|
|
(5 intermediate revisions by the same user not shown) |
Line 2: |
Line 2: |
| | number = ML15240A154 | | | number = ML15240A154 |
| | issue date = 09/08/2015 | | | issue date = 09/08/2015 |
| | title = Saint Lucie, Unit 1 - Staff Observations of Sump Strainer Head Loss Testing at Alden Laboratory for Generic Safety Issue 191 | | | title = Staff Observations of Sump Strainer Head Loss Testing at Alden Laboratory for Generic Safety Issue 191 |
| | author name = Robinson L R | | | author name = Robinson L |
| | author affiliation = NRC/NRR/DSS/SSIB | | | author affiliation = NRC/NRR/DSS/SSIB |
| | addressee name = Cusumano V G | | | addressee name = Cusumano V |
| | addressee affiliation = NRC/NRR/DSS/SSIB | | | addressee affiliation = NRC/NRR/DSS/SSIB |
| | docket = 05000335 | | | docket = 05000335 |
Line 15: |
Line 15: |
|
| |
|
| =Text= | | =Text= |
| {{#Wiki_filter:September 8, 2015 | | {{#Wiki_filter:September 8, 2015 MEMORANDUM TO: Victor G. Cusumano, Chief Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation FROM: Lindsay R. Robinson, Reactor Systems Engineer |
| | | /RA by ARussell for/ |
| MEMORANDUM TO: Victor G. Cusumano, Chief Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation | | Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation |
| | |
| FROM: Lindsay R. Robinson, Reactor Systems Engineer /RA by ARussell for/ | |
| Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation | |
|
| |
|
| ==SUBJECT:== | | ==SUBJECT:== |
| STAFF OBSERVATIONS OF SAINT LUCIE UNIT 1 SUMP STRAINER HEAD LOSS TESTING AT ALDEN LABORATORY FOR GENERIC SAFETY ISSUE 191 On August 4 and 5, 2015, U.S. Nuclear Regulatory Commission (NRC) staff traveled to the Alden Research Laboratory in Holden, Massachusetts to observe testing associated with the resolution of Generic Safety Issue 191 (GSI-191). The objective of this trip was to observe sump strainer head loss tests being conducted for St. Lucie Unit 1. The participating NRC staff | | STAFF OBSERVATIONS OF SAINT LUCIE UNIT 1 SUMP STRAINER HEAD LOSS TESTING AT ALDEN LABORATORY FOR GENERIC SAFETY ISSUE 191 On August 4 and 5, 2015, U.S. Nuclear Regulatory Commission (NRC) staff traveled to the Alden Research Laboratory in Holden, Massachusetts to observe testing associated with the resolution of Generic Safety Issue 191 (GSI-191). The objective of this trip was to observe sump strainer head loss tests being conducted for St. Lucie Unit 1. The participating NRC staff members were Ashley Smith and Lindsay Robinson of the Safety Issues Resolution Branch in the Division of Safety Systems and Marioly Diaz-Colon and Paul Klein of the Steam Generator Tube Integrity and Chemical Engineering Branch from the Division of Engineering. The staff interacted with personnel from ALDEN Research Laboratory, Inc. (Alden), Enercon Services, Inc. (Enercon), Calvert Cliffs Power Station (Calvert Cliffs), and Wolf Creek Generating Station (Wolf Creek). |
| | | The enclosure summarizes the staffs visit on August 4-5, 2015. |
| members were Ashley Smith and Lindsay Robinson of the Safety Issues Resolution Branch in the Division of Safety Systems and Marioly Diaz-Colon and Paul Klein of the Steam Generator Tube Integrity and Chemical Engineering Branch from the Division of Engineering. The staff interacted with personnel from ALDEN Research Laboratory, Inc. (Alden), Enercon Services, Inc. (Enercon), Calvert Cliffs Power Station (Calvert Cliffs), and Wolf Creek Generating Station | | CONTACT: Lindsay R. Robinson, NRR/DSS/SSIB 301-415-4115 |
| | |
| (Wolf Creek). | |
| | |
| The enclosure summarizes the staff's visit on August 4-5, 2015. | |
| | |
| CONTACT: Lindsay R. Robinson, NRR/DSS/SSIB 301-415-4115 September 8, 2015 MEMORANDUM TO: Victor G. Cusumano, Chief Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation | |
|
| |
|
| FROM: Lindsay R. Robins on, Reactor Systems Engineer /RA by ARussell for/ | | September 8, 2015 MEMORANDUM TO: Victor G. Cusumano, Chief Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation FROM: Lindsay R. Robinson, Reactor Systems Engineer |
| Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation | | /RA by ARussell for/ |
| | Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation |
|
| |
|
| ==SUBJECT:== | | ==SUBJECT:== |
| STAFF OBSERVATIONS OF SAINT LUCIE UNIT 1 SUMP STRAINER HEAD LOSS TESTING AT ALDEN LABORATORY FOR GENERIC SAFETY ISSUE 191 On August 4 and 5, 2015, U.S. Nuclear Regulatory Commission (NRC) staff traveled to the Alden Research Laboratory in Holden, Massachusetts to observe testing associated with the resolution of Generic Safety Issue 191 (GSI-191). The objective of this trip was to observe sump strainer head loss tests being conducted for St. Lucie Unit 1. The participating NRC staff | | STAFF OBSERVATIONS OF SAINT LUCIE UNIT 1 SUMP STRAINER HEAD LOSS TESTING AT ALDEN LABORATORY FOR GENERIC SAFETY ISSUE 191 On August 4 and 5, 2015, U.S. Nuclear Regulatory Commission (NRC) staff traveled to the Alden Research Laboratory in Holden, Massachusetts to observe testing associated with the resolution of Generic Safety Issue 191 (GSI-191). The objective of this trip was to observe sump strainer head loss tests being conducted for St. Lucie Unit 1. The participating NRC staff members were Ashley Smith and Lindsay Robinson of the Safety Issues Resolution Branch in the Division of Safety Systems and Marioly Diaz-Colon and Paul Klein of the Steam Generator Tube Integrity and Chemical Engineering Branch from the Division of Engineering. The staff interacted with personnel from ALDEN Research Laboratory, Inc. (Alden), Enercon Services, Inc. (Enercon), Calvert Cliffs Power Station (Calvert Cliffs), and Wolf Creek Generating Station (Wolf Creek). |
| | | The enclosure summarizes the staffs visit on August 4-5, 2015. |
| members were Ashley Smith and Lindsay Robinson of the Safety Issues Resolution Branch in the Division of Safety Systems and Marioly Diaz-Colon and Paul Klein of the Steam Generator Tube Integrity and Chemical Engineering Branch from the Division of Engineering. The staff interacted with personnel from ALDEN Research Laboratory, Inc. (Alden), Enercon Services, Inc. (Enercon), Calvert Cliffs Power Station (Calvert Cliffs), and Wolf Creek Generating Station | | Docket No.: 50-335 |
| | |
| (Wolf Creek). | |
| The enclosure summarizes the staff's visit on August 4-5, 2015. | |
| Docket No.: 50-335 | |
|
| |
|
| ==Enclosure:== | | ==Enclosure:== |
| Trip Report | | Trip Report CONTACT: Lindsay R. Robinson, DSS/SSIB 301-415-4115 DISTRIBUTION: |
| | | Public ASmith LRobinson JStang ARussell GKulesa RidsNrrPMStLucie PKlein MDiaz SSmith MYoder VCusumano RidsRgn2MailCenter Accession No.: ML15240A154 NRR-106 OFFICE NRR/DSS/SSIB/RSE NRR/DSS/SSIB/BC NRR/DSS/SSIB/RSE NAME LRobinson/ARussell for VCusumano/JStang for LRobinson/ARussell for DATE 08/31/2015 09/02/2015 09/08/2015 OFFICIAL RECORD COPY |
| CONTACT: Lindsay R. Robinson, DSS/SSIB 301-415-4115 | |
| | |
| DISTRIBUTION | |
| : Public ASmith LRobinson JStang ARussell GKulesa RidsNrrPMStLucie PKlein MDiaz SSmith MYoder VCusumano RidsRgn2MailCenter Accession No.:
| |
| ML15240A154 NRR-106 OFFICE NRR/DSS/SSIB/RSENRR/DSS/SSIB/BC NRR/DSS/SSIB/RSE NAME LRobinson/ | |
| ARussell forVCusumano/ | |
| JStang for LRobinson/ | |
| ARussell for DATE 08/31/2015 09/02/2015 09/08/2015 OFFICIAL RECORD COPY OBSERVATIONS OF TESTING AT ALDEN TEST FACILITY AUGUST 4 AND 5, 2015 DOCKET NO.: 50-335 OBJECTIVE On August 4 and 5, 2015, U.S. Nuclear Regulatory Commission (NRC) staff observed sump strainer head loss tests associated with the resolution of Generic Safety Issue 191 (GSI-191). | |
| The objective of this trip was to observe the experimental testing to better understand the St. Lucie Unit 1 approach to GSI-191 resolution and to inform staff review of similar methods that may be used by other licensees.
