakage Control System (MSIV-LCS) pressure. Fermi 2 provides the range of 0-10 psid for the specific application.
Fermi 2 design provides pneumatic MSIV leakage control by detecting pressure between 1st MSIV and 2nd MSIV and comparing it with containment pressure. The pneumatic supply maintains differential pressure between approximately 5.5 and 8.0 psid. The MSIV-LCS becomes inoperable when differential pressure drops below approximately 2.0 psid. Thus, based on the application, Fermi 2 MSIV-LCS pressure indication with a range of 0-10 psid is acceptable and R.G. 1.97, Rev. 2 ranges of 0-15" WC and 0-5 psid do not apply to Fermi 2 design.
- 20) Regulatory Guide 1 97, Revision 2 requires that the instrumentation be seismically qualified to the provisions of Regulatory Guide 1.100 provided instrumentation is part of safety-related system. Fermi 2 provides backlighted pushbuttons at valve display on respective Control Room panels.
Fermi 2 provides a non-seismic indicating light bulb in the valve position indication assembly. The seismic capability of the design is considered adequate as a result of the following:
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Two redundant lamps are provided for both the open and close function.
2.
Seismic qualification tests of the control room panels established the fact that the indicators would function following a seismic event. The indication equipment was not energized during the shake table tests, but the operability of the. indication equipment was determined following the test.
. event and, therefore,.is not environmentally qualified to the requirements of NUREG-0588. The subject RCIC instruments are qualified to the applicable standard effective at the time of their procurement, i.e.,
IEEE 323-1971 and IEEE-344-1971.
- 22) Regulatory Guide 1.97, Revision 2 requires Standby Liquid Control System (SLCS) storage tank level instrumentation range shall be bottom to top of the tank. Fermi 2 design utilizes a 144" high SLCS storage tank with an overflow connection at 135 75" from the bottom. The SLCS storage tank level instrumentation measures the level from 9 5" to 135.75" from the bottom of the tank instead of bottom to top of the tank as required per Regulatory Guide 1.97, Revision 2.
The centerline for pump suction piping is 9.5" from the tank bottom.
The suction pump is manually controlled by the operator based on the high and low level alarm as well as level indication in the main Control Room.- Furthermore, because of the overflow line the possibility of having level above 135.75" is remote. Thus, based on the system operation and as-built tank configuration, the range of 9 5" to 135.75" meets the intent of Regulatory Guice 1.97, Revision 2.
23).R. G. 1.97, Revision 2 requires the level range from top to bottom of the High Radioactivity Liquid Tank. Fermi 2 provides indication in the Radwaste Control Room from 8.07" to 132.07" from bottom.- Pump suction is provided from the bottom of the tank with trip interlock from level instrumentation. Overflow protection is provided to Radwaste Building floor drain sump.
Following a LOCA event, radwaste systems are not operated, and the radwaste control room is not occupied to reduce personnel exposure. Since all of the sump pumps within the Reactor Building (secondary containment) are automatically tripped, liquid waste is not pumped to the radwaste collection tank and knowledge of liquid tank level is not required. When processing of radwaste is
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! September 12, 1989 NRC-89-0201
~Page-26' re-established it will be done from the radwaste control room where liquid tank level is displayed.
.24) The emergency ventilation damper positions are indicated in the main control room by the position switches. However, damper position switches are not the priinary instruments used to monitor the operation of the Standby Gas Treatment System (SGTS). The SGTS flow instrumentation is used to monitor the proper operation of SGTS and this instrumentation is qualified per the guidelines of. Regulatory Guide 1.97 for this variable.
In addition to the Standby Gas Treatment System, the control center HVAC duct system has emergency dampers which are equipped with non-safety related position indication in the main control room.. However, for the verification of proper operation of the control center HVAC system, the operator relies on control room differential pressure indication instead of dampers position indication. The control center differential pressure indications are redundant and use QA Level 1 instrumentation except the recorders, which are maintained as QA Level 1 instruments. Thus, Fermi 2 design meets the intent of R.G. 1.97, Rev. 2.
- 25) Regulatory Guide 1.97, Revision 2 requires the Suppression Pool Water Temperature (Table 1 Variable Items A4 and D6) to be Category 1 & 2 variables.
