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 Entered dateSiteRegionReactor typeEvent description
ENS 5395324 March 2019 05:23:00HatchNRC Region 2At 0159 (EDT), with Unit 2 in Mode 1 at 25 percent power, the reactor was manually tripped due to degrading condenser vacuum. After the turbine was tripped, the station service electrical buses did not transfer to alternate supply resulting in loss of the condensate feedwater system and level being controlled by the RCIC system. Operators responded and stabilized the plant. Reactor water level is being maintained via the RCIC system. Pressure is being controlled and decay heat is being removed by the HPCI system in pressure control mode. Unit 1 is not affected. Additionally, an actuation of the primary containment isolation system occurred during the reactor scram. The reason for the actuation was a group II isolation signal was received on reactor water level and a group I isolation was received on decreasing vacuum. Due to the Reactor Protection System actuation while critical, this event is being reported as a four-hour, non- emergency notification per 10 CFR 50.72(b)(2)(iv)(B). Additionally, this event is being reported in accordance with 10 CFR 50.72(b)(3)(iv)(A) as an event that results in a valid actuation of the primary containment isolation system. There was no impact on the health and safety of the public or plant personnel. The NRC Resident Inspector has been notified."
ENS 5394419 March 2019 07:41:00HatchNRC Region 2At 0140 (EDT) on 03/19/2019, while the unit was at approximately 1% power and 154 psig pressure in MODE 2, it was discovered that Unit 2 High Pressure Coolant Injection (HPCI) was INOPERABLE. HPCI does not have a redundant system, therefore, this condition is being reported as an eight-hour, non-emergency notification per 10 CFR 50.72(b)(3)(v). There was no impact on the health and safety of the public or plant personnel. The NRC Resident Inspector has been notified. Unit 2 entered LCO 3.5.1.c for the HPCI being inoperable. There is no effect on Unit 1.
ENS 5389323 February 2019 09:13:00HatchNRC Region 2At 0212 EST on February 23, 2019, with Unit 2 in Mode 5, an actuation signal for the 2C Emergency Diesel Generator (EDG) was received during the Loss of Coolant Accident / Loss of Offsite Power logic system functional test. The 2C EDG was running and tied onto the 2G 4160 emergency bus when the alternate supply breaker was closed as required per the test procedure. Immediately upon closing the alternate supply breaker, both the alternate supply breaker and 2C EDG output breaker tripped open. The 2C EDG output breaker reclosed once the 2G 4160 bus undervoltage relays sensed a deenergized bus. When the 2C EDG tied to the 2G 4160 bus, the bus voltage was noted as being high, and the 2C EDG was secured. Investigation is ongoing to determine the cause of the initial bus undervoltage and the subsequent bus excessive voltage. This event is being reported in accordance with 10 CFR 50.72(b)(3)(iv)(A) as an event that results in a valid actuation of the emergency AC power system. There was no impact on the health and safety of the public or plant personnel. The NRC Resident Inspector has been notified. This event puts Unit 1 in a 72 hour Limiting Condition for Operation for the 1C Startup Transformer being out of service.
ENS 538178 January 2019 08:12:00HatchNRC Region 2On November 12, 2018, at 1331 EST, Unit 1 secondary containment isolated and Standby Gas Treatment (SBGT) systems started on Unit 1 and Unit 2 due to a blown fuse. The blown fuse was caused by a degraded refuel floor radiation monitoring relay, causing the radiation monitor to trip and resulted in an invalid actuation of the Unit 1 Group 10 and Group 11 primary containment isolation valves, all Unit 1 secondary containment isolation valves, and auto start of the Unit 1 and Unit 2 SBGT system. The Unit 1 Fission Product Monitor isolated and tripped and both Unit 1 H202 Analyzers isolated. This event is reportable per 10 CFR 50.73(a)(2)(iv)(A) since the containment isolation and auto-start of SBGT on both units was not part of a pre-planned sequence and the event resulted in the invalid actuation of general containment isolation valves in more than one system. All primary and secondary containment isolation valves, with the exception of the 2T41F003A, Refueling Floor Inboard Vent Supply Isolation valve, functioned successfully. The refuel floor inboard vent supply isolation valve failed to travel fully closed on the secondary containment isolation signal and was therefore declared inoperable. The 2T41F003B refuel floor outboard vent supply isolation valve was verified to go fully closed and therefore isolation of that associated penetration line was successful. After assistance from maintenance, the valve was verified to be fully closed. All SBGT systems functioned successfully. The associated fuse and relay were replaced, and secondary containment was returned to normal service. The licensee notified the NRC Resident Inspector."
ENS 5281822 June 2017 09:32:00HatchNRC Region 2GE-4On April 27, 2017 at 0029 EDT, Unit 2 received an invalid partial Group 2 isolation due to a failed relay (2D11-K80) on the auxiliary trip unit. Both of the U1 and U2 Standby Gas Treatment (SGT) trains started and the U2 Group II primary containment and all secondary containment inboard isolation valves closed. Also, the refuel floor isolation dampers closed, the reactor building supply and exhaust fans tripped, and the refueling floor supply and exhaust fans tripped. This event is reportable per 10 CFR 50.73(a)(2)(iv)(A) since the containment isolation and auto-start of SGT on both units was not part of a pre-planned sequence and the event resulted in the invalid actuation of general containment isolation valves in more than one system. All primary and secondary containment inboard isolation valves and SGT systems functioned successfully. The failed relay was replaced and the systems were restored to normal alignment. The licensee will notify the NRC Resident Inspector.
ENS 5280314 June 2017 08:42:00HatchNRC Region 2GE-4On April 17, 2017 at 1120 EDT, following scheduled maintenance, the Reactor Protection System (RPS) 'A' bus was returned to its normal supply, the RPS 'A' motor generator (MG) set. The RPS MG set had been running loaded for 1 hour when the RPS 'A' bus tripped. Maintenance personnel had connected probes of a grounded oscilloscope to check for proper operation of the MG set, resulting in the RPS 'A' bus trip. The controlling procedure did not contain a caution about using only an ungrounded oscilloscope. The trip of the RPS 'A' MG set resulted in a half scram and an invalid isolation signal causing primary containment isolation valves in multiple systems to isolate. This event is reportable per 10 CFR 50.73 (a)(2)(iv)(A) since the containment isolation was not part of a pre-planned sequence and the event resulted in the invalid actuation of general containment isolation valves in more than one system. Corrective actions include revising the governing procedure with the proper precaution and limitation to require the use of an ungrounded oscilloscope. A training needs analysis will also be performed to cover the lessons learned from this event. The licensee notified the NRC Resident Inspector.
ENS 5270021 April 2017 05:41:00HatchNRC Region 2GE-4At 2345 (EDT) on 04/20/2017, the Unit 1 Reactor Mode Switch was taken to the Shutdown position to comply with Technical Specification 3.10.4 due to having no operable IRM's (Intermediate Range Monitors) in one quadrant of the reactor vessel as a result of maintenance activities. Placing the mode switch to Shutdown inserts a valid scram signal into the Reactor Protection System (RPS). All control rods had been previously inserted and no rod movement occurred when the mode switch was positioned to Shutdown. Due to this valid RPS scram, and not being a part of a preplanned evolution, this condition is reportable under criteria 50.72(b)(3)(iv)(A) as an event or condition that results in valid actuation of any of the systems listed in paragraph (b)(3)(iv)(B) of this section except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation. The licensee notified the NRC Resident Inspector.
ENS 5269620 April 2017 05:57:00HatchNRC Region 2GE-4On 04/20/2017 at 0302 EST during a reactor startup, a reactor scram resulted from upscale spike on two Intermediate Range Monitors (IRMs), 1C51K601A and 1C51K601B. IRM A, 1C51K601A is in Reactor Protection System Channel A and IRM B, 1C51K601B is in Reactor Protection System Channel B. All control rods fully inserted. No PCIS (Primary Containment Isolation System) actuations occurred and none were expected to occur based upon plant condition following the reactor scram. Investigation is in progress. Condition was not due to a true flux event. This event is reportable per 10 CFR 50.72(b)(2)(iv)(B) as an event or condition that resulted in actuation of the reactor protection system (RPS) when the reactor is critical except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation. CR 10356172 The NRC Resident has been notified. The reactor was at 0.5% (percent) power at the time of the event and will remain in Hot Shutdown pending the results of the root cause investigation.
ENS 5268517 April 2017 13:35:00HatchNRC Region 2GE-4On February 17, 2017 at 1021 EST, secondary containment isolated and Standby Gas Treatment (SBGT) systems started on Unit 1 and Unit 2 during a maintenance activity to replace a relay in the Unit 2 primary containment isolation system. The work was being conducted as part of planned maintenance during the Unit 2 refueling outage. Poor work instruction led to a jumper not being installed as required, thus causing relays to de-energize, resulting in an invalid actuation of the Unit 1 and Unit 2 outboard primary and secondary containment isolation valves and auto-start of the Unit 1 and Unit 2 SBGT system. This event is reportable per 10 CFR 50.73(a)(2)(iv)(A) since the containment isolation and auto-start of SBGT on both units was not part of a pre-planned sequence and the event resulted in the invalid actuation of general containment isolation valves in more than one system. All primary and secondary containment isolation valves and SBGT systems functioned successfully. The associated wires were re-landed and secondary containment was returned to normal service. The licensee notified the NRC Resident Inspector.
ENS 5265030 March 2017 12:58:00HatchNRC Region 2GE-4During the evaluation of tornado missile vulnerabilities and the potential impacts to safety-related plant equipment, it was concluded that the following structures are vulnerable to tornado generated missiles: All five of the Unit 1 and Unit 2 Emergency Diesel Generator (EDG) fuel oil storage tanks have ventilation pipe extending approximately 5 feet above grade. In the event that a tornado missile impact occurs on the aforementioned ventilation piping, there is a possibility that the vent lines could crimp. This could prevent the tanks from venting and inhibit the transfer of fuel oil from the main fuel oil storage tanks to the day tank. Ultimately, this causes the emergency diesels to be inoperable. These conditions are reportable per 10 CFR 50.72(b)(3)(ii)(B) and 10 CFR 50.72(b)(3)(v)(D) for any event or condition that results in the nuclear power plant being in an unanalyzed condition that significantly degrades plant safety and also an event or condition that could have prevented fulfillment of a safety function needed to mitigate the consequence of an accident. This issue is being addressed in accordance with EGM-15-002, Revision 1, Enforcement Discretion for Tornado-Generated Missile Protection Noncompliance. The NRC Resident Inspector has also been notified.
ENS 5256720 February 2017 01:14:00HatchNRC Region 2GE-4On 2/19/2017 at 2323 EST, during LLRT (local leak rate test) testing per 42SV-TET-001-2, 2T48F320 exceeded the maximum allowable leakage limit. The companion isolation valve in the same line (2T48F319) had previously failed LLRT. The failure of the 2T48F320 represents a failure of the 2T23X26 penetration to maintain primary containment integrity. This event is reportable per 10CFR50.72(b)(3)(ii)(A) since the failure of the 2T23X26 penetration caused primary containment leakage to exceed La (allowable leakage) and thus represents a degraded principle safety barrier. CR (condition report) 10333178. NRC Resident Inspector has been notified. 2T48F319 and 2T48F320 are 18 inch dampers. This event places the licensee in a Technical Specification limit that requires the dampers to be repaired and pass LLRT prior to the plant entering Mode 3.
ENS 5256317 February 2017 17:46:00HatchNRC Region 2GE-4On 2/17/2017 at 1414 EST, secondary containment was declared inoperable due to the discovery of an 18-inch open pipe penetration in the secondary containment boundary. During walkdown activities, it was discovered that a blind flange installed to support removal of a Unit 2 secondary containment isolation valve had been installed on the wrong flange to provide isolation for secondary containment. At 1503 EST, the blind flange was moved to the correct side of the flange and secondary containment was declared operable. This event is reportable per 10 CFR 50.72(b)(3)(v)(C) as a condition that at the time of discovery could have prevented the fulfillment of the safety function of a system needed to control the release of radioactive material. In conjunction with operation of the Standby Gas Treatment (SGT) subsystems, secondary containment is designed to reduce the activity level of the fission products prior to release to the environment and to isolate and contain fission products that are released during certain operations. Therefore, the lack of a qualified isolation device to limit the release of radioactive material constitutes a loss of safety function due to a loss of secondary containment integrity. CR 10332592 The NRC Resident has been notified.
ENS 5255816 February 2017 17:28:00HatchNRC Region 2GE-4On February 16, 2017 at 1320 EST, the 2A Emergency Diesel Generator (EDG) started in response to a valid actuation signal due to the momentary loss of the 2C Startup Transformer (SAT). While performing maintenance activities on the 2D SAT, the alternate supply breaker tripped and reclosed, allowing the 4160 2E Emergency Bus to be momentarily de-energized. When the 4160 2E Emergency Bus de-energized, the 2A EDG received a valid autostart signal due to emergency bus low voltage. Although, the 2A EDG did autostart, it did not tie to the 4160 2E Emergency Bus as the 4160 2E Emergency Bus was re-energized from the 2C SAT. This event is reportable per 10 CFR 50.72(b)(3)(iv)(A) since the autostart of the 2A EDG was not part of a pre-planned sequence and the event resulted in the valid actuation of an emergency ac electrical power system. CR 10332134 The NRC Resident has been notified.
ENS 525438 February 2017 17:31:00HatchNRC Region 2GE-4During a control room panel walk down by an on-shift Reactor Operator at approximately 1151 (EST) on 2/8/2017, Unit 1 High Pressure Coolant Injection (HPCI) suction and discharge pressure indicators were noted to be downscale. I & C investigated and found the output of 1E41K603, DC to AC inverter, degraded. This inverter also powers the HPCI flow controller. Without the flow controller HPCI would not auto-start to mitigate the consequences of an accident, thus HPCI was declared inoperable. All other emergency core cooling systems and the Reactor Core Isolation Cooling (RCIC) system remain operable. HPCI is a single train system with no redundant equipment in the same system, thus this failure is reportable as an event or condition that could have prevented fulfillment of a safety function needed to mitigate the consequences of an accident, 10CFR50.72(b)(3)(v)(D). Inverter 1E41K603 was replaced and functionally tested satisfactorily at 1630 on 2/8/2017, restoring HPCI to operable status. The NRC Resident Inspector was notified.
ENS 525313 February 2017 16:33:00HatchNRC Region 2GE-4In preparation for transitioning the Plant Hatch Fire Protection Licensing Basis from 10CFR50.48(b) (Appendix R) to 10CFR50.48(c) (NFPA 805), a weak-link and operator manual action (OMA) analysis for Information Notice (IN) 92-18 type hot shorts on motor-operated valves (MOVs) was performed to support the Plant Hatch Appendix R Safe Shutdown Analysis. As a result of the analysis, it was identified that cable impacts can bypass valve limit and torque switches, resulting in physical damage to valves required for Safe Shutdown. This would prevent the valves from being operated locally or being operated from the remote shutdown panel. These cable failures could also cause the valve motors to fail. This updated analysis has identified circuit configuration deficiencies in Fire Areas 0024 A & C (Main Control Room & Cable Spread Room), 1203F (U1 Reactor Building SE), 1205F (U1 Reactor Building NE), and 2203F (U2 Reactor Building NE). Therefore, due to the identified deficient conditions, it was determined that in the event of a postulated fire in the affected fire areas, the paths of safe shutdown on the affected unit(s) could be compromised and impact the ability to achieve safe shutdown conditions. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions in these same fire areas. The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded conditions can be repaired. CRs 10326399, 10326401, 10326402, 10326404 and 10326405 The licensee notified the NRC Resident Inspector. The unanalyzed condition is applicable to 10CFR50.48(b) Appendix R and not to 10CFR50.48(c) (NFPA 805).
ENS 525261 February 2017 16:46:00HatchNRC Region 2GE-4

Plant Hatch declared a notification of unusual event. Subsequent investigation determined the paraphernalia was related to plant drills. The Unusual Event was terminated at 1727 EST. The licensee notified the NRC Resident Inspector. Notified the DHS SWO, FEMA, NICC, and NNSA (via e-mail).