| |
|
| |
|
| | OBSERVATIONS OF TESTING AT ALDEN TEST FACILITY AUGUST 4 AND 5, 2015 DOCKET NO.: 50-335 OBJECTIVE On August 4 and 5, 2015, U.S. Nuclear Regulatory Commission (NRC) staff observed sump strainer head loss tests associated with the resolution of Generic Safety Issue 191 (GSI-191). |
| | The objective of this trip was to observe the experimental testing to better understand the St. Lucie Unit 1 approach to GSI-191 resolution and to inform staff review of similar methods that may be used by other licensees. |
| This particular test (identified by Alden as 1152PSLTST-455-00) was conducted by Alden to determine, by incremental debris addition representing increasing Loss-Of-Coolant Accident (LOCA) pipe break sizes, the maximum pipe break size that would still maintain acceptable Emergency Core Cooling System (ECCS) performance at St. Lucie Unit 1. The configuration of the test strainer assembly and the flume geometry remained constant. The strainer approach velocity was constant except for flow sweeps performed to characterize the debris bed prior to chemical precipitate addition. The quantities of particulate and fiber, along with the particulate-to-fiber ratio, varied during the test to be representative of each incremental pipe break size. | | This particular test (identified by Alden as 1152PSLTST-455-00) was conducted by Alden to determine, by incremental debris addition representing increasing Loss-Of-Coolant Accident (LOCA) pipe break sizes, the maximum pipe break size that would still maintain acceptable Emergency Core Cooling System (ECCS) performance at St. Lucie Unit 1. The configuration of the test strainer assembly and the flume geometry remained constant. The strainer approach velocity was constant except for flow sweeps performed to characterize the debris bed prior to chemical precipitate addition. The quantities of particulate and fiber, along with the particulate-to-fiber ratio, varied during the test to be representative of each incremental pipe break size. |
| OVERVIEW OF FACILITY The test tank occupies a 12.5 ft x 5 ft x 5.5 ft area and contains a strainer, simulated containment piping, and the geometry to simulate the strainer keyway configuration inside containment (see Figure 1). The test strainer area is 360.6 ft 2 and matches the configuration of one keyway module in the plant. For the head loss tests, the test fluid is borated and pH adjusted with sodium hydroxide to be more r epresentative of the plant compared to using potable water. Total volume of water in the tank is about 165 ft³ or 1,232 gallons. The tank is elevated above the ground to create space for piping, a heat exchanger, sensory equipment, test leads, and a main recirculating pump. There are two debris hoppers located next to the tank to provide for mixing and entry to the test tank for fine debris additions. The fine and small fibrous debris solutions were created in mixing tanks located above and next to the test tank. | | OVERVIEW OF FACILITY The test tank occupies a 12.5 ft x 5 ft x 5.5 ft area and contains a strainer, simulated containment piping, and the geometry to simulate the strainer keyway configuration inside containment (see Figure 1). The test strainer area is 360.6 ft2 and matches the configuration of one keyway module in the plant. For the head loss tests, the test fluid is borated and pH adjusted with sodium hydroxide to be more representative of the plant compared to using potable water. Total volume of water in the tank is about 165 ft³ or 1,232 gallons. The tank is elevated above the ground to create space for piping, a heat exchanger, sensory equipment, test leads, and a main recirculating pump. There are two debris hoppers located next to the tank to provide for mixing and entry to the test tank for fine debris additions. The fine and small fibrous debris solutions were created in mixing tanks located above and next to the test tank. |
| | | TEST SETUP To set up the head loss testing, the fibrous debris is prepared to meet either fiber fines (Class 2) or fiber smalls (sizes varying from multiple attached or interwoven strands, also known as Class 3 fiber fines, up to 6 in length) requirements. The fiber debris solution is prepared by placing a predetermined amount (based on procedure) of 2 inch x 2 inch squares of baked Nukon into a mixing container (see Figure 2). Using high powered water jets on a timed interval, the Nukon is broken down into fines until it reaches the desired fine characteristic as dictated by the procedure. Once the fiber debris solution is prepared as either fines or smalls, additions of particulates, Calcium-Silicate (Cal-Sil), and dirt and dust are added to the mixtures and manually combined with a large stirring rod. |
| TEST SETUP | | ENCLOSURE |
| | |
| To set up the head loss testing, the fibrous debris is prepared to meet either fiber fines (Class 2) or fiber smalls (sizes varying from multiple attached or interwoven strands, also known as Class 3 fiber fines, up to 6" in length) requirements. The fiber debris solution is prepared by placing a predetermined amount (based on procedure) of 2 inch x 2 inch squares of baked Nukon into a mixing container (see Figure 2). Using high powered water jets on a timed interval, the Nukon is broken down into fines until it reaches the desired fine characteristic as dictated by the procedure. Once the fiber debris solution is prepared as either fines or smalls, additions of particulates, Calcium-Silicate (Cal-Sil), and dirt and dust are added to the mixtures and manually combined with a large stirring rod. | |
| | |
| ENCLOSURE The amount of Nukon, particulate, Cal-Sil, dirt and dust used is determined by the break size being evaluated (see Table 1). | |
| | |
| In the test setup (see Figure 3), the fine fiber debris solution, as prepared above, is poured into each debris hopper in equal portions. The debris hopper then further breaks down the fibers before adding the debris solution into each end of the test tank. Once the fiber enters into the test tank, the suction strainer then draws suction on the solution using the main recirculating pump. A small portion of the solution is then heated by the heat exchanger before returning to the debris hopper where it gets returned to the test tank or the mixing flow lines. The small fibrous debris solution has a similar transport flow path in the test setup except that it is added by pouring it through a cross-sectional pipe segment at the front of the test tank only instead of debris hoppers at each end of the test tank. The test loop is held at a constant 120°F by directing a portion of the overall recirculation flow over an in-line heat exchanger. The test temperature helps lower the air content in the test tank fluid. The flow rate is set to match a target approach velocity of 0.0026 ft/sec. The initial debris additions to the test represented break size "G" (Table 1), which simulated an 8.5-inch break.
| |
| | |
| Figure 1: Test Tank Design Concept, Isometric View Figure 2: Nukon Fiber Before and After Preparation
| |
|
| |
|
| Figure 3: Piping and Instrumentation Diagram (P&ID)
| | The amount of Nukon, particulate, Cal-Sil, dirt and dust used is determined by the break size being evaluated (see Table 1). |
| Table 1: Debris Content in Breaks of Interest Designation Pipe ID (in) Cal-Sil (lbs) Particulates (ft3) Nukon (lbs) Temp-Mat (lbs) Fines Smalls Fines Smalls A 42 1170.16 11.71 513.9 570.24 6.08 6.41 B 31 341.34 7.94 351.88 385.1 3.41 1.94 C 31 556.95 9.29 282.21 285 3.78 3.14 D 30 258.69 7.76 332.51 369.16 48.58 68.61 E 30 531.59 8.96 278.67 284.2 4.26 5.06 F 10.126 88.44 7.33 88.7 77.34 0.5 0.22 G 8.5 61.33 7.39 53.09 38.21 1.33 1.24 TEST PERFORMANCE The head loss testing began by adding the fine fiber plus particulate debris solution (see Figure 4). Once all the fine debris solution for a given break size was added, then the small fiber plus particulate debris solution was added. The testing alternated between adding fine debris solution and then adding the small debris solution until all required debris was added to reach a specified break size per Table 1. Each addition took at least 90 minutes before the next fiber debris solution was added to the tank. Over time, the sump strainer became covered with fibrous debris. The small fibers and some fines settled to the bottom of the tank and along the suction screen (see figure 5).