As such, for Category 1 & 2 variables, the instrumentation from sensor to the display is to be environmentally qualified (EQ) in accordance with Regulatory Guide 1.89 and the methodology of NUREG-0588. The seismic portion of qualification should be in accordance with Regulatory Guide 1.100.
Detroit Edison utilizes thermocouple T50N404A and T50N405B for the environmentally qualified instrument system for Suppression Pool Water Temperature. Only two thermocouple loops (one per division) are needed for the post accident monitoring of this variable. Thermocouple T50N404B and T50N405A are not qualified but provide the operator with additional information as do the T23 thermocouple (T23N001-N008) which also monitor Suppression Pool Water Temperature and are recorded in the control room.
- 26) Regulatory Guide 1.97, Revision 2 requires the range of 10 psia to 4 times design pressure (62.5 psig for Fermi 2) for Primary Containment Pressure (Variables B9, C10, and D4 in Table 1).
Detroit Edison utilizes transmitters T50N415A & B which have a range of 0-250 psig for the environmentally qualified instrument system for positive containment pressure only. This is based on
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.Encictura-1 September 12, 1989 NRC-89-0201-Page.27-theLfact that the accident scenario following the DBA (Design Basis Accidenti always results in pressurization of the containment..
' Only a specific small break accident combined with an operator
- error will result in a negative pressure excursion for the Mark I containment. This particular event is automatically mitigated by As a
. redundant, single-failure proof vacuum breakers..
consequence, operator action relying upon an indication of negative containment pressure from transmitters T50N401A & B is not required.
-Transmitters T50N401A & B are listed in Table 1 (Variable Items B9, C10, and D4)=since they provide the negative pressure range required by R.G. 1.97, Rev. 2.
These transmitters are not qualified but provide additional information to the operator although not required for operator action as discussed above.
- 27) Regulatory Guide 1.97, Revision 2 requires the Drywell Atmosphere Temperature (Table 1 Variable Item D7) to be a Category 2 variable.
As such, for a Category 2 variable, the instrumentation from sensor to the display is to be environmentally qualified (EQ) in accordance with Regulatory Guide 1.89 and the methodology of NUREG-0588. This seismic portion of qualification should be in accordance with Regulatory Guide 1.100 for a Category 2 variable provided the instrumentation is part of a safety related sy. stem.
Detroit Edison utilizes thermocouple T50N409B and T50N412A for the environmentally qualified instrument system for Drywell Atmosphere. Temperature. Only two thermocouple loops (one per division) are needed for the post accident monitoring of this variable. Thermocouple T50N400A,B; N407B; N408A; N410A; N411B, and N413B are not qualified but provide the operator with additional information as do the T47 thermocouple (T47N014A-D; N015A,B; N016A-D; N017A-D; N018A-D; N019A-D; NO20A-D) which also monitor Drywell Atmosphere Temperature and are recorded in the control room.
Justification Code a) Fermi 2 design provides several ranges of reactor water level indication in the main Control Room. The wide range 10" to 220" water level above top of active fuel instrumentation is safety related, redundant and fully qualified. The fuel zone range of
-150" to +50" water level instrumentations has two channels to provide redundant indication. One channel is fully qualified and
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- September 12, 1989 NRC-89-0201 Page 28 has Class 1E power supply. The other channel utilizes safety grade sensor and Class 1E loop power supply. However, the signal cables from trip unit to indicator is routed in a non-seismic raceway system, level indicator B21R610 is not qualified to IEEE-344-1975, and indicator illuminating power is a non-Class 1E Lsupply. 'Since loop power is a Class 1E supply and loss of illuminating power.cannot affect the indication loop, non-IE power for indicator illumination is acceptable.
The fuel zone reactor level indication is required in the event of a LOCA. Since one channel of fuel zone level instrumentation is fully qualified, both channels of fuel zone level indication in the main control room will be lost only when a single failure occurs in the qualified channel and a seismic event causes the loss of the non-seismically qualified redundant channel. The Licensing basis for Fermi 2 does not require consideration of coincident LOCA and seismic events (Reference 10). This is consistent with the NRC basis for seismic adequacy reviews of mechanical and electrical equipment (NRC Generic Letter 87-02) which states:
"The seismic event does not cause a Loss of Coolant Accident (LOCA), a Steam Line Break Accident (SLBA), or a High Energy Line Break (HELB) and'a LOCA, SLBA, or HELB does not occur simultaneously with or during a seismic event".
