JAFP-12-0032, Response to Request for Additional Information Application for Change to the Current Licensing Basis, Authorizing Use of on Load Tap Changers with the Reserve Station Service Transformers
| ML12090A613 | |
| Person / Time | |
|---|---|
| Site: | FitzPatrick  |
| Issue date: | 03/30/2012 |
| From: | Michael Colomb Entergy Nuclear Northeast, Entergy Nuclear Operations |
| To: | Document Control Desk, NRC Region 1 |
| References | |
| JAFP-12-0032, TAC ME6887 | |
| Download: ML12090A613 (34) | |
Text
Entergy Nuclear Northeast Entergy Nuclear Operations, Inc.
James A. FitzPatrick NPP P.O. Box 110 Lycoming, NY 13093 Tel 315-349-6024 Fax 315-349-6480 Michael J. Colomb Site Vice President - JAF JAFP-12-0032 March 30, 2012 United States Nuclear Regulatory Commission Attn: Document Control Desk Washington, D.C. 20555
SUBJECT:
Response to Request for Additional Information Re: Application for Change to the Current Licensing Basis, Authorizing use of On Load Tap Changers with the Reserve Station Service Transformers (TAC No. ME6887)
James A. FitzPatrick Nuclear Power Plant Docket No. 50-333 License No. DPR-59
References:
- 1. Entergy Letter, JAFP-11-0102, Application for Change to the Current Licensing Basis, Authorizing use of On Load Tap Changers with the Reserve Station Service Transformers (TAC No. ME6887), dated August 16, 2011
- 2. NRC Request For Additional Information Regarding James A. FitzPatrick Nuclear Power Plant Application for Change to the Current Licensing Basis, Authorizing use of On Load Tap Changers with the Reserve Station Service Transformers (TAC No. ME6887), dated February 27, 2012
- 3. Teleconference with NRC to clarify Request for Additional Information, dated February 27, 2012
Dear Sir or Madam:
On August 16, 2011 Entergy Nuclear Operations, Inc. (ENO), submitted an application for amendment to the Current Licensing Basis for the James A. FitzPatrick Nuclear Power Plant (JAF) that would approve the use of On Load TAP Changers with the Reserve Station Service Transformers [Reference 1]. On February 27, 2012, JAF received a Request for Additional Information (RAI) from the Nuclear Regulatory Commission (NRC) staff [Reference 2]. That request was clarified in a conference call with the staff on February 27, 2012 [Reference 3].
Based on the clarifying discussions with the staff, ENO is supplementing the amendment application with enclosed RAI responses.
JAFP-12-0032 Page 2 of 3 There are no new commitments made in this letter.
Questions concerning this submittal may be addressed to Mr. Joseph Pechacek, Licensing Manager, at (315) 349-6766.
I declare under penalty of perjury that the foregoing is true and correct.
Executed on the 27'h day of March 2012.
SinCereIY'
~ . ~ .
. 1.~-.&-.J6........AJ"---
Michael J. Co omb Site Vice President - JAF MC/JP/jo
Enclosures:
- 1. Responses to Request for Additional Information Questions
- 2. Draft UFSAR Changes (Figures and Text)
- 3. Draft UFSAR Text, Figure and Table Changes
- 4. Modification Drawings for Replacement RSSTs
JAFP-12-0032 Page 3 of 3 cc:
Regional Administrator, Region I U. S. Nuclear Regulatory Commission 475 Allendale Road King of Prussia, PA 19406-1415 Resident Inspectors Office U.S. Nuclear Regulatory Commission James A. FitzPatrick Nuclear Power Plant P.O. Box 136 Lycoming, NY 13093 Mr. Bhalchandra Vaidya, Project Manager Plant Licensing Branch I-1 Division of Operating Reactor Licensing Office of Nuclear Reactor Regulation U.S. Nuclear Regulatory Commission Mail Stop O-8-C2A Washington, DC 20555-0001 Ms. Bridget Frymire New York State Department of Public Service 3 Empire State Plaza, 10th Floor Albany, NY 12223 Mr. Francis J. Murray Jr., President New York State Energy and Research Development Authority 17 Columbia Circle Albany, NY 12203-6399
JAFP-12-0032 Enclosure 1 Responses to Request for Additional Information Questions (6 Pages)
JAFP-12-0032 Enclosure 1 Responses to Request for Additional Information Questions
- 1. Question:
Provide revised Figures 8.2-1 and 8.5-1 of Updated Final Safety Analysis Report and any others, in which the new ratings of RSSTs are shown.