  • * * RETRACTION FROM KENNETH HUNTER TO MARK ABRAMOVITZ AT 1829 EST ON 2/1/2017 * * *

The event was retracted. The licensee notified the NRC Resident Inspector. Notified the R2DO (Shakur), NSIR (Holian), IRD MOC (Gott), DHS SWO, FEMA, NICC, and NNSA (via e-mail).

ENS 5195023 May 2016 17:02:00HatchNRC Region 2GE-4On May 23, 2016, at 1009 EDT, while personnel were performing turbine testing with Unit 2 offline for planned maintenance, an event resulted in the actuation of containment isolation valves in more than one system. In response to this unexpected signal, 2B21F016 (Steam Line Drain Line Inboard Isolation Valve), 2B21F019 (Steam Line Drain Line Outboard Isolation Valve), and 2B31F019 (Reactor Water Sample Inboard Isolation Valve) went closed, all of which are primary containment isolation valves actuated by Group 1 Isolation. The Group 1 Isolation signal initiated based on low condenser vacuum during the turbine testing procedure, a valid condition that was expected to have been bypassed in the logic during the performance of this procedure. Human performance is believed to be the cause of these systems having actuated in a way that was not part of the planned evolution. Although the Unit was shut down when this signal was received, and primary containment isolation was not required to mitigate the consequences of an event, this Isolation signal has been determined to have been valid due to the initiation in response to actual plant conditions or parameters which satisfy the requirements for initiation of the system. The event is reportable as required by 10 CFR 50.72(b)(3)(iv)(A)(2): (A) Any event or condition that results in valid actuation of any of the systems listed in paragraph (b)(3)(iv)(B) of this section except when the actuation results from and is part of a pre-planned sequence during testing or reactor operation. (2) General containment isolation signals affecting containment isolation valves in more than one system or multiple main steam Isolation valves (MSIVs). The licensee has notified the NRC Resident Inspector.
ENS 5174218 February 2016 15:48:00HatchNRC Region 2GE-4As part of the upgrade to the full structural weld overlays (FSWOL) per NRC-approved ISI (In-service Inspection) Alternative HNP-ISI-ALT-15-01, the surface of the existing weld overlay for the 1E Recirculation weld (1B31-1RC-12BR-E-5) was ground to prepare the surface for receipt of a new Alloy 52M overlay. Upon performance of the subsequent liquid penetrant testing examination, it was discovered that the as-found condition of the flaw did not meet acceptance criteria. It was determined that the flaw constituted a defect in the primary coolant system that could not be found acceptable per ASME Section XI. Therefore, this event notification is being made in accordance with 10 CFR 50.72(b)(3)(ii)(A). Evaluation of the flaw found in the weld overlay suggests that the non-satisfactory liquid penetrant surface examination is a result of the propagation of the original flaw that was found on the 1E Recirculation Loop Piping. The flaw is axial in nature and therefore there is no impact on structure integrity degradation. No leakage is currently present or was seen during the previous operating cycle from this flaw. There is also reasonable assurance that there was not a breach in the credited RCS (Reactor Coolant System) boundary during the previous operating cycle. As part of the corrective action to fix the flaw, the 1E Recirculation weld will be upgraded to full structural weld overlay per the NRC-approved ISI Alternative. The Licensee notified the NRC Resident Inspector.
ENS 5125623 July 2015 15:52:00HatchNRC Region 2GE-4At 1120 EDT on 07/23/2015, while performing Chemistry rounds, a Chemistry Technician discovered an underground leak near the Plant Service Water bleach moat. The Plant Service Water bleach injection pumps were secured at 1130 EDT on 07/23/2015. The leak was later confirmed to be bleach. Approximately 200-300 gallons of 12.5% sodium hypochlorite are estimated to have leaked out of a broken underground pipe. This amount exceeded the reportable limit (100 lbs. or 80 gallons) as specified by the National Response Center. The bleach leaked into the surrounding soil and into a Plant Hatch storm drain where it pooled before reaching the Altamaha river. No bleach discharged into the river. Cleanup began immediately by neutralizing the bleach with sodium bisulfite and is still on-going. Plant Management authorized Southern Nuclear Company Environmental Affairs to report to the US Coast Guard National Response Center at 1305 EDT on 07/23/2015 in accordance with corporate procedures. The event was reported to the National Response Center at 1316 EDT. The Georgia Environmental Protection Division was also contacted. This event is reportable under 10 CFR 50.72(b)(2)(xi) as an event or situation related to the protection of the environment for which a notification to other government agencies have been made. NRC Resident Inspector was notified at 1530 at 07/23/2015. CR (Condition Report) 10099779
ENS 511204 June 2015 12:56:00HatchNRC Region 2GE-4

In preparation for transitioning the Plant Hatch Fire Protection Licensing Basis from 10 CFR 50.48(b) (Appendix R) to 10 CFR 50.48(c) (NFPA 805), an update to the Plant Hatch Appendix R Safe Shutdown Analysis has been performed for the Unit 1 and Unit 2 Reactor Buildings. This updated analysis has identified circuit configurations in four Fire Areas where an Appendix R postulated fire could impact the ability to achieve safe shutdown conditions. These are Category 1 barrier impairments. In the Unit 1 Safe Shutdown Analysis, RCIC (1E51C001) (Path 1) components are impacted by a fire in Fire Area 1203. The postulated failure described above impacts HPCI (1E41C001) (Path 2) operation. Therefore, in the updated analysis there is no safe shutdown method for high pressure injection that remains free of fire damage for an Appendix R postulated fire in Fire Area 1203. While this represents an unanalyzed condition for Appendix R, the described scenario is only possible given a fire has occurred in Fire Area 1203. In the Unit 1 Safe Shutdown Analysis, Path 2 components are impacted by a fire in Fire Area 1205. The postulated failure described above impacts the 1E 4160 Kv (1R22S005) emergency bus power to Path 1 components. Therefore, in the updated analysis there is no safe shutdown method that remains available for an Appendix R postulated fire in Fire Area 1205. While this represents an unanalyzed condition for Appendix R, the described scenario is only possible given a fire has occurred in Fire Area 1205. In the Unit 2 Safe Shutdown Analysis, Path 2 components are impacted by a fire in Fire Area 2205. The postulated failure described above impacts the 2E 4160 Kv (2R22S005) emergency bus power to Path 1 components. Therefore, in the updated analysis there is no safe shutdown method that remains available for an Appendix R postulated fire in Fire Area 2205. While this represents an unanalyzed condition for Appendix R, the described scenario is only possible given a fire has occurred in Fire Area 2205. In the updated post-fire safe shutdown model, both safe shutdown paths include the same three options for Torus Water Temperature indication (1T48R072, 1T47R611 or 1T47R612). Only one of these three components is required to succeed, however, all are impacted by the postulated fire. Thus, there is no Unit 1 Torus Water Temperature Indication available for a fire in Fire Area 1205. While this represents an unanalyzed condition for Appendix R, the described scenario is only possible given a fire has occurred in Fire Area 1205. Based on the updated Plant Hatch Appendix R Safe Shutdown analysis recommendations and the plant's Fire Hazard Analysis (FHA), compensatory measures have been taken and will remain in place until the conditions are resolved. The presence of the compensatory measures, in addition to portable fire protection equipment and installed fire protection and detection equipment, ensures the safe shutdown paths are preserved until the conditions are resolved. CR 10079009, 10079019, 10079022, 10079025 The licensee has notified the NRC Resident Inspector.

  • * * UPDATE FROM STANLEY STONE TO DONALD NORWOOD AT 1634 EDT ON 6/17/2015 * * *

In preparation for transitioning the Plant Hatch Fire Protection Licensing Basis from 10 CFR 50.48(b) (Appendix R) to 10 CFR 50.48(c) (NFPA 805), an update to the Plant Hatch Appendix R Safe Shutdown Analysis has been performed for the Unit 1 and Unit 2 Turbine Building. This updated analysis has identified circuit configurations in two Fire Areas where an Appendix R postulated fire could impact the ability to achieve safe shutdown conditions. These are Category 1 barrier impairments. 1) In the Unit 1 Safe Shutdown Analysis, Path 1 RCIC components are impacted by a fire in Fire Area 1105. The postulated failure would impact Path 2 (HPCI) operation. Therefore, in the current analysis for the credited safe shutdown method for high pressure injection may be affected for an Appendix R postulated fire in Fire Area 1105. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 1105. 2) In the updated post-fire safe shutdown model, both safe shutdown paths include the same two options for Torus Water Level Indication: 2T48-R622A and 2T48-R622B. Only one of these two components is required to succeed, however both would be impacted by a postulated fire in Fire Area 2104. Consequently, both credited paths of Unit 2 Torus Water Level Indication could potentially be affected due to a fire in Fire Area 2104. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 2104. Based on the updated Plant Hatch Appendix R Safe Shutdown analysis recommendations and the plant's Fire Hazard Analysis (FHA), compensatory measures have been taken and will remain in place until the conditions are resolved. The presence of the compensatory measures, in addition to portable fire protection equipment and installed fire protection and detection equipment, ensures the safe shutdown paths are preserved until the conditions are resolved. The analysis associated with the transition of the Plant Hatch Fire Protection Licensing Basis from Appendix R to NFPA 805 is continuing, and this and any subsequent similar conditions that meet reporting requirements will be in included in an ENS Update Report. CR 10084753, CR 10084757. The licensee notified the NRC Resident Inspector. Notified R2DO (HAAG).

  • * * UPDATE FROM SCOTT BRITT TO VINCE KLCO ON 6/24/15 AT 2114 EDT * * *

In preparation for transitioning the Plant Hatch Fire Protection Licensing Basis from 10 CFR 50.48(b) (Appendix R) to 10 CFR 50.48(c) (NFPA 805), an update to the Plant Hatch Appendix R Safe Shutdown Analysis has been performed for the Diesel Generator Building. This updated analysis has identified circuit configurations in five Fire Areas where an Appendix R postulated fire could impact the ability to achieve safe shutdown conditions. These are Category 1 barrier impairments. 1) An Appendix R postulated fire in Fire Area 1404 is assessed to impact a cable required for RHR Inboard Injection Valve A, 1E11-F015A, to open. This cable was not identified in the current Safe Shutdown Analysis Report (SSAR) for this component. This valve is normally closed and is required to open to support the operation of RHR Loop A in LPCI mode, which is the credited Low Pressure Injection system for Unit 1 in support of Inventory Control to the RPV for a fire in Fire Area 1404. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 1404. RHR Loop B is not available in this fire area due to fire impacts. 2) An Appendix R postulated fire in Fire Area 1408 is assessed to impact cables required for RHR Inboard Injection Valve B, 1E11-F015B, to open. These cables were not identified in the current Safe Shutdown Analysis Report (SSAR) for this component. This valve is normally closed and is required to open to support the operation of RHR Loop B in LPCI mode, which is the credited Low Pressure Injection system for Unit 1 in support of Inventory Control to the RPV for a fire in Fire Area 1408. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 1408. RHR Loop A is not available in this fire area due to fire impacts. 3) An Appendix R postulated fire in Fire Area 1412 is assessed to impact a cable required for RHR Inboard Injection Valve B, 1E11-F015B, to open. This cable was not identified in the current Safe Shutdown Analysis Report (SSAR) for this component. This valve is normally closed and is required to open to support the operation of RHR Loop B in LPCI mode, which is the credited Low Pressure Injection system for Unit 1 in support of Inventory Control to the RPV for a fire in Fire Area 1412. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 1412. RHR Loop A is not available in this fire area due to fire impacts. 4) An Appendix R postulated fire in Fire Area 2404 is assessed to impact a cable required for RHR Inboard Injection Valve B, 2E11-F015B, to open. This cable was not identified in the current Safe Shutdown Analysis Report (SSAR) for this component. This valve is normally closed and is required to open to support the operation of RHR Loop B in LPCI mode, which is the credited Low Pressure Injection system for Unit 2 in support of Inventory Control to the RPV for a fire in Fire Area 2404. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 2404. RHR Loop A is not available in this fire area due to fire impacts. 5) An Appendix R postulated fire in Fire Area 2408 is assessed to impact cables required for RHR Inboard Injection Valve B, 2E11-F015B, to open. These cables were not identified in the current Safe Shutdown Analysis Report (SSAR) for this component. This valve is normally closed and is required to open to support the operation of RHR Loop B in LPCI mode, which is the credited Low Pressure Injection system for Unit 2 in support of Inventory Control to the RPV for a fire in Fire Area 2408. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 2408. RHR Loop A is not available in this fire area due to fire impacts. Based on the updated Plant Hatch Appendix R Safe Shutdown analysis recommendations and the plant's Fire Hazard Analysis (FHA), compensatory measures have been taken and will remain in place until the conditions are resolved. The presence of the compensatory measures, in addition to portable fire protection equipment and installed fire protection and detection equipment, ensures the safe shutdown paths are preserved until the conditions are resolved. The analysis associated with the transition of the Plant Hatch Fire Protection Licensing Basis from Appendix R to NFPA 805 is continuing, and this and any subsequent similar conditions that meet reporting requirements will be in included in an ENS Update Report. CR 10088142 The licensee will notify the NRC Resident Inspector. Notified the R2DO (O'Donohue).