| | In the test setup (see Figure 3), the fine fiber debris solution, as prepared above, is poured into each debris hopper in equal portions. The debris hopper then further breaks down the fibers before adding the debris solution into each end of the test tank. Once the fiber enters into the test tank, the suction strainer then draws suction on the solution using the main recirculating pump. A small portion of the solution is then heated by the heat exchanger before returning to the debris hopper where it gets returned to the test tank or the mixing flow lines. The small fibrous debris solution has a similar transport flow path in the test setup except that it is added by pouring it through a cross-sectional pipe segment at the front of the test tank only instead of debris hoppers at each end of the test tank. The test loop is held at a constant 120°F by directing a portion of the overall recirculation flow over an in-line heat exchanger. The test temperature helps lower the air content in the test tank fluid. The flow rate is set to match a target approach velocity of 0.0026 ft/sec. The initial debris additions to the test represented break size G (Table 1), which simulated an 8.5-inch break. |
| | Figure 1: Test Tank Design Concept, Isometric View Figure 2: Nukon Fiber Before and After Preparation |
|
| |
|
| Figure 4: Test Tank 5 Minutes into Designation G and 40 Minutes into Designation G, Respectively | | Figure 3: Piping and Instrumentation Diagram (P&ID) |
|
| |
|
| Figure 5: Clean Test Tank and Test Tank 20 hours After Initial Fiber Addition, Respectively While batches of fiber and particulate were being added to the maximum debris head loss test, Alden personnel began preparing chemical precipitates for later additions to the test. Alden had the chemicals and necessary equipment for generating large quantities of both Aluminum Oxyhydroxide and Sodium Aluminum Silicate (SAS) precipitates using the methodology outlined in WCAP-16530-NP-A, "Evaluation of Post-Accident Chemical Effects in Containment Sump Fluids to support GSI-191." The NRC staff had the opportunity to observe preparation of a 500 gallon batch of SAS precipitate. | | Table 1: Debris Content in Breaks of Interest Pipe ID Cal-Sil Particulates Nukon (lbs) Temp-Mat (lbs) |
| For the preparation of SAS precipitate, potable (tap) water was mixed with aluminum nitrate (Al
| | Designation (in) (lbs) (ft3) Fines Smalls Fines Smalls A 42 1170.16 11.71 513.9 570.24 6.08 6.41 B 31 341.34 7.94 351.88 385.1 3.41 1.94 C 31 556.95 9.29 282.21 285 3.78 3.14 D 30 258.69 7.76 332.51 369.16 48.58 68.61 E 30 531.59 8.96 278.67 284.2 4.26 5.06 F 10.126 88.44 7.33 88.7 77.34 0.5 0.22 G 8.5 61.33 7.39 53.09 38.21 1.33 1.24 TEST PERFORMANCE The head loss testing began by adding the fine fiber plus particulate debris solution (see Figure 4). Once all the fine debris solution for a given break size was added, then the small fiber plus particulate debris solution was added. The testing alternated between adding fine debris solution and then adding the small debris solution until all required debris was added to reach a specified break size per Table 1. Each addition took at least 90 minutes before the next fiber debris solution was added to the tank. Over time, the sump strainer became covered with fibrous debris. The small fibers and some fines settled to the bottom of the tank and along the suction screen (see figure 5). |
| | Figure 4: Test Tank 5 Minutes into Designation G and 40 Minutes into Designation G, Respectively Figure 5: Clean Test Tank and Test Tank 20 hours After Initial Fiber Addition, Respectively |
|
| |
|
| (NO3)3) and sodium ortho-silicate (Na 4SiO4) solution. The ingredients were added slowly and mixing was allowed to continue for 1 hour to allow the chemical reaction to complete. | | While batches of fiber and particulate were being added to the maximum debris head loss test, Alden personnel began preparing chemical precipitates for later additions to the test. Alden had the chemicals and necessary equipment for generating large quantities of both Aluminum Oxyhydroxide and Sodium Aluminum Silicate (SAS) precipitates using the methodology outlined in WCAP-16530-NP-A, Evaluation of Post-Accident Chemical Effects in Containment Sump Fluids to support GSI-191. The NRC staff had the opportunity to observe preparation of a 500 gallon batch of SAS precipitate. |
| | For the preparation of SAS precipitate, potable (tap) water was mixed with aluminum nitrate (Al (NO3)3) and sodium ortho-silicate (Na4SiO4) solution. The ingredients were added slowly and mixing was allowed to continue for 1 hour to allow the chemical reaction to complete. |
| Approximately one hour after the precipitates were prepared, the Alden staff began a settlement test in a graduated cylinder. The one-hour precipitate settlement was approximately 9.3 milliliters (mL) out of 10 mL. In other words, the cloudy portion of precipitate covered up to the 9.3 mL mark with 0.7 mL of clear fluid from the 9.3 mL mark to the 10 mL mark. This measurement easily met the one-hour settlement criteria specified in WCAP-16530-NP-A and was acceptable to the NRC staff. Figure 6 shows various points in the preparation of SAS chemical precipitate. | | Approximately one hour after the precipitates were prepared, the Alden staff began a settlement test in a graduated cylinder. The one-hour precipitate settlement was approximately 9.3 milliliters (mL) out of 10 mL. In other words, the cloudy portion of precipitate covered up to the 9.3 mL mark with 0.7 mL of clear fluid from the 9.3 mL mark to the 10 mL mark. This measurement easily met the one-hour settlement criteria specified in WCAP-16530-NP-A and was acceptable to the NRC staff. Figure 6 shows various points in the preparation of SAS chemical precipitate. |
| Figure 6: Preparation of SAS chemical precipitate | | Figure 6: Preparation of SAS chemical precipitate |
|
| |
|
| The lead test engineer for Alden also walked down the piping from the chemical precipitate tanks to the test tank and described how precipitate addition would be performed. Although the NRC staff was not able to observe chemical precipitate addition to the St. Lucie Unit 1 head loss test due to testing delays and schedule constraints, the NRC staff has observed chemical precipitate addition to head loss tests during previous visits to the facility. As an example, see "Staff Observations of Testing for Generic Safety Issue 191 during July 12-14, 2010 trip to Alden Test Facility for PCI Strainer Tests," (Agencywide Documents Access and Management System (ADAMS) Accession Number ML102160226). | | The lead test engineer for Alden also walked down the piping from the chemical precipitate tanks to the test tank and described how precipitate addition would be performed. Although the NRC staff was not able to observe chemical precipitate addition to the St. Lucie Unit 1 head loss test due to testing delays and schedule constraints, the NRC staff has observed chemical precipitate addition to head loss tests during previous visits to the facility. As an example, see Staff Observations of Testing for Generic Safety Issue 191 during July 12-14, 2010 trip to Alden Test Facility for PCI Strainer Tests, (Agencywide Documents Access and Management System (ADAMS) Accession Number ML102160226). |
| | | TEST RESULTS The NRC staff observed multiple additions of debris but was unable to observe the entire test due to the length of the test and schedule constraints. At the time of the staffs departure on August 5, all debris representative of a 30-inch break and approximately one half of the incremental debris to go from the 30-inch break to a 42-inch break had been introduced to the test loop. Head loss at that point was approximately 1 ft H20. The NRC staff and the St. Lucie representatives had a closeout discussion and agreed to have a follow-up phone call after the current test and subsequent thin bed test had been performed. |
| TEST RESULTS The NRC staff observed multiple additions of debris but was unable to observe the entire test due to the length of the test and schedule constraints. At the time of the staff's departure on August 5, all debris representative of a 30-inch break and approximately one half of the incremental debris to go from the 30-inch break to a 42-inch break had been introduced to the test loop. Head loss at that point was approximately 1 ft H | |
| : 20. The NRC staff and the St. Lucie representatives had a closeout discussion and agreed to have a follow-up phone call after the current test and subsequent thin bed test had been performed.