- 1. Response:
Draft copies of Updated Final Safety Analysis Report Figures 8.2-1, 8.3-4, 8.5-1, 8.5-3 and 8.5-4 are provided in Enclosure 2. Drafts are provided since the figures can not be finalized until the new Reserve Station Service Transformers (RSSTs) are installed.
Included in Enclosure 3 are copies of the UFSAR changes related to the existing Reserve Station Service Transformers (RSSTs) that are currently being processed as a result of a revision to an electrical calculation. This change affects Figure 8.6-1, section 8.6.6 and Table 8.6-1.
- 2. Question:
In the LAR, Attachment 1, Page Nos. 5 and 6, the following is stated: The normal power source for the primary and backup digital OLTC Beckwith microcontrollers is from a potential transformer that is located between the RSST secondary windings and the 4kV [kilo-Volt] RSST bus supply breakers.
Provide a copy of the diagram which shows the connection of the potential transformer that is located between the RSST secondary windings and the 4kV RSST bus supply breakers. Also, identify which 4kV buses are monitored and controlled by the OLTC, and which 4kV buses are shown in Figures 1 and 2 of the LAR.
- 2. Response:
Modification drawing FE-1F (Enclosure 4) shows the connection of the potential transformer that is located between Reserve Station Service Transformer 71T-3 low voltage Y winding and non-safety related bus 10300 (71H03). Modification drawing FE-1G (Enclosure 4) shows the connection of the potential transformer that is located between Reserve Station Service Transformer 71T-2 low voltage Y winding and non-safety related bus 10400 (71H04). (Note: The JAF RSSTs are normally energized and unloaded.) The OLTCs monitor and control voltage to 4.16kV switchgear buses 10300 (71H03) and 10400 (71H04) that supply power to downstream safety related buses 10500 (71H05) and 10600 (71H06). Also included in Enclosure 4, are modification drawings FE-1B, which provides an electrical one line diagram of Station Service Transformers, and 1.22-106 which details the Reserve Station Service Transformer connections to the OLTC. The Typical Pre Transfer Voltage Control and Limit Bands shown in Figure 1 of the LAR and the Typical Post Transfer Control and Limit Bands shown in Figure 2 of the LAR are applicable to the 10300 (71H03) and 10400 (71H04) buses.
Page 1 of 6
JAFP-12-0032 Enclosure 1 Responses to Request for Additional Information Questions
- 3. Question:
In the LAR, Attachment 1, Page No. 6, the following is stated: The primary microcontroller is set with a time delay during operation; this setting is needed to inhibit the tap changer from unnecessary operations on temporary voltage excursions.
Provide the above time delay setting associated with the primary microcontroller, and confirm whether the above time delay is bypassed in case of a design basis accident signal.
- 3. Response:
The primary microcontroller is set for a two (2) second inverse time delay. The primary controller intertap time delay setting is set to zero (0) seconds in order to allow immediate adjustment if the voltage remains outside the established primary microcontroller control band. These settings are not bypassed in the event of a Design Basis Accident (DBA).
The backup microcontroller time delay is set to the minimum setting of one (1) second to enable a quick response to possible overvoltage conditions. The backup microcontroller is bypassed / blocked during unloaded conditions; however its function is enabled after closing of the 4.16kV bus feeder breakers coupled with a ten (10) second time delay.
This action enables the starting of the electrical safety-related loads, while eliminating the potential of lowering bus voltages lower than the degraded voltage relay reset setting.
- 4. Question:
In the LAR, Attachment 1, Page Nos. 6 and 7, the following is stated: By providing automatic adjustment of the voltage to the auxiliary power system from the offsite 115kV system, the RSST OLTCs will compensate for a wide range of 115kV (110kV - 121kV) system operating voltages. To prevent unnecessary disconnection of the safety-related buses from offsite power, analyses have determined the minimum permissible pre LOCA
[loss-of-coolant accident] contingency voltage that can occur following generator trip without actuating the DVR [degraded voltage relay] scheme.
Provide the basis for considering the above voltage range for the 115kV system. What is the current minimum permissible pre LOCA 115kV contingency voltage that can occur following a generator trip without actuating the DVR scheme, prior to the proposed amendment?