Given the above, it is concluded that probability of the simultaneous occurrence of a LOCA and seismic event which could cause a complete loss of reactor fuel zone level indication when it is needed is exceedingly low and beyond the Licensing basis for Fermi 2.
Furthermore, even though raceways in the Reactor Building, Auxiliary Building, etc., designated as "0" are considered as non-seismic raceways, in reality these raceways and seismically qualified raceways are installed with the same hangers utilizing the same construction practice. Thus, failure of a raceway is also very remote. The two channels of fuel zone reactor level measurement instrumentation are electrically independent and physically separated from each other.
b) Fermi 2 design does not provide any analog instrumentation to measure reactor coolant boron concentration. The RCS soluble boron concentration is deternined by obtaining and analyzing a coolant sample via the post accident sampling system. This sample is drawn on demand. A discussion of the post accident sampling system can be found in UFSAR section 11.4.4.4.
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The analytical technique used at Fermi 2 to determine boron L
_ concentration has a range of 0 to 1,000 + 50_ parts per million (ppe). The laboratory sample would be expected to yield approximately_250 ppm total boron following completion of EDP 1021 which cnanges the SLCS boron to enriched boron. This correlates to.the Technical Specification required minimum shutdown margin of approximately 825 ppm boron, using natural boron. These concentrations are within the range of the analytical technique, c) Fermi 2 design does not provide reactor core thermocouple l:
ir.strumentation.
Extensive. analysis by BWR Owner's Group indicates that this system does not appreciably improve the detection of the onset of clad failure. Analysis of coolant and/or primary containment atmosphere providec a more accurate assessment of fuel damage.
NRC has accepted the BWR Owner's Group position on the adequacy of water level instrumentation for detection of the onset of inadequate' core cooling in BWRs.
(Refer to SER (NUREG 0798) for Fermi 2 specific discussion).
i d) Regulatory Guide 1 97, Revision 2 requires that drywell sumps level measurement instrumentation channel shall be single failure proof, environmentally and seismically qualified, Class 1E powered j
and QA Level 1 design in addition to other Category 1 require-j ments. Fermi 2 drywell drain sumps level measurement channels are
{
neither environmentally nor seismically qualified. Neither are they class 1E powered due to the fact that the sumps are isolated by a LOCA signal and subsequent level information is not 1
required. Following the isolation of the sump, the sump is expected to fill and the overflow will go into the suppression j
pool where continuous safety grade level monitoring is provided.
l Since this instrument channel does not support post accident monitoring functions, it is not a single failure proof or a QA Level _1 design Therefore, the sump level measurements are not required to meet the requirements of Regulatory Guide 1.97, Revision 2, since the needed information is provided by the suppression pool instrumentation.
e) Fermi 2 design does not provide any instrument channel for radiation level in the circulating primary coolant system. The measurement is obtained by analysis of a grab sample. The sample of coolant can be directly obtained using the post accident sampling system and subsequently analyzed in the laboratory. This l
method meets the Regulatory Guide 1.97, Revision 2 requirement.
Fermi 2 UFSAR section 11.4.4.4 describes the post accident sampling system capability.
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. September-12, 1989 NRC-89-0201 Page 30 f)- Fermi 2 design does not provide any instrumentation to perform the analysis of primary coolant. The reactor coolant analysis is performed by taking grab sample from Post Accident Sample System and analyzed by using gamma spectroscopy system. A hard copy print can be made from the gamma spectrometer for computer analysis to assist-in the determination of fuel damage. This method of reactor coolant analysis meets the intent of Regulatory Guido.1 97, Revision 2.
g) Primary containment Division I hydrogen and oxygen recorder T50R806A uses a Non-IE power supply..However, the rest of the Divisien I loop as well as Division II hydrogen / oxygen recorder T50R806B and its associated loop are powered from Class 1E power supply.
The Modular Power Unit (MPU) #3 provides ron-IE power supply to Division I recorder T50R806A. MPU #3 will de-energize on loss of o fsite power. 'However, power to MPU #3'is restorable by operator r
action from a Class IE power source (diesel backed bus).