| |
|
| |
|
| SUMMARY The NRC staff became more familiar with the St. Lucie Unit 1 approach to addressing GSI-191 and the Alden Test Procedure, 1152PSLTST-455-00, being used to evaluate its maximum head loss requirements that must be met for ECCS. | | ==SUMMARY== |
|
| |
|
| Overall, the trip was effective and will assist the review of the licensee's submittal to closeout GSI-191. | | The NRC staff became more familiar with the St. Lucie Unit 1 approach to addressing GSI-191 and the Alden Test Procedure, 1152PSLTST-455-00, being used to evaluate its maximum head loss requirements that must be met for ECCS. |
| | Overall, the trip was effective and will assist the review of the licensees submittal to closeout GSI-191. |
| FOLLOW-UP PHONE CALL The NRC staff, St. Lucie representatives, and Alden representatives participated in a phone call to discuss the results from the St. Lucie Unit 1 maximum load and thin bed strainer tests and the plans for the third confirmatory strainer head loss test. The licensee representatives indicated that the chemical precipitate addition to the initial head loss test (representing a maximum calcium silicate, near maximum fiber load) resulted in approximately a 4 times increase in head loss from the conventional fiber and particulate debris head loss. The total head loss was still well within the acceptance value. | | FOLLOW-UP PHONE CALL The NRC staff, St. Lucie representatives, and Alden representatives participated in a phone call to discuss the results from the St. Lucie Unit 1 maximum load and thin bed strainer tests and the plans for the third confirmatory strainer head loss test. The licensee representatives indicated that the chemical precipitate addition to the initial head loss test (representing a maximum calcium silicate, near maximum fiber load) resulted in approximately a 4 times increase in head loss from the conventional fiber and particulate debris head loss. The total head loss was still well within the acceptance value. |
| The total head loss from the thin bed test was approximately 25 percent of the first maximum load test demonstrating that the "thin bed" condition is not more challenging with respect to strainer head loss for St. Lucie Unit 1. The licensee indicated that the plans for the confirmatory test are to add approximately 10 percent more fiber and 30 percent less calcium silicate relative to the first test. After some discussion on debris sequencing, the licensee indicated that they will be adding all fine fibrous debris first followed by all small fibrous debris. The NRC staff requested and the licensee agreed to have an additional phone call after the confirmatory test results are available.}} | | The total head loss from the thin bed test was approximately 25 percent of the first maximum load test demonstrating that the thin bed condition is not more challenging with respect to strainer head loss for St. Lucie Unit 1. The licensee indicated that the plans for the confirmatory test are to add approximately 10 percent more fiber and 30 percent less calcium silicate relative to the first test. After some discussion on debris sequencing, the licensee indicated that they will be adding all fine fibrous debris first followed by all small fibrous debris. The NRC staff requested and the licensee agreed to have an additional phone call after the confirmatory test results are available.}} |
|
---|
Category:Memoranda
MONTHYEARML23166A0042023-06-15015 June 2023 Summary of Meeting Concerning 2023 Annual Assessment of the Saint Lucie and the Turkey Point Nuclear Plants ML22188A0862022-07-0707 July 2022 SLRA - Audit Report ML22145A3932022-05-25025 May 2022 Public Meeting Summary 2021 Annual Assessment Meeting 20220434 ML21337A1962021-12-16016 December 2021 Public Scoping Meeting Summary for the Environmental Review of the Subsequent License Renewal Application for St. Lucie Plant, Units 1 and 2 ML21159A1352021-06-0808 June 2021 Public Meeting Summary Regarding the Saint Lucie Nuclear Plant, Units 1 and 2, Docket No. 50-335 and 389, and the Turkey Point Nuclear Generating Station Units 3 and 4, Docket No. 50-250 and 50-251; Meeting Number 20210505 ML20150A4732020-05-29029 May 2020 EOC Meeting Summary ML19121A6102019-05-0101 May 2019 Public Meeting Summary - St Lucie Nuclear Plant, Docket Nos. 50-389 and 50-335 ML18144A1452018-05-24024 May 2018 Public Meeting Summary - St. Lucie Nuclear Plant Docket Nos. 50-335 and 50-389 ML17103A0342017-04-12012 April 2017 Summary of Category 1 Public Meeting to Discuss the Significance Determination Process for a Finding at St. Lucie, Unit 1 ML16097A1302016-04-0404 April 2016 March 29, 2016 Summary of Public Meeting - 2015 Annual Assessment Regarding Saint Lucie ML15320A5512015-11-23023 November 2015 SER MF5835 ML15240A1542015-09-0808 September 2015 Staff Observations of Sump Strainer Head Loss Testing at Alden Laboratory for Generic Safety Issue 191 ML14163A6522014-06-19019 June 2014 Summary of May 29, 2014, Public Meeting with NextEra Energy, Inc. and Florida Power & Light Company Regarding Proposed Amendment to Transition Fuel Type at St. Lucie Unit 2 ML14156A2132014-06-0404 June 2014 Public Meeting Summary - St. Lucie Nuclear Plant Docket Nos. 50-335 and 50-389 ML13059A5522013-03-0101 March 2013 3/14/13 - Forthcoming Meeting with Florida Power and Light Company Regarding Steam Generator Performance at St. Lucie Nuclear Plant, Units 1 and 2 ML12222A0392012-08-0909 August 2012 8/16/2012 Cancellation Notice of Forthcoming Conference Call with NextEra Energy and Florida Power and Light Concerning Generic Letter 2004-02 and Request for NRC Staff Review of Draft Proposed Guideline for Strainer Fiber Bypass Test Proto ML12213A0612012-08-0101 August 2012 8/16/12 Forthcoming Conference Call with NextEra Energy and Florida Power & Light Concerning Generic Letter 2004-02 and Request for NRC Staff Review of Draft Proposed Guideline for Strainer Fiber Bypass Test Protocol ML12150A2992012-06-0505 June 2012 May 17, 2012, Summary of Teleconference Held Between the U.S. Nuclear Regulatory Commission, U.S. Fish and Wildlife Service, and Florida Power & Light Co. to Discuss the Terms of the Biological Opinion at the St. Lucie Plant, Units 1 and 2 ML1204005162012-02-0909 February 2012 Notification of Inspection and Request for Information for NRC Problem Identification and Resolution Inspection ML11251A0052011-09-0909 September 2011 9/21/11 Notice of Forthcoming Meeting with Florida Power and Light Regarding St. Lucie Nuclear Plant, Units 1 and 2 Extended Power Uprate ML11231A7172011-08-25025 August 2011 Notice of Forthcoming Meeting with Florida Power and Light Company (FPL) Regarding Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design Basis Accidents at Pressurized-Water Reactors. ML11182A0142011-07-0101 July 2011 Forthcoming Meeting with Florida Power & Light Company Regarding St. Lucie Nuclear Plant, Unit 1 to Discuss Extended Power Uprate License Amendment Request That Is Currently Under Review ML1109006712011-04-21021 April 2011 Acceptance of License Amendment Request for an Extended Power Uprate (Epu), St Lucie Nuclear Plant ML1106104272011-03-0707 March 2011 Notice of Forthcoming Pre-Application Meeting with Florida Power & Light Company and NextEra Energy Regarding Turkey Point, Units 3 and 4, St. Lucie, Units 1 and 2, Point Beach, Units 1, and 2, and Duane Arnold ML1035405732010-12-21021 December 2010 Acceptance of License Amendment Request for an Extended Power Uprate (Epu), St. Lucie Nuclear Plant, Unit 1 ML1025601362010-09-0707 September 2010 Notice of Meeting with Florida Power & Light Company to Discuss the Florida Power & Light Company'S Forthcoming Applications for the Extended Power Uprates of St. Lucie Units 1 & 2 and Turkey Point Units 3 & 4, Focusing on the Topic of Spen ML0921805182009-08-0606 August 2009 Notice of Public Meeting with Florida Power & Light Energy ML0909705822009-04-0707 April 2009 Phone Call Summary with Licensees and Alion Science and Technology on April 2, 2009 to Address NRC Staff Position on Chemical Effects Refinements ML0832502332008-12-0202 December 2008 Summary of Public Meeting with Operators of Vogtle Units 1 & 2, San Onofre Units 2 & 3, St. Lucie Unit 1, Turkey Point Unit 3, Indian Point Units 2 & 3, Nuclear Energy Institute, and Alion Science and Technology ML0826006252008-09-16016 September 2008 Draft Request for Additional Information on Relief Request No. 2 Regarding Structural Weld Overlays ML0820008422008-07-18018 July 2008 Memorandum of the Secretary (Referring a Petition to Intervene to the ASLBP) ML0807400842008-03-14014 March 2008 Draft Regulatory Guide for Comment ML0810502852008-03-11011 March 2008 NDE Report, on PSL-1 Pressurizer Nozzles, Attachment 3 ML0635602592006-12-27027 December 2006 Forthcoming Meeting with Florida Power and Light to Discuss Proposed License