  • * * UPDATE AT 1739 EDT ON 08/13/15 FROM PAUL UNDERWOOD TO JEFF HERRERA * * *

In preparation for transitioning the Plant Hatch Fire Protection Licensing Basis from 10 CFR 50.48(b) (Appendix R) to 10 CFR 50.48(c) (NFPA 805), an update to the Plant Hatch Appendix R Safe Shutdown Analysis has been performed for the Control Building. This updated analysis has identified circuit configurations in a Fire Area where an Appendix R postulated fire could impact the ability to achieve safe shutdown conditions. This is a Category 1 barrier impairment. 1) An Appendix R postulated fire in Fire Area 0014 is assessed to impact a cable that is required for Diesel Building MCC 1C, 1R24-S027, to remain energized. Further analysis has shown that an inter-cable hot short between two conductors could cause the feeder breaker to this MCC to trip. This MCC is required to support the operation of Diesel Generator 1C, which is a credited power source in the Safe Shutdown analysis for both Unit 1 and Unit 2 in the event of a fire in this area. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 0014. Based on the updated Plant Hatch Appendix R Safe Shutdown analysis recommendations and the plant's Fire Hazard Analysis (FHA), compensatory measures have been taken and will remain in place until the conditions are resolved. The presence of the compensatory measures, in addition to portable fire protection equipment and installed fire protection and detection equipment, ensures the safe shutdown paths are preserved until the conditions are resolved. CR 10108999. The licensee notified the NRC Resident Inspector. Notified the R2DO (Nease).

  • * * UPDATE AT 1331 EDT ON 08/25/15 FROM JOHN MITCHELL TO JEFF HERRERA * * *

In preparation for transitioning the Plant Hatch Fire Protection Licensing Basis from 10 CFR 50.48(b) (Appendix R) to 10 CFR 50.48c (NFPA 805), an update to the Plant Hatch Appendix R Safe Shutdown Analysis has been performed for the Diesel Building. This updated analysis has identified circuit configurations in a Fire Area where an Appendix R postulated fire could impact the ability to achieve safe shutdown conditions. This is Category 1 barrier impairment. 1) An Appendix R postulated fire in Fire Area 1408 is assessed to impact a cable that is required for Station Battery Chargers 1D, 1E, and 1F to remain energized. These chargers support 125V DC Switchgear 1B which is the credited DC Switchgear for Unit 1 Path 2 Safe Shutdown in the event of a fire in this area. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 1408. 2) An Appendix R postulated fire in Fire Area 2408 is assessed to impact a cable that is required for Station Battery Chargers 2D, 2E, and 2F to remain energized. These chargers support 125V DC Switchgear 2B which is the credited DC Switchgear for Unit 2 Path 2 Safe Shutdown in the event of a fire in this area. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 2408. Based on the updated Plant Hatch Appendix R Safe Shutdown analysis recommendations and the plant's Fire Hazard Analysis (FHA), compensatory measures have been taken and will remain in place until the conditions are resolved. The presence of the compensatory measures, in addition to portable fire protection equipment and installed fire protection and detection equipment, ensures the safe shutdown paths are preserved until the conditions are resolved. The analysis associated with the transition of the Plant Hatch Fire Protection Licensing Basis from Appendix R to NFPA 805 is continuing, and this and any subsequent similar conditions that meet reporting requirements will be in included in an ENS Update Report.

CR 10113740, CR 10113745 The Licensee notified the NRC Resident Inspector. Notified the R2DO (Rose).

  • * * UPDATE FROM KENNY HUNTER TO DONALD NORWOOD AT 1717 EDT ON 8/28/2015 * * *

In preparation for transitioning the Plant Hatch Fire Protection Licensing Basis from 10 CFR 50.48(b) (Appendix R) to 10 CFR 50.48(c) (NFPA 805), an update to the Plant Hatch Appendix R Safe Shutdown Analysis has been performed for the Turbine Building. This updated analysis has identified circuit configurations in a Fire Area where an Appendix R postulated fire could impact the ability to achieve safe shutdown (SSD) conditions. This is a Category 1 barrier impairment. 1) An Appendix R postulated fire in Fire Area 1105 is assessed to impact cables which are required for HPCI Steam Supply Isolation MOV, 1E41-F002, to remain open. This valve is required open in support of HPCI (SSD Path 2), which is the credited form of high pressure injection in this fire area. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 1105. 2) An Appendix R postulated fire in Fire Area 1104 is assessed to impact a cable required for the RCIC Vacuum Breaker Isolation MOV, 1E51-F105, to remain open. This valve is required open to ensure operability of the RCIC turbine if RCIC is required to stop and restart. Failure of this valve to remain open could cause a siphon that would impact the operability of RCIC, and thus disable Safe Shutdown Path 1 High Pressure Injection. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 1104. In preparation for transitioning the Plant Hatch Fire Protection Licensing Basis from 10 CFR 50.48(b) (Appendix R) to 10 CFR 50.48(c) (NFPA 805), an update to the Plant Hatch Appendix R Safe Shutdown Analysis has been performed for the Reactor Building. This updated analysis has identified circuit configurations in a Fire Area where an Appendix R postulated fire could impact the ability to achieve safe shutdown conditions. This is a Category 1 barrier impairment. 1) An Appendix R postulated fire in Fire Area 1203 is assessed to impact a cable required for HPCI Steam Supply Isolation MOV, 1E41-F002, to remain open. This valve is required open to ensure steam flow to the HPCI turbine. Failure of this valve to remain open would isolate steam to the HPCI turbine, which would disable HPCI, and thus disable Safe Shutdown Path 2 High Pressure Injection. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 1203. 2) An Appendix R postulated fire in Fire Area 2203 is assessed to impact cables required for RHR Outboard Injection Valve B, 2E11-F017B, to remain open. This valve is required open to support RHR Loop B in LPCI mode, which is the credited lineup for Path 2 Safe Shutdown Decay Heat Removal. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 2203. 3) An Appendix R postulated fire in Fire Area 2203 is assessed to impact cables required for HPCI Vacuum Breaker Isolation Valve, 2E41-F104, to remain open. This valve is required open in support of Safe Shutdown Path 2 High Pressure Injection. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 2203. Based on the updated Plant Hatch Appendix R Safe Shutdown analysis recommendations and the plant's Fire Hazard Analysis (FHA), compensatory measures have been taken and will remain in place until the conditions are resolved. The presence of the compensatory measures, in addition to portable fire protection equipment and installed fire protection and detection equipment, ensures the safe shutdown paths are preserved until the conditions are resolved. The analysis associated with the transition of the Plant Hatch Fire Protection Licensing Basis from Appendix R to NFPA 805 is continuing, and this and any subsequent similar conditions that meet reporting requirements will be in included in an ENS Update Report. CR 10115432, CR10115473, CR10115436, CR10115446, CR10115444 The licensee will notify the NRC Resident Inspector. Notified R2DO (Rose).

  • * * UPDATE PROVIDED BY GUY GRIFFIS TO JEFF ROTTON AT 1815 EDT ON 09/04/2015 * * *

In preparation for transitioning the Plant Hatch Fire Protection Licensing Basis from 10 CFR 50.48(b) (Appendix R) to 10CFR50.48(c) (NFPA 805), an update to the Plant Hatch Appendix R Safe Shutdown Analysis has been performed for the Control Building and Reactor Building. This updated analysis has identified circuit configurations in Fire Area's where an Appendix R postulated fire could impact the ability to achieve safe shutdown (SSD) conditions. These are Category 1 barrier impairments. 1) An Appendix R postulated fire in Fire Area 0024 is assessed to impact a cable that is required for Torus Suction Valve, 1E11-F065B to remain open. This valve is required to remain open in support of LPCI train B which is credited for Unit 1 Safe Shutdown in the event that the RPV has spuriously depressurized and low pressure inventory control is performed from the remote shutdown panel. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 0024. 2) An Appendix R postulated fire in Fire Area 0024 is assessed to impact a cable required for Torus Suction Valve, 2E11-F065B to remain open. This valve is required to remain open in support of LPCI train B which is credited for Unit 2 Safe Shutdown in the event that the RPV has spuriously depressurized and low pressure inventory control is performed from the remote shutdown panel. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 0024. 3) An Appendix R postulated fire in Fire Area 0014 is assessed to impact all three Air Handling Units; 1Z41-B003A, 1Z41-B003B, and 1Z41-B003C. The fire impacts a cable required for MCC 1C, 1R23-S003 to remain energized. This MCC supports the operation of Air Handling Unit B, 1Z41-B003B which is required in support of Main Control Room HVAC. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 0014. 4) An Appendix R postulated fire in Fire Area 0031 is assessed to impact all three Air Handling Units; 1Z41-B003A, 1Z41-B003B, and 1Z41-B003C. These AHUs are required in support of MCR HVAC. MCR HVAC was not required in the current Safe Shutdown Analysis Report, and thus these failures were not evaluated in this fire area. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 0031. 5) An Appendix R postulated fire in Fire Area 2014 is assessed to impact a cable required for Station Battery Chargers 2A (2R42-S026) 2B (2R42-S027) and 2C (2R42-S028) to remain energized. These chargers support 125 VDC Switchgear 2A (2R22-S016), which is the credited DC Switchgear for Path 1 Safe Shutdown. Path 2 Safe Shutdown is not available in this fire area due to fire impacts. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 2014. 6) An Appendix R postulated fire in Fire Area 2014 is assessed to impact a cable required for 125 VDC Switchgear 2A (2R22-S016) to remain energized. This is the credited DC Switchgear for Path 1 Safe Shutdown. Path 2 Safe Shutdown is not available in this fire area due to fire impacts. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 2014. 7) An Appendix R postulated fire in Fire Area 0014 is assessed to impact cables required for Station Battery Chargers 1D (1R42-S029), 1E (1R42-S030), and 1F (1R42-S031) to remain energized. These chargers support 125VDC Switchgear 1B (1R22-S017) which is the credited DC Switchgear for Path 2 Safe Shutdown. Path 1 Safe Shutdown is not available in this fire area due to fire impacts. While this represents an unanalyzed condition for Appendix R, the described scenario presumes a fire has occurred in Fire Area 0014. Based on the updated Plant Hatch Appendix R Safe Shutdown analysis recommendations and the plant's Fire Hazard Analysis (FHA), compensatory measures have been taken and will remain in place until the conditions are resolved. The presence of the compensatory measures, in addition to portable fire protection equipment and installed fire protection and detection equipment, ensures the safe shutdown paths are preserved until the conditions are resolved. The analysis associated with the transition of the Plant Hatch Fire Protection Licensing Basis from Appendix R to NFPA 805 is continuing, and this and any subsequent similar conditions that meet reporting requirements will be in included in an ENS Update Report. CR 10118312, CR 10118328, CR10118333, CR10118338, CR10118345 The licensee will notify the NRC Resident Inspector. Notified R2DO (Seymour)

ENS 5109126 May 2015 17:45:00HatchNRC Region 2GE-4
  • * * UPDATE ON 05/26/15 AT 1745 EDT FROM SCOTT BRITT TO JEFF HERRERA * * *

During an expanded scope inspection, deficiencies in the Control Building 147(foot) elevation were observed that caused the affected barrier to be considered nonfunctional: - Gaps were identified around cables in the foam cable tray penetration seal for penetration 1Z43H006F in the floor of the Cable Spreading Room (separating Fire Areas 0024A and 1104). The nonconforming condition observed for the affected fire barrier was identified as affecting both safe shutdown paths for Units 1 and 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10074859 The licensee will be notifying the NRC Resident Inspector.

  • * * UPDATE FROM STANLEY STONE TO JOHN SHOEMAKER AT 2017 EDT ON 6/1/15 * * *

During an expanded scope inspection for penetration seals, using more intrusive tools and methods, fire barriers in the Control Building El. 112 (foot) were found not to meet acceptance criteria. The fire protection engineering staff has examined the situations and recommends that these conditions be considered NON-FUNCTIONAL. - An issue was identified with the wall separating the el. 112 (foot) Control Building Working Floor, Fire Area (FA) 0001 from the Station Battery Room 1B, FA 1005. - An issue was identified with the wall separating the Station Battery Room 2A, Fire Area (FA) 2004 from the Station Battery Room 2B, FA 2005, on el. 112 (foot). The nonconforming conditions observed for the affected fire barriers were identified as affecting both safe shutdown paths for Units 1 and 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10077573 & 10077574. The licensee has notified the NRC Resident Inspector. Notified the R2DO(O'Donohue).

  • * * UPDATE FROM PAUL UNDERWOOD TO DONG PARK AT 1704 EDT ON 6/2/15 * * *

During an expanded scope inspection for penetration seals, using more intrusive tools and methods, fire barriers in the Control Building El. 112 (foot) were found not to meet acceptance criteria. The fire protection engineering staff has examined the situations and recommends that these conditions be considered NON-FUNCTIONAL: - Issues were identified with the wall separating the el. 112 (foot) Control Building Working Floor, Fire Area (FA) 0001 from the Unit 1 AC Inverter Room, FA 1008. The nonconforming conditions observed for the affected fire barriers were identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10078011. The licensee has notified the NRC Resident Inspector. Notified the R2DO (Rose).

  • * * UPDATE FROM PAUL UNDERWOOD TO DONG PARK AT 1501 EDT ON 6/3/15 * * *

During an expanded scope inspection for penetration seals, using more intrusive tools and methods, fire barriers in the Control Building El. 112 (foot) were found not to meet acceptance criteria. The fire protection engineering staff has examined the situations and recommends that these conditions be considered NON-FUNCTIONAL: - Issues were identified with the wall separating the el. 112 (foot) Control Building U2 Water Analysis Room, Fire Area (FA) 2006 from the Control Building East Corridor, FA 0007 The nonconforming conditions observed for the affected fire barriers were identified as affecting both safe shutdown paths for Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10078561. The licensee has notified the NRC Resident Inspector. Notified the R2DO (Rose).

ENS 5107014 May 2015 23:02:00HatchNRC Region 2GE-4

On May 14, 2015, it was determined that the number of 55 gallon drums of 2-Butoxyethanol analyzed to be transported and stored within the owner-controlled area (OCA) at any one time had been exceeded. It was discovered that contrary to the toxic gas analysis performed, fourteen 55-gallon drums of 2-Butoxyethanol were transported and stored in the OCA to support the construction of a dome being built to provide storage for FLEX equipment. The number of drums exceeded the limitation specified in the toxic gas analysis performed as part of the design project for transportation and storage could potentially impact Control Room habitability, emergency diesel generator air intake and have an adverse impact on security personnel. Upon determination that an unanalyzed condition existed, Operations placed the control room ventilation system in the 'isolation mode' until the number of drums on-site was reduced within the analyzed number. A substantial covering had been placed over the drums which also decreased the likelihood that any of the drums would fail and would also limit the potential dispersion of chemicals should a breach occur. The excess number of drums of 2-Butoxyethanol being transported and stored on-site is considered an unanalyzed condition that significantly degraded plant safety and is reportable in accordance with 10CFR50.72(b)(3)(ii)(B). The allowed number of 55 gallon drums of 2-butoxyethanol allowed per the current toxic gas analysis is 4 drums. The number of drums has been reduced to 2 as of 2024 EDT. The licensee has notified the NRC Resident Inspector.