- 4. Response:
Since the RSSTs are normally unloaded, the Transmission Owner utilizes a post LOCA contingency analysis in lieu of a pre LOCA contingency voltage range. JAFs basis for considering the voltage range of the 115kV system is based on the fact that the Transmission Owner (National Grid) maintains the 115kV system operating voltages between 109.25kV and 120.75kV (115kV +/-5%). The current permissible post LOCA 115kV contingency voltage that can occur following a generator trip without actuating the DVR scheme with the existing RSSTs installed is 112.5kV.
Page 2 of 6
JAFP-12-0032 Enclosure 1 Responses to Request for Additional Information Questions The minimum post LOCA contingency voltage with the replacement RSSTs installed that can occur following a generator trip without actuating the DVR scheme and the OLTC in automatic operation is 106.8kV.
The Transmission Owner has procedural controls in place that monitor the minimum 115kV system post LOCA contingency voltage for JAF. In the event the minimum post LOCA voltage alarm occurs, notification is made to the JAF Control Room, at which time the 115kV would be declared inoperable, and the Transmission Owner takes actions to raise the 115kV system voltage to JAF. After actions have been taken by the Transmission Owner to raise 115kV system voltage, another load flow will be performed to determine if the post LOCA voltage alarm has cleared. If the alarm is still present the Transmission Owner will take additional actions to raise the 115kV system voltage and if the alarm has cleared, the JAF Control Room will be notified. Within 30 minutes from the initial alarm another load flow will be performed by the Transmission Owner and the JAF Control Room will be notified if the minimum post LOCA contingency voltage alarm has cleared or if the Transmission Owner was not successful in raising the raising the 115kV system voltage above the minimum post LOCA contingency voltage. If the post LOCA contingency alarm has cleared, the 115kV system would be declared operable; otherwise the 115kV system would remain inoperable.
- 5. Question:
In order to find the voltage improvements due to the OLTC, please provide the voltage profiles for the 4kV major load buses in the following scenarios:
- a. Accident load sequencing with the 115kV switchyard voltage at the minimum voltage level, without OLTC (prior to proposed amendment).
- c. Non-Accident load sequencing due to spurious sudden trip of the main generator, with the 115kV switchyard voltage at the minimum voltage level, loads fast transfer to RSST (prior to proposed amendment).
- 5. Response:
The JAF analysis for the replacement RSSTs with the OLTC in service has been analyzed to a 115kV grid voltage of 106.8kV. This analyzed voltage is lower than the Transmission Owner lower voltage of 109.25kV (115+/-5%) and as such the OLTC will maintain the bus voltage at the OLTC microcontroller setting provided the 115kV bus voltage is above the analyzed voltage.
- a. The transient voltage bus profiles for this scenario are not available.
Page 3 of 6
JAFP-12-0032 Enclosure 1 Responses to Request for Additional Information Questions
- b. The transient voltage profile of the 4kV buses resulting from a transfer of non-safety related loads from the Normal Station Service Transformer to the replacement Reserve Station Service Transformer and the sequencing of ECCS loads with the OLTC is in an automatic mode of operation. It is provided on the attached Transient Stability Analysis plot labeled JAF-CALC-11-00002 Attachment 6 Page 103 in Enclosure 5.
- c. The transient voltage bus profiles for this scenario are not available.
- d. The transient voltage profile of the 4kV buses resulting from a transfer of non-safety related loads from the Normal Station Service Transformer to the replacement Reserve Station Service Transformer due to a turbine trip or generator trip, while the OLTC is in an automatic mode of operation is provided on the attached Transient Stability Analysis plot labeled JAF-CALC-11-00002 Attachment 6 Page 1 in Enclosure 6.
- 6. Question:
Provide a discussion of the power and control voltage sources for operation of the OLTC, and primary and backup microcontrollers. Also, confirm the location of primary and backup microcontrollers, and the locations where an Operator can locally and remotely control the OLTCs, if needed.
- 6. Response:
The primary microcontroller and backup microcontroller are fed from the potential transformers which are connected to the RSST transformers Y low voltage winding
(
Reference:
Drawings supplied in response to Question 2). The power for RSST 71T-2 OLTC is fed from non-safety related motor control center 71MCC-341 compartment BF2 and the power for RSST 71T-3 OLTC is fed from non-safety related motor control center 71MCC-331 compartment CF2. The motor control centers which feed the RSSTs OLTCs are normally fed from the Normal Station Service Transformer (NSST) 71T-4. Upon transfer of plant loads to the RSSTs these motor control centers will be supplied power from the RSSTs. (Note: The selection of the RSST automatic microcontroller settings does not require operation during the time interval of a transfer of loads from the NSST to the RSSTs.)