Amendment Request to Adopt Alternate Source Term at the St. Lucie Nuclear Plant ML0633303802006-11-29029 November 2006 Forthcoming Meeting with Florida Power & Light Regarding Proposed License Amendment Request to Adopt Alternate Source Term at St. Lucie Nuclear Plant ML0614505922006-05-26026 May 2006 Wits 200600198 - Actions to Be Taken in Response to Hurricane Lessons Learned Task Report ML0609602052006-04-0606 April 2006 Meeting Notice, Florida Power & Light, St. Lucie Unit 2, Steam Generator Tube Inspection During Refueling ML0523704412005-08-31031 August 2005 Closeout Letter for Bulletin 2003-01, Potential Impact of Debris Blockage on Emergency Sump Recirculation at Pressurized-Water Reactors. ML0517402732005-06-23023 June 2005 Notice of Meeting with Florida Power and Light Company (FPL) & Westinghouse LAR to Increase SG Tube Plugging at St. Lucie ML0502701092005-01-25025 January 2005 Safety Evaluation on the Relief Request 2 Associated with the Third 10-year Inservice Inspection Interval - Inservice Inspection Program for St. Lucie Unit 2 ML0419005722004-07-0101 July 2004 Ltr, Temporary Change in Personnel Assignment ML0326809972003-10-0909 October 2003 Renewal of Full-Power Operating Licenses for St. Lucie, Units 1 and 2 ML0324005942003-08-25025 August 2003 June 10-11, 1997, Summary of NRC Senior Management Meeting to Review Performance of Operating Nuclear Power Plants and Materials Facilities Licensed by Nrc. Partially Withheld ML0321800032003-08-0606 August 2003 08/20-21/2003 Notice of Meeting with Florida Power and Light Regarding Increased Steam Generator Tube Plugging and Reload Methodology at St. Lucie, Unit 2 ML0316210252003-06-11011 June 2003 Peer Review of Risk-informed Safety Evaluation of the Suppression Capability in the Cable Spreading Room at St. Lucie Nuclear Power Plant Unit 1 ML0312702872003-05-0707 May 2003 Submission of Draft Request for Additional Information and Summary of a Conference Call Regarding Steam Generator Tubesheet Amendment ML0309808612003-04-0909 April 2003 Corrected Notice for Meeting with FPL to Discuss Requests for Relaxation from Reactor Pressure Vessel Head Inspection Order at St.Lucie, Unit 2 ML0309306732003-04-0303 April 2003 Meeting with FPL to Discuss Requests for Relaxation from Reactor Pressure Head Inspection Order at St. Lucie ML0306902142003-03-0606 March 2003 Halon 1301 Fire Suppression System ML0305806052003-02-26026 February 2003 Memo - Submission of Draft Request for Additional Information Regarding Risk Informed Inservice Inspection 2023-06-15
[Table view] Category:Report
MONTHYEARL-2023-131, Subsequent License Renewal Application - Second Annual Update2023-09-28028 September 2023 Subsequent License Renewal Application - Second Annual Update L-2023-076, In-Service Inspection Program Owner'S Activity Report (OAR-1)2023-07-11011 July 2023 In-Service Inspection Program Owner'S Activity Report (OAR-1) L-2023-028, and Point Beach Units 1 and 2, 10 CFR 50.46 Annual Reporting of Changes to, or Errors in Emergency Core Cooling System Models or Applications2023-03-27027 March 2023 and Point Beach Units 1 and 2, 10 CFR 50.46 Annual Reporting of Changes to, or Errors in Emergency Core Cooling System Models or Applications L-2023-009, Owner'S Activity Report2023-01-31031 January 2023 Owner'S Activity Report ML22227A0532022-08-15015 August 2022 Biological Opinion for the Continued Operation of St. Lucie Nuclear Power Plant ML22124A0112022-04-30030 April 2022 Scoping Summary Report - Final L-2022-046, Subsequent License Renewal Application Revision - Documents WCAP-18623-P/NP Revision 1 Submittal2022-04-13013 April 2022 Subsequent License Renewal Application Revision - Documents WCAP-18623-P/NP Revision 1 Submittal L-2022-015, Relief Request Number 20 - Request for an Alternative to the Requirements of the ASME Code for Examination of Reactor Vessel Closure Head Control Element Drive Mechanism (CEDM) Housing 27 Canopy Seal Weld - RAI2022-01-14014 January 2022 Relief Request Number 20 - Request for an Alternative to the Requirements of the ASME Code for Examination of Reactor Vessel Closure Head Control Element Drive Mechanism (CEDM) Housing 27 Canopy Seal Weld - RAI L-2022-011, Relief Request Number 20 - Request for an Alternative to the Requirements of the ASME Code for Examination of Reactor Vessel Closure Head Control Element Drive Mechanism (CEDM) Housing 27 Canopy Seal Weld2022-01-12012 January 2022 Relief Request Number 20 - Request for an Alternative to the Requirements of the ASME Code for Examination of Reactor Vessel Closure Head Control Element Drive Mechanism (CEDM) Housing 27 Canopy Seal Weld ML22010A0942022-01-0404 January 2022 Trp 29 St. Lucie SLRA - Tank Breakout L-2021-178, Report of 10 CFR 50.59 Plant Changes2021-11-0808 November 2021 Report of 10 CFR 50.59 Plant Changes L-2021-142, Westinghouse Report LTR-REA-21-1-NP, Revision 1, St. Lucie Nuclear Plant, Units 1 and 2, Subsequent License Renewal: Unit 1 Reactor Vessel, Vessel Support, and Bioshield Concrete Exposure Data, May 26, 20212021-08-0303 August 2021 Westinghouse Report LTR-REA-21-1-NP, Revision 1, St. Lucie Nuclear Plant, Units 1 and 2, Subsequent License Renewal: Unit 1 Reactor Vessel, Vessel Support, and Bioshield Concrete Exposure Data, May 26, 2021 ML19252A4002019-09-0909 September 2019 FPL to NRC, Notification of Smalltooth Sawfish Capture at St. Lucie L-2019-010, Proposed Alternative for the Use of Encoded Phased Array Ultrasonic Examination Techniques in Lieu of Radiography for Ferritic and Austenitic Welds2019-03-19019 March 2019 Proposed Alternative for the Use of Encoded Phased Array Ultrasonic Examination Techniques in Lieu of Radiography for Ferritic and Austenitic Welds ML18096B3952018-04-0606 April 2018 Exhibit III Estimate of Construction Costs and Exhibit IV Technical Qualifications of Contractors ML18088B1952018-03-29029 March 2018 Hutchinson Island Plant Units 1 and 2 - Chapter 9, Auxiliary Systems and Chapter 10, Steam and Power Conversion System ML18088B1942018-03-29029 March 2018 Hutchinson Island Plant Units 1 and 2 - Chapter 11, Radioactive Waste Management System, Chapter 12, Radiation Protection, and Chapter 13, Conduct of Operations ML18088A0942018-03-29029 March 2018 Unit II Plants ECCS Performance Results L-2017-173, Environmental Protection Plan Report, Unusual or Important Environmental Event - Turtle Mortality - 09/11/2017 Event2017-09-28028 September 2017 Environmental Protection Plan Report, Unusual or Important Environmental Event - Turtle Mortality - 09/11/2017 Event L-2018-081, Kld Engineering, Pc - 2017 Population Update Analysis2017-09-20020 September 2017 Kld Engineering, Pc - 2017 Population Update Analysis L-2017-117, Submittal of SL2-23 Outage, Owner'S Activity Report, Form OAR-12017-06-20020 June 2017 Submittal of SL2-23 Outage, Owner'S Activity Report, Form OAR-1 L-2018-015, Plan of Study 316(b) Implementation2017-04-28028 April 2017 Plan of Study 316(b) Implementation L-2017-015, PWROG-15105-NP PA-MSC-1288 PWR Rv Internals Cold-Work Assessment, Materials Committee.2016-04-30030 April 2016 PWROG-15105-NP PA-MSC-1288 PWR Rv Internals Cold-Work Assessment, Materials Committee. ML16084A6162016-03-24024 March 2016 Submittal of Biological Opinion for the Continued Operation of St. Lucie Nuclear Power Plant, Units 1 and 2 in St. Lucie County, Florida ML16063A0072016-02-26026 February 2016 Participation in Additional Work Under the Support for Applicant Action Items 1, 2, and 7 from the Final Safety Evaluation on MRP-227, Revision 0 PA-MSC-0983 R2 Cafeteria Task 8 and Acceptance Criteria for Measurement Of.. ML15352A0532016-01-0707 January 2016 Staff Assessment of Information Provided Pursuant to Title 10 of the Code of Federal Regulations Part 50, Section 50.54(f) Seismic Hazard Revaluations for Recommendation 2.1 of the Near-Term Task Force Review of Insights L-2015-297, Status of Required Actions for EA-12-049 Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events, and Submittal of Site FLEX Final Integrated Plan2015-12-10010 December 2015 Status of Required Actions for EA-12-049 Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events, and Submittal of Site FLEX Final Integrated Plan L-2015-300, ANP-3352NP, Revision 1, Transition License Amendment Request, Technical Report.2015-11-30030 November 2015 ANP-3352NP, Revision 1, Transition License Amendment Request, Technical Report. ML15314A1602015-10-29029 October 2015 St. Lucie, Units 1 and 2 - License Renewal Commitment, Submittal of Pressurizer Surge Line Welds Inspection Program L-2015-221, Report of 10 CFR 50.59 Plant Changes2015-10-16016 October 2015 Report of 10 CFR 50.59 Plant Changes ML15240A1542015-09-0808 September 2015 Staff Observations of Sump Strainer Head Loss Testing at Alden Laboratory for Generic Safety Issue 191 L-2015-206, ANP-3428NP, Revision 0, St. Lucie Unit 2 Fuel