  • * * UPDATE FROM PAUL UNDERWOOD TO VINCE KLCO ON 7/8/2015 AT 1657 EDT * * *

Further investigation into the chemicals transported on-site (F183M, of which 2-Butoxyethanol is a component) revealed that an on-site spill of all fourteen 55-gallon drums will not adversely affect Main Control Room Habitability, Security Personnel, or the Emergency Diesel Generators (EDGs). The Control Room Habitability Determination flowchart in Attachment 3 of NMP-CH-002-002 establishes a 10 mmHg vapor pressure threshold for determining if chemicals need to be evaluated for impact on the Main Control Room. Chemicals with a vapor pressure less than 10 mmHg do not need to be evaluated for control room habitability. The basis for the threshold is found in Reg Guide 1.78 Revision 0 section C.5.a, 'For chemicals that are not gases at 100F and normal atmospheric pressure but are liquids with vapor pressures in excess of 10 torr (10 mmHg), consideration should be given to the rate of flashing and boil off to determine the rate of release to the atmosphere and the appropriate time duration of the release.' The individual chemical component (including 2-Butoxyethanol) vapor pressures are less than 10 mmHg. As their vaporization rate is too low to adversely affect Control Room Habitability, it is also too low to create a hazard for Security personnel or to adversely affect the Emergency Diesel Generators. Based on this information, the transportation and storage of these chemical barrels did NOT represent a condition that significantly degraded plant safety. As such, this condition has been determined to no longer meet reporting requirement 10CFR50.72(b)(3)(ii)(B) and is therefore NOT reportable. Based on this information the previous notification for Event 51070 is being retracted. The licensee notified the NRC Resident Inspector Notified the R2DO (McCoy).

ENS 5099820 April 2015 21:26:00HatchNRC Region 2GE-4
  • * * UPDATE FROM STEVE BRUNSON TO CHARLES TEAL ON 4/20/15 AT 2126 EDT * * *

During an expanded scope inspection, deficiencies in the following areas were observed that caused the affected barriers to be considered nonfunctional: - A gap 1/4" wide, 1" tall, and 6" deep was found at penetration 1Z43H594D on the west wall of the U1 East Cableway (separating Fire Area 1104 and Fire Area 1020) - Near penetration 1Z43J837D, and approximately 12" south and above 1Z43H837D, gaps were observed in the mortar joint between CMU on the west wall of the U1 East Cableway (separating Fire Area 1104 and Fire Area 1020) - A triangular gap 1" wide, 1" tall and 6" deep was found at penetration 1Z43H592D on the west wall of the U1 East Cableway (separating Fire Area 1104 and Fire Area 1020) - A gap 4" tall and 3" wide was found behind Turn Box TB1-1272 which covers penetrations 1Z43H590D, 1Z43H589D, 1Z43H588, and 1Z43H587D on the west wall of the U1 East Cableway (separating Fire Area 1104 and Fire Area 1020) - At the architectural joint between the vertical wall to the horizontal floor/ceiling assembly above door 1C-22, above and to the south of 1Z43H1105D, a gap was observed approximately 1/4" tall, 3" wide, and 6" deep on the west wall of the U1 East Cableway Foyer (separating Fire Area 1105 and Fire Area 0014K) - Gap between the grout and the conduit of penetration 1Z43H778D approximately 1/4" tall x 1.5" wide x 6" deep on the east wall of the Unit 1 130' Elevation Control Building Working Floor Hallway (separating Fire Area 0014K and Fire Area 1105) The nonconforming conditions observed for the affected fire penetrations and fire barriers were identified as affecting both safe shutdown paths for Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensure the safe shutdown paths are preserved until the degraded conditions are repaired. CR 10058276; CR 10058278 The following deficiencies were also observed causing the affected penetrations to be considered nonfunctional: - A gap 1/4" wide, 1" tall, and 6" deep was located at penetration 1Z43H532D on the west wall of the U1 East Cableway (separating Fire Area 1104 and Fire Area 0014M) - A gap 1/8" wide, 1" tall and 6" deep was located at penetration 1Z43H780D on the west wall of the U1 East Cableway (separating Fire Area 1104 and Fire 0014M) - A gap 1/2" wide, 1" tall, and 6" deep was located at penetration 1Z43H781D on the west wall of the U1 East Cableway (separating Fire Area 1104 and Fire 0014M). A 1/4" x 1/2" defect was also identified at penetration 1Z43H781D on the east wall of the Men's Restroom in the Control Building (separating Fire Area 0014M and Fire Area 1104) The nonconforming conditions observed for the affected penetrations were identified as affecting both safe shutdown paths for Unit 1 and Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until degraded conditions are repaired. CR 10058277 The expanded scope inspection activity is continuing and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. The licensee has notified the NRC Resident Inspector. Notified R2DO (Blamey).

  • * * UPDATE FROM SCOTT BRITT TO DONG PARK ON 4/23/15 AT 1654 EDT * * *

During an expanded scope inspection, deficiencies in the following areas were observed that caused the affected barriers to be considered nonfunctional: - A gap 1/4" wide, 1" tall and 7" deep was found at penetration 1Z43H1138D on the east wall of the U1 RPS MG Set Room (separating Fire Area 1013 and Fire Area 0040). No seal material was seen between the sleeve and the cinderblock on the north side of penetration. - A void 1" tall, 1" wide, and 7" deep was found in the south upper corner under a concrete beam at column line T12 above penetration 1Z43H941D on the east wall of the U1 RPS MG Set Room (separating Fire Area 1013 and Fire Area 0040). - At penetration 1Z43H1139D, it appears that combustible neoprene insulation is used around the pipe within the plane of the west wall of the Vertical Cable Chase Room (separating Fire Area 0040 and Fire Area 1013). Combustible materials would not be part of a rated pen seal. - A gap 1" wide, 1" tall and 7" deep was observed at penetration 1Z43H1138D on the west wall of the Vertical Cable Chase Room (separating Fire Area 0040 and Fire Area 1013). The nonconforming conditions observed for the affected fire penetrations and fire barriers were identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10060228 The licensee will notify the NRC Resident Inspector. Notified R2DO (Blamey).

  • * * UPDATE FROM STANLEY STONE TO DONG PARK ON 4/27/15 AT 2047 EDT * * *

During an expanded scope inspection, deficiencies in the following areas were observed that caused the affected barriers to be considered nonfunctional: -An opening in the grout 1/4" wide, 1/2" tall and over 7" deep was found between the wall and the outside sleeve for penetration 2Z43H028D on the west wall of the U2 Transformer Room (separating Fire Area 2019 and Fire Area 2016). -A 1/4" diameter hole in the grout approximately 2.5" deep was found above conduit 2MI2128 on the west wall of the U2 Transformer Room (separating Fire Area 2019 and Fire Area 2016). The nonconforming conditions observed for the affected penetration and fire barrier were identified as affecting both safe shutdown paths for Unit 1 and Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10061830 The licensee notified the NRC Resident Inspector. Notified R2DO (Blamey).

  • * * UPDATE FROM PAUL UNDERWOOD TO DONG PARK ON 4/28/15 AT 1640 EDT * * *

During an expanded scope inspection, deficiencies in the following areas were observed that caused the affected barriers in the Unit 2 Control Building 130' elevation to be considered nonfunctional and represented degraded conditions of penetrations through the wall separating the Unit 2 Switchgear Access Hallway - Fire Area 2014, from the U2 West 600 V Switchgear Room - Fire Area 2016. The following conditions were located on the south wall of the Unit 2 Switchgear Access Hallway (Fire Area 2014). 1. An opening between the conduit and the wall 1/4" wide, 2" long and probed to be at least 2 1/2" deep was identified for penetration 2Z43H668D. A similar condition exists for this penetration on the opposite side of the wall in Fire Area 2016. 2. An opening between the conduit and the wall 1/4" wide, 1/2" long and probed to be at least 3" deep was identified for penetration 2Z43H667D. A similar condition exists for this penetration on the opposite side of the wall in Fire Area 2016. The following conditions were located on the opposite side of the same wall. This is the north wall of the U2 West 600V Switchgear Room (Fire Area 2016): 3. An opening between the conduit and the wall 1/8" wide, 1" long and probed to be at least 4" deep was identified for penetration 2Z43H668D. 4. An opening between the conduit and the wall 1/8" wide, 1/2" long and probed to be at least 3" deep was identified for penetration 2Z43H667D. 5. An opening between the conduit and the wall 2 1/2" wide, 2 1/2" long and probed to be at least 4" deep was identified around the 2" continuous run conduit located above cable tray penetration 2Z43H031D. 6. An opening between the conduit and the wall 1/4" wide, 3/4" long and probed to be at least 6" deep was identified above a 3/4" continuous run conduit (first of three) located at the ceiling near column line TE. 7. An opening between the conduit and the wall 1/4" wide, 1/2" long and probed to be at least 6" deep was identified above a 3/4" continuous run conduit (second of three) located at the ceiling near column line TE. 8. An opening between the conduit and the wall 1/4" wide, 3/4" long and probed to be at least 5" deep was identified above a 3/4" continuous run conduit (third of three) located at the ceiling near column line TE. The nonconforming conditions observed for the affected penetration and fire barrier were identified as affecting both safe shutdown paths for Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10062254 The licensee notified the NRC Resident Inspector. Notified R2DO (Ehrhardt).

  • * * UPDATE FROM PAUL UNDERWOOD TO DANIEL MILLS ON 4/29/15 AT 1804 EDT * * *

During an expanded scope inspection, deficiencies in the Unit 2 Control Building 130 foot elevation were observed that caused the affected barriers to be considered nonfunctional and represented degraded conditions of penetrations through the wall separating the Unit 2 West DC Switchgear Room 2A (Fire Area 2018) and the Unit 2 Switchgear Access Hallway (Fire Area 2014). The following conditions were located on the west wall of the Unit 2 Switchgear Access Hallway (Fire Area 2014). 1. An opening between the conduit and the wall 1/4 inch wide, 1 inch long and probed to be greater than 2 inch deep, was identified for penetration 2Z43H673D. 2. There is insufficient masonry material to fill the full depth of the wall above the ductwork that passes through penetration 2Z43H032D. This deficiency affects a small area on the south side of the ductwork and penetrations 2Z43H789D, 2Z43H790D, and 2Z43H791D. 3. An opening between the conduit and the wall 1/4 inch wide, 1 inch long and probed to be 4 inch deep was identified for penetration 2Z43H671D. A similar condition exists for this penetration on the opposite side of the wall (see Item 5 below). The following conditions were located on the east wall of the Unit 2 West DC Switchgear Room 2A (Fire Area 2018). 4. There are openings between the conduits and the wall 1/2 inch wide and 1 inch long for penetrations 2Z43H789D, 2Z43H790D, and 2Z43H791D. These penetrations are affected in Item 2 above. 5. An opening between the conduit and the wall 1 inch wide, 1 inch long and probed to be greater than 6 inch deep, was identified for penetration 2Z43H671D. 6. An opening between the conduit and the wall 1/4 inch wide, 1 inch long and probed to be at least 2 inch deep, was identified for penetration 2Z43H673D. 7. An opening between the conduit and the wall 1/4 inch wide, 1 inch long and probed to be at least 2 1/2 inch deep, was identified for penetration 2Z43H676D. The nonconforming conditions observed for the affected penetrations were identified as affecting both safe shutdown paths for Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR10062955 The licensee notified the NRC Resident Inspector. Notified R2DO (Ehrhardt).

  • * * UPDATE FROM JOHN MITCHELL TO HOWIE CROUCH AT 2137 EDT * * *

During an expanded scope inspection, deficiencies in the Control Building 130' elevation were observed that caused the affected barriers to be considered nonfunctional and represented degraded conditions of the following penetrations through the wall separating the Unit 2 East Cableway (Fire Area 2104) and the Health Physics Hallway and Counting Room (Fire Areas 0014B and 0014G). - Penetration 2Z43H783D terminates open within a foot of the east wall of the Health Physics Counting Room (Fire Area 0014G) - Penetration 2Z43H603D contains no visible seal material and is located on the east wall of the Health Physics Hallway (Fire Area 0014B). The nonconforming conditions observed for the affected penetrations were identified as affecting both safe shutdown paths for Unit 1 and Unit 2. Deficiencies were also observed that caused the affected barriers to be considered nonfunctional and represented degraded condition of the wall separating the Unit 2 East Cableway (Fire Area 2104) from the common East Cableway Foyer (Fire Area 1105). - Gap near penetration 2Z43H170D between a conduit and the concrete masonry unit (CMU) wall located on the south wall of the Unit 2 East Cableway (Fire Area 2104).

The nonconforming conditions observed for the affected fire barriers were identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas but were modified based on the nature of the degradations noted in the condition report and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR10063642 Notified R2DO (Ehrhardt).

  • * * UPDATE FROM JOHN MITCHELL TO JOHN SHOEMAKER AT 1638 EDT ON 5/7/15 * * *

During an expanded scope inspection, deficiencies in the Control Building 147' elevation were observed that caused the affected barriers to be considered nonfunctional. These deficiencies represented degraded conditions of the following penetrations through the wall separating the Unit 1 CO2 Tank Room (Fire Area 0025) and the Computer Room (Fire Areas 0024B) as well as a discrepancy in the affected wall.

   - In Fire Area 0024B, a small gap in the foam, approximately 6 (inch) deep was identified in Penetration 1Z43H592F.  The adjacent Fire Area is FA 0025.
   - In Fire Area 0024B, penetration 1Z43H325F was identified with no sealant for the penetration sleeve.  The adjacent Fire Area is FA 0025.
   - In Fire Area 0024B, foam sealant was missing in cable-tray, 1Z43H061F. The adjacent Fire Area is FA 0025
   - In Fire Area 0024B, a gap was identified in a concrete masonry unit (CMU) wall joint, directly above 1Z43H062F.

The nonconforming conditions observed for the affected fire barriers were identified as affecting both safe shutdown paths for Unit 1 and Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR10066678 The licensee has notified the NRC Resident Inspector. Notified the R2DO (Sandal).

  • * * UPDATE AT 2151 EDT ON 05/07/15 FROM SCOTT BRITT TO S. SANDIN * * *

During an expanded scope inspection, a deficiency in the Control Building 147 ft. elevation was observed that caused the affected barrier to be considered nonfunctional. This deficiency represented degraded conditions of the following fire barrier separating the Unit 1 CO2 Tank Room (Fire Area 0025) and the Cable Spreading Room (Fire Areas 0024A). - A 1/4 inch x 2 inch x approximately 4 inch deep gap in the east CMU wall of Unit 1 CO2 Tank Room above penetration 1Z43H046F. The nonconforming condition observed for the affected fire barrier was identified as affecting both safe shutdown paths for Unit 1 and Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR10066844 The licensee will inform the NRC Resident Inspector. Notified R2DO (Sandal).

  • * * UPDATE AT 2029 EDT ON 05/08/15 FROM SCOTT A. BRITT TO S. SANDIN * * *

During an expanded scope inspection, deficiencies in the Control Building 147 ft. elevation were observed that caused the affected barrier to be considered nonfunctional. These deficiencies represent degraded conditions of the following fire barrier separating the Cable Spreading Room (FA 0024A) and the CO2 Tank Room (FA 0025). - Multiple gaps in the caulk at the top of the ceiling of the west wall of the Cable Spreading Room (separating FA 0024A and FA 0025). The nonconforming condition observed for the affected fire barrier was identified as affecting both safe shutdown paths for Unit 1 and Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10067163 The licensee will inform the NRC Resident Inspector. Notified R2DO (Sandal).