In the event of loss of offsite power, the primary containment hydrogen / oxygen monitoring will be available to operator by Division II recorder T50R806B, provided'there is no single failure i
that disables it. When a single failure and loss of offsite power occurs simultaneously, the operator can manually energize MPU #3 per the plant operating procedure NPP-20 300.08 and, thereby, recorder T50R806A can be made available.
Furthermore, in addition to hydrogen / oxygen recorders in the main control room, Fermi 2 design provides safety related, redundant, local indicators on panels H21P376 and H21P377 which are located in a non harsh environment on the 4th floor Auxiliary Building.
Thus, non-IE power supply to the one division of hydrogen / oxygen recorder T50R806A is acceptable.
l h) Fermi 2 does not have an isolation condenser.
I i) Fermi 2 design does not provide any flow measurement instrumentation for standby liquid control system (SLCS). No useful information is provided by the flow measurement. The 1
amount of boron injected is determined by level : measurement.
Backup indications are neutron flux or pump CMC control switch along with valve position indication for the SLCS flow path.
In addition, there is a pump dischargs pressure indication in the main control room which will indicate the presence of SLCS flow.
j) Regulatory Guide 1.97, Revision 2 requires that Category 2 l
instrumentation should be qualified in accordance with Regulatory i
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[' 4 Enclo;urs September.12, 1989 NRC-89-0201 Page 31 Guide 1.89 and WUREG-0588. It also requires that instrument'shall comply with the applicaole Regulatory Guides pertaining to quality assurance. Fermi 2 design utilizes instrumentation for Standby Liquid Control System (SLCS) storage tank level measurement which
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are not environmentally qualified nor QA Level 1 for purposes of design basis accident mitigation.
l Fermi 2 has determined that SLCS storage tank level measurement instrumentation is not required to operate under DBA accidents nor g
-is its failure in any mode detrimental to plant safety or accident mitigation, and it need not be qualified for any accident environment. This is consistent with the NRC position on ATWS, which does not consider a simultaneous LOCA and ATWS event as a credible event.
Standby Liquid control is designed to act as an alternate method of achieving a reactor shutdown if both the Reactor Protection and i-
.the Alternate Rod Insertion System fail.
ATWS events are not postulated to occur as a consequence of pipe breaks or other environmentally severe failures. As a consequence, the use of high commercial quality instrumentation for this specific application is judged to be appropriate. This level transmitter has been reclassified as Q1M to assure that it will be tested, maintained and repaired as a QA1 instrument and as a result' achieve the highest level of availability and reliability.
Therefore, based on the application, the SLCS storage tank level measurement instrumentation meets the objective of Regulatory Guide 1 97, Revision 2.
k) Fermi 2 thermocouple are located in a potentially harsh, accident generated environment; however, the instrument does not serve any safety function, therefore is not safety-related and is not included in the EQ Program. The RHR heat exchanger outlet temperature indication is not required to safely shutdown the reactor.
In the RHR shutdown cooling mode, an RHR loop and associated heat exchanger must remove the heat from the suppression pool to maintain the ability to keep the core flooded. Suppression pool cooldown rate is a backup measurement to quantify heat removal capability. Furthermore, suppression pool has Categorf 1 water temperature measurement instrumentation.
m) Fermi 2 design provides the measurement of cooling water to ESF system components temperature. The temperature sensors are safety related and the balance of the loop components are non-safety components and thus deviate from full compliance with the
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September 12, 1989 NRC-89-0201
.Page 32-applicable Regulatory Guides pertaining to quality assurance as required per Regulatory Guide 1.97, Revision 2.
No operator action is required based on the cooling water temperature indication instrumentation. The safety related temperature sensor has dual elements and one element is used through other safety grade instrumentation to control the cooling water flow. Since temperature indication is not required for operator action and automatic control is being performed through safety grade instrumentation, the Fermi 2 design of Emergency
-Equipment Cooling Water temperature measurement meets the objective of Regulatory Guide 1.97, Revision 2.
'n)' Fermi 2 design does not provide any direct flow indication for Emergency Equipment Cooling Water System (EECW) flow in the main Control Room.= However, there is adequate information available to the operator to determine the status of EECW flow. For exaeple, pump discharge pressure, suction pressure, valve position indication, motor ammeter, etc., are indicated in the main Control l
Room.