Transition: Response to SNPB-RAI-1, Attachment 4 to L-2015-2062015-07-31031 July 2015 ANP-3428NP, Revision 0, St. Lucie Unit 2 Fuel Transition: Response to SNPB-RAI-1, Attachment 4 to L-2015-206 L-2015-177, Fuel Transition Small Break LOCA Summary Report, ANP-3345NP, Revision 12015-06-30030 June 2015 Fuel Transition Small Break LOCA Summary Report, ANP-3345NP, Revision 1 L-2015-143, Status of Required Actions for EA-12-049 Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events2015-05-14014 May 2015 Status of Required Actions for EA-12-049 Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events L-2015-272, 1301103.401, Revision 0, Flaw Tolerance Evaluation of St. Lucie Surge Line Welds Using ASME Code Section XI, Appendix L, May 20152015-05-0808 May 2015 1301103.401, Revision 0, Flaw Tolerance Evaluation of St. Lucie Surge Line Welds Using ASME Code Section XI, Appendix L, May 2015 L-2016-052, TN-5696-00-02, Revision 0, Technical Note Assessment of Laboratory PWSCC Crack Growth Rate Data Compiled for Alloys 690, 52, and 152 with Regard to Factors of Improvement (Foi) Versus Alloys 600 and 182.2015-03-31031 March 2015 TN-5696-00-02, Revision 0, Technical Note Assessment of Laboratory PWSCC Crack Growth Rate Data Compiled for Alloys 690, 52, and 152 with Regard to Factors of Improvement (Foi) Versus Alloys 600 and 182. L-2015-091, ANP-3396NP, Revision 0, Fuel Transition Supplemental Information to Support the LAR2015-03-31031 March 2015 ANP-3396NP, Revision 0, Fuel Transition Supplemental Information to Support the LAR L-2015-093, Acceptance Criteria for Emergency Core Cooling Systems for Light Water Nuclear Power Reactors 10 CFR 50.46 Annual Report2015-03-24024 March 2015 Acceptance Criteria for Emergency Core Cooling Systems for Light Water Nuclear Power Reactors 10 CFR 50.46 Annual Report ML15083A2642015-03-10010 March 2015 St. Lucie, Units 1 and 2 - Submittal of Revision 0 to FPL-072-PR-002, Flooding Hazards Reevaluation Report L-2015-048, St. Lucie, Units 1 and 2 - Submittal of Revision 0 to FPL-072-PR-002, Flooding Hazards Reevaluation Report2015-03-10010 March 2015 St. Lucie, Units 1 and 2 - Submittal of Revision 0 to FPL-072-PR-002, Flooding Hazards Reevaluation Report L-2015-048, to FPL-072-PR-002, Flooding Hazards Reevaluation Report for St. Lucie Nuclear Power Plant Units 1 & 2. Cover Page to Page 1092015-02-0606 February 2015 to FPL-072-PR-002, Flooding Hazards Reevaluation Report for St. Lucie Nuclear Power Plant Units 1 & 2. Cover Page to Page 109 L-2015-048, to FPL-072-PR-002, Flooding Hazards Reevaluation Report for St. Lucie Nuclear Power Plant Units 1 & 2. Table 2-1 Through Figure 4-92015-02-0606 February 2015 to FPL-072-PR-002, Flooding Hazards Reevaluation Report for St. Lucie Nuclear Power Plant Units 1 & 2. Table 2-1 Through Figure 4-9 L-2015-048, to FPL-072-PR-002, Flooding Hazards Reevaluation Report for St. Lucie Nuclear Power Plant Units 1 & 2. Figure 4-10 Through the End2015-02-0606 February 2015 to FPL-072-PR-002, Flooding Hazards Reevaluation Report for St. Lucie Nuclear Power Plant Units 1 & 2. Figure 4-10 Through the End ML15083A2652015-02-0606 February 2015 to FPL-072-PR-002, Flooding Hazards Reevaluation Report for St. Lucie Nuclear Power Plant Units 1 & 2. Table 2-1 Through Figure 4-9 ML15083A2662015-02-0606 February 2015 to FPL-072-PR-002, Flooding Hazards Reevaluation Report for St. Lucie Nuclear Power Plant Units 1 & 2. Figure 4-10 Through the End L-2014-366, ANP-3352NP, Revision 0, St. Luice, Unit 2, Fuel Transition License Amendment Request, Technical Report2014-12-31031 December 2014 ANP-3352NP, Revision 0, St. Luice, Unit 2, Fuel Transition License Amendment Request, Technical Report ML14338A5552014-12-0404 December 2014 NRC-2013-TN3079-NRC 2014 St. Lucie License Renewal ML14338A5542014-12-0404 December 2014 NRC-2013- TN2986-NRC 2014 St. Lucie L-2014-125, Report of 10 CFR 50.59 Plant Changes2014-05-0606 May 2014 Report of 10 CFR 50.59 Plant Changes ML13360A2022013-12-12012 December 2013 EPA Echo Report Martin County, Fl 2023-09-28
[Table view] Category:Miscellaneous
MONTHYEARL-2023-131, Subsequent License Renewal Application - Second Annual Update2023-09-28028 September 2023 Subsequent License Renewal Application - Second Annual Update L-2023-076, In-Service Inspection Program Owner'S Activity Report (OAR-1)2023-07-11011 July 2023 In-Service Inspection Program Owner'S Activity Report (OAR-1) L-2023-028, and Point Beach Units 1 and 2, 10 CFR 50.46 Annual Reporting of Changes to, or Errors in Emergency Core Cooling System Models or Applications2023-03-27027 March 2023 and Point Beach Units 1 and 2, 10 CFR 50.46 Annual Reporting of Changes to, or Errors in Emergency Core Cooling System Models or Applications L-2023-009, Owner'S Activity Report2023-01-31031 January 2023 Owner'S Activity Report ML22227A0532022-08-15015 August 2022 Biological Opinion for the Continued Operation of St. Lucie Nuclear Power Plant ML22124A0112022-04-30030 April 2022 Scoping Summary Report - Final ML22010A0942022-01-0404 January 2022 Trp 29 St. Lucie SLRA - Tank Breakout L-2021-178, Report of 10 CFR 50.59 Plant Changes2021-11-0808 November 2021 Report of 10 CFR 50.59 Plant Changes ML19252A4002019-09-0909 September 2019 FPL to NRC, Notification of Smalltooth Sawfish Capture at St. Lucie L-2017-173, Environmental Protection Plan Report, Unusual or Important Environmental Event - Turtle Mortality - 09/11/2017 Event2017-09-28028 September 2017 Environmental Protection Plan Report, Unusual or Important Environmental Event - Turtle Mortality - 09/11/2017 Event L-2017-117, Submittal of SL2-23 Outage, Owner'S Activity Report, Form OAR-12017-06-20020 June 2017 Submittal of SL2-23 Outage, Owner'S Activity Report, Form OAR-1 ML15352A0532016-01-0707 January 2016 Staff Assessment of Information Provided Pursuant to Title 10 of the Code of Federal Regulations Part 50, Section 50.54(f) Seismic Hazard Revaluations for Recommendation 2.1 of the Near-Term Task Force Review of Insights L-2015-297, Status of Required Actions for EA-12-049 Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events, and Submittal of Site FLEX Final Integrated Plan2015-12-10010 December 2015 Status of Required Actions for EA-12-049 Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events, and Submittal of Site FLEX Final Integrated Plan ML15314A1602015-10-29029 October 2015 St. Lucie, Units 1 and 2 - License Renewal Commitment, Submittal of Pressurizer Surge Line Welds Inspection Program L-2015-221, Report of 10 CFR 50.59 Plant Changes2015-10-16016 October 2015 Report of 10 CFR 50.59 Plant Changes ML15240A1542015-09-0808 September 2015 Staff Observations of Sump Strainer Head Loss Testing at Alden Laboratory for Generic Safety Issue 191 L-2015-143, Status of Required Actions for EA-12-049 Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events2015-05-14014 May 2015 Status of Required Actions for EA-12-049 Order Modifying Licenses with Regard to Requirements for Mitigation Strategies for Beyond-Design-Basis External Events ML15083A2642015-03-10010 March 2015 St. Lucie, Units 1 and 2 - Submittal of Revision 0 to FPL-072-PR-002, Flooding Hazards Reevaluation Report L-2015-048, St. Lucie, Units 1 and 2 - Submittal of Revision 0 to FPL-072-PR-002, Flooding Hazards Reevaluation Report2015-03-10010 March 2015 St. Lucie, Units 1 and 2 - Submittal of Revision 0 to FPL-072-PR-002, Flooding Hazards Reevaluation Report ML14338A5552014-12-0404 December 2014 NRC-2013-TN3079-NRC 2014 St. Lucie License Renewal ML14338A5542014-12-0404 December 2014 NRC-2013- TN2986-NRC 2014 St. Lucie L-2014-125, Report of 10 CFR 50.59 Plant Changes2014-05-0606 May 2014 Report of 10 CFR 50.59 Plant Changes ML13360A2022013-12-12012 December 2013 EPA Echo Report Martin County, Fl L-2013-193, Transition to 10 CFR 50.48(c) - NFPA 805 Performance-Based Standard for Fire Protection for Light Water Reactor Generating Plants (2001 Edition) Acceptance Review Clarification Response2013-06-14014 June 2013 Transition to 10 CFR 50.48(c) - NFPA 805 Performance-Based Standard for Fire Protection for Light Water Reactor Generating Plants (2001 Edition) Acceptance Review Clarification Response L-2013-175, Report of 10 CFR 50.59 Plant Changes2013-05-23023 May 2013 Report of 10 CFR 50.59 Plant Changes L-2012-437, Standardization of Senior Reactor Operator Fuel Handling Duties2012-12-27027 December 2012 Standardization of Senior Reactor Operator Fuel Handling Duties L-2012-105, Response to Nuclear Performance and Code Review Branch Request for Additional Information Identified During an Audit of Analyses Supporting the Extended Power Uprate License Amendment Request2012-03-15015 March 2012 Response to Nuclear Performance and Code Review Branch Request for Additional Information Identified During an Audit of Analyses Supporting the Extended Power Uprate License Amendment