  • * * UPDATE FROM PAUL UNDERWOOD TO DANIEL MILLS ON 5/11/15 AT 1711 EDT * * *

During an expanded scope inspection activity, multiple fire penetrations on the Control Building El. 130' elevation were identified that resulted in the affected barriers being considered NON-FUNCTIONAL. An issue was identified with the wall separating the Vertical Cable Chase, Fire Area 0040, from the Unit 2 RPS MG Set Room, Fire Area 2013. - A 1/4" wide x 1/2" long x approximately 6" deep gap in the grout of a 2" continuous run conduit, 6" away from 2Z43H581D was identified. - A 1/4" wide x 3" long x approximately 6" deep gap in the grout of penetration 2Z43H581D was identified. - A 1/2" wide x 2" long x approximately 6" deep gap in the grout of penetration 2Z43H580D was identified. The nonconforming condition observed for the affected fire barrier was identified as affecting both safe shutdown paths for Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10068138 The NRC Resident Inspector has been notified. Notified R2DO (Bonser).

  • * * UPDATE FROM GUY GRIFFIS TO DANIEL MILLS ON 5/12/15 AT 2151 EDT * * *

During an expanded scope inspection activity, a fire barrier on the Control Building El. 164' elevation was identified as being NON-FUNCTIONAL as follows; - A discrepancy was identified with the fire barrier separating the Unit 1 Turbine Building Main Floor Area, Fire Area 0101A from the Main Control Room, Fire Area 0024C. The condition consists of a small gap 1/4" wide, 3" long and probed to be greater than 6" deep between the wall and conduit at penetration 1Z43H605J on the Turbine Building side of the wall. The nonconforming condition observed for the affected fire barrier was identified as affecting both safe shutdown paths for Units 1 and 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10068842 The NRC Resident Inspector has been notified. Notified R2DO (Bonser).

  • * * UPDATE FROM GUY GRIFFIS TO VINCE KLCO ON 5/14/15 AT 2121 EDT * * *

During an expanded scope inspection, deficiencies in the Control Building 164' elevation were observed that caused the affected barrier to be considered nonfunctional: - A 1/4 inch x 1/2 inch x approximately 6 inch deep gap in the grout of the annulus of penetration 1Z43H602J was identified in the east wall of the Main Control Room (separating Fire Areas 0024C and 0101A). - A 1/4 inch wide x 8 inch long vertical crack, approximately 6 inch deep was identified in the CMU below penetration 1Z43H602J was identified in the east wall of the Main Control Room (separating Fire Areas 0024C and 0101A). - Three abandoned anchor holes, 1/2 inch in diameter and approximately 4 inch deep, were identified below penetration 1Z43H604J in the east wall of the Main Control Room (separating Fire Areas 0024C and 0101A). - A 1 inch diameter abandoned anchor hole, approximately 6 inch deep, was identified directly above a 1/4 inch pipe penetration in the east wall of the Main Control Room (separating Fire Areas 0024C and 0101A). - A 1/2 inch to 3/4 inch gap exists between the top of each of the 3 concrete block (CMU) walls enclosing the HVAC chase and the underside of the floor/ceiling assembly separating the Main Control Room (Fire Area 0024C) and the HVAC Room Chase (Fire Area 0014L). - A 1/2 inch diameter hole exists in the CMU at the upper right corner of penetration 1Z43H1184J separating the Main Control Room (Fire Area 0024C) and the HVAC Room Chase (Fire Area 0014L). The nonconforming condition observed for the affected fire barrier was identified as affecting both safe shutdown paths for Units 1 and 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10069898; CR 10069995 The licensee will notify NRC Resident Inspector. Notified the R2DO (Bonser).

  • * * UPDATE FROM R.S. STONE TO VINCE KLCO ON 5/15/15 AT 1807 EDT * * *

During an expanded scope inspection for penetration seals, the following discrepancies were identified with the wall separating the Unit 1 Working Floor, Fire Area 0001, from the Unit 1 AC Inverter Room, Fire Area 1008 that caused the affected barriers to be considered nonfunctional:

A 1/4 inch x 1 inch x approximately 2 inch deep gap in the grout of the annulus of penetration 1Z43H553C.

A 1/4 inch x 1 inch x approximately 2 inch deep gap in the grout of the annulus of penetration 1Z43H546C.

A 1/8 inch wide x 1/2 inch tall x approximately 6 inch deep gap in the foam block out, below penetration 1Z43H546C.

A 3 inch x 3 inch x 10 inch deep gap in the grout around a 2-1/2 inch continuous run conduit.

A 1/4 inch x 1 inch x 10 inch deep gap in the grout around 1-1/2 inch continuous run and 1-1/4 inch continuous run conduits.

2 inch deep gaps in the grout around 1-1/2 inch and 2-1/2 inch continuous run conduits.

A 1/4 inch hole x 1 inch deep gap in the grout around penetration 1Z43H060C.

A 1/4 inch x 1/4 inch x 2 inch deep gap around the annulus of a 1-1/4 inch continuous run and 2 inch continuous run conduits. The nonconforming condition observed for the affected fire barrier was identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10070439 The licensee notified the NRC Resident Inspector. Notified the R2DO (Bonser).

  • * * UPDATE ON 1638 EDT ON 05/21/15 FROM GUY S. GRIFFIS TO JEFF HERRERA * * *

During an expanded scope inspection, the following discrepancies were identified in the Unit 1 Control Building 130(foot) elevation that caused the affected fire barrier to be considered nonfunctional: - Six 3(inch) x 3(inch) holes in the wall of the Men's Rest Room (separating Fire Areas 0014M and 1104). The nonconforming conditions observed for the affected barrier were identified as affecting both safe shutdown paths for Unit 1 and Unit 2. Deficiencies were also observed in the Diesel Generator Building 130(foot) elevation that caused the affected fire barrier to be considered nonfunctional: - Through-wall gap around the conduit that passes through penetration 2Y43H511D on the south wall of the U2 Diesel Generator Switchgear Room 2F (separating Fire Areas 2408 and 2409). The nonconforming condition observed for the affected fire barrier was identified as affecting both safe shutdown paths for Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR10073041; CR10073187 The licensee notified the NRC Resident Inspector. Notified the R2DO (Ernestes).

ENS 506629 December 2014 20:02:00HatchNRC Region 2GE-4

During an inspection of a fire penetration between Fire Area 1404, Switchgear Room 1G and Fire Area 1408, Switchgear Room 1F in the diesel generator building, the penetration was determined to be non-functional as a 3 hour fire barrier. In the event of a postulated fire in the affected areas, both safe shutdown paths on Unit 1 could be compromised. Given this information, the determination was made that this condition meets the reporting criteria of 10 CFR 50.72(b)(3)(ii)(B). Compensatory measures were established in accordance with the plant's Fire Hazard Analysis (FHA). The presence of the compensatory measures in addition to automatic fire detection in the fire areas ensure that the safe shutdown paths are preserved until the degraded condition can be repaired. (Condition report No.) CR904013 The licensee notified the NRC Resident Inspector

  • * * RETRACTION PROVIDED BY KENNY HUNTER TO JEFF ROTTON AT 0915 EST ON 12/30/2014 * * *

Further investigation revealed that after removing the outermost two inches of loose silicone foam material, and taking additional measurements there remained adequate silicone foam material to provide 10 inches of silicone foam sealing the penetration. Plant design shows that the wall in question is 18 inches thick and also that 9 inches of silicone foam is required in the penetration in order maintain a 3 hour fire rating for the wall/penetration. Since there is adequate foam in the penetration to maintain the 3 hour fire rating the penetration is fully functional. Based on this information, this penetration in its 'as found' state does NOT represent a condition that seriously degrades a principal safety barrier. As such this condition has been determined to no longer meet reporting requirement 10CFR50.72(b)(3) and is therefore NOT reportable. Based on this information the previous notification for Event 50662 is being retracted. The licensee notified the NRC Resident Inspector. Notified R2DO (Bartley)

ENS 5062919 November 2014 21:44:00HatchNRC Region 2GE-4During a fire inspection activity involving inspection of fire penetrations that serve as Appendix R barriers, degradation of a fire penetration was identified that was sufficient to prevent this penetration from meeting Appendix R requirements as a 3 hour fire barrier. In the event of a postulated fire in the affected areas both safe shutdown paths on Unit 1 and 2 could be compromised. Given this information the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were put in place in accordance with the plant's Fire Hazard Analysis (FHA) for the degraded penetration in the affected fire areas. The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded conditions can be corrected. The degraded fire penetration is located between the turbine deck and the main control room. The licensee has notified the NRC Resident Inspector.
ENS 505882 November 2014 12:26:00HatchNRC Region 2GE-4

On November 2, 2014 EST, the bus providing power to the Health Physics emergency HVAC system for climate control tripped unexpectedly and has been out of service for greater than 30 minutes. The Health Physics emergency HVAC system for climate control is required for functionality of the Operations Support Center (OSC), which is a required emergency response facility (ERF). Actions to determine the cause of loss of 1R24-S030 Load Center and to return ERF to functional status are in progress with high priority. In the interim, the backup OSC remains fully functional and capable of providing the required support as defined in the Hatch Emergency Plan and emergency implementing procedures. This notification is being made in accordance with the plant's Technical Requirements Manual Specifications to make the notification within 8 hours in accordance with 10 CFR 50.72 (b)(3)(xiii) due to the unplanned loss of an emergency response facility. An update will be provided once the OSC has been restored to normal operation. The licensee notified the NRC Resident Inspector.

  • * * UPDATE FROM JOHN MITCHELL TO HOWIE CROUCH AT 2126 EST ON 11/2/14 * * *

Power was restored to the 1R24-S030 Load Center at 1955 EST. At 2038 EST, power to the Health Physics emergency HVAC system was restored. The OSC was returned to service at 2120 EST. The licensee has notified the NRC Resident Inspector. Notified R2DO (Blamey).

  • * * RETRACTION FROM KENNY HUNTER TO DANIEL MILLS AT 1641 EST on 12/31/14 * * *

In accordance with NUREG 1022, Revision 3, Supplement 1, the NRC endorsed NEI 13-01, 'Reportable Action Levels for Loss of Emergency Preparedness Capabilities,' such that 'if a licensee has a 'backup ERF' that is capable of performing the functions of the primary facility, the licensee's emergency assessment capability is not significantly impaired if the primary facility is not available.' Based on this information this condition is not reportable. Although NUREG 1022, Rev. 3, Supplement 1 did not require an event notification report to be made, an initial notification was generated based on requirements within licensee control documents. These documents have been updated to reflect the guidance provided in the supplement to NUREG 1022. This report is therefore being retracted in accordance with NUREG 1022, Rev. 3, Supplement 1 since a backup ERF remained fully functional and capable of providing the required support during the event. The licensee notified the NRC Resident Inspector. Notified R2DO (Hopper).

ENS 5045513 September 2014 09:53:00HatchNRC Region 2GE-4A fire penetration on the Unit 1 reactor building 158 foot elevation was discovered to be degraded such that the associated wall would not meet Appendix R requirements as a 3-hour barrier. In the event of a postulated fire in either of the affected fire areas, separated by the affected penetration, both Unit 1 safe shutdown paths could be compromised. Given this information, the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were established in accordance with the plant's Fire Hazard Analysis (FHA). The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded condition can be corrected. Condition Report: 865615 The NRC Resident Inspector has been informed.
ENS 503517 August 2014 20:00:00HatchNRC Region 2GE-4

During a fire inspection activity involving inspection of fire walls that serve as Appendix R barriers, degradation of some fire walls was identified that was sufficient to prevent these walls from meeting Appendix R requirements as 3-hour fire barriers. In the event of a postulated fire in the affected areas, both safe shutdown paths on the affected unit could be compromised. Given this information, the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded penetrations in these same fire areas. The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded conditions can be corrected. Condition Reports: 850802, 850819 In addition to automatic fire protection features, the licensee has posted fire watches as a compensatory measure. The licensee has notified the NRC Resident Inspector.

  • * * UPDATE FROM STANLEY STONE TO DONALD NORWOOD AT 1814 EST ON 11/24/2014 * * *

As part of the 'extent of condition' corrective action for the condition identified in EN 50351, an inspection activity is in progress to inspect the remaining fire walls for conditions similar to those reported on 8/7/2014. During this inspection, another condition was identified involving some degradation of the fire wall between Fire Area 1023 - RPS MG Set Room and Fire Area 1015 - Annunciator Room. In the event of a postulated fire in the affected areas both safe shutdown paths on Unit 1 could be compromised. Given this information, the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded penetrations in these same fire areas and will remain in place until the wall is repaired. The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded condition is repaired. The inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS update report and will be documented in a revised LER at the end of the inspection activity. Condition Report: 898908. The licensee will notify the NRC Resident Inspector. Notified R2DO (Ehrhardt).

  • * * UPDATE FROM KENNY HUNTER TO DANIEL MILLS AT 1758 EST ON 11/25/2014 * * *

As part of the 'extent of condition' corrective action for the condition identified in EN 50351, an inspection activity is in progress to inspect the remaining fire walls for conditions similar to those reported on 8/7/2014. During this inspection, another condition was identified involving some degradation of the fire wall between Fire Area 1016 - 600 Volt Switchgear Room 1C and Fire Area 1017 - 600 Volt Switchgear Room 1D. In the event of a postulated fire in the affected areas, both safe shutdown paths on Unit 1 could be compromised. Given this information the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded penetrations in these same fire areas and will remain in place until the wall is repaired. The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded condition is repaired. The inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS update report and will be documented in a revised LER at the end of the inspection activity. The licensee notified the NRC Resident Inspector. Notified R2DO (Ernstes).

  • * * UPDATE FROM SCOTT BRITT TO DONALD NORWOOD AT 1706 EST ON 12/4/2014 * * *

As part of the 'extent of condition' corrective action for the condition identified in EN 50351, an inspection activity is in progress to inspect the remaining fire walls for conditions similar to those reported on 8/7/2014. During this inspection, additional conditions were identified involving multiple fire barriers in the control building that affected both safe shutdown paths on Unit 1 and Unit 2 based on the respective inspection results. In the event of a postulated fire in the affected areas both safe shutdown paths on Unit 1 and 2 could be compromised. Given this information the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded penetrations in these same fire areas and will remain in place until the wall is repaired. The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded condition is repaired. The inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS update report as required and will be documented in a revised LER at the end of the inspection activity. The licensee will notify the NRC Resident Inspector. Notified R2DO (Freeman).