The primary microcontroller and backup microcontroller are located at the RSSTs.
The Operator has the ability to place the OLTC in manual / automatic control and manually raise / lower the tap setting at the RSSTs or in the Control Room from the 09-8 panel.
- 7. Question:
In the LAR, Attachment 1, Page No. 9, the following is stated: The 4400V used in Figure 1 is 110% of the voltage rating of the safety-related motors fed from the bus, consistent with ANSI/NEMA Standard MG-1-2009, Revision 1-2010, "Motors and Generators."
Page 4 of 6
JAFP-12-0032 Enclosure 1 Responses to Request for Additional Information Questions The staff finds that in Figure 1, the nominal voltage shown in Figure 1 is 4441.5V instead of 4400V. Please provide an explanation for this discrepancy.
- 7. Response:
The Reserve Station Service Transformers are normally in the energized unloaded condition. In this configuration the electrical buses and loads are not fed from the Reserve Station Service Transformers; however, the transformers and electrical non-segregated phase buses are energized and controlled between 4259.5V and 4476.5V (see revised Figure 1 and 2 below), with the microcontroller OLTC Pre Transfer nominal setting of 4368V. The Reserve Station Service Transformers are rated for 4,800V and the electrical non-segregated phase bus is rated for 5,000V; as such the electrical equipment is designed for the applied voltage.
The following changes are provided to the submittal:
- [[::JAF-11-0102|JAF-11-0102]] Attachment 1 page 4 of 20, replace Figure 1 Typical Pre Transfer Voltage Control and Limit Bands with the following:
Upper Band Limit 4476.5V Nominal 4368V Voltage Control Band (Primary Microcontroller)
Lower Band Limit 4259.5V 3909.5V Degraded Voltage Relay Reset (Upper Limit) 3885V Degraded Voltage Relay Drop-out (Upper Limit)
Figure 1 Typical Pre Transfer Voltage Control and Limit Bands Page 5 of 6
JAFP-12-0032 Enclosure 1 Responses to Request for Additional Information Questions
- [[::JAF-11-0102|JAF-11-0102]] Attachment 1 page 5 of 20, replace Figure 1 Typical Voltage Control and Limit Bands with the following:
4400V Maximum Allowable Voltage Overvoltage Limit (Microcontroller -
Block Raise Limit (V>) 4322.5V Upper Band Limit Voltage Control Band Nominal 4184.6V Voltage Limit (Primary Microcontroller)
Band (Backup Microcontroller)
Lower Band Limit 4076.1V Undervoltage Limit (Microcontroller -
Block Lower Limit (V<)) 4042.5V 3909.5V Degraded Voltage Relay Reset (Upper Limit) 3885V Degraded Voltage Relay Drop-out (Upper Limit)
Figure 2 Typical Post Transfer Control and Limit Bands
- [[::JAF-11-0102|JAF-11-0102]] Attachment 1 Page 6 of 20 change:
From: The OLTC will provide a range of -10% to +10% of the rated secondary voltage in 16 step increments, each step being 1.25% of rated secondary voltage. By providing automatic adjustment of the voltage to the auxiliary power system from the offsite 115kV system, the RSST OLTCs will compensate for a wide range of 115kV (110kV - 121kV) system operating voltages.
To: The OLTC will provide a range of -10% to +10% of the rated secondary voltage in 16 step increments, each step being 1.25% of rated secondary voltage. By providing automatic adjustment of the voltage to the auxiliary power system from the offsite 115kV system, the RSST OLTCs will compensate for a wide range of 115kV (109.25kV - 120.75V) system operating voltages.
Page 6 of 6
JAFP-12-0032 Enclosure 2 Draft UFSAR Changes (Figures and Text)
(7 Pages)
T2 & T3 -15/20/25 MVA (65 C), 115-4.16-4.16 kV, 3 PH, 60 CY, ONAN/ONAF1/ONAF2, 65 C Rise H Winding - 15/20/25 MVA EC X Winding - 5/6.66/8.33 MVA 12703 Y Winding - 10/13.33/16.66 MVA DELETE EC 12703 DELETE
EC 12703 15/20/25 MVA ONAN/ONAF1/ONAF2
JAF FSAR UPDATE Reserve station service transformer T2 high voltage winding is connected to the 115 kV bus through an underground low pressure oil filled cable; reserve station service transformer T3 hi h volta e windin is connected to the 115 kV bus through an overhead transmission line. oil natural air natural/oil natural air forced/oil
~ natural air forced cooled Each of the reserve s a Ion service rans ormers IS rated a emperature rise. The high voltage windings are rated 450 kV BIL and are w e connected with so I ounded neutrals; the two low voltage windings, and are wye connec ith resistance grounded neutral I 110 kV I 115/20/25 MVA, 65 C 115 kV .
rtTe-tow:::litCIttalae windings of the reserve ansformers supply 4160 V reserve nonsegregated bus e plant servi AC distribution buses as follows:
TransformerT2 AC I Bus "X"winding "Y"winding TransformerT3 AC Distribution Bu "X"winding 10100 "Y"winding 10300 The low voltage Y winding is equipped with a load tap changer.