In addition, there is flow indication on the local rack for EECW return flow. The Control Room operator has access to this flow indication through Emergency Response Information System (ERIS). computer access.
The pump suction and discharge pressure instrumentation channels, pump motor ammeters and flow indication at the local racks are not QA level 1 nor are they environmentally or seismically qualified.
The Fermi 2 Environmental Qualification Program determined that these items are not required for plant safe shutdown and their failure does not impact the mitigation of accident. The equipment is thus classified as 2C per NUREG-0588, Appendix E.
p) Regulatory Guide 1.97, Revision 2 requires status indication of standby power and other energy sources important to safety (hydraulic, pneumatic). Fermi 2 provides status indication of the Emergency Safety System (ESS) buses on control room panels H11P809, P810, P811 and P812. Status indication of the DC System / Battery buses are provided by valtmeters locally near the battery rooms adjacent to the control room. Status indication of the Non-Interruptible Air Supplies (Div I/II) are provided by recorder P50R801 (2-pen) in the control room. Status indication of the Primary Containment Pneumatic Supplies N2 or NIAS (Ulv I/II) are provided by recorder T49R809 (2-pen) in the control room.
System safety functions are performed automatically and independently of these indications. Therefore, the status of 1.
Q o s' Enclorura September 12, 1989 NRC-89-0201 Page 33 standby power and other energy sources in the control center are not required to be qualified.
q) Regulatory Guide 1.97, Revision 2 requires two (2) redundant channels which are single failure proof. Fermi 2 provides a common 2-pen recorder (D11R810) which is powered from a non-IE power supply and has the signal cables from the microprocessor to the recorder routed in a non-safety grade raceway. However, Fermi 2 design provides redundancy in primary containment area radiation design up to microprocessor by providing redundant microprocessors and safety grade redundant sensors. The microprocessors are located on divisional panels in the relay room which is part of the control center. These microprocessors have local indicator.
Thus, in the event of loss of indication in the main control room, operators can use containment area radiation level indication from the local indicators on microprocessors at the relay room. This parameter is also displayed on the non-safety related Safety Parameter Display System (SPDS).
In addition, after a LOCA, fuel damage information will be obtained from grab sample analysis of reactor coolant.
r) Revision 2 of Regulatory Guide 1.97 indicated that range, location and qualification criteria for instrumentation to be installed per this requirement would be developed. Reg. Guide 1.97, Revisien 3 deleted this variable from the requirements for accident monitoring instrumentation, s) The description of the Fermi 2 Post Accident Sampling System (PASS) is located in Section 11.4.4.4 of the UFSAR. As Category 3 instrumentation, the PASS equipment selected is of a high-quality commercial grade and was selected to withstand the expected service environment.Section II.B.3 of NUREG-0737 provides the criteria for post accident sampling and analysis capabilities.
Detroit Edison provided the details of post accident sampling system to the NRC in Reference 10.
The NRC has accepted the sampling and analysis capabilities for Post Accident Sampling at Fermi 2 as documented in the Fermi 2 SER (NUREG-0798) Supplement No. 5, Chapter 22,Section II.B.3 on pages 22-4 and 5 In summary, the Fermi 2 Post Accident Sampling System has been previously accepted by the NRC in regards to sampling and analysis capabilities and meets the requirements of Regulatory Guide 1.97, Rev. 2 for Category 3 instrumentation. Corner room sumps, which are recommended for sampling by Regulatory Guide 1.97, Rev. 2, are not sampled because at Fermi 2 they are isolated in the event of a LOCA.
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September 12,.1989
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Page 34-i t) Transmitters B21N051A, B are not identified within the Fermi 2 Environmental Qualification program since they are not required to
~ itigate a LOCA or High Energy Line Break. Sensors were qualified mto the standard effective at the time of procurement (i.e., IEEE
- 323-1971).: This qualification meets the intent of the Regulatory l'
Guide,.andfis complemented by additional reactor pressure indication data that is available in the auxiliary building if primary senscrs B21N051A and B fail after long term radiation exposure. This additional indication is. located on the trip units. However, transmitters B21N051A and B are scheduled to be L
replaced'by environmentally qualified transmitters-during the implementation of EDP-6740. The portion of EDP-6740 which contains these transmitters is scheduled to be implemented during
'the second refueling outage.
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