  • * * UPDATE AT 1842 EST ON 12/12/2014 FROM G.S. GRIFFIS TO MARK ABRAMOVITZ * * *

As part of the 'extent of condition' corrective action for the condition identified in EN# 50351, an inspection activity is in progress to inspect the remaining fire walls and associated penetrations for conditions similar to those reported on 08/07/2014. During this inspection, nonconformances of multiple fire barriers were identified that bring into question the functionality of the affected fire barriers that can compromise safe shutdown paths on Unit 1 and 2 based on the respective inspection results. Since additional time is required to further evaluate each nonconformance to conclusively determine if the nonconformance is sufficient to consider the barrier nonfunctional, interim conservative fire actions were taken by considering these fire barriers as nonfunctional. Based on this conservative conclusion, in the event of a postulated fire in the affected areas both safe shutdown paths on Unit 1 and 2 could be compromised. Given this information the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded penetrations and fire walls in most of these same fire areas and will remain in place until the barrier(s) are repaired. Additional fire actions were taken as required to address the additional fire areas identified. The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded condition is repaired. The inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report and will be documented in a revised LER at the end of the inspection activity. Unit 1 is entering a planned outage due to unrelated activities. Condition Report: 10000607 The licensee notified the NRC Resident Inspector. Notified the R2DO (Desai).

  • * * UPDATE FROM STANLEY STONE TO DONALD NORWOOD AT 2315 EST ON 1/15/2015 * * *

As part of the 'extent of condition' corrective action for the conditions identified in EN# 50351, an inspection activity was performed of a fire wall for conditions similar to those reported on 12/12/2014. During this inspection, another condition was identified involving some degradation of the fire wall between Fire Area 1008 - Unit 1 AC Inverter Room and Fire Area 0001 to consider the barrier nonfunctional. In the event of a postulated fire in the affected areas both safe shutdown paths on Unit 1 could be compromised. Given this information the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded fire barriers in these same fire areas and will remain in place until the wall is repaired. The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded condition is repaired. The inspection activity is continuing and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report and will be documented in a revised LER at the end of the inspection activity. Condition Report: 10013077 The licensee notified the NRC Resident Inspector. Notified the R2DO (Musser).

  • * * UPDATE FROM JOHN MITCHELL TO JEFF HERRERA AT 2025 EST ON 1/21/2015 * * *

During review and closeout of fire barrier and penetration seals work orders and surveillance procedures performed as part of the 'extent of condition' inspection activity initially described in Event # 50351, the following conditions were identified that in the event of a postulated fire in the respective fire areas listed both safe shutdown paths could be compromised.

Unit 2 Control Bldg. el. 130', gap in the grout around conduit penetration between fire areas 2013 and 2015 Unit 1 Reactor Bldg. el. 130', open conduit between fire areas 1203C and 1105 Given this information the determination was made that this condition meets the reporting criteria of 10 CFR 50.72(b)(3)(ii)(B). Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded fire barriers in the Unit 2 fire area and will remain in place until the affected barrier areas are repaired. Compensatory measures were established for the Unit 1 areas and will remain in place until the affected barriers areas are repaired. The presence of the compensatory measures in addition to automatic fire detection in these fire areas ensure that the safe shutdown paths are preserved until the degraded condition is repaired. Subsequent similar condition(s) found when performing remaining inspections that meet the reporting requirements will be included in an ENS Update Report and will be documented in a revised LER at the end of the inspection activity.

Condition Report 10015417 Condition Report 10015437 The licensee notified the NRC Resident Inspector. Notified the R2DO (McCoy).

  • * * UPDATE FROM G.S. GRIFFIS TO HOWIE CROUCH AT 1714 EST ON 2/4/15 * * *

During the review of fire barrier surveillance procedures performed as part of the 'extent of condition' inspection activity for the event initially identified in EN# 50351, some degradation was observed on the east wall of fire area 2006. These nonconforming issues observed on the affected fire wall were identified as affecting both safe shutdown paths for Unit 2. Therefore, in the event of a postulated fire for the affected area, both safe shutdown paths on Unit 2 could be compromised. Given this information, the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire area and will remain in place until the wall is repaired. The presence of the compensatory measures, in addition to portable fire protection equipment located in adjacent areas, ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The extent of condition inspection activity is continuing, and this, and any subsequent similar condition(s) that meets the reporting requirements, will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10021623 Notified R2DO (HAAG).

  • * * UPDATE FROM JOHN MITCHELL TO DANIEL MILLS AT 1823 EST ON 2/18/15 * * *

During performance of work package closeouts to support the 'extent of condition' inspection activity for the event initially identified in EN# 50351, the following fire barriers were identified as failing to meet the procedure acceptance criteria: - Three penetrations separating Unit 1 Fire Areas 1013 and 0040 - A fire wall deficiency in the wall separating Unit 1 Fire Areas 1015 and 1013 These nonconforming issues observed on the affected penetrations and fire wall were identified as affecting both safe shutdown paths for Unit 1. Therefore, in the event of a postulated fire for the affected area, both safe shutdown paths on Unit 1 could be compromised. Given this information, the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire area and will remain in place until the wall is repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The extent of condition inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10028364 CR 10028366 The NRC Resident Inspector has been notified. Notified R2DO (Rose).

  • * * UPDATE AT 2035 EST ON 02/25/15 FROM SCOTT BRITT TO S. SANDIN * * *

During the review and closeout of a work package performed as part of the 'extent of condition' for the inspection activity initially described in EN #50351, a fire penetration seal was identified as failing to meet the procedure acceptance criteria. This penetration seal is located in the 2C Diesel Generator (DG) room and passes between Fire Area 2407 and 2408. The nonconforming issue observed on the affected penetration was identified as affecting both safe shutdown paths for Unit 2. Compensatory measures were established for the Unit 2 Areas and will remain in place until the affected barriers areas are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The extent of condition inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10032202 The licensee will inform the NRC Resident Inspector. Notified R2DO (Seymour).

  • * * UPDATE FROM SCOTT BRITT TO HOWIE CROUCH AT 2000 EST ON 3/4/15 * * *

During an expanded scope inspection, two deficiencies in the following areas were observed that caused the affected barriers to be considered nonfunctional: - Small imperfections and a hole through Penetration 1Z43-H116C that passes between Fire Area 1101G (Unit 1 Reactor Building Closed Cooling Water (RBCCW) Room) and Fire Area 1006 (Unit 1 Water Analysis Room), and - Gaps in a civil/architectural joint at the top of the south wall leading from Fire Area 1006 (Unit 1 Water Analysis Room) to Fire Area 0007A (East Corridor in the Control Bldg.). These nonconforming conditions observed for the affected penetration and fire barrier were identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire area and will remain in place until the wall is repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS update report as required and will be documented in a revised LER at the end of the inspection activity. CR 10035730 The licensee will be notifying the NRC Resident Inspector. Notified R2DO (Sykes).

  • * * UPDATE FROM SCOTT BRITT TO DANIEL MILLS AT 2047 EDT ON 3/16/15 * * *

During an expanded scope inspection, deficiencies in the following areas were observed that caused the affected barriers to be considered nonfunctional: - Imperfections in three penetration seals (2Z43-H037C, 2Z43-H038C, and 2Z43-H177C) located in the 2A Battery Room separating Unit 2 Fire Areas 2004 and 2005 - Imperfections in fire penetration seal 2Z43-H644C located in the U2 Water Analysis Room separating Fire Area 2006 and 0007A - Imperfections in the grout between two tiers of concrete masonry wall and at the intersection of the walls in the upper northeast corner of the U2 Water Analysis Room separating Fire Areas 2006 and 0007A The nonconforming conditions observed for the affected penetrations and fire barriers were identified as affecting both safe shutdown paths for Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10041392, CR 10041394, and CR 10041397 The NRC Resident Inspector will be notified. Notified R2DO (Shaeffer)

  • * * UPDATE FROM JOHN MITCHELL TO HOWIE CROUCH AT 1619 EDT ON 3/17/15 * * *

During an expanded scope inspection, a fire penetration seal was observed to contain imperfections that did not meet acceptance criteria. Penetration seal 1Z43H542C is located between the U1 Corridor, Fire Area 0001, and the Unit 1 AC Inverter Room, Fire Area 1008, in the Unit 1 Control Building. The nonconforming issue observed on the affected penetration was identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until all associated non-functional fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The extent of condition inspection activity is continuing and this, and any subsequent similar condition(s) that meets the reporting requirements, will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10041766 The licensee notified the NRC Resident Inspector. Notified R2DO (Desai).

  • * * UPDATE FROM GUY GRIFFIS TO HOWIE CROUCH AT 1648 EDT ON 3/18/15 * * *

During an expanded scope inspection, deficiencies in the following areas were observed that caused the affected barriers to be considered nonfunctional: - Gap in the concrete masonry wall at penetration seal 1Z43-H547C located between the Unit 1 AC Inverter Room (Fire Area 1008) and the Unit 1 Corridor (Fire Area 0001) - Gap in the annulus around the 2 inch continuous run penetration seal located between the Unit 1 AC Inverter Room (Fire Area 1008) and the Unit 1 Corridor (Fire Area 0001) - Gap in penetration seal 1Z43-H059C located between the Unit 1 AC Inverter Room (Fire Area 1008) and the Unit 1 Corridor (Fire Area 0001) The nonconforming conditions observed for the affected penetrations and barrier were identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10042532; CR 10042530; CR 10042526 The licensee has notified the NRC Resident Inspector. Notified R2DO (Desai).

  • * * UPDATE FROM JOHN MITCHELL TO DANIEL MILLS AT 1814 EDT ON 3/31/15 * * *

During an expanded scope inspection, a fire wall was observed to contain a gap behind a 3 inch square plate attached to the thru-bolt anchor that did not meet acceptance criteria and caused the affected barrier to be considered nonfunctional. The affected fire barrier is located between the U2 RPS MG Set Room (Fire Area 2013) and the U2 Annunciator Room (Fire Area 2015). The nonconforming issue observed on the affected fire barrier was identified as affecting both safe shutdown paths for Unit 2. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until all associated non-functional fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The extent of condition inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10048449 The licensee will notify the NRC Resident Inspector. Notified R2DO (Walker).

  • * * UPDATE FROM KEN HUNTER TO VINCE KLCO ON 4/13/15 AT 1722 EDT * * *

During an expanded scope inspection, deficiencies in the following areas were observed that caused the affected barriers to be considered nonfunctional: - Gap around penetration 1Z43H805D located between the Unit 1 East DC Switchgear Room 1D (Fire Area 1017) and the Unit 1 Transformer Room (Fire Area 1019). - Gaps in a fire barrier around a unistrut, below penetration 1Z43H012D, that are approximately 7 deep and into the CMU core located between the Unit 1 East DC Switchgear Room 1B (Fire Area 1020) and the Unit 1 130' Elevation Control Building Working Floor Hallway (Fire Area 0014K) - Gap in the top corner of the wall, above 1Z43H842D that protrudes into the CMU approximately 7 deep located between the Unit 1 East DC Switchgear Room 1B (Fire Area 1020) and the Unit 1 130' Elevation Control Building Working Floor Hallway (Fire Area 0014K) - Two anchor bolt holes east of penetration 1Z43H810D located between the Unit 1 East DC Switchgear Room 1B (Fire Area 1020) and the Unit 1 East DC Switchgear Room 1D (Fire Area 1017) The nonconforming conditions observed for the affected penetrations and fire barriers were identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. The licensee will notify the NRC Resident Inspector. Notified the R2DO (Heissierer).

  • * * UPDATE FROM GUY GRIFFIS TO CHARLES TEAL ON 04/14/15 AT 1728 EDT * * *

During an expanded scope inspection, deficiencies in the following areas were observed that caused the affected barriers to be considered nonfunctional: - A 1/16" wide x 4" long x 5" deep gap was identified at the top of the wall, above penetration 1Z43H646D, in the west wall in Unit 1 East 600V Switchgear Room (separating Fire Area 1017 and Fire Area 1016). - A 1/16" wide x 4" long x 7" deep gap was identified at the top of the wall, above penetration 1Z43H646D, in the east wall in the Unit 1 West 600V Switchgear Room (separating Fire Area 1016 and Fire Area 1017). - The nonconforming conditions observed for the affected penetrations and fire barriers were identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10055316; CR 10055377 The licensee will notify the NRC Resident Inspector. Notified the R2DO (Bartley).

  • * * UPDATE FROM SCOTT BRITT TO JOHN SHOEMAKER AT 2000 EDT ON 4/16/15 * * *

During an expanded scope inspection, deficiencies in the following areas were observed that caused the affected barriers to be considered nonfunctional: - A 1" wide x 2" long x 7" deep gap was identified at the top of penetration 1Z43H622D in the west wall of the Unit 1 RPS MG Set Room (separating Fire Area 1013 and Fire Area 0014K). - A 1/4" wide x 1/4" long x 7" deep gap was identified near a ground wire, above penetration 1Z43H595D, at the top of the east wall of the Unit 1 East DC Switchgear Room (separating Fire Area 1020 and Fire Area 1104). - A 3" wide x 1/4" tall x 7" deep gap was identified at penetration 1Z43H617D on the south wall of the Unit 1 Working Floor (separating Fire Area 0014K and Fire Area 1013). The nonconforming conditions observed for the affected penetrations and fire barriers were identified as affecting both safe shutdown paths for Unit 1. Compensatory measures were already in place in accordance with the plant's Fire Hazard Analysis (FHA) as a result of previous conditions involving degraded barriers in the same fire areas and will remain in place until the fire barriers are repaired. The presence of the compensatory measures in addition to portable fire protection equipment located in adjacent areas ensures the safe shutdown paths are preserved until the degraded conditions are repaired. The expanded scope inspection activity is continuing, and this and any subsequent similar condition(s) that meets the reporting requirements will be included in an ENS Update Report as required and will be documented in a revised LER at the end of the inspection activity. CR 10056548; CR 10056555; CR 10056582 The licensee will notify the NRC Resident Inspector. Notified the R2DO (Bartley).

  • * * SEE EN #50998 FOR CONTINUATION OF UPDATES * * *
ENS 5016030 May 2014 20:16:00HatchNRC Region 2GE-4Conditions were identified in which grouting in some fire penetrations through hollow block walls on Units 1 and 2 do not comply with design drawings. While some grouting is present in the penetration, the determination has been made that the qualification of the amount and configuration of the grouting present does not meet Appendix R requirements. Further evaluation by Engineering concluded that this condition could compromise both safe shutdown paths on each unit in the event of a postulated fire. Given this information, the determination was made that this condition meets the reporting criteria of 10CFR50.72(b)(3)(ii)(B). Compensatory measures were established in accordance with the plant's Fire Hazard Analysis (FHA) to compensate for this condition to ensure that safe shutdown paths are preserved until the conditions can be corrected. The licensee has notified the NRC Resident Inspector.
ENS 500801 May 2014 22:33:00HatchNRC Region 2GE-4

While investigating a Unit 1 high pressure coolant injection (HPCI) room instrument sump level high alarm, condensation was observed dripping out around the HPCI turbine shaft gland seals. A steady stream of water was also observed coming out of the governor end gland seal along with a slight leak coming from the coupling end. Observation revealed that leakage through the 'closed' steam admission valve (1E41-F001) was apparently resulting in water accumulation in the HPCI turbine. A blown fuse that prevented the associated HPCI exhaust drain pot from draining in conjunction with the leakage by the steam admission valve was determined to be sufficient to impact HPCI operability. Required actions were taken in accordance with the Technical Specifications. Efforts are underway to determine the actions needed to restore the HPCI system to operable status. The licensee has notified the NRC Resident Inspector.