8.4.2.5 Safety Evaluation The lines connecting the reserve station service transformers to the 115 kV bus are arranged so that failure of either line does not result in the loss of the other line. The overhead line to reserve station s rvice transformer T3 is designed to equal or exceed the requirements of the 115 kV incoming transmission li es.
The line to reserve station service transformer T2 is underground. The underground line is not subjecte to the surface conditions which affect the overhead line.
The overhead and underground lines are each capable of continuously carrying full capacity of their respective reserve station service transformers.
The transformers are located approximately 153 ft apart and are further protected by fire walls.
The secondary leads from each transformer consist of a non-segregated phase bus duct.
Each transformer and its high and low voltage connections are capable of starting and supplying all loads 0 I its associated emergency service bus of the Plant Service AC Power Distribution System.
In the event that the normal AC power source is lost, the reserve AC power sources are automatically connected to the Plant Service AC Power Distribution System as described in Section 8.5.
Monitoring and indicating devices are provided in the Control Room to permit supervision of the operational status of the reserve AC power source.
8.4.2.6 in:::.pectlon ana Testing Inspection and testing at vendor facilities and initial system tests were conducted to ensure that all components are operational within their design ratings.
The system and its components are tested throughout plant life in accordance with plant operating procedures.
8.4-3 Rev. 1 5/05
EC 12703 15/20/25 MVA ONAN/ONAF1/ONAF2
EC 90 12703 T3 LTC
90 EC T2 LTC 12703
JAF FSAR UPDATE
- b. EHV Grid System Voltages The normal operating range of the 345 kV grid system is between a minimum of 345 kV and a maximum of 370 kV. If the 345 kV system voltage should decay to a minimum of 323 kV, undervoltage tripping and system load shedding are initiated by the system dispatcher to maintain the system voltage above this minimum. If the 345 kV system voltage should operate above 370 kV, Control Room operators will notify the appropriate power grid control dispatchers to reduce the grid voltage below 370 kV.
The normal operating range of the 115 kV system at the JAF switchyard bus is between a minimum of 117 kV and a maximum of 122 kV. The minimum voltage on the 115 kV bus that is expected at anytime is 116 kV, however, for conservatism a condition of 115 kV minimum voltage on the 115 kV bus was considered.
With a 115 kV system bus voltage of 117 kV, the voltage on the 4160 V emergency buses is 4143 V and 577 V at the 600 V emergency load center buses at normal load. A system voltage of 122 kV prod uces 4333 V at the 4160 V emergency buses and 605 V at the 600 V emergency load center buses at normal load.
- c. Emergency Bus Voltages When Operating From the Reserve Source Computer studies have been performed to calculate the voltages at the 4160 V and 600 V emergency buses for the full range of the 115 kV switchyard bus voltages taken in conjunction with the existing transformer tap settings and normal load, no load, and full load emergency bus and normal conditions. The voltage profiles at the emergency buses are shown in Figure 8.6-1 t A summa of results for the si nificant conditions is shown below:
> and are bounding for application of the load tap changer.
- 1. Normal operati ange maximum on the 115 kV switchyard bus of 122 kV and no load on th serve station service transformer and load center transformers.
4160 V emergency bus voltage is 4472 V (107.5 percent of nominal) 600 V emergency bus voltage is 634.5 V (105.75 percent of nominal)
Normal operating range minimum on the 115 kV switchyard bus of 117 kV and full load on the reserve station service transformers and load center transformers.
- a. 4160 V emergency bus voltage is 4067 V (97.76 percent of nominal)
- b. 600 V emergency bus voltage is 553 V (92.17 percent of nominal)
The reserve station service transformers are provided with a load tap changer on the low voltage Y winding with 8 steps above and 8 steps below 4.16 kV for a range of +/-1a perce!!t.