Request ML1026405722010-09-14014 September 2010 E-mail St. Lucie Capture Summary Update for January Through August 2010 ML1019304172010-05-0606 May 2010 Tritium Database Report ML1012704392010-05-0505 May 2010 Y020100187 - List of Historical Leaks and Spills at U.S. Commercial Nuclear Power Plants L-2010-059, Florida Dept of Environmental Protection - Wastewater Application Form 2CS - Permit to Discharge Process Wastewater from New or Existing Industrial Wastewater Facilities to Surface Water2010-03-18018 March 2010 Florida Dept of Environmental Protection - Wastewater Application Form 2CS - Permit to Discharge Process Wastewater from New or Existing Industrial Wastewater Facilities to Surface Water ML1008304422010-03-18018 March 2010 Florida Dept of Environmental Protection - Wastewater Application Form 2CS - Permit to Discharge Process Wastewater from New or Existing Industrial Wastewater Facilities to Surface Water L-2009-101, Report of 10 CFR 50.59 Plant Changes, for the Period of May 28, 2007 Through November 21, 20082009-04-22022 April 2009 Report of 10 CFR 50.59 Plant Changes, for the Period of May 28, 2007 Through November 21, 2008 L-2008-261, Technical Specification Special Report Inoperable Containment Sump Wide Range Level Channel B2008-12-16016 December 2008 Technical Specification Special Report Inoperable Containment Sump Wide Range Level Channel B ML0807010172008-03-10010 March 2008 EPRI Reports (St. Lucie Pressurizer Nozzle DM Weld Examination Project Internal Office Report) L-2008-030, Supplemental Response to NRC Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design Basis Accidents at Pressurized-Water Reactors2008-02-27027 February 2008 Supplemental Response to NRC Generic Letter 2004-02, Potential Impact of Debris Blockage on Emergency Recirculation During Design Basis Accidents at Pressurized-Water Reactors NOC-AE-07002231, Request for Relaxation of Requirements from Revision 1 of Order EA-03-009 Establishing Interim Inspection Requirements for Reactor Pressure Vessel Head Penetrations (Relief Request RR-ENG-2-46)2007-11-0707 November 2007 Request for Relaxation of Requirements from Revision 1 of Order EA-03-009 Establishing Interim Inspection Requirements for Reactor Pressure Vessel Head Penetrations (Relief Request RR-ENG-2-46) L-2007-167, Report of 10 CFR 50.59 Plant Changes During the Period of December 19, 2005 Through May 27, 20072007-10-29029 October 2007 Report of 10 CFR 50.59 Plant Changes During the Period of December 19, 2005 Through May 27, 2007 L-2007-168, Technical Specifications Bases Control Program Periodic Report of Bases Changes TS 6.8.4.j.42007-10-29029 October 2007 Technical Specifications Bases Control Program Periodic Report of Bases Changes TS 6.8.4.j.4 L-2007-137, Technical Specification Special Report, Inoperable Containment Sump Wide Range Level Channel B2007-08-31031 August 2007 Technical Specification Special Report, Inoperable Containment Sump Wide Range Level Channel B L-2007-029, Semi-Annual Fitness-For-Duty Program Performance Data for the Six-Month Period Ending December 31, 20062007-02-26026 February 2007 Semi-Annual Fitness-For-Duty Program Performance Data for the Six-Month Period Ending December 31, 2006 L-2007-020, Annual Summary of Commitment Changes Implemented Without Prior NRC Notification for Calendar Year 20062007-02-0606 February 2007 Annual Summary of Commitment Changes Implemented Without Prior NRC Notification for Calendar Year 2006 L-2006-078, Proposed License Amendment, Containment Spray Nozzle Surveillance Change2006-10-19019 October 2006 Proposed License Amendment, Containment Spray Nozzle Surveillance Change L-2006-217, Day Post Outage Steam Generator Report Technical Specification 4.4.5.5.c2006-09-20020 September 2006 Day Post Outage Steam Generator Report Technical Specification 4.4.5.5.c L-2006-152, NRC Order EA-03-009 - Reactor Vessel Head and Vessel Head Penetration Nozzle Inspection Results SL2-162006-08-10010 August 2006 NRC Order EA-03-009 - Reactor Vessel Head and Vessel Head Penetration Nozzle Inspection Results SL2-16 L-2006-180, Sation; St. Lucie, Units 1 and 2 and Turkey Point, Units 3 and 4 - Groundwater Questionnaire2006-07-31031 July 2006 Sation; St. Lucie, Units 1 and 2 and Turkey Point, Units 3 and 4 - Groundwater Questionnaire L-2006-167, Environmental Protection Plan Report Responses to FDEP Comments on FPL Proposal for Information Collection Clean Water Act Section 316(b)2006-07-0606 July 2006 Environmental Protection Plan Report Responses to FDEP Comments on FPL Proposal for Information Collection Clean Water Act Section 316(b) L-2006-139, Report of 10 CFR 50.59 Plant Changes2006-06-16016 June 2006 Report of 10 CFR 50.59 Plant Changes L-2006-063, Technical Specification Special Report, Radwaste Building Exhaust System, Plant Ventilation Stack Particulate Iodine and Noble Gas (Sping) Radiation - Out of Service2006-02-22022 February 2006 Technical Specification Special Report, Radwaste Building Exhaust System, Plant Ventilation Stack Particulate Iodine and Noble Gas (Sping) Radiation - Out of Service L-2006-043, Responses to NRC Requests for Additional Information on WCAP-16208-P, Rev. 0, NDE Inspection Length for CE Steam Generator Tubesheet Region Explosive Expansions.2006-01-23023 January 2006 Responses to NRC Requests for Additional Information on WCAP-16208-P, Rev. 0, NDE Inspection Length for CE Steam Generator Tubesheet Region Explosive Expansions. 2023-09-28
[Table view] |
Text
September 8, 2015 MEMORANDUM TO: Victor G. Cusumano, Chief Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation FROM: Lindsay R. Robinson, Reactor Systems Engineer
/RA by ARussell for/
Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation
SUBJECT:
STAFF OBSERVATIONS OF SAINT LUCIE UNIT 1 SUMP STRAINER HEAD LOSS TESTING AT ALDEN LABORATORY FOR GENERIC SAFETY ISSUE 191 On August 4 and 5, 2015, U.S. Nuclear Regulatory Commission (NRC) staff traveled to the Alden Research Laboratory in Holden, Massachusetts to observe testing associated with the resolution of Generic Safety Issue 191 (GSI-191). The objective of this trip was to observe sump strainer head loss tests being conducted for St. Lucie Unit 1. The participating NRC staff members were Ashley Smith and Lindsay Robinson of the Safety Issues Resolution Branch in the Division of Safety Systems and Marioly Diaz-Colon and Paul Klein of the Steam Generator Tube Integrity and Chemical Engineering Branch from the Division of Engineering. The staff interacted with personnel from ALDEN Research Laboratory, Inc. (Alden), Enercon Services, Inc. (Enercon), Calvert Cliffs Power Station (Calvert Cliffs), and Wolf Creek Generating Station (Wolf Creek).
The enclosure summarizes the staffs visit on August 4-5, 2015.
CONTACT: Lindsay R. Robinson, NRR/DSS/SSIB 301-415-4115
September 8, 2015 MEMORANDUM TO: Victor G. Cusumano, Chief Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation FROM: Lindsay R. Robinson, Reactor Systems Engineer
/RA by ARussell for/
Safety Issues Resolution Branch Division of Safety Systems Office of Nuclear Reactor Regulation
SUBJECT:
STAFF OBSERVATIONS OF SAINT LUCIE UNIT 1 SUMP STRAINER HEAD LOSS TESTING AT ALDEN LABORATORY FOR GENERIC SAFETY ISSUE 191 On August 4 and 5, 2015, U.S. Nuclear Regulatory Commission (NRC) staff traveled to the Alden Research Laboratory in Holden, Massachusetts to observe testing associated with the resolution of Generic Safety Issue 191 (GSI-191). The objective of this trip was to observe sump strainer head loss tests being conducted for St. Lucie Unit 1. The participating NRC staff members were Ashley Smith and Lindsay Robinson of the Safety Issues Resolution Branch in the Division of Safety Systems and Marioly Diaz-Colon and Paul Klein of the Steam Generator Tube Integrity and Chemical Engineering Branch from the Division of Engineering. The staff interacted with personnel from ALDEN Research Laboratory, Inc. (Alden), Enercon Services, Inc. (Enercon), Calvert Cliffs Power Station (Calvert Cliffs), and Wolf Creek Generating Station (Wolf Creek).
The enclosure summarizes the staffs visit on August 4-5, 2015.
Docket No.: 50-335
Enclosure:
Trip Report CONTACT: Lindsay R. Robinson, DSS/SSIB 301-415-4115 DISTRIBUTION:
Public ASmith LRobinson JStang ARussell GKulesa RidsNrrPMStLucie PKlein MDiaz SSmith MYoder VCusumano RidsRgn2MailCenter Accession No.: ML15240A154 NRR-106 OFFICE NRR/DSS/SSIB/RSE NRR/DSS/SSIB/BC NRR/DSS/SSIB/RSE NAME LRobinson/ARussell for VCusumano/JStang for LRobinson/ARussell for DATE 08/31/2015 09/02/2015 09/08/2015 OFFICIAL RECORD COPY
OBSERVATIONS OF TESTING AT ALDEN TEST FACILITY AUGUST 4 AND 5, 2015 DOCKET NO.: 50-335 OBJECTIVE On August 4 and 5, 2015, U.S. Nuclear Regulatory Commission (NRC) staff observed sump strainer head loss tests associated with the resolution of Generic Safety Issue 191 (GSI-191).