  • * * UPDATE FROM JOHN SELLERS TO CHARLES TEAL AT 0154 EDT ON 5/2/14 * * *

HPCI has been restored to an Operable but degraded nonconforming condition. Fuses replaced and automatic functions restored. Leakage confirmed to not be excessive for this condition. Compensatory actions established. Restoration time 2345 EDT 5/1/14. The licensee will notify the NRC Resident Inspector. Notified R2DO (Ayers).

ENS 5007230 April 2014 08:09:00HatchNRC Region 2GE-4

On April 30, 2014, at 0800 EDT, the Technical Support Center (TSC) will be unavailable due to pre-planned maintenance on a motor control center associated with the TSC. The TSC is expected to be restored to a functional status in approximately 13 hours. If an emergency is declared requiring TSC activation during this period, the TSC will be staffed and activated using existing emergency planning procedures, and the TSC staff will relocate to an alternate TSC location in accordance with the Hatch emergency plan and applicable site procedures. This notification is being made in accordance with 10CFR 50.72 (b)(3)(xiii) due to the planned loss of an emergency response facility (ERF). An update will be provided once the TSC has been restored to normal operation. The NRC Resident Inspector has been notified.

  • * * UPDATE PROVIDED BY JOHN SELLERS TO JEFF ROTTON AT 2011 EDT ON 04/30/2014 * * *

The planned maintenance activities have been completed. The power was restored to the TSC at 1802 EDT on 4/30/14. Ventilation has been confirmed to be functional. The TSC was fully functional at 1802 EDT on 04/30/14. The licensee has notified the NRC Resident Inspector. Notified R2DO (Ayres).

ENS 4994721 March 2014 21:22:00HatchNRC Region 2GE-4A licensed supervisor violated the company's fitness-for-duty policy. The employee's plant access has been suspended. The licensee has notified the NRC Resident Inspector.
ENS 4991514 March 2014 15:38:00HatchNRC Region 2GE-4

While evaluating IER 13-54, regarding the impact of unfused direct current (DC) circuits, a determination was made that the described condition is applicable to Edwin I. Hatch Units 1 and 2 for reactor protection system (RPS) battery/battery charger ammeter circuits. This results in an unanalyzed condition with respect to 10CFR50 Appendix R analysis requirements. In the postulated event, a fire induced hot short could adversely impact safe shutdown equipment. The Unit 1 and 2 RPS battery/battery charger ammeter indication circuits are routed from the affected components to the main control room. It is postulated that a fire in one fire area can damage the affected cables and cause short circuits without protection that would overheat the cable and possibly result in secondary fires in other fire areas where the cables are routed. The secondary fire could adversely affect safe shutdown equipment and potentially cause the loss of the ability to conduct a safe shutdown as required by 10CFR50 Appendix R. Interim compensatory measures (i.e., fire watches) have been implemented for the affected areas of the plant. This condition is being reported pursuant to 10CFR50.72(b)(3)(ii)(B).

The NRC Resident Inspector has been notified.

ENS 4964117 December 2013 13:07:00HatchNRC Region 2GE-4Invalid partial Reactor Protection System (RPS) actuation results in; Closure of Containment Isolation Valves (CIVs) in multiple systems, including isolation of the Reactor Water Clean-Up (RWCU) System. On October 21, 2013, at 0419 EST, Unit 2 received a Reactor Auto SCRAM System 'B' trip signal in the main control room. Initial investigations at the local RPS Motor-Generator (MG) set room discovered breaker 52-3D tripped in cabinet 2C71-P003D. This resulted in a half-scram and the closure of CIVs in multiple systems, including closure of the RWCU system outboard isolation valve, 2G31-F004. These trips are normal responses to the loss of the 'B' RPS. The operating crew entered abnormal operating procedures, including those for loss of RPS and for loss of the RWCU system, and confirmed that all isolations and trips occurred as expected. Additionally, the crew restored the 'B' RPS bus from its alternate source, reset the half scram, returned the CIVs to their normal positions, and placed RWCU in service. Upon investigation, the determination was made that the trip and reset setpoints for under-voltage relay 2C71 -K752D had drifted. Consequently, once the drift reached the trip setpoints during the event, breaker 52-3D tripped, resulting in the loss of the 'B' RPS bus. Because a malfunctioning subcomponent caused the partial RPS trip rather than a valid CIV actuation signal, the resulting isolation is considered an invalid actuation. Further evaluation into the cause of the drift revealed solder joint cracks in the relay circuit board and an inadequate previous refurbishment of the subject relay. The drifting relay was removed and a refurbished relay was installed in location 2C71-K752D. Plans are to replace both units' RPS Power Monitoring relays with a different design. Until that design change is implemented, the frequency of calibration for these relays is being increased from every 182 days to every 91 days. The licensee has notified the NRC Resident Inspector.
ENS 496074 December 2013 21:32:00HatchNRC Region 2GE-4As a result of questions raised by inspectors as part of the 2013 Triennial Fire Protection Inspection, a vulnerability from a postulated fire in the Unit 1 Cable Spreading Room was identified. This vulnerability involved the assumption of a fire occurring in Fire Area 0024A (Cable Spreading Room) which would create an inter-cable vulnerability that could result in an inter-system LOCA (Loss of Coolant Accident). Hatch's licensing basis included credit for the use of disconnect or remote shutdown panel 'Emergency' switches located on the respective remote shutdown panels to isolate the circuits in the cable spreading room thereby eliminating this vulnerability. However, the presence of these switches does not fully address this vulnerability. The Unit 1 RHR (Residual Heat Removal) shutdown cooling isolation valves 1E11-F008 and 1E11-F009 need to be de-energized in order to preclude the opening of these valves should this vulnerability occur on Unit 1. Since the Unit 2 RHR shutdown cooling isolation valves 2E11-F008 and 2E11-F009 are already closed and deactivated, they are not presently impacted by this additional vulnerability. Immediate actions were taken to de-energize the valves in the 'closed' position which removed the vulnerability. The postulated intersystem LOCA represents an unanalyzed condition that significantly degraded plant safety. The licensee notified the NRC Resident Inspector.
ENS 4928515 August 2013 16:47:00HatchNRC Region 2GE-4A condition was identified that resulted from an inter-cable circuit analysis as part of the safe shutdown analysis that identified a vulnerability associated with two Unit 2 valves with controls in Fire Area 2203. Specifically, during the postulated fire scenario, an inter-cable hot short could occur on the control cables for the RHR shutdown cooling suction valve 2E11-F008 valve and cause the valve to open in the event of a postulated fire in Fire Area 2203F which is in the vicinity of the Unit 2 remote shutdown panel. In addition, a spurious opening of RHR shutdown cooling suction valve 2E11-F009 valve could occur due to a hot short on the control cables. The fire is postulated while in Mode 1 which could cause both valves to open during power operation. This postulated event would expose the low pressure RHR-shutdown cooling suction line to normal operating pressures which would result in an inter-system LOCA. Immediate actions were taken to de-energize the valves in the 'closed' position which removed the vulnerability. When this condition was first discovered, the consequences of this postulated condition were evaluated and there was reasonable assurance that the condition did not represent an unanalyzed condition that significantly degrades/degraded plant safety. A review of the FSAR, design documents and regulatory requirements was performed to document the foundational logic for the engineering judgment to support the original conclusion that there was reasonable assurance that the inter-system LOCA did not represent an unanalyzed condition that significantly degraded plant safety and that this would not result in a loss of a safety function. Based on information learned in this review there was not sufficient information to make a conclusive determination. Since a conclusive determination cannot be made at this time and since there is some doubt regarding whether or not the report is needed, this report is being made in accordance with 10CFR50.72(b)(3)(ii). The licensee has notified the NRC Resident Inspector.
ENS 4921525 July 2013 16:58:00HatchNRC Region 2GE-4

On Thursday, July 25, 2013, at 1135 EDT, Hatch Nuclear Plant (HNP) experienced of a loss of the National Weather Service (NWS) Tone Alert Weather Radio System and was unable to contact the NWS Jacksonville, Florida Office. Site emergency procedures define a loss of Tone Alert Radio for greater than 15 minutes as a significant loss of emergency communications. Plant Hatch EP contacted NOAA and was told they had lost phone service and were attempting to restore it. The NWS Tone Alert Weather Radio is utilized as the Prompt Notification System (PMS) for HNP. The loss impacts the ability to notify the Emergency Planning Zone (EPZ) population for the HNP. This failure meets NRC 8-hour reporting criteria 10 CFR 50.72(b)(3)(xiii). The State of Georgia Department of Homeland Security/Georgia Emergency Management Agency (GEMA) 24 hour warning point and the '911' dispatch centers of Appling, Jeff Davis, Tattnall and Toombs Counties were notified so compensatory measures would be available should the Prompt Notification System be needed. This consists of utilizing route alerting and the 'Code Red' system which is a reverse 911 feature available from the county 911 center. As of the time of this report, the NOAA (system) has not been returned to service nor does the Jacksonville Office have a cause for the loss or a projected RTS (return to service) time. The licensee notified the NRC Resident Inspector.

* * * UPDATE FROM SCOTT BRITT TO PETE SNYDER AT 2005 EDT ON 7/25/13 * * * 

As of 1910 EDT on 7/25/13, the tone alert radio systems have been returned to service and are fully operational. The licensee notified the NRC Resident Inspector. Notified R2DO (Hopper).

ENS 4913419 June 2013 08:03:00HatchNRC Region 2GE-4An alarm was observed in the Technical Support Center (TSC). Initial investigation revealed the TSC to be warmer than usual and alarm 'TSC Vent Air Handling Unit B001 Disch Low Flow' was annunciated on the local panel. Annunciator response was followed as per 34SO-X75-002-0 with maintenance assistance. Further investigation revealed that the 1X75B001 Air Handling Unit fan belt was broken which made the TSC non-functional. The availability of the alternate TSC was verified as required. Actions are in place to return the TSC to functional status. If an emergency condition occurs that requires activation of the TSC, plans are to utilize the TSC as long as habitability conditions allow. Procedure 73EP-EIP-063-0, Technical Support Center Activation provides instructions to direct TSC management to the Control Room and TSC support personnel to the Simulator Building to continue TSC activities if it is necessary to relocate from the primary TSC. This event is reportable per 10CFR50.72 (b)(3)(xiii) as described in NUREG-1022, Rev. 2 and TRM T3.10.1 since the facility was rendered non-functional for greater than 30 minutes. The TSC was returned to FUNCTIONAL status at 0430 EDT on 6/19/2013. The licensee notified the NRC Resident Inspector
ENS 4905521 May 2013 16:46:00HatchNRC Region 2GE-4On March 24, 2013, at 1009 EDT, while personnel were entering the torus compartment to perform planned maintenance activities via permanently installed plant ladder, the sensing line to transmitter 2E41-N062D was inadvertently bumped. (This) was confirmed to be the cause for an invalid torus high water level alarm and a HPCI (High Pressure Core Injection) pump suction swap. This resulted in the HPCI suction swapping from its normal lineup, condensate storage tank (CST), to the torus as designed. Once actuated the suction swap occurred as designed. The cause was attributed to the close proximity between an individual descending/ascending the fixed ladder and the affected sensing line in conjunction with a loose tubing restraint which made the line more sensitive to being bumped. After confirming that the actuation on high torus level was invalid, HPCI suction was realigned to the CST. The HPCI pump suction was subsequently realigned to the CST and the loose tubing restraints were tightened. The licensee notified the NRC Resident Inspector.
ENS 4882718 March 2013 16:50:00HatchNRC Region 2GE-4On 3/18/2013, with the Unit 2 reactor at approximately 165 psig while in Mode 2 (Startup) following a refueling outage, the high pressure coolant injection (HPCI) system was undergoing post-maintenance testing to demonstrate operability of the system following the performance of major system maintenance. The provision allowed by the Technical Specifications was being used to increase reactor pressure above 150 psig for the purpose of performing operability testing and there was reasonable assurance that the HPCI system had been restored to support successful test results. (However, the HPCI system failed to pass operability testing and) as a result of the inability of the HPCI system to function as required during this testing while above 150 psig, HPCI was not capable of performing its safety function. Reactor pressure was decreased below the Technical Specification 3.5.1 LCO Applicability Requirement of 150 psig and work is in progress to make the needed repairs to support returning HPCI to an operable condition. The licensee notified the NRC Resident Inspector.
ENS 4879528 February 2013 17:13:00HatchNRC Region 2GE-4

On February 28, 2013, at 1155 EST, with the unit in Refueling Mode, a determination was made that reactor building closed cooling water (RBCCW) isolation valve (2P42-F051) exceeded its acceptance criteria for designed leakage when performing local leak rate testing. Diagnostic testing confirmed that all the leakage from its test boundary is going through this valve with an 'as found' leakage of >200,000 sccm at 32.87 psig. This valve is the outboard isolation barrier for that affected primary containment penetration with the inboard barrier being the RBCCW system itself as a 'closed' system. Previous practice is to conservatively include any leakage through this valve when performing as found leak rate tests as part of the primary containment leakage summary or as part of 0.6La. This is considered conservative since the RBCCW system inside containment is assumed to remain intact following a design basis accident (DBA) loss of coolant accident (LOCA). If the closed system remains intact there is no path for leakage to exit primary containment through this system. Since the past practice is to include the 'as found' leakage through this valve as part of 0.6La and since the 'as found' leakage would result in exceeding La, this condition is being considered a condition that results in the principal safety barriers being seriously degraded. This leakage would represent a loss of the containment function since the leak rate exceeded the Technical Specification limiting condition for operation (LCO) for primary containment. Further investigation is underway to determine if leakage through this single containment barrier is required to be included in the Appendix J primary containment leakage summary, since it is associated with a closed system. The licensee notified the NRC Resident Inspector.

  • * * RETRACTION ON 3/15/13 AT 1607 EDT FROM KENNY HUNTER TO DONG PARK * * *

Further investigation revealed an Appendix J exemption that was granted for the Hatch Unit 2 local leak rate test (LLRT) program in the 1978 time frame that specifically addressed the primary containment penetration that has primary containment isolation valve (PCIV) 2P42-F051 as its outboard barrier and the 'closed' system as its inboard barrier. The exemption recognizes that this system is designed to be intact and water filled post-LOCA, allows testing of the of the PCIV with water and states that the leakage through this PCIV is not included in the 0.6 La total. Since the Hatch RBCCW system supplying components inside primary containment is a 'closed' system and remains intact and water filled post-LOCA, there is no leakage path from primary containment through this RBCCW penetration. Since no leakage from primary containment can occur through this penetration in its 'as found' state, this condition does not represent a condition that seriously degrades a principal safety barrier. As such this condition has been determined to no longer meet reporting requirement 10CFR50.72(b)(3) and is therefore not reportable. Based on this information the previous notification is being retracted. The licensee notified the NRC Resident Inspector. Notified R2DO (O'Donohue).