A no load tap changer is provided on the high voltage H winding with 2 steps above and 2 steps below 115 kV for a range of +/-5%. The taps will remain at a fixed position.
8.6-9 Rev. 5 5/03
JAFP-12-0032 Enclosure 3 Draft UFSAR Text, Figure and Table Changes (6 Pages)
l I
I VOLTAGE PROFILE - ESSENTIAL BUSES - EXISTING TRANSFORMER I TAP SETTINGS I
I J
BUS VOLTAGE BUS VOLTAGE NO LOCA NORMAL NO LOCA NORMAL LOAD LOAD LOAD LOAD
_107.5 (645.0V)
LOAD LOAD
------ 106.2 (637.2V) 121 KV= 105.2 105 ~f§=::~::~~~1~-0~g~£~4~~Ve::!~1~0~4.~22
. . (4335.6V_)-+-_-----:-::;;o"----ILJ-""'--=-------~'1----
103.7 (622.0V) 117KV=101.7 115KV= 100 r--------+------t>-<:>t----"""'"""""ot----+--~---___k"rr_---_t'<AI--
112.5KV=97.8 112KV=97.4 109.25KV=95 ~
r::::~~;;:i~~~~~~--j~ ~.95 (3949.8V) -~I----~*---
115KV BASE 4160KV BASE 600V BASE 4KV EM BUS II 115KV SYSTEM 10,000 tN, .,N OPERATING RANGE 117-'121 KV
- --1 R.S.S.T
~
r--
X y
115KV-4160V 113KV TAP JAMES A. FITZPATRICK FSAR UPDATE VOLTAGE PROFILE - ESSENTIAL BUSES I REV, 4 DEC,2011 I FIGURE NO.8, 6-1
JAF FSAR UPDATE
- b. EHV Grid System Voltages The normal operating range of the 345 kV grid system is between a minimum of 345 kVand a maximum of 370 kV. If the 345 kV system voltage should decay to a minimum of 323 kV, undervoltage tripping and system load shedding are initiated by the system dispatcher to maintain the system voltage above this minimum. If the 345 kV system voltage should operate above 370 kV, Control Room operators will notify the appropriate power grid control dispatchers to reduce the grid voltage below 370 kV.
The normal operating range of the 1~~:;'~m at the JAF switchyard bus is between a minimum of 117 kV and a maximum o~~V. The minimum voltage on the 115 kV bus that is expected at anytime is 116 kV, however, for conservatism a condition of 115 kV minimum voltage on the 1 flbl was c nsidered. "J}?"':Jt r 4, V
.3 I ;t.. 1/2 ,.,.. .;;I';;;';;;. . ,
With 115 is Van sys em us voltage 0 V, the voltage on the 4160 V emergency buses Vat the 600 V mergency load center buses at normal loa.d. A system voltage of..@kV produces Vat the 4160 V emergency buses and~V at the 600 I
V emergency load center buses at normal load.
Emergency Bus Voltages When Operating From the Reserve Source Computer studies have been performed to calculate the voltages at the 4160 V an~dOO
~
V B
~~.
emergency buses for the full range of the 115 kV switchyard bus voltages taken i conjunction with the existing transformer tap settings and normal load, no load, and emergency bus and normal conditions. The voltage profiles at the emergency buses are oad I shown in Figure 8.6-1. A summary of results for the significant conditions is ~~
- 1. Normal operating range maximum on the 115 kV sWitchyard bus of~ kV -;;;~
load on the reserve station service transfo er and load cent transformers.
I r--7'<eL..;I;..,;c 'jd~, 0
- a. 4160 V emergency bus voltage IS . pe ent of nominal)
- b. 600 V emergency bus voltage i~V (~p...crent of nominal) "..,-
"'--~~~~a!i~~~-~
- 2. . .. on the(Jp!D @Z.,vbus of ~
115 kV switchyard r//:Z'~
kV ande-- ~~
~d :::;~::::::: ::~~~:::~-a£::~
on
- b. 600 V emergency bus v ; ; ; : : V ( percent of nominal)
~9 8.6-9 Rev. 5 5/03
3.
- a. 41.60 V emergency bus IS
- b. 600 V emergency bus volta e is f nominal).
54 3,;:t..; 3~81 Calculations were performed to establish the wors case voltage leve a e safety related load terminals, when starting the non-safety related load producing the largest voltage drops throughout the plant electrical distribution system. The calculations assumed full load on the plant electrical buses with the offsite power supply grid at its lowest voltage of 115 kV. It was found that the worst case occurred while starting one 3000 hp condensate booster pump at the 4000 V level. The starting of one of the 7000 hp Recirculation Pump M-G sets results in a lesser disturbance since these loads are fed from separate windings in the reserve transformers.