The objective of this trip was to observe the experimental testing to better understand the St. Lucie Unit 1 approach to GSI-191 resolution and to inform staff review of similar methods that may be used by other licensees.
This particular test (identified by Alden as 1152PSLTST-455-00) was conducted by Alden to determine, by incremental debris addition representing increasing Loss-Of-Coolant Accident (LOCA) pipe break sizes, the maximum pipe break size that would still maintain acceptable Emergency Core Cooling System (ECCS) performance at St. Lucie Unit 1. The configuration of the test strainer assembly and the flume geometry remained constant. The strainer approach velocity was constant except for flow sweeps performed to characterize the debris bed prior to chemical precipitate addition. The quantities of particulate and fiber, along with the particulate-to-fiber ratio, varied during the test to be representative of each incremental pipe break size.
OVERVIEW OF FACILITY The test tank occupies a 12.5 ft x 5 ft x 5.5 ft area and contains a strainer, simulated containment piping, and the geometry to simulate the strainer keyway configuration inside containment (see Figure 1). The test strainer area is 360.6 ft2 and matches the configuration of one keyway module in the plant. For the head loss tests, the test fluid is borated and pH adjusted with sodium hydroxide to be more representative of the plant compared to using potable water. Total volume of water in the tank is about 165 ft³ or 1,232 gallons. The tank is elevated above the ground to create space for piping, a heat exchanger, sensory equipment, test leads, and a main recirculating pump. There are two debris hoppers located next to the tank to provide for mixing and entry to the test tank for fine debris additions. The fine and small fibrous debris solutions were created in mixing tanks located above and next to the test tank.
TEST SETUP To set up the head loss testing, the fibrous debris is prepared to meet either fiber fines (Class 2) or fiber smalls (sizes varying from multiple attached or interwoven strands, also known as Class 3 fiber fines, up to 6 in length) requirements. The fiber debris solution is prepared by placing a predetermined amount (based on procedure) of 2 inch x 2 inch squares of baked Nukon into a mixing container (see Figure 2). Using high powered water jets on a timed interval, the Nukon is broken down into fines until it reaches the desired fine characteristic as dictated by the procedure. Once the fiber debris solution is prepared as either fines or smalls, additions of particulates, Calcium-Silicate (Cal-Sil), and dirt and dust are added to the mixtures and manually combined with a large stirring rod.
ENCLOSURE
The amount of Nukon, particulate, Cal-Sil, dirt and dust used is determined by the break size being evaluated (see Table 1).
In the test setup (see Figure 3), the fine fiber debris solution, as prepared above, is poured into each debris hopper in equal portions. The debris hopper then further breaks down the fibers before adding the debris solution into each end of the test tank. Once the fiber enters into the test tank, the suction strainer then draws suction on the solution using the main recirculating pump. A small portion of the solution is then heated by the heat exchanger before returning to the debris hopper where it gets returned to the test tank or the mixing flow lines. The small fibrous debris solution has a similar transport flow path in the test setup except that it is added by pouring it through a cross-sectional pipe segment at the front of the test tank only instead of debris hoppers at each end of the test tank. The test loop is held at a constant 120°F by directing a portion of the overall recirculation flow over an in-line heat exchanger. The test temperature helps lower the air content in the test tank fluid. The flow rate is set to match a target approach velocity of 0.0026 ft/sec. The initial debris additions to the test represented break size G (Table 1), which simulated an 8.5-inch break.
Figure 1: Test Tank Design Concept, Isometric View Figure 2: Nukon Fiber Before and After Preparation
Figure 3: Piping and Instrumentation Diagram (P&ID)
Table 1: Debris Content in Breaks of Interest Pipe ID Cal-Sil Particulates Nukon (lbs) Temp-Mat (lbs)
Designation (in) (lbs) (ft3) Fines Smalls Fines Smalls A 42 1170.16 11.71 513.9 570.24 6.08 6.41 B 31 341.34 7.94 351.88 385.1 3.41 1.94 C 31 556.95 9.29 282.21 285 3.78 3.14 D 30 258.69 7.76 332.51 369.16 48.58 68.61 E 30 531.59 8.96 278.67 284.2 4.26 5.06 F 10.126 88.44 7.33 88.7 77.34 0.5 0.22 G 8.5 61.33 7.39 53.09 38.21 1.33 1.24 TEST PERFORMANCE The head loss testing began by adding the fine fiber plus particulate debris solution (see Figure 4). Once all the fine debris solution for a given break size was added, then the small fiber plus particulate debris solution was added. The testing alternated between adding fine debris solution and then adding the small debris solution until all required debris was added to reach a specified break size per Table 1. Each addition took at least 90 minutes before the next fiber debris solution was added to the tank. Over time, the sump strainer became covered with fibrous debris. The small fibers and some fines settled to the bottom of the tank and along the suction screen (see figure 5).
Figure 4: Test Tank 5 Minutes into Designation G and 40 Minutes into Designation G, Respectively Figure 5: Clean Test Tank and Test Tank 20 hours2.314815e-4 days <br />0.00556 hours <br />3.306878e-5 weeks <br />7.61e-6 months <br /> After Initial Fiber Addition, Respectively
While batches of fiber and particulate were being added to the maximum debris head loss test, Alden personnel began preparing chemical precipitates for later additions to the test. Alden had the chemicals and necessary equipment for generating large quantities of both Aluminum Oxyhydroxide and Sodium Aluminum Silicate (SAS) precipitates using the methodology outlined in WCAP-16530-NP-A, Evaluation of Post-Accident Chemical Effects in Containment Sump Fluids to support GSI-191. The NRC staff had the opportunity to observe preparation of a 500 gallon batch of SAS precipitate.
For the preparation of SAS precipitate, potable (tap) water was mixed with aluminum nitrate (Al (NO3)3) and sodium ortho-silicate (Na4SiO4) solution. The ingredients were added slowly and mixing was allowed to continue for 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> to allow the chemical reaction to complete.
Approximately one hour after the precipitates were prepared, the Alden staff began a settlement test in a graduated cylinder. The one-hour precipitate settlement was approximately 9.3 milliliters (mL) out of 10 mL. In other words, the cloudy portion of precipitate covered up to the 9.3 mL mark with 0.7 mL of clear fluid from the 9.3 mL mark to the 10 mL mark. This measurement easily met the one-hour settlement criteria specified in WCAP-16530-NP-A and was acceptable to the NRC staff. Figure 6 shows various points in the preparation of SAS chemical precipitate.
Figure 6: Preparation of SAS chemical precipitate
The lead test engineer for Alden also walked down the piping from the chemical precipitate tanks to the test tank and described how precipitate addition would be performed. Although the NRC staff was not able to observe chemical precipitate addition to the St. Lucie Unit 1 head loss test due to testing delays and schedule constraints, the NRC staff has observed chemical precipitate addition to head loss tests during previous visits to the facility. As an example, see Staff Observations of Testing for Generic Safety Issue 191 during July 12-14, 2010 trip to Alden Test Facility for PCI Strainer Tests, (Agencywide Documents Access and Management System (ADAMS) Accession Number ML102160226).
TEST RESULTS The NRC staff observed multiple additions of debris but was unable to observe the entire test due to the length of the test and schedule constraints. At the time of the staffs departure on August 5, all debris representative of a 30-inch break and approximately one half of the incremental debris to go from the 30-inch break to a 42-inch break had been introduced to the test loop. Head loss at that point was approximately 1 ft H20. The NRC staff and the St. Lucie representatives had a closeout discussion and agreed to have a follow-up phone call after the current test and subsequent thin bed test had been performed.
SUMMARY
The NRC staff became more familiar with the St. Lucie Unit 1 approach to addressing GSI-191 and the Alden Test Procedure, 1152PSLTST-455-00, being used to evaluate its maximum head loss requirements that must be met for ECCS.
Overall, the trip was effective and will assist the review of the licensees submittal to closeout GSI-191.
FOLLOW-UP PHONE CALL The NRC staff, St. Lucie representatives, and Alden representatives participated in a phone call to discuss the results from the St. Lucie Unit 1 maximum load and thin bed strainer tests and the plans for the third confirmatory strainer head loss test. The licensee representatives indicated that the chemical precipitate addition to the initial head loss test (representing a maximum calcium silicate, near maximum fiber load) resulted in approximately a 4 times increase in head loss from the conventional fiber and particulate debris head loss. The total head loss was still well within the acceptance value.
The total head loss from the thin bed test was approximately 25 percent of the first maximum load test demonstrating that the thin bed condition is not more challenging with respect to strainer head loss for St. Lucie Unit 1. The licensee indicated that the plans for the confirmatory test are to add approximately 10 percent more fiber and 30 percent less calcium silicate relative to the first test. After some discussion on debris sequencing, the licensee indicated that they will be adding all fine fibrous debris first followed by all small fibrous debris. The NRC staff requested and the licensee agreed to have an additional phone call after the confirmatory test results are available.