ENS 4877220 February 2013 10:21:00HatchNRC Region 2GE-4

On February 20, 2013, at 0538 EST, local leak-rate testing (LLRT) of the 'A' feedwater check valves 2B21-F010A and 2B21-F077A revealed that neither valve would pressurize. Based on this information this line would not remain water filled post-LOCA and would result in the 'as found' minimum pathway leakage exceeding the limiting condition of operation (LCO) for Technical Specification 3.6.1.1. The cause for the LLRT failures will be determined and required corrective maintenance will be performed and valves successfully tested during the current refueling outage. The licensee notified the NRC Resident Inspector.

  • * * RETRACTION FROM KEN HUNTER TO VINCE KLCO ON 2/22/13 AT 1611 EST* * *

Subsequent investigation into the reported LLRT failure revealed that the initial LLRT performed on feedwater check valve 2B21-F010A was not considered an acceptable test, since that LLRT was not representative of the 'as found' condition of this check valve. The test volume for this valve had been slowly filled such that the check valve did not have the normal expected differential pressure across the valve disc to achieve normal check valve seating. After draining the test volume and refilling it by allowing the test volume to gravity fill from the reactor pressure vessel, the expected differential pressure across the valve disc occurred and seated the disc in such a way that it was more representative of the 'as found' condition for the check valve. An LLRT was then performed with a leakage of 50 accm (actual cubic centimeters per minute) against an acceptance criterion of 194 accm. No maintenance or operation of the check valve had occurred between the initial invalid test and the subsequent test performed with the disc in its 'as found' condition. An engineering evaluation was performed that documented the acceptability of using this means for establishing the test volume for feedwater check valves 2B21-F010A and 2B21-F010B for the 'A' and 'B' loops of feedwater, respectively. This engineering evaluation concluded that establishment of the required test volume in the manner described for primary containment penetration 9A satisfies the Hatch LLRT program requirements and that the leakage acceptance criterion for feedwater check valve 2B21-F010A in its 'as found' state was satisfied. The 2B21-F077A valve will be retested at a later date. Based on this information, the LLRT of this check valve in its 'as found' state was successful which actually resulted in successful minimum pathway leak rate test results for primary containment penetration 9A. These conclusive test results clearly indicated that the initial test results were incorrect and the 'as found' condition of this penetration isolation capability did not represent a significant degradation of a principal safety barrier as described in 10CFR50.72(b)(3)(ii)(A). For these reasons Notification # 48772 is being retracted. The licensee notified the NRC Resident Inspector. Notified the R2DO (McCoy).

ENS 4876016 February 2013 08:38:00HatchNRC Region 2GE-4On 2/16/13, at 0310 EST, with the reactor shutdown for a refueling outage, a full RPS actuation was received on Hatch Unit 2 due to Scram Discharge Volume High level. The Operations crew placed the Unit 2 mode switch to the Start-up/Hot Standby position per approved procedure for the purpose of performing the U2 Refueling Interlock functional test. The cause of the Scram was due to a Scram Discharge Volume high level caused by a malfunctioning SDV drain valve. Hatch Condition Report 591279 has been generated to document the event. The NRC Resident Inspector has been informed.
ENS 4875113 February 2013 17:42:00HatchNRC Region 2GE-4As part of routine rounds on 2/13/13, site personnel discovered an overflow condition at a collection tank containing water with low levels of tritium (approximately 6,000 pCi/L). The discharge pump for the tank was found to be nonfunctional which resulted in the overflow condition. Following discovery, a portable pump was utilized to pump the water to the normal monitored discharge path and terminate the overflow condition. The exact volume could not be determined but it is estimated that the volume of water that overflowed to the ground was greater than the 100 gallon threshold for voluntary reporting as indicated in Nuclear Energy Institute (NEI) 07-07, 'Industry Ground Water Initiative-Final Guidance Document.' A rough estimate of the release is between 100 and 300 gallons. The tritium was contained to a small area on the plant site in the vicinity of the discharge structure, and there is no significant potential for off-site impact or impact to on-site personnel. Because the leak remained on site, there will be no offsite impact to drinking water sources. Furthermore, the release posed no threat to employees or the public. Southern Nuclear (SNC) will continue to monitor the affected area as required. In accordance with SNC's groundwater protection procedures and the NEI guidance, a voluntary notification of this discovery will be made to the State of Georgia Environmental Protection Division and other agencies to inform them of this matter. The NRC Region II Resident Inspector was also notified. Reference: Condition Report 589402. Event occurred at 1111 EST, decision to make offsite notifications authorized at 1545 EST. The tank was the outfall collection tank. Environmental Protection Agency limit for tritium in drinking water is 20,000 pCi/l.
ENS 4873810 February 2013 09:11:00HatchNRC Region 2GE-4During normal power operations, the crew observed condensate/feedwater conductivity begin to increase at approximately 0530 EST on 02/10/13. The crew responded to the associated alarm response procedures and entered abnormal operating procedure 34AB-N61-001-1 due to degrading reactor water chemistry parameters. A power reduction (from 100%) was initiated at 0555 EST in accordance with station procedures for responding to a suspected condenser tube leak. At 0700 EST, a manual reactor SCRAM (from approximately 47%) was inserted due to the elevated reactor water conductivity in accordance with station abnormal operating procedures. All rods inserted completely and no complications were encountered following the reactor SCRAM, normal feedwater injection remained available. Following the SCRAM, a Group 2 Primary Containment Isolation Signal (PCIS) was received as a result of reactor water level lowering below +3 inches. The lowest reactor water level observed was (minus) 2 inches and was restored to normal operating levels utilizing normal feedwater injection. Following restoration of reactor water level to the normal operating level, the Group 2 PCIS signal was reset. No ECCS injection systems actuated as a result of the reactor SCRAM. The SCRAM was uncomplicated and the plant is stable. Decay heat removal is to the main condenser via the turbine bypass valves. The plant is in a normal offsite electrical power shutdown alignment. Efforts are in progress to isolate the condenser in-leakage. There was no impact on Unit 2. The licensee has notified the NRC Resident Inspector.
ENS 487216 February 2013 11:39:00HatchNRC Region 2GE-4On December 8, 2012, at 0116 EST, with Unit 1 operating near 100 percent rated thermal power (RTP), annunciator 601-135 'Torus Level High' was received in the main control room and immediately cleared. Torus water level was reading between 148.1 inches and 148.8 inches on torus water level sensors but torus water level indications from the High Pressure Coolant Injection (HPCI) sensors were observed to be fluctuating between 149 inches and 150 inches immediately after the event. Technical Specification LCO 3.6.2.2 requires torus water level to remain greater than or equal to 146 inches and less than or equal to 150 inches. The Technical Specification allowable limit is 154 inches for the HPCI torus water level sensors and the actual set point for the HPCI suction swap is 152 inches. When the HPCI torus water level instruments' reference legs are not completely filled, fluctuations in indicated level occur. This was determined to be the cause for this invalid actuation. Enough fluctuation occurred such that the HPCI suction swap instruments completed the actuation logic causing the HPCI suction swap design function to occur. This resulted in HPCI automatically realigning to the torus. It had been manually aligned to the condensate storage tank (CST), which is its primary source. HPCI DID NOT realign to mitigate an event or condition nor did it realign for actuation and injection to send water to the reactor vessel. Should the automatic suction swap fail to occur, the Technical Specifications require that the suction be manually realigned to the torus in accordance with plant procedures and training. The operability of HPCI was maintained throughout the event and no HPCI system actuation signal (low reactor water level or high drywell pressure) was received during the event. At approximately 0337 EST, Instrumentation and Controls technicians began backfilling the reference legs for sensors 1E41N062B, 1T48N010A, and 1T48N021A. This task was completed at approximately 0503 EST at which time the normal torus water level and HPCI torus water level instrument indications were in agreement. The HPCI suction source was then realigned to the CST in accordance with plant procedures at approximately 0507 EST. This report is being made as an actuation of a system named in 50.73(a)(2)(iv)(B)(4) and is being reported in accordance with 50.73(a)(2)(iv)(A) and under the provision of 50.73(a)(1) based on an NRC interpretation that this actuation within the HPCI system was considered an ECCS actuation. Since the actual torus water level never actually reached 152 inches, the automatic realignment was determined to be an invalid actuation. SNC (Southern Nuclear Company) takes exception to the NRC interpretation on reportability of this condition, but are making this 60 day phone LER notification on a voluntary basis while this issue is being pursued with the NRC. The initiating signal was invalid and this report is being made under the auspices of 10 CFR 50.73(a)(1) for invalid specified system actuations. The licensee notified the NRC Resident Inspector.
ENS 4860819 December 2012 20:55:00HatchNRC Region 2GE-4On December 19, 2012, results from routine monitoring of groundwater at Plant Hatch indicated tritium was detected above historical background levels at two sample points on site. Additional samples were taken from the same points and analysis confirmed that tritium was present at elevated levels in both samples and that tritium had not migrated out of the general area of initial discovery. Immediate actions are being taken to locate the source of the leak and actions are in progress to stop the leak. The investigation currently shows that the tritium is confined to a small area on the plant site in the vicinity of the Unit 1 Condensate Storage Tank (CST), and there is no significant potential for off-site impact. Additionally, there is no impact to on-site personnel. No tritium levels above background have been detected or migrated outside the area where the two sample points are located. Southern Nuclear (SNC) will continue to sample strategic locations in the ground water monitoring network to determine if there are changes in the impacted area and beyond. SNC is confident that these levels are of low safety significance and do not pose any issues to the public health and safety. In accordance with SNC's groundwater protection procedures and the Nuclear Energy Institute (NEI), SNC contacted the NRC Region II Resident Inspector and will be notifying the State of Georgia Environmental Protection Division and other agencies to inform them of this matter.
ENS 485656 December 2012 16:34:00HatchNRC Region 2GE-4On October 8, 2012, at 1709 EDT, Unit 2 received a Reactor Auto SCRAM System 'B' Trip signal in the main control room. The power monitoring breaker in RPS panel 2C71P003D tripped, causing a half-SCRAM in conjunction with the automatic actuation of the Unit 2 standby gas treatment system (SGT) and isolation of CIVs (Containment Isolation Valves) in multiple systems, both of which are normal responses to this loss of the 'B' RPS bus. The crew entered the appropriate abnormal operating procedures and confirmed the actuations automatically occurred as required given the loss of the RPS bus. They investigated the 'B' RPS Motor/Generator (M/G) set, placed the 'B' RPS bus on its alternate supply, reset the SGT and CIV actuation logic, and returned the CIVs to their normal position. Upon investigation, the 'B' RPS M/G set was found running with a steady output of 120 VAC. The breaker in RPS panel 2C71P003B stayed closed in. Further troubleshooting did not identify a cause for the failure of RPS breaker 2C71B003D. The breaker was replaced and the power monitoring relays were rebuilt. The 'B' MG Set was left running unloaded for 8 days with no trips observed. On October 26, 2012, approximately 20 seconds after returning the RPS 'B' M/G Set to service, RPS breaker 2C71B003D tripped again. At this time, investigators determined that 2C71B003B had no output voltage present when load was increased to 25 amps or greater. 2C71B003D tripped because 2C71B003B was not supplying load to it. A lug mounting screw was subsequently found to be loose on 2C71B003B. After tightening the screw, maintenance personnel determined that continuity existed and the 2C71B003B indicated closed with output voltage present as expected. Review of the six-month surveillances on 2C71B003B and the more-detailed 5-year surveillance that took place in August 2010 revealed no previous problems with the breaker. It is unknown when the lug mounting screw became loose or if repeated cycles of operation caused it to loosen. For broadness, thermography testing is being completed on 2C71P003 A, C, D, E, F and 1C71P003 A, B, C, D, E, F. When the second trip of 2C71B003D occurred on October 26, 2012, U1 SGT trains started and CIVs in multiple systems closed. This was an expected actuation with radiation monitor 2D11K634C already out of service and in the tripped condition at the time of the RPS 'B' trip. The RPS 'B' trip caused radiation monitor 2D11K634D to also trip thereby completing the logic to start U1 SGT trains and to close associated CIVs. The second event is included in this report since the failures are related as a result of having the same general cause and since they occurred over a reasonably short period of time. Because a malfunctioning subcomponent caused the loss of RPS 'B' rather than a valid CIV actuation signal, the resulting isolation of CIVs in multiple systems is considered an invalid actuation in both cases. Based on that information 10CFR50.73(a)(2)(iv) allows these events to be reported via a telephone notification within 60 days instead of submitting a written LER. The licensee will notify the NRC Resident Inspector.
ENS 4852921 November 2012 13:01:00HatchNRC Region 2GE-4A chlorine leak was discovered in an area near the Unit 2 cooling towers. The leak has been isolated; the amount leaked is under investigation. Sodium bisulfite has been used to neutralize the (leaked) chlorine. The Georgia Environmental Protection Division and U.S. Coast Guard have been notified. The licensee has notified the NRC Resident Inspector.
ENS 483703 October 2012 12:26:00HatchNRC Region 2GE-4On August 5, 2012, at 21:25 EDT, Unit 1 received a Reactor Auto SCRAM System 'A' Trip signal in the main control room. The annunciator was initially reset by operators, but the operating crew noted that some white SCRAM lights and some Group 2 PCIV indication lights were flickering in the control room. This anomaly coupled with the ability to reset the annunciated condition immediately indicated an issue with fluctuating voltage on the power supply for RPS (Reactor Protection System) 'A'. Approximately 30 seconds after the annunciator was reset, the 'A' RPS bus tripped, causing a half SCRAM in conjunction with the automatic actuation of the Standby Gas Treatment system (SGT) and isolation of PCIVs in multiple systems, both of which are normal responses to this loss of the 'A' RPS bus. The crew entered the appropriate abnormal operating procedures and confirmed the actuations automatically occurred as required given the loss of the RPS bus. They investigated the 'A' RPS Motor/Generator (M/G) set, placed the 'A' RPS bus on its alternate supply, reset the SGT and PCIV actuation logic, and returned the PCIVs to their normal position. Upon investigation, the 'A' RPS M/G set was found running, but the Over Voltage Relay in the power monitoring cabinet was chattering. The field investigation team determined that the RPS trip was caused by the failure of its voltage regulator which was then replaced. The 'A' RPS M/G set was consequently returned to service as the primary RPS power source on August 6, 2012. Maintenance personnel subsequently determined that a voltage regulator subcomponent was defective. Because the malfunctioning subcomponent caused the loss of RPS 'A' as the initiating event rather than a valid SGT or PCIV actuation signal, the resulting actuation of SGT and the isolation of multiple PCIVs are considered invalid actuations. Based on that information, 10CFR50.73(a)(2)(iv) allows this event to be reported via a telephone notification within 60 days instead of submitting a written LER. The licensee has notified the NRC Resident Inspector.