The resulting values of load terminal voltages found as described above, are shown in Figure 8.6-2.
- d. Emergency Bus Voltages When Operating From the Normal Source The normal station service transformer is provided with a load tap changer with 16 steps above and 16 steps below 22.8 kV for a range of :!: 10 percent. The taps are changed by use of remote manual control in the Control Room. As the main generator voltage changes in response to changes in grid voltage and generator loading, the operator changes transformer taps to maintain a voltage of 4160 V, and as a result voltages at the 600 V emergency buses will also be satisfactory.
For any voltage in the normal operating range (370 to 345 kV) of the 345 kV grid I\ system, or with the voltage at the degraded condition of 323 kV where load shedding begins to occur (rather than generator trip), the voltage at the normal station service transformer primary will remain within the range of the load tap changer.
\
- e. Set Point and Location of Loss of Voltage Trip Sensors The loss of offsite power (loss of voltage trip) relays sense the voltage at the 4160
\ V emergency buses. The devices which are used to detect and alarm an undervoltage condition, initiate starting of the emergency diesel generators, isolate the bus from the normal and reserve supply, initiate bus load shedding, permit closure of the emergency diesel generator breakers, and initiate the program restart circuit, are located in the instrument and breaker control compartments of the 4160
,--0 -----*-*--=---
V emergency bus M/1AJ~/i.~ VtJd8iA.4- P}t. ~ I/§"I<
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11Il_~
"'"-_-----. 8.6-10 Rev. 5 5103
JAF FSAR UPDATE Setting of the degraded grid relay is very critical to the protection scheme. Analyses show that the 600 V bus must be maintained at 90 percent of nominal at 600 V load center bus to ensure proper operation of 600 V loads, 600 V MGG control circuits and control circuits fed from 120 V AG emergency buses. To maintain this voltage at the 600 V level, a minimum voltage of 92 percent of nominal is required on 4160 V emergency buses. Adding instrument inaccuracies to this value, the drop-out setting of the relay is determined to be 93 percent of nominal. The pick-up setting of the relay was selected to be 93.64 percent of the nominal, which is 0.64 percent overl the drop-out setting.
The maximum allowable time delay setting for degraded voltage protection, coincident with a LOGA condition is approximately 9 seconds. The maximum allowable time delay setting for extended degraded voltage protection during a non-LOGA condition is approximately 45 seconds. Time delay settings do not exceed the maximum time delay that is assumed in the FSAR accident analysis and will provide protection of the safety related loads from thermal damage or tripping of protective devices due to degraded voltage. These time delays will allow for recovery of bus voltage from voltage drops caused by the starting of large motors during normal operation, from the transfer of house loads during start-up and by the sequence starting of EGGS pump motors during an accident condition.
- g. Degraded Grid Voltage at Loss~of-Voltage Trip Setting
~~~l unaervoltage trip set point of 71.5 percent on the 4160 emergency bus and the corresponding voltage on the 115 kV system would be approximately 88 kV.
- h. Voltage Ranges of Electrical Equipment The 4000 V RHR and core spray pump motors will start and accelerate at 75 percent and 70 percent voltage respectively. Other 4000 V and 600 V load center motors will start and accelerate at 70 percent to 80 percent rated voltage. The breaker control circuits for the 4160 V bus and 600 V load center bus loads are supplied by the station batteries and are independent of grid voltage.
8.6-12 Rev. 9 5/07
JAF FSAR UPDATE TABLE 8.6-1 (Sheet 1 of 2)
AUTOMATIC STARTING AND SEQUENTIAL LOADING OF EMERGENCY AC POWER SOURCE LOSS OF VOLTAGE DEGRADED VOLTAGE COINCIDENT WITH POSTULATED ACCIDENT OR EXTENDED DEGRADED VOLTAGE OF BOTH NORMAL AND RESERVE POWER SOURCES TYPICAL FOR EACH OF TWO REDUNDANT AC POWER SOURCES Elapsed Time Event (Sec.) Load, KW Remarks Coincident undervoltage condition of normal and reserve power supplies to 4160 V emergency bus and postulated accident or extended undervoltage condition of normal and reserve power supplies to 4160V Emergency Bus.
Initiate starting diesel generators 0 Emergency bus undervoltage condition is still present Emergency diesel generators up to speed and voltage.
Normal/reserve source tie breakers and all feeder except supply to 600 V emergency busses tripped open.
Generator breakers closed 11 (14 (3>>) 1775(7) Worst case load centers load assumed, including load center transformers'losses Start first RHR pump (1060) hp 12 (15 (3>>) 961 (4) Approximately one second after restoration of bus voltage First RHR pump at speed Start second RHR pump (1060 hp)(1) 17 (20 (3>>) 961 (4)
Second RHR pump at speed Start core spray pump (1250 hpP&2) 22 1017(4)
Core spray pump at speed 27 (30 (3>>) This completes automatic start sequence Total Automatic Loading @60Hz, 4.16 kV 4714
@61.2 Hz, 4.4 k\j5, 6) 5026 Begin manual sequence 600 Manually stop one RHR pump 961 (4)
Rev. 4 4/09
JAF FSAR UPDATE TABLE 8.6-1 (Sheet 2 of 2)
Elapsed Time (Sec.) Load, KW Remarks Manually start 2 RHR service+ 582 water pumps (2 at 350 hp)
Manual Loading Total@ 60 Hz, 4.16 kV 4335
@ 61.2 and 4.4 kV(5, 6) 4683 Additional loads may be added manually within capacity of the emergency AC power source.
(1 ) This RHR pump will not be started should one machine of the emergency AC power source experience a malfunction.
(2) If only one EDG is automatically sequenced onto an emergency bus, the single EDG may be overloaded beyond its capability to supply load.
(3) If only a single EDG is automatically sequenced onto an emergency bus, a 3-second time delay is added to the sequence time. However, no analytical credit for accident mitigation is taken for loads on a bus in this scenario.
(4) The pump load values are worst case loading under run-out condition.
(5) If EDG is running with the maximum Technical Specification value of 61.2 Hz, then the rotating equipment, such as pump, loads will increase loading on the EDG approximately up to 6%.
(6) If EDG is running with the maximum Technical Specification value at 4400 volts, then the static loads, such as heaters will increase loading on the EDG approximately up to 11.9%.
(7) For additional margin, 2% loading is added.
Rev. 4 4/09
JAFP-12-0032 Enclosure 4 Modification Drawings for Replacement RSSTs (4 Pages)
8 7 6 5 4 3 2 1
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JAFP-12-0032 Enclosure 5 Replacement RSSTs Non-Safety Related / ECCS Load Sequencing Voltage Profile (1 Page)
JAF-CALC-11-00002 ATTACHMENT 6 PAGE 103 ETAP Project: JAF AC Auxiliary System 7.1.0N Date: 08-03-2011 Location: Oswego, NY SN: SARGENTLDY Contract: 11021-023 Revision: Revision 2 Engineer: Sargent & Lundy, LLC Study Case: Case 4 Config.: LOCA_D2T_GEN Project File: C:\Documents and Settings\0r6702\Desktop\Fitzpatrick\new\JAF_ETAP_MODEL Output Report: Case 4 TRANSIENT STABILITY ANALYSIS Bus Voltage BUS 10100 (71H01) BUS 10200 (71H02) BUS 10300 (71H03) BUS 10400 (71H04) EMERG BUS 10500 (71H05) EMERG BUS 10600 (71H06) 120 100 80
% of Bus Nominal kV 60 40 20 0
0 2 4 6 8 10 12 14 Time (Sec.)
JAFP-12-0032 Enclosure 6 Replacement RSSTs Non-Safety Related Load Voltage Profile on Transfer from NSST (1 Page)
JAF-CALC-11-00002 ATTACHMENT 6 PAGE 1 ETAP Project: JAF AC Auxiliary System 7.1.0N Date: 08-03-2011 Location: Oswego, NY SN: SARGENTLDY Contract: 11021-023 Revision: Revision 2 Engineer: Sargent & Lundy, LLC Study Case: Case 1 Config.: FLSUM_D2_GEN Project File: C:\Documents and Settings\0r6702\Desktop\Fitzpatrick\new\JAF_ETAP_MODEL Output Report: Case 1 TRANSIENT STABILITY ANALYSIS Bus Voltage BUS 10100 (71H01) BUS 10200 (71H02) BUS 10300 (71H03) BUS 10400 (71H04) EMERG BUS 10500 (71H05) EMERG BUS 10600 (71H06) 120 110 100
% of Bus Nominal kV 90 80 70 60 0 1 2 3 4 5 6 7 8 Time